UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

 

FORM 6-K

 

 

REPORT OF FOREIGN PRIVATE ISSUER

PURSUANT TO RULE 13a-16 OR 15d-16

UNDER THE SECURITIES EXCHANGE ACT OF 1934

For the month of April, 2023

Commission File Number: 000-54516

 

 

Emera Incorporated

(Exact name of registrant as specified in its charter)

 

 

5151 Terminal Road

Halifax NS B3J 1A1

Canada

(Address of principal executive offices)

 

 

Indicate by check mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40-F.

Form 20-F  ☐            Form 40-F  ☒

Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(1):  ☐

Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(7):  ☐

 

 

 


SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

 

    EMERA INCORPORATED
Date: April 12, 2023     By:  

/s/ Stephen D. Aftanas

      Name: Stephen D. Aftanas
      Title: Corporate Secretary


EXHIBIT INDEX

 

Exhibit No.   

Description

99.1    Emera Incorporated - Notice of Annual Meeting of Common Shareholders on Wednesday, May 24,2023 and 2023 Management Information Circular
99.2    Emera Incorporated 2022 Annual Report
99.3    Emera Incorporated - Form of Proxy relating to the May 24, 2023 Annual meeting
99.4    Emera Incorporated - Voting Instruction Form (VIF) relating to the May 24, 2023 Annual meeting
99.5    Emera Incorporated - Notice and Access Notification to Registered Shareholders
99.6    Emera Incorporated - Notice and Access Notification to Non-Registered Shareholders

Exhibit 99.1

 

LOGO


About Emera

We’re a team of experts focused on building a cleaner energy future. Our Environmental, Social and Governance (“ESG”) commitments are core to our strategy and we’re leading the way to a cleaner energy future with clear climate goals and a vision to achieve net-zero carbon emissions by 2050. We primarily invest in regulated electric and gas utilities, driving predictable returns and steady growth for our investors, enabling us to reinvest in our teams, our companies and our communities.

Table of Contents

 

Notice of the Annual Meeting

     8  

Management Information Circular

     9  

Annual Meeting of Shareholders

     10  

Meeting Details

     11  

Voting Instructions

     11  

Items to Be Discussed

     14  

Director Nominees Information

     16  

Skills and Experience Matrix

     28  

Governance

     33  

Statement of Corporate Governance Practices

     34  

Executive Compensation

     63  

Message from the Management Resources and

  

Compensation Committee to Our Shareholders

     64  

Statement of Executive Compensation

     66  

Compensation Discussion and Analysis

     73  

Performance Graph

     88  

NEO Summary Compensation Table

     90  

Appendix “A” – Board of Directors Charter

     103  

Appendix “B” – Resolution Amending the

  

Senior Management Stock Option Plan

     105  
 

 

FORWARD-LOOKING INFORMATION

This Circular contains forward-looking information and forward-looking statements within the meaning of applicable securities laws (collectively, “forward-looking information”). Words such as anticipates, believes, budget, could, estimates, expects, forecast, intends, may, might, plans, projects, schedule, should, targets, will, would and similar expressions are often intended to identify forward-looking information, although not all forward- looking information contains these identifying words. References to “Emera” in this section include references to the subsidiaries of Emera.

The forward-looking information includes, without limitation, statements which reflect the current view of Emera’s management with respect to Emera’s objectives, plans, financial and operating performance, carbon dioxide emissions reduction goals, business prospects and opportunities. All such forward-looking information is provided pursuant to safe harbour provisions contained in applicable securities laws.

The forecasts and projections that make up the forward-looking information are based on reasonable assumptions which include, but are not limited to: the receipt of applicable regulatory approvals and requested rate decisions; expectations regarding the nature, timing and costs of capital investments of Emera and its subsidiaries; continued investment in solar, wind and hydro generation; sufficient liquidity and capital resources; the absence of significant changes in government energy plans and environmental laws and regulations that may materially affect Emera’s operations and cash flows; and sufficient human resources to deliver service and execute Emera’s capital investment plan.

The forward-looking information is subject to risks, uncertainties and other factors that could cause actual results to differ materially from historical results or results anticipated by the forward-looking information. Factors that could cause results or events to differ from current expectations include, but are not limited to: regulatory and political risk; changes in economic conditions; liquidity and capital market risk; future dividend growth; timing and costs associated with certain capital investments; global climate change; regulatory and government decisions, including changes to environmental legislation; uncertainties associated with infectious diseases, pandemics and similar public health threats, such as the COVID-19 novel coronavirus (“COVID-19”) pandemic; labour relations; and availability of labour and management resources.

Readers are cautioned not to place undue reliance on forward-looking information as actual results could differ materially from the plans, expectations, estimates or intentions and statements expressed in the forward-looking information. For additional information with respect to certain of these risks or factors, refer to the continuous disclosure materials filed from time to time by Emera with Canadian securities regulatory authorities and the United States Securities and Exchange Commission. All such forward-looking information is qualified in its entirety by the above cautionary statements and, except as required by law, Emera undertakes no obligation to revise or update any forward-looking information as a result of new information, future events or otherwise.


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Emera at a Glance

Data is as of December 31, 2022, unless otherwise indicated.

From our origins as a single electric utility in Nova Scotia, Emera has grown into an energy leader with $40 billion in total assets, serving 2.5 million customers in Canada, the US and the Caribbean. Our companies include electric and natural gas utilities, gas pipelines, and energy marketing and trading operations.

 

LOGO

 

1

Based on 2022 adjusted net income, excluding Corporate costs of $267 million. Adjusted net income is a non-GAAP measure which does not have standardized meaning under USGAAP. For more information and a reconciliation to the nearest GAAP measure, refer to “Non-GAAP Financial Measures and Ratios” in Emera’s Q4 2022 MD&A.

 

  EMERA INCORPORATED   1


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Our Strategy

For nearly two decades, we’ve been focused on safely delivering cleaner, reliable energy at a pace that’s balanced with the cost impacts for our customers.

 

LOGO    LOGO    LOGO

EXPERT

TEAMS

  

DELIVERING FOR

OUR CUSTOMERS

  

DRIVING GROWTH

AND REINVESTMENT

We’re a team of experts leading the way to a cleaner energy future as we work toward our 2050 net-zero vision.    Every day, we’re safely and cost- effectively delivering cleaner, more reliable energy for our customers.    Delivering for our customers drives predictable returns and steady growth for our investors, enabling us to reinvest in our teams, companies and communities.

LOGO

 

2   EMERA INCORPORATED  


LOGO

 

  EMERA INCORPORATED   3


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Why Invest in Emera

Through our proven strategy and our portfolio of high-quality, regulated utilities, our expert teams across Emera continue to drive long-term value for shareholders.

 

Visible Growth Plan

$8B to $9B capital investment

plan1 through 2025

  

7% to 8% forecasted rate

base growth through 2025

      

65% of adjusted net income2, excluding

Corporate costs, came from Florida in 2022

  

75% of CapEx plan from 2023–2025 is focused in

Florida — the fastest growing US state in 2022

 

Strong,

ESG-Driven

Strategy

  

Sustainable

Dividend

Growth

  

Constructive

Regulatory

Environments

 

63% of capital plan to 2025

committed to decarbonization

and reliability

  

4% to 5% dividend growth target

through 2025

  

Highly rated

regulatory environments

 

$18M invested in our

communities in 20223

  

5.3%

dividend yield4

  

89% of adjusted net

income2, excluding Corporate

costs, derived from our four core

regulated utilities

 

1

Emera’s capital investment plan includes a $240 million equity investment in 2023.

2

Based on 2022 adjusted net income, excluding Corporate costs of $267 million. Adjusted net income is a non-GAAP measure which does not have standardized meaning under USGAAP. For more information and a reconciliation to the nearest GAAP measure, refer to “Non-GAAP Financial Measures and Ratios” in Emera’s Q4 2022 MD&A.

3

Includes a one-time, $5 million contribution to the University of South Florida to establish the TECO Clean Energy Research Center.

4

As of December 31, 2022. Our share price on this date was $51.75.

 

4   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Fellow Shareholders,

On behalf of Emera’s Board of Directors and management team, we’re pleased to invite you to our Annual Meeting of Shareholders on May 24, 2023. Details about the meeting and how to participate are available on page 11 of this Circular.

2022 was challenging on a number of fronts, with rising inflation rates, supply chain issues and two historic hurricanes. We were also challenged by the introduction and passage of Bill 212 in Nova Scotia, which directly and negatively impacted Nova Scotia Power, and in turn Emera’s total shareholder return (“TSR”) for the year. Despite these challenges, a lot was accomplished in the year as our team continued to advance our strategy of safely delivering cleaner, more reliable energy to our customers with a focus on delivering growth and long-term value for our shareholders.

OUR PROVEN STRATEGY AND ESG FOCUS

Our Environmental, Social and Governance (ESG) focus is driving our growth and shaping our commitments to our customers, communities, shareholders and team.

Environmental

We’re leading a balanced energy transition that’s driving growth through strategic investments that reduce the carbon intensity of the energy we deliver to our customers. Our focus and responsibility remains on doing this in a manner and at a pace that is cost-effective for our customers and does not sacrifice system reliability.

Our Climate Commitment articulates our goals and vision to achieve net-zero CO2 emissions by 2050 with a focus on reducing the use of coal in our generation mix. The team is making progress and, in 2022, less than 20 per cent of our energy generation came from coal, compared to almost 60 per cent in 2005 – a 68 per cent reduction. We also achieved a 41 per cent overall reduction in CO2 emissions compared to 2005 levels.

The execution of our strategy in 2022 was evidenced by our $2.6 billion of capital investment, largely focused on cleaner energy and reliability investments. This included the final investment in and completion of the Big Bend Modernization project at Tampa Electric. This ambitious project was delivered safely, on time and under budget. Big Bend is now one of the most efficient natural gas plants in North America and is estimated to produce enough energy to power more than 250,000 homes and save customers more than $700 million USD over its 30-year life span – all while reducing carbon emissions.

We also continued to invest in solar generation in Florida. At the end of 2022, Tampa Electric had more than 1,000 MW of solar generation in its fleet, and it continues to have the highest proportion of solar generation per customer of any utility in Florida. These investments are not only helping us deliver on our Climate Commitment, but they also saved customers over $80 million USD in avoided fuel costs last year.

Our investment in the transformative $1.8 billion Maritime Link project saved Nova Scotia customers almost $100 million in 2022 by replacing expensive high-carbon generation with clean hydro energy from Newfoundland and Labrador. These savings to customers represent over $250 million in avoided fuel costs netted against the costs of the Link included in customer rates in 2022. The clean hydro electricity we are receiving through the Nova Scotia block of energy over the Maritime Link will continue to deliver value to customers for decades to come.

Innovation and new technologies play an important role in our ability to achieve carbon reduction goals. We continue to advance our work on microgrids, battery storage and electric vehicle smart chargers. Through Emera Technologies, our BlockEnergy microgrid solution continues to be tested and enhanced as part of two successful residential pilot projects, with a third expected to be completed later this year.

To keep building on our progress, more than 60 per cent of Emera’s $8.4 billion capital plan through 2025 will be directed to clean energy and reliability initiatives.

Social

We understand that the success of our business is dependent on the support of our customers and the communities where we operate, and it is driven by the strength and commitment of our team. Our social commitments continue to shape our culture and drive our performance.

 

  EMERA INCORPORATED   5


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Diversity, Equity and Inclusion (“DEI”)

We know a strong, diverse and inclusive workforce is critical to building and maintaining the right team to guide the complex transition to a clean energy future. We continue to advance initiatives to foster DEI across Emera and to create safe, diverse workplaces where everyone feels included and supported.

Based on self-identification surveys and feedback from our teams, we’ve continued to identify areas for improvement that will drive further diversity across Emera. To support DEI-focused education and awareness, we launched an Emera-wide DEI learning program in 2022. Through this platform, we’re sharing consistent information to support meaningful discussion, increase diversity, equity and inclusion, and cultivate positive change across our companies. While there’s still a lot of work ahead, we are proud of the progress we are making.

DEI continues to be an area of considerable focus for our Board of Directors as well. We believe diversity on our Board broadens discussion, fosters more effective decision-making and ultimately strengthens corporate governance. Emera’s Board of Directors adopted a Board Diversity Policy that adds additional rigour and transparency to our renewal, recruitment and board succession strategies. In 2023, the minimum requirement for women on the Board was updated from 30 per cent to 40 per cent. For the upcoming Annual Meeting of Shareholders, 45 per cent of our Director nominees are women, including our Chair. Of the 21 external directors that serve on the Boards of our four largest operating companies, 47 per cent are female and 33 per cent are Black, Hispanic or Indigenous.

Focus on Safety

The safety of our teams, customers and communities is our number one priority. Sadly, early in 2022 we had an employee fatality in Nova Scotia. This tragic loss of our colleague was felt right across our organization. Every member of our team is committed to learning from this tragedy as we work toward an Emera where no one gets hurt. In 2022, we made meaningful progress on our critical safety programs, achieving reductions in our lost-time incident rates in the majority of our operating companies. Overall, we reduced our frequency of lost-time safety incidents by 17 per cent across Emera.

Governance

Strong corporate governance is another essential pillar of our performance culture. We continue to develop and embed policies and practices representing high standards of governance across all of our businesses and activities.

In 2022, led by the Risk and Sustainability Committee (“RSC”), the Board oversaw the ongoing integration of our core ESG priorities across our business. The RSC regularly reviews our ESG disclosures and identifies opportunities for additional transparency. Throughout the year, the RSC, along with the entire Board, has been supporting the team as we prepare for mandatory climate-related disclosures that are being contemplated by North American securities regulators.

At our Annual Meeting, 11 Directors are standing for re-election. We would like to acknowledge long-time Director Rick Sergel, who is retiring from the Emera Board this year. Since joining the Board in 2010, Rick has provided invaluable guidance and expertise. His deep experience in the US electricity sector, along with his extensive regulatory background, has been of great benefit to Emera. Rick will be missed and we wish him all the best.

FINANCIAL RESULTS AND SHAREHOLDER VALUE

Despite the challenges facing the energy industry in 2022, we continued to deliver earnings and dividend growth to our shareholders. This is a testament to the strength of our portfolio of assets, the durability of our strategy and the resiliency of our teams.

In 2022, we delivered an eight per cent ( 1) increase in our adjusted earnings per share (“EPS”) compared to the previous year. This growth was driven primarily by the strength of our regulated utilities, particularly in Florida, as well as a strong year in our natural gas marketing and trading business.

 

( 1 )

Excluding the $0.17 after-tax impact of a litigation award recognized in the fourth quarter.

 

6   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Our Florida assets continue to perform extremely well. Florida was the fastest growing state in the US last year and is one of the 20 largest economies in the world. This is resulting in strong customer growth for both Tampa Electric and Peoples Gas and supporting significant customer-focused capital investment and overall growth for Emera. Looking forward, over 75 per cent of our three-year capital program will be invested in our Florida operations.

We raised our dividend by four per cent in 2022 and we are committed to delivering on our four to five per cent dividend growth target through 2025. This is a continuation of the solid dividend growth we’ve provided over the long term – 5.4 per cent growth on an annualized basis since 2000.

While our TSR has historically been strong relative to our energy industry peers, our performance fell short of our expectations in 2022, largely due to the direct and indirect impacts of the introduction of Bill 212 in Nova Scotia. Our team is focused on and committed to addressing this recent underperformance and returning to delivering superior value for shareholders. We believe that we are well positioned, and we remain confident in our ability to do so. For additional information about Emera’s long-term shareholder returns, see Message from the Management Resources and Compensation Committee to Our Shareholders on page 64 of this Circular.

2023 ANNUAL MEETING

We value your input. Our annual general meeting (AGM) is an important way for us to engage with shareholders. Details on how to participate in the virtual meeting are described in this Circular and will be available on our website at http://www.emera.com/investors. You will have the opportunity to ask questions at the AGM in several ways: questions can be submitted during the virtual meeting or submitted in advance to AGM@emera.com or the mailing address provided below. We strongly encourage shareholders to take advantage of the option to vote in advance by proxy.

If you have any questions regarding our Annual Meeting of Shareholders, please contact Emera’s Corporate Secretary, Stephen Aftanas:

Mail        P.O. Box 910, Halifax, Nova Scotia B3J 2W5

Phone      1-800-358-1995 from anywhere in North America

Email      AGM@emera.com

THANK YOU

We encourage you to review this information and exercise your right to vote at our Annual Meeting of Shareholders. It’s important to us that your views be expressed and that your shares be counted.

On behalf of the Board and management team, thank you for your ongoing confidence in Emera.

 

LOGO

 

   

LOGO

 

Jackie Sheppard     Scott Balfour
Chair, Emera Inc. Board of Directors     President and Chief Executive Officer, Emera Inc.

 

  EMERA INCORPORATED   7


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Notice of the Annual Meeting

 

   Items of Business
LOGO   

1.  Electing Directors to serve until the next Annual Meeting of Shareholders

Annual Meeting

Wednesday, May 24, 2023

5:00 p.m. Atlantic time

  

 

2.  Appointing Auditors

  

 

3.  Authorizing the Directors to establish the Auditors’ fee

  

 

4.  Considering an advisory resolution on the Company’s approach to executive compensation

  

 

5.  Approving an amendment to the Company’s Senior Management Stock Option Plan

LOGO   
Participation    How to Vote

Emera’s 2023 Annual Meeting of

Shareholders will be held virtually

via live webcast online at

https://web.lumiagm.com/458327786

Password: emera2023

(case sensitive)

  

 

As a shareholder, there are several ways that you can vote.

  

 

•   To participate virtually in the meeting, visit https://web.lumiagm.com/458327786 and use password: emera2023 (case sensitive). Please note, beneficial owners will only be able to vote virtually or ask questions through the live webcast if they are duly appointed and registered as proxyholders.

 

•   If you do not plan to participate in the meeting:

 

•   You can return your proxy or voting instruction form using the postage-paid, pre-addressed envelope provided.

LOGO

 

Record Date

Close of business

  

 

•   You can vote by telephone or via internet (see the proxy or voting instruction form). Proxies must be received prior to 12:00 noon Atlantic time on Tuesday, May 23, 2023, or if the meeting is adjourned, or postponed, 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date.

March27, 2023   

 

This is the date we used to determine who is an eligible Emera shareholder to participate in the 2023 Annual Meeting of Shareholders.

   If you have questions, please contact us by writing to the Corporate Secretary, Emera Incorporated, P.O. Box 910, Halifax, Nova Scotia B3J 2W5 or by calling 1-800-358-1995 from anywhere in North America.

LOGO

 

  

LOGO

 

Stephen D. Aftanas

1-800-358-1995 North America    Corporate Secretary

 

8   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Management Information Circular

All information is as of March 20, 2023

(unless otherwise noted)

 

You are receiving Emera’s Management Information Circular (the “Circular”) because you held common shares of Emera Inc.      

 

In this document:

 

•   we, us, our and Emera mean Emera Inc.

 

•   you, your and shareholder refer to holders of Emera common shares

 

•   shares and Emera shares mean common shares of Emera, unless otherwise indicated

 

•   all dollar amounts are in Canadian dollars, unless indicated otherwise

 

•   all information is as of March 20, 2023, unless otherwise noted

 

(TSE: EMA) as of the Record Date – March 27, 2023. You are entitled to receive notice of and vote at our Annual Meeting of Shareholders on Wednesday, May 24, 2023 at 5:00 p.m. (Atlantic time) (the “Meeting”). Only shareholders of record at the close of business on the Record Date will be entitled to vote. Each common share owned as of the Record Date entitles the holder to one vote.

 

To the knowledge of the Directors and Officers, as of the date of this Circular, no person owned or exercised control over more than 10 per cent of the outstanding common shares of the Company and the only outstanding voting shares were 271,386,740 common shares. Each common share entitles the holder of record thereof to one vote at the Meeting.

Meeting Materials and Notice and Access

Emera follows Canadian securities rules called “Notice and Access” that permit us to provide electronic access to this Circular and the 2022 Annual Report (the “Meeting Materials”) instead of sending you paper copies. We are sending Meeting Materials to registered holders and beneficial owners using Notice and Access. The notice also provides instructions on voting by proxy at the meeting and how to request a paper copy of the Meeting Materials.

Shareholders who have previously provided instructions to receive paper copies of Meeting Materials have been sent a paper copy in addition to the notice regarding their electronic availability.

Solicitation of Proxies

This Circular is furnished in connection with the solicitation of proxies by the Board of Directors of Emera (the “Board of Directors” or “Emera’s Board” or the “Board”) and management of Emera for use at the Meeting as set forth in the Notice of Annual Meeting. All shareholders have received a proxy or voting instruction form. The solicitation of proxies will be primarily by mail although proxies may also be solicited by telephone, facsimile or email, in writing, or in person, by directors of the Company (“Directors”), Officers, or other employees or agents of the Company.

We have retained TMX Investor Solutions Inc. as the proxy solicitation agent to assist with the solicitation of votes from shareholders. The proxy solicitation agent will monitor the number of shareholders voting and will contact shareholders in order to increase participation in voting. The cost of this solicitation is covered by Emera and is not expected to exceed $50,000.

We encourage all shareholders to review this Circular and exercise your vote. Full details on voting options are included on page 11.

 

  EMERA INCORPORATED   9


LOGO

IN THIS SECTION:

11     MEETING DETAILS

11     VOTING INSTRUCTIONS

14     ITEMS TO BE DISCUSSED

16     DIRECTOR NOMINEES INFORMATION

 

 

10   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Annual Meeting Details

Emera is holding its 2023 Annual Meeting as a virtual-only meeting. Participation in the meeting through the virtual meeting technology is enabled online at https://web.lumiagm.com/458327786, using password: emera2023 (case sensitive).

Voting Details and Instructions

VOTING INSTRUCTIONS

You are eligible to receive notice and vote at the meeting if you are a shareholder as of March 27, 2023 (the “Record Date”). You can vote in advance or during the meeting.

The voting process is different depending on whether you are a registered shareholder, Non-Objecting Beneficial Owner or Objecting Beneficial Owner. If you have shares registered in your own name, then you are a registered shareholder. If your shares are listed in the name of a nominee, then you are a beneficial or non-registered shareholder. For example, if an account statement is provided to you by a broker, then it is likely that those shares will not be registered in your name and are likely registered under the broker’s name or under the name of an agent of the broker such as CDS Clearing and Depository Services Inc., the nominee for many Canadian brokerage firms, or its nominee.

Registered shareholders and duly appointed proxyholders (including non-registered shareholders who have duly appointed themselves as proxyholder) will be entitled to participate in and vote at the Meeting. Non-registered shareholders who do not duly appoint themselves as proxyholder may still attend the Meeting as guests, meaning they will be able to listen to the Meeting but will not be able to vote at the Meeting or ask questions.

It is important to note that you will not be able to attend this year’s Meeting in person. We recommend logging in at least 15 minutes prior to the start of the Meeting. To ensure that your vote is recorded, make sure that you are connected to the internet at all times. It is your responsibility to ensure internet connectivity for the duration of the Meeting. For the best experience, virtual participants will need the latest versions of Chrome, Safari, Edge or Firefox (please do not use Internet Explorer). Please note that internal network security protocols including firewalls and VPN connections may block access to the virtual meeting technology. If, during the meeting, participants experience any difficulty connecting, they should ensure their VPN setting is disabled or use their computer on a network that is not restricted to security settings of a participant’s organization.

Shareholders are encouraged to vote in advance of the Meeting as described below under the heading How to Vote in Advance, particularly if they are worried about their ability to remain connected to the internet for the duration of the Meeting.

HOW TO VOTE DURING THE MEETING

Registered Shareholders and Proxyholders

Registered shareholders can participate in the Meeting by logging in to https://web.lumiagm.com/458327786 and entering their 13-digit Control Number as their username, using the password: emera2023 (case sensitive). If you are a registered shareholder and have appointed a proxyholder to act on your behalf at the Meeting, you must register your proxyholder prior to the proxy deadline. Once your proxyholder has been registered, they will receive a Control Number from TSX Trust Company (“TSX Trust”) to access the virtual meeting. If you do not register your proxyholder, your proxyholder will not receive a Control Number to log in to the Meeting. For additional information on appointing a proxyholder, please see How to Vote in Advance – Registering Your Proxyholder below.

Proxyholders for all shareholders can participate in the Meeting by logging in in the same manner as for registered shareholders (as described above) and entering the Control Number provided to the proxyholder by TSX Trust.

 

  EMERA INCORPORATED   11


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Beneficial (or Non-Registered) Owners

Non-registered shareholders wishing to participate virtually in the Meeting must:

 

1.

Appoint themselves as proxyholder;

 

2.

Register themselves as proxyholder; and

 

3.

Access the meeting as a proxyholder using the Control Number received after registering as a proxyholder.

If you do not register yourself as proxyholder, you will not receive a Control Number in order to log in to the Meeting. The Control Number included in any voting instruction form sent to you will not enable you to log in to the Meeting. A new Control Number will be needed to log in, and one will be issued to you upon registering yourself as a proxyholder.

In order to appoint yourself as a proxyholder, follow the instructions in the form of proxy or voting instruction form sent to you by your intermediary. In most cases, you can simply insert your own name in the form of proxy or voting instruction form, sign it and return it in the envelope provided or you can make the appointment online. Do not complete the voting instructions, as you will be voting at the Meeting. However, many Objecting Beneficial Owners located in the United States instead will need to (i) send a request to their intermediary or its agent to send them a legal proxy appointing them as proxyholder and (ii) promptly following receipt of the legal proxy, submit the legal proxy to TSX Trust, Proxy Department, P.O. Box 721, Agincourt, ON, M1S 0A1 prior to 12:00 noon Atlantic time on Tuesday, May 23, 2023.

Once a beneficial or non-registered owner has been appointed a proxyholder and has registered as proxyholder, they will receive a Control Number from TSX Trust to access the virtual meeting. The beneficial owner should follow the instructions under Registered Shareholders and Proxyholders above to log in to the virtual meeting as a proxyholder.

There are two kinds of beneficial owners: (i) Objecting Beneficial Owners – those who object to their name being made known to the issuers of shares that they own and (ii) Non-Objecting Beneficial Owners – those who do not object to their name being made known to the issuers of the shares that they own. Non-Objecting Beneficial Owners will receive a voting instruction form from Emera’s registrar and transfer agent, TSX Trust. This is to be completed and returned to TSX Trust in the envelope provided. In addition, TSX Trust provides both telephone voting and internet voting as described on the voting instruction form.

Securities regulation requires brokers or agents to seek voting instructions from Objecting Beneficial Owners in advance of the Meeting. Objecting Beneficial Owners should be aware that brokers or agents can only vote shares if instructed to do so by the Objecting Beneficial Owner. Your broker or agent (or their agent, Broadridge) will have provided you with a voting instruction form or form of proxy for the purpose of obtaining your voting instructions. Every broker has its own mailing procedures and provides instructions for voting. You must follow those instructions carefully to ensure your shares are voted at the Meeting.

If you are an Objecting Beneficial Owner receiving a voting instruction form or proxy from a broker or agent, you cannot use that proxy to vote at the Meeting. To vote your shares at the Meeting, the voting instruction form or proxy must be returned as instructed by the broker well in advance of the Meeting. If you wish to attend and vote your shares at the Meeting, follow the instructions for doing so provided by your broker or agent.

How Can I Ask Questions at the Meeting?

Emera believes that the ability to participate in the Meeting in a meaningful way, including asking questions, is an important responsibility for shareholders. It is anticipated that registered shareholders and proxyholders (including non-registered shareholders who have validly appointed themselves as proxyholder) will have substantially the same opportunity to ask questions on matters of business before the Meeting as they would if the Meeting were being held in person.

Upon logging in to the Meeting, shareholders will have an opportunity to ask questions at the Meeting through a chat box in the online Meeting platform. Questions received from shareholders will be read by the chair of the Meeting or a designee of the chair and responded to by a representative of Emera at the applicable point in the Meeting or in the question and answer session that is expected to follow the Meeting.

The chair of the Meeting will decide on the amount of time allocated to each question and will have the right to limit or consolidate questions from shareholders in order to ensure as many shareholders as possible will have the opportunity to ask questions, and to reject questions that do not relate to the business of the Meeting or which are determined to be inappropriate or otherwise out of order.

 

12   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Who Do I Contact If I Cannot Log In to the Meeting?

If you have any difficulties logging in to the Meeting online, please contact LUMI’s online shareholder meeting email support via the address: support-ca@lumiglobal.com.

If you are participating in the Meeting online, you must remain connected to the internet at all times during the Meeting in order to vote when balloting commences. It is your responsibility to ensure internet connectivity for the duration of the Meeting. Note that if you lose connectivity once the Meeting has commenced, there may be insufficient time to resolve your issue before ballot voting is completed.

Even if you currently plan to participate in the Meeting, you should consider voting your shares in advance so that your vote will be counted in the event you experience any difficulties.

HOW TO VOTE IN ADVANCE

You can appoint a proxyholder to attend the meeting and vote your shares for you.

Registering Your Proxyholder

Registered shareholders and beneficial or non-registered owners wishing to appoint a proxyholder to participate virtually in the Meeting (including beneficial or non-registered owners wishing to appoint themselves as proxyholder to participate in the Meeting) must contact TSX Trust, Emera’s registrar and transfer agent, before 12:00 noon (Atlantic time) on Tuesday, May 23, 2023 to obtain a new Control Number to use to access the virtual meeting by:

 

(i)

calling:

1-866-751-6315 (within North America); or

1-647-252-9650 (outside of North America); or

 

(ii)

going to TSX Trust’s website at https://www.tsxtrust.com/control-number-request to request the Control Number by completing an electronic form. This form, once completed and submitted online, will generate a message to TSX Trust to send the Control Number to the designated proxyholder.

Shareholder Proxy Materials

These security holder materials are being sent to both registered and non-registered owners of the securities. If you are a non-registered owner, and the issuer or its agent has sent these materials directly to you, your name, address and information about your holdings of securities have been obtained in accordance with applicable securities regulatory requirements from the intermediary holding on your behalf. Emera has arranged for its registrar and transfer agent, TSX Trust, to send materials directly to Non-Objecting Beneficial Owners in accordance with National Instrument 54-101 – Communication with Beneficial Owners of Securities of a Reporting Issuer.

By choosing to send these materials to you directly, Emera (and not the intermediary holding on your behalf) has assumed responsibility for (i) delivering these materials to you as a Non-Objecting Beneficial Owner, and (ii) executing your proper voting instructions. Please return voting instructions as specified in the request for voting instructions.

Emera will bear costs of delivering shareholder proxy materials and the request for voting instructions, as applicable, to registered shareholders, Non-Objecting Beneficial Owners and Objecting Beneficial Owners.

Appointment and Revocation of Proxies

The persons named as proxyholders in the enclosed proxy are Jackie Sheppard, Chair of the Board, Scott Balfour, President and Chief Executive Officer, and Stephen Aftanas, Corporate Secretary of the Company.

For a vote by proxy or voting instruction form to be counted, it must be received prior to 12:00 noon (Atlantic time) on Tuesday, May 23, 2023, or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date. The Company reserves the right to accept late proxies and to waive the proxy cut-off with or without notice, but is under no obligation to accept or reject a late proxy. For Canadian residents, a postage-paid, pre-addressed envelope is provided for this purpose.

You may vote by proxy or voting instruction form via mail, the internet or telephone.

 

  EMERA INCORPORATED   13


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Completion of a proxy gives discretionary authority to the proxyholder to vote as he, she or they see fit in respect of amendments to matters identified in the Notice, and other matters that may properly come before the Meeting or any adjournment or postponement thereof, whether or not the amendment or other matter that comes before the Meeting is, or is not, routine and whether or not the amendment or other matter that comes before the Meeting is contested. Management of the Company is not aware of any amendments or other matters to be presented for action at the Meeting.

If you appoint Ms. Sheppard, Mr. Balfour or Mr. Aftanas as your proxyholder, they will vote, or withhold from voting, in accordance with your directions. If you do not specify how you want your shares voted, they will vote “For” the:

 

  •  

Election of each of the Directors named in this Circular;

 

  •  

Appointment of Ernst & Young LLP as Auditors;

 

  •  

Authorization of the Directors to establish the Auditors’ fee;

 

  •  

Advisory resolution on the Company’s approach to executive compensation; and

 

  •  

Approval to amend the Company’s Senior Management Stock Option Plan.

They will vote in accordance with their best judgment if any other matters are properly brought before the Meeting.

You may appoint any other person (who need not be a shareholder) to represent you at the Meeting by inserting that person’s name in the space provided on the proxy or voting instruction form. That person is your proxyholder and must participate and vote at the Meeting for your vote to count.

You may revoke your proxy by providing new voting instructions in a new proxy or voting instruction form with a later date, or at a later time if you are voting on the internet or by telephone. Any new voting instructions, however, will only take effect if received prior to 12:00 noon (Atlantic time) on Tuesday, May 23, 2023, or if the meeting is adjourned or postponed, 5:00 p.m. (Atlantic time) two business days prior to the reconvened meeting date. You may also revoke your proxy without providing new voting instructions by giving written notification addressed to Mr. Stephen Aftanas, Corporate Secretary, P.O. Box 910, Halifax, Nova Scotia B3J 2W5, no later than the last business day preceding the day of the Meeting or preceding the day of any postponement or adjournment thereof or with the Chair of the Meeting on the day of the Meeting or the day of any postponement or adjournment thereof or in any other manner permitted by law. If your new voting instructions (including the appointment of a new proxyholder) are received after the proxy cut-off described above, they may only be effective to revoke your previously provided instructions. Similarly, registered shareholders may participate in the Meeting and vote their shares and, if they do so, any voting instructions previously given by such persons for such shares will be revoked.

Restriction on Share Ownership and Voting

Under Nova Scotia legislation, no Emera shareholder may own or control, directly or indirectly, more than 15 per cent of the outstanding voting shares. This restriction may be enforced by limiting non-complying shareholders’ voting rights (including by disqualifying or deeming votes to have not been cast by such non-complying shareholders), dividend rights and transfer rights. Shareholders may be required, at any time, to furnish a statutory declaration to verify the number of shares held to ensure compliance with this restriction.

If you have any questions about the share ownership and voting restriction, please contact the Corporate Secretary.

Items to Be Discussed at the Meeting

During the Meeting, the Emera team will provide an overview of the Company performance in 2022 and you will have the opportunity to vote on the following items:

 

1.

Election of the Board of Directors: The 11 nominees proposed for election as Directors at the 2023 Meeting are identified under Director Nominees Information in this Circular. For more information about the process for nominating Directors, see Nomination of Directors and Director Recruitment Process in the Statement of Corporate Governance Practices.

All nominees are currently Directors of the Company. Each nominee has indicated their willingness to serve as a Director. Each Director elected at the Meeting will hold office until the next Annual Meeting of Shareholders.

Ms. Sheppard, Mr. Balfour and Mr. Aftanas intend to vote proxies received “For” the 11 nominees unless instructed otherwise by shareholders in their proxy.

 

14   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

2.

Appointment of Auditors: Ernst & Young LLP (“EY”) have been the Auditors of the Company since 1998. However, prior to 2018, PricewaterhouseCoopers were auditors of Tampa Electric Company, Peoples Gas System, and New Mexico Gas Company (representing 67% of the Company’s total assets at the end of 2022). In 2017, the Company initiated a competitive process and selected EY as Auditors for its full business beginning in 2018.

The independence of the Auditors is of utmost importance to the Audit Committee. Consistent with best practices, the Audit Committee reviews the performance of the Auditors annually and conducts a comprehensive review every five years. It also reviews and pre-approves any non-audit services to be provided by EY.

The lead audit partner and other partners with EY are rotated at least every five years, consistent with independence rules. The current lead audit partner commenced her rotation in 2021.

In 2022, the Audit Committee conducted a comprehensive review of EY’s performance and independence, consistent with recommendations of the Chartered Professional Accountants of Canada, the Canadian Public Accountancy Board, and the Institute of Corporate Directors. Based on the results of this review, the Audit Committee recommends the reappointment of EY as Auditors for 2023.

Ms. Sheppard, Mr. Balfour and Mr. Aftanas intend to vote proxies received “For” the reappointment of EY as Auditors of the Company, to hold office until the close of the next Annual Meeting of Shareholders, unless a shareholder specifies their shares be withheld from voting.

 

3.

Auditors’ Fee: The Company is incorporated under the Nova Scotia Companies Act. Shareholder approval of the authorization of Directors to establish the Auditors’ fee is required pursuant to the Companies Act. The aggregate fees billed by EY, during the last two fiscal years ended December 31, 2021 and December 31, 2022, were as follows:

 

Service fee

   2022 ($)      2021 ($)  

Audit fees

     2,018,989        2,078,760  

Audit-related fees (1)

     19,600        19,600  

Tax fees (2)

     337,999        372,618  
  

 

 

    

 

 

 

Total

     2,376,588        2,470,978  
  

 

 

    

 

 

 

 

(1)

Audit-related fees for Emera relate to fees associated with the audit of pension plans.

(2)

Tax fees for Emera relate to the structuring of cross-border financing of Emera’s operating companies as well as tax compliance services and general tax consulting advice on various matters.

Ms. Sheppard, Mr. Balfour and Mr. Aftanas intend to vote proxies received “For” the authorization of Directors to establish the Auditors’ fee, unless a shareholder instructs otherwise in their proxy.

 

4.

Advisory Vote on Executive Compensation: You will be asked to consider and approve, on an advisory basis, the resolution stated below on Emera’s approach to executive compensation as disclosed in this Circular. This advisory vote forms an important part of the ongoing process of engagement between shareholders and the Board on executive compensation.

Our executive compensation programs are designed to attract, retain, motivate and reward high-calibre leaders to deliver strong performance in alignment with Emera’s corporate strategy and to create and sustain shareholder value. Programs are designed to reflect a blend of short- and long-term incentive plans to reflect our pay-for-performance philosophy and to provide for a significant portion of an executive’s compensation to be at risk, while aligning the structure of programs and payouts with sound risk management and good governance principles.

The Board, through the Management Resources and Compensation Committee (“MRCC”), has directed and reviewed the contents of the Statement of Executive Compensation in this Circular and has unanimously approved it as part of the MRCC’s report to you.

As our shareholder, on an advisory basis, you have the opportunity to vote “For” or “Against” our approach to executive compensation through the following resolution:

“RESOLVED, on an advisory basis, and not to diminish the role and responsibilities of the Board of Directors, that the shareholders accept the approach to executive compensation disclosed in the Company’s Management Information Circular delivered in advance of the 2023 Annual Meeting of Shareholders of Emera Incorporated.”

 

  EMERA INCORPORATED   15


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Since your vote is advisory, it will not be binding on the Board; however, the Board, and in particular the MRCC, will seriously consider the outcome of the vote and may communicate with certain shareholders as a follow-up matter as part of its ongoing review of executive compensation.

Ms. Sheppard, Mr. Balfour and Mr. Aftanas intend to vote proxies received “For” the advisory resolution on executive compensation, unless otherwise instructed.

 

5.

Senior Management Stock Option Plan Amendment: To consider and, if thought appropriate, to pass an ordinary resolution (the full text of which is reproduced in Appendix “B” to this Circular), ratifying, confirming and approving an amendment to the Company’s Senior Management Stock Option Plan (the “Plan”) providing that if an option is scheduled to expire or be settled during a trading blackout period or within five (5) business days following the expiry of such blackout period, then, notwithstanding any other provision of the Plan, the option shall expire ten (10) business days after a trading blackout period is lifted by the Company. The Plan is an important part of Emera’s long-term incentive program for senior management. For more information about this amendment of the Plan, see Amendment to the Senior Management Stock Option Plan in the Statement of Executive Compensation later in this Circular.

Ms. Sheppard, Mr. Balfour and Mr. Aftanas intend to vote proxies received “For” the approval to amend the Plan, unless a shareholder instructs otherwise in their proxy.

Director Nominees Information

Biographical information about the 11 Director nominees, including age, municipality and country of residence, year first elected or appointed as a Director, principal occupation, education, skills and experience, is included below. Each Director proposed for re-election was elected to their positions on May 26, 2022, and the terms of their appointment will expire at the close of the Meeting unless they are re-elected.

The information also includes Committee memberships and meeting attendance (where applicable) for meetings held in 2022, as well as any memberships on other public company boards in the last five years.

There is information about the common shares and deferred share units (“DSUs”) of Emera held as of the last trading day of each year by each Director nominee for the past three years. The estimated value of each Director nominee’s common shares and DSU holdings is based on the following:

 

Year-end

   Closing price of Emera common shares ($)  

December 31, 2020

     54.10  

December 31, 2021

     63.22  

December 30, 2022

     51.75  

All Director nominees are required to meet Emera’s share ownership guideline. The information below details their status under the guideline. For further information on Emera’s share ownership guideline for Directors, see Director Share Ownership Guideline in the Statement of Corporate Governance Practices later in this Circular. For further information on the share ownership guidelines for the Company’s executive officers, including Mr. Balfour, see Executive Share Ownership Requirements and Anti-Hedging Policy in the Statement of Executive Compensation.

All Director nominees, except Mr. Balfour, are considered by the Board to be independent. For more information about the Company’s definition of independence, see Director and Chair Independence in the Statement of Corporate Governance Practices later in the Circular.

 

16   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

SCOTT BALFOUR

 

Director Since: 2018                                      Not Independent, Chief Executive Officer of Emera

 

 

LOGO

 

Halifax, Nova Scotia

Canada

Age: 58
Skills and Experience

•   CEO/Senior Executive

•   Sustainability/ESG

•   Governance

•   Risk Management

•   Customer/Stakeholder

•   Energy Sector or Utility Sector

•   Strategic Planning, M&A or Growth Strategy

•   Talent Management and Executive Compensation

•   Financial Literacy and Accounting

•   Government Relations, Public Policy and Regulatory

2022 Annual Meeting Votes for: 99.72%
Other Public Company Boards (last five years)

•   Martinrea International Inc. (June 2013 to June 2020)

Mr. Balfour was appointed a Director and President and Chief Executive Officer of Emera in 2018.

Since joining Emera in April 2012, Mr. Balfour has served as Chief Operating Officer and Chief Financial Officer. Before joining Emera, he held a variety of roles, including President and Chief Financial Officer at Aecon Group Inc., a Canadian publicly traded construction and infrastructure development company.

Mr. Balfour is a Director of many Emera subsidiaries, including being Chair of Tampa Electric Company, Nova Scotia Power Inc. and Peoples Gas System, Inc. He also serves as Director of the Business Council of Canada. He is a former Director of Martinrea International Inc. and past-Chair of the Ontario Energy Association.

Mr. Balfour received his Master of Business Administration from Richard Ivey School of Business, University of Western Ontario. He earned a Bachelor of Business Administration (Honours) from Wilfrid Laurier University.

Mr. Balfour’s strong financial, operations and public company executive experience provide the foundation for his contribution to the Board and his leadership of Emera. His knowledge of capital markets and his experience in growing a business through the development and execution of strategy as well as through mergers and acquisitions, and then leading teams and structuring systems to manage that growth, are tremendous assets for the Company.

 

Board and Committee membership

   Attendance      Total  

•   Board (1)

     11 of 11        100 % 

 

DSUs awarded and held

 
2022 share-based
         awards ($)          
     Total 2022 change in value
of all DSUs held ($)
    Market value of total
DSU holdings ($)
 
  841,662        (1,214,329 )      6,320,486  

 

Emera Securities held

 
     2020      2021      2022  

Common shares

     55,388        63,242        72,392  

DSUs

     88,165        105,870        122,135  

Value of shares and DSUs ($)

     7,766,217        10,691,261        10,066,772  

Status under share ownership guideline

    





As Chief Executive Officer of
Emera, Mr. Balfour is subject to
Executive Share Ownership
Requirements. This requires that he
own shares and/or DSUs valued at
no less than five times his salary. He
exceeds this requirement.
 
 
 
 
 
 
 

 

(1)

Mr. Balfour attended all committee meetings in 2022 in his capacity as President and Chief Executive Officer.

 

 

  EMERA INCORPORATED   17


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

JAMES BERTRAM

 

Director Since: 2018                                      Independent Director

 

 

LOGO

 

Calgary, Alberta

Canada

Age: 67
Skills and Experience

•   CEO/Senior Executive

•   Sustainability/ESG

•   Governance

•   Customer/Stakeholder

•   Energy Sector or Utility Sector

•   Strategic Planning, M&A or Growth Strategy

•   Talent Management and Executive Compensation

2022 Annual Meeting Votes for: 99.64%
Other Public Company Boards (last five years)

•   Keyera Corp. (2003 to present)

•   Methanex Corporation (October 2018 to present)

Mr. Bertram has been a Director since July 2018. He became a member of the Management Resources and Compensation Committee in November 2018. He was appointed Chair of the Health, Safety and Environment Committee in May 2019.

Mr. Bertram is a corporate director and is currently the Chair of the Board of Keyera Corp., one of Canada’s leading publicly traded midstream oil and gas operators. He was Chief Executive Officer of Keyera from its inception in 1998 until 2015, when he became Executive Chair. He retired as an officer of Keyera in 2016. He was previously Vice President, Marketing for the worldwide operations of Gulf Canada.

Mr. Bertram is a Director of Methanex Corporation, the world’s largest producer and supplier of methanol to major international markets.

Mr. Bertram received his Bachelor of Commerce from the University of Calgary.

With his experience growing a business and completing major acquisitions, while enabling consistent delivery of value to customers and shareholders, Mr. Bertram makes an important contribution to the Emera Board of Directors.

 

Board and Committee membership

   Attendance      Total  

•   Board

     11 of 11        100 % 

•   Management Resources and Compensation Committee

     3 of 3        100 % 

•   Health, Safety and Environment Committee (Chair)

     3 of 3        100 % 

 

Total compensation

 

Fees earned in 2022 ($)

     All other compensation ($)      Total ($)  
  293,034                     Nil        293,034  

 

DSUs awarded and held

 
2022 share-based
        awards ($)         
     Total 2022 change in value
of all DSUs held ($)
    Market value of total
DSU holdings ($)
 
  293,034        (214,753 )      1,258,842  

 

Emera Securities held

 
     2020      2021      2022  

Common shares

     Nil        6,470        14,170  

DSUs

     12,799        18,723        24,325  

Value of shares and DSUs ($)

     692,426        1,592,701        1,992,140  

Status under share ownership guideline (1)

    

Mr. Bertram has met the
requirement under the share
ownership guideline.
 
 
 

 

(1)

See Director Share Ownership Guideline for additional information regarding the required level of share ownership for Emera’s Directors.

 

 

18   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

HENRY DEMONE

 

Director Since: 2014                                      Independent Director

 

 

LOGO

 

Lunenburg, Nova Scotia

Canada

Age: 68
Skills and Experience

•   CEO/Senior Executive

•   Sustainability/ESG

•   Governance

•   Customer/Stakeholder

•   Strategic Planning, M&A or Growth Strategy

•   Talent Management and Executive Compensation

2022 Annual Meeting Votes for: 98.84%
Other Public Company Boards (last five years)

•   Saputo Inc. (2012 to present)

•   High Liner Foods Inc. (1989 to 2019)

Mr. Demone joined the Emera Board of Directors in September 2014 and became a member of the Management Resources and Compensation Committee at that time. He became Chair of the Committee in May 2021. He was appointed to the Nominating and Corporate Governance Committee in May 2017.

He is the former Chairman of High Liner Foods of Lunenburg, Nova Scotia, the leading North American processor and marketer of value-added frozen seafood. He was President of High Liner Foods from 1989 until he became President and Chief Executive Officer from 1992 until May 2015. He was reappointed Chief Executive Officer of High Liner Foods on an interim basis from August 2017 until April 2018.

Mr. Demone is a corporate director, and currently sits on the Board of Saputo Inc., a Montreal-based Canadian dairy company that produces, markets and distributes a wide array of dairy products. He is past-Chair of the Fisheries Council of Canada and The Groundfish Forum, a global trade association representing industry leaders. He has served on the Boards of Dover Industries Ltd. and Maritime Tel & Tel (Aliant). Mr. Demone was also the first non-US citizen to be named Chair of the National Fisheries Institute, a US national trade association.

Mr. Demone received his Bachelor of Science in Mathematics with honours from Acadia University.

In both public and private entities, Mr. Demone has extensive experience in strategic planning, global markets, and mergers and acquisitions. As a long-time business leader in Atlantic Canada, Mr. Demone’s robust business relationships and his solid reputation make him a valuable member of Emera’s Board of Directors.

 

Board and Committee membership

   Attendance      Total  

•   Board

     11 of 11        100 % 

•   Nominating and Corporate Governance Committee

     5 of 5        100 % 

•   Management Resources and Compensation Committee (Chair)

     3 of 3        100 % 

 

Total compensation

 

Fees earned in 2022 ($)

     All other compensation ($)      Total ($)  
  293,034        Nil        293,034  

 

DSUs awarded and held

 

2022 share-based

        awards ($)         

     Total 2022 change in value
of all DSUs held ($)
    Market value of total
DSU holdings ($)
 
  160,000        (387,262 )      1,963,047  

 

Emera Securities held

 
     2020      2021      2022  

Common shares

     9,062        9,062        9,062  

DSUs

     29,389        33,763        37,933  

Value of shares and DSUs ($)

     2,080,199        2,707,397        2,432,006  

Status under share ownership guideline

    

Mr. Demone has met the
requirement under the share
ownership guideline.
 
 
 
 

 

  EMERA INCORPORATED   19


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

PAULA GOLD-WILLIAMS

 

Director Since: 2022                                      Independent Director

 

 

LOGO

 

San Antonio, Texas

United States

Age: 60
Skills and Experience

•   CEO/Senior Executive

•   Sustainability/ESG

•   Governance

•   Risk Management

•   Customer/Stakeholder

•   Energy Sector or Utility Sector

•   Strategic Planning, M&A or Growth Strategy

•   Talent Management and Executive Compensation

•   Financial Literacy and Accounting

•   Government Relations, Public Policy and Regulatory

2022 Annual Meeting Votes for: 99.75%
Other Public Company Boards (last five years)
None

Ms. Gold-Williams joined the Emera Board in February 2022. She is the former President and CEO of CPS Energy, a fully integrated electric and natural gas municipal utility based in San Antonio, Texas. Ms. Gold-Williams served in positions of increasing responsibility at CPS Energy before becoming CEO in 2015. She held multiple other positions during her 17-year career at CPS Energy, including Group EVP – Financial & Administrative Services, CFO and Treasurer.

Ms. Gold-Williams is a corporate director who serves as the Chair of the Keystone Policy Center, and has been a member of both the Policy Center and its Energy Board since 2016. She is a board member and Treasurer of EPIcenter, an innovation think tank, incubator and accelerator, and strategic advisory organization. She serves as an Energy Pillar Co-Chair of Dentons’ Global Smart Cities & Communities Initiatives and Think Tank. She is an Advisory Board Member of iEmpower, an all-inclusive organization that optimizes the concept of community to engage and inspire women. She also serves on the US Secretary of Energy’s Advisory Board (“SEAB”).

Previously, Ms. Gold-Williams held other board positions including First Vice Chair of the Electric Power Resource Institute (“EPRI”); a member and designated Chair Pro Tem of the Federal Reserve Bank of Dallas’ San Antonio Branch; and a past-Chair of the San Antonio Chamber of Commerce.

Ms. Gold-Williams has an Associate Degree in Fine Arts from San Antonio College. She has a BBA in accounting from St. Mary’s University. She earned a Finance and Accounting MBA from Regis University in Denver, Colorado. She is a Certified Public Accountant and a Chartered Global Management Accountant.

As the former President and CEO of CPS Energy, the largest municipally owned electric and natural gas utility in the United States, with a diverse mix of nuclear, coal, gas, wind, and solar generation, and battery storage, Ms. Gold-Williams’ skill and experience creating business strategies focused on consistently prioritizing customers, community and employees is tremendously important to Emera.

 

Board and Committee membership

   Attendance      Total  

•   Board

     11 of 11        100 % 

•   Health, Safety and Environment Committee (1)

     1of 1        100 % 

•   Audit Committee (1)

     2of 2        100 % 

 

Total compensation

 

Fees earned in 2022 ($)

     All other compensation ($)      Total ($)  
  277,035        Nil        277,035  

 

DSUs awarded and held

 

2022 share-based

        awards ($)         

     Total 2022 change in value
of all DSUs held ($)
     Market value of total
DSU holdings ($)
 
  275,132        N/A        230,280  

 

Emera Securities held

 
                           2021      2022  

Common shares

        Nil        Nil  

DSUs

        Nil        4,450  

Value of shares and DSUs ($)

        Nil        230,280  

Status under share ownership guideline

    










Ms. Gold-Williams
owns shares valued
at 30 per cent of the
requirement under
the share ownership
guideline. She
joined the Board in
February 2022 and
has until February
2025 to meet the
share ownership
guideline.
 
 
 
 
 
 
 
 
 
 
 
 

 

(1)

Ms. Gold-Williams was appointed a member of the Audit Committee and the Health, Safety and Environment Committee on May 26, 2022 and has attended all meetings of those Committees since being appointed.

 

 

20   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

KENT HARVEY

 

Director Since: 2017                                      Independent Director

 

 

LOGO

 

New York, New York

United States

Age: 65
Skills and Experience

•   CEO/Senior Executive

•   Sustainability/ESG

•   Governance

•   Risk Management

•   Energy Sector or Utility Sector

•   Strategic Planning, M&A or Growth Strategy

•   Financial Literacy and Accounting

•   Government Relations, Public Policy and Regulatory

2022 Annual Meeting Votes for: 95.84%
Other Public Company Boards (last five years)
None

Mr. Harvey is a retired utility industry executive who joined the Emera Board of Directors in November 2017 and was appointed to the Audit Committee at that time. He became Chair of the Audit Committee in June 2020. He has been a member of the Health, Safety and Environment Committee since May 2019.

Mr. Harvey is former Chief Financial Officer for PG&E Corporation, which is headquartered in San Francisco. PG&E Corporation is the parent company of Pacific Gas and Electric Company, one of the largest combined natural gas and electric energy companies in the United States. After 33 years in progressively senior roles, he retired from PG&E Corporation in 2016.

Born in Montreal, Mr. Harvey is a naturalized US citizen. He holds a bachelor’s degree in Economics and a master’s degree in Engineering – Economic Systems, both from Stanford University. He works as a crisis services volunteer at the Trevor Project, which focuses on suicide prevention among LGBTQ youth.

Mr. Harvey is an energy industry leader and strategic thinker with strong US experience and financial depth, which are great assets to the Emera Board.

 

Board and Committee membership

   Attendance      Total  

•   Board

     11 of 11        100 % 

•   Audit Committee (Chair)

     5 of 5        100 % 

•   Health, Safety and Environment Committee

     3 of 3        100 % 

 

Total compensation

 

Fees earned in 2022 ($)

     All other compensation ($)      Total ($)  
  339,400        Nil        339,400  

 

DSUs awarded and held

 

2022 share-based

        awards ($)         

     Total 2022 change in value
of all DSUs held ($)
    Market value of total
DSU holdings ($)
 
  339,400        (179,207 )      1,129,530  

 

Emera Securities held

 
     2020      2021      2022  

Common shares

     Nil        Nil        Nil  

DSUs

     9,065        15,624        21,827  

Value of shares and DSUs ($)

     490,417        987,749        1,129,530  

Status under share ownership guideline

    

Mr. Harvey has met the
requirement under the share
ownership guideline.
 
 
 
 

 

  EMERA INCORPORATED   21


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

LYNN LOEWEN, FCPA, FCA

 

Director Since: 2013                                      Independent Director

 

 

LOGO

 

Westmount, Quebec

Canada

Age: 62
Skills and Experience

•   CEO/Senior Executive

•   Sustainability/ESG

•   Governance

•   Risk Management

•   Customer/Stakeholder

•   Strategic Planning, M&A or Growth Strategy

•   Talent Management and Executive Compensation

•   Financial Literacy and Accounting

2022 Annual Meeting Votes for: 99.42%
Other Public Company Boards (last five years)

•   National Bank of Canada (2022 to present)

Ms. Loewen has been a Director of the Company since February 2013. She has been a member of the Audit Committee since May 2013 and the Health, Safety and Environment Committee since May 2017. In September 2021, she became a member of the Risk and Sustainability Committee.

Ms. Loewen is the former President of Minogue Medical Inc., a healthcare organization specializing in the delivery of innovative medical technologies, supplies and equipment to hospitals and medical clinics. She was President of Expertech Network Installation Inc. from 2008 to 2011. She held key positions with Bell Canada Enterprises, as Vice President of Finance Operations from 2005 to 2008, and as Vice President of Financial Controls from 2003 to 2005. Prior to that, she was Vice President of Corporate Services and Chief Financial Officer of Air Canada Jazz, where she held positions of increasing responsibility since 1988.

Ms. Loewen is a member of the Board of Directors of National Bank of Canada, a Canadian Chartered Bank. She is also a Director of Xplore Communications Inc., a Canadian broadband service provider, and member of the Audit Committee. She was a member of the Public Sector Pension Investment Board from 2001 to 2007, where she served on the Audit Committee from 2003 to 2007 and as Audit Committee Chair from 2006 to 2007. She was Chair of the Governance Committee from 2003 to 2006.

Ms. Loewen has been the Chancellor of Mount Allison University since 2018 and was a member of the Board from 1998 to 2008. She served as Chair from 2007 to 2008. Ms. Loewen holds a Bachelor of Commerce from Mount Allison University. Ms. Loewen is a Fellow of the Chartered Professional Accountants and has received the Institute of Corporate Directors, Directors Designation.

Ms. Loewen’s financial expertise and business acumen gained as a senior executive in the telecom and airline sectors are valuable assets for Emera’s Board.

 

Board and Committee membership

   Attendance      Total  

•   Board

     11 of 11        100 % 

•   Audit Committee

     5 of 5        100 % 

•   Health, Safety and Environment Committee

     3of 3        100 % 

•   Risk and Sustainability Committee

     4of 4        100 % 

 

Total compensation

 

Fees earned in 2022 ($)

     All other compensation ($)      Total ($)  
  293,534        Nil        293,534  

 

DSUs awarded and held

 

2022 share-based

        awards ($)         

     Total 2022 change in value
of all DSUs held ($)
    Market value of total
DSU holdings ($)
 
  293,534        (538,884 )      2,790,675  

 

Emera Securities held

 
     2020      2021      2022  

Common shares

     4,384        4,490        4,490  

DSUs

     39,882        46,982        53,926  

Value of shares and DSUs ($)

     2,394,791        3,254,060        3,023,033  

Status under share ownership guideline

    

Ms. Loewen has met the
requirement under the share
ownership guideline.
 
 
 
 

 

22   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

IAN ROBERTSON

 

Director Since: 2022                                      Independent Director

 

 

LOGO

 

Oakville, Ontario

Canada

Age: 63
Skills and Experience

•   CEO/Senior Executive

•   Sustainability/ESG

•   Governance

•   Risk Management

•   Customer/Stakeholder

•   Energy Sector or Utility Sector

•   Strategic Planning, M&A or Growth Strategy

•   Talent Management and Executive Compensation

•   Financial Literacy and Accounting

•   Government Relations, Public Policy and Regulatory

2022 Annual Meeting Votes for: 96.13%
Other Public Company Boards (last five years)

•   Embark Technology, Inc. (November 2021 to present)

•   Northern Genesis Acquisition Corp. III (June 2020 to present)

 

•   Largo Resources Ltd. (March 2021 to June 2022)

 

•   Atlantica Sustainable Infrastructure plc (March 2018 to April 2020)

 

•   Algonquin Power & Utilities Corp. (2009 to 2020)

Mr. Robertson joined the Emera Board in February 2022.

He is a principal of the Northern Genesis investment group focused on identifying and acquiring energy transition businesses that demonstrate strong sustainability and Environmental, Social and Governance (ESG) alignment. (1) He is the former CEO of Algonquin Power & Utilities Corp. (Algonquin Power), a publicly traded, diversified, international generation, transmission, and distribution utility. He was the founder and principal of Algonquin Power Corporation Inc., a private independent power developer formed in 1988 that was a predecessor organization to Algonquin Power. Mr. Robertson has over 30 years of experience in the development of electric power generating projects and the operation of diversified regulated utilities.

Mr. Robertson is a member of the Board of Directors of Northern Genesis Acquisition Corp. III. He is also a Director of Embark Technology, Inc., an autonomous vehicle company. He is a former Director of Largo Resources Ltd., Algonquin Power and Atlantica Sustainable Infrastructure plc.

Mr. Robertson is an electrical engineer and holds a Professional Engineering designation through his Bachelor of Applied Science degree awarded by the University of Waterloo. He earned a Master of Business Administration degree from York University’s Schulich School of Business. He holds a Chartered Financial Analyst designation, as well as a global professional Master of Laws degree from the University of Toronto. He received a Chartered Director designation from the Directors College of McMaster University. Since 2013, Mr. Robertson is a former member of the board of directors of the American Gas Association.

Mr. Robertson was the CEO of Algonquin Power and its predecessor entities during the extraordinary growth of Algonquin Power, and his entrepreneurial approach to building a leading North American regulated utility business, focused on renewable energy, is a distinct asset to the Emera Board.

 

Board and Committee membership

   Attendance      Total  

•   Board (2)

     9 of 11        82 % 

•   Audit Committee (3)

     2 of 2        100 % 

•   Risk and Sustainability Committee (3)

     2 of 2        100 % 

 

Total compensation

 

Fees earned in 2022 ($)

     All other compensation ($)      Total ($)  
  245,534        Nil        245,534  

 

DSUs awarded and held

 

2022 share-based

        awards ($)         

     Total 2022 change in value
of all DSUs held ($)
     Market value of total DSU
holdings ($)
 
  243,547        N/A        202,453  

 

Emera Securities held

 
                       2021      2022  

Common shares

        7,950        12,600  

DSUs

        Nil        3,912  

Value of shares and DSUs ($)

        502,599        854,503  

Status under share ownership guideline

    




Mr. Robertson joined
the Board in February
2022 and has met the
requirement under the
share ownership
guideline.
 
 
 
 
 
 

 

(1)

Mr. Robertson formerly served as CEO of Northern Genesis Acquisition Corp. III (“NG3”) until May 9, 2022, and he no longer serves as an executive officer of NG3.

(2)

The two Board meetings Mr. Robertson was unable to attend were not regularly scheduled Board meetings, and were scheduled at times that conflicted with prior commitments he had which could not be re-scheduled.

(3)

Mr. Robertson was appointed a member of the Audit Committee and the Risk and Sustainability Committee on May 26, 2022 and has attended all the meetings of those Committees since being appointed.

 

 

  EMERA INCORPORATED   23


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

ANDREA ROSEN

 

Director Since: 2007                                      Independent Director

 

 

LOGO

 

Toronto, Ontario

Canada

Age: 68
Skills and Experience

•   CEO/Senior Executive

•   Sustainability/ESG

•   Governance

•   Risk Management

•   Strategic Planning, M&A or Growth Strategy

•   Financial Literacy and Accounting

•   Government Relations, Public Policy and Regulatory

2022 Annual Meeting Votes for: 94.80%
Other Public Company Boards (last five years)

•   Element Fleet Management Corp. (May 2019 to present)

•   Ceridian HCM Holding Inc. (July 2018 to present)

•   Manulife Financial Corporation (August 2011 to present)

Ms. Rosen has been a Director since January 2007 and became a member of Emera’s Audit Committee in May of the same year. She served as Audit Committee Chair from April 2008 to June 2020. She was appointed to the Nominating and Corporate Governance Committee in May 2019 and was appointed Chair of that Committee in June 2020.

Ms. Rosen was a member of the two ad hoc Committees formed by the Board in August 2015 and November 2016 to oversee certain aspects of the financing related to the TECO transaction and the equity offering completed in December 2016. She was also appointed to the ad hoc Committee formed by the Board in November 2017 to oversee the equity offering completed in December 2017.

Ms. Rosen was Vice Chair of TD Bank Financial Group and President of TD Canada Trust from 2002 to 2005. Prior to this, she was Executive Vice President of TD Commercial Banking and Vice Chair of TD Securities. From 1991 to 1994, Ms. Rosen also served as Vice President of Varity Corporation. Between 1981 and 1990, she held a variety of roles at Wood Gundy Inc. (later CIBC Wood Gundy), eventually becoming Vice President and Director.

Ms. Rosen is a corporate director. She is a Director of Manulife Financial Corporation, a Canadian multinational insurance company and financial services provider. She is also a Director on the Boards of Ceridian HCM Holding Inc., a global human capital management software company, and Element Fleet Management Corp., a global fleet management company providing services and financing for commercial vehicle fleets. She is a former Director of Alberta Investment Management Corporation (“AIMCo”) and Hiscox Ltd. She is also a member of the Board of Directors of the Institute of Corporate Directors.

Ms. Rosen received her Bachelor of Laws degree from Osgoode Hall Law School and a Master of Business Administration from the Schulich School of Business at York University. She earned a Bachelor of Arts degree from Yale University.

Ms. Rosen has spent over 20 years in the corporate finance field and is an experienced senior executive. Her career in the investment and commercial banking industry has given her extensive financial and investment knowledge. Her expertise is of significant value to Emera.

 

Board and Committee membership

   Attendance      Total  

•   Board

     10 of 11        91 % 

•   Audit Committee

     5 of 5        100 % 

•   Nominating and Corporate Governance Committee (Chair)

     5 of 5        100 % 

 

Total compensation

 

Fees earned in 2022 ($)

     All other compensation ($)      Total ($)  
  295,034        Nil        295,034  

 

DSUs awarded and held

 

2022 share-based

        awards ($)         

     Total 2022 change in value
of all DSUs held ($)
    Market value of total DSU
holdings ($)
 
  295,034        (968,527 )      4,821,821  

 

Emera Securities held

 
     2020      2021      2022  

Common shares

     14,336        14,336        14,336  

DSUs

     75,559        84,440        93,175  

Value of shares and DSUs ($)

     4,863,320        6,244,619        5,563,709  

Status under share ownership guideline

    

Ms. Rosen has met the
requirement under the share
ownership guideline.
 
 
 
 

 

24   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

JACKIE SHEPPARD

 

Director Since: 2009                                      Independent Director

 

 

LOGO

 

Calgary, Alberta

Canada

Age: 67
Skills and Experience

•   CEO/Senior Executive

•   Sustainability/ESG

•   Governance

•   Risk Management

•   Customer/Stakeholder

•   Energy Sector or Utility Sector

•   Strategic Planning, M&A or Growth Strategy

•   Talent Management and Executive Compensation

•   Financial Literacy and Accounting

•   Government Relations, Public Policy and Regulatory

2022 Annual Meeting Votes for: 99.35%
Other Public Company Boards (last five years)

•   Suncor Energy Inc. (July 2022 to present)

•   ARC Resources Ltd. (March 2021 to present)

•   Seven Generations Energy Ltd. (May 2016 to March 2021) (1)

•   Cairn Energy PLC (May 2010 to December 2018)

Ms. Sheppard has been an Emera Director since February 2009 and became Chair of the Board in May 2014.

She was a member of the MRCC from May 2009 to May 2014, and the Audit Committee from May 2009 to October 2014. She was Chair of the two ad hoc Committees formed by the Board in August 2015 and November 2016 to oversee certain aspects of the financing related to the TECO transaction and the equity offering completed in December 2016. She was also Chair of the ad hoc Committee formed by the Board in November 2017 to oversee the equity offering completed in December 2017.

Ms. Sheppard was a Director of the Company’s subsidiary Emera Newfoundland & Labrador Holdings Inc. from 2011 until May 2016.

Ms. Sheppard is a corporate director and the former Executive Vice President, Corporate and Legal of Talisman Energy Inc. She is a Director of Suncor Energy Inc., a Canadian integrated energy company. She is also a Director of ARC Resources Ltd., a publicly traded Canadian energy company. She was founder and Lead Director of Black Swan Energy Inc., an Alberta upstream energy company that was sold in July 2021. She is a former Director of Cairn Energy PLC, a publicly traded UK-based international upstream company, as well as Alberta Investment Management Corporation (“AIMCo”), an institutional investment manager and she served as Chair of the Research and Development Corporation of the Province of Newfoundland and Labrador, a provincial Crown corporation, until June 2014.

Ms. Sheppard is a Rhodes Scholar, having received an Honours Jurisprudence, Bachelor of Arts and Master of Arts from Oxford University in 1979. She earned a Bachelor of Laws degree (Honours) from McGill University in 1981 and a Bachelor of Arts degree from Memorial University of Newfoundland in 1977. She was awarded an honorary Doctor of Laws degree from Memorial University in 2019.

With her extensive roles as an executive in the energy industry, and as a director of public, private and Crown corporations, Ms. Sheppard’s experience in strategic planning, business development, public markets, legal and governance are the foundation for her leadership of the Board.

 

Board and Committee membership

   Attendance      Total  

•   Board (Chair) (2)

     11 of 11        100 % 

 

Total compensation

 

Fees earned in 2022 ($)

     All other compensation ($)      Total ($)  
  457,534        Nil        457,534  

 

DSUs awarded and held

 

2022 share-based

        awards ($)         

     Total 2022 change in value
of all DSUs held ($)
    Market value of total DSU
holdings ($)
 
  457,534        (1,178,049 )      5,947,179  

 

Emera Securities held

 
     2020      2021      2022  

Common shares

     11,947        11,947        11,947  

DSUs

     90,060        102,707        114,921  

Value of shares and DSUs ($)

     5,518,579        7,248,426        6,565,436  

Status under share ownership guideline

    

Ms. Sheppard has met the
requirement under the share
ownership guideline.
 
 
 

 

(1)

Ms. Sheppard was a member of the Board of Seven Generations Energy Ltd. from May 2016 until March 31, 2021 when it merged with ARC Resources Ltd.

(2)

Ms. Sheppard attended all Committee meetings in 2022 in her capacity as Chair of the Board.

 

 

  EMERA INCORPORATED   25


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

KAREN SHERIFF

 

Director Since: 2021                                      Independent Director

 

 

LOGO

 

Picton, Ontario

Canada

Age: 65
Skills and Experience

•   CEO/Senior Executive

•   Sustainability/ESG

•   Governance

•   Risk Management

•   Customer/Stakeholder

•   Energy Sector or Utility Sector

•   Strategic Planning, M&A or Growth Strategy

•   Talent Management and Executive Compensation

•   Financial Literacy and Accounting

•   Government Relations, Public Policy and Regulatory

2022 Annual Meeting Votes for: 99.71%
Other Public Company Boards (last five years)

•   BCE Inc. (2017 to present)

•   WestJet Airlines Ltd. (2016 to 2019)

Ms. Sheriff has been a Director since February 2021. She became a member of the Management Resources and Compensation Committee in May 2021 and became a member of the Risk and Sustainability Committee in September 2021.

Ms. Sheriff is a corporate director and past President and CEO of Q9 Networks Inc., a data centre services provider. Prior to her role at Q9, she served as President and CEO of Bell Aliant, Inc., a telecommunications company, from 2008 to 2014. She was in senior leadership positions for more than nine years with BCE Inc. and currently serves on the BCE Inc. Board of Directors. She also spent over 10 years at United Airlines in the areas of marketing, strategy, human resources, and finance.

Ms. Sheriff is a former member of the Board of Directors of CPP Investments and WestJet Airlines Ltd.

Ms. Sheriff received her master’s degree in business administration with concentrations in marketing and finance from the University of Chicago. She was named one of Canada’s top 25 Women of Influence for 2013 and 2014 by Women of Influence Inc. She was named Woman of the Year by Canadian Women in Communications and has been recognized as one of Atlantic Canada’s Top 50 CEOs by Atlantic Business Magazine and one of Canada’s Top 100 Most Powerful Women on multiple occasions.

With her extensive senior executive experience, including as CEO of a public company and in a leading role in transforming Bell Aliant, Ms. Sheriff brings 20 years of technology- based industry experience. She brings to Emera valuable experience leading a regulated utility along with her involvement in the sale and acquisition of major business units, including Bell Aliant, Q9, CTV and the sale of WestJet to Onex.

 

Board and Committee membership

   Attendance      Total  

•   Board

     10 of 11        91 % 

•   Management Resources and Compensation Committee

     3of 3        100 % 

•   Risk and Sustainability Committee

     4of 4        100 % 

 

Total compensation

 

Fees earned in 2022 ($)

     All other compensation ($)      Total ($)  
  281,034        Nil        281,034  

 

DSUs awarded and held

 

2022 share-based

        awards ($)         

     Total 2022 change in value
of all DSUs held ($)
    Market value of total DSU
holdings ($)
 
  281,034        (50,227 )      471,535  

 

Emera Securities held

 
     2020      2021      2022  

Common shares

     Nil        1,000        1,000  

DSUs

     Nil        4,379        9,112  

Value of shares and DSUs ($)

     Nil        340,060        523,285  

Status under share ownership guideline

    






Ms. Sheriff owns shares
and DSUs valued at
69 per cent of the
requirement under the
share ownership
guideline. She has until
February 2026 to meet
the guideline.
 
 
 
 
 
 
 
 
 

 

26   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

JOCHEN TILK

 

Director Since: 2018                                      Independent Director

 

 

LOGO

Toronto, Ontario

Canada

Age: 59
Skills and Experience

•   CEO/Senior Executive

•   Sustainability/ESG

•   Governance

•   Risk Management

•   Strategic Planning, M&A or Growth Strategy

•   Talent Management and Executive Compensation

2022 Annual Meeting Votes for: 99.37%
Other Public Company Boards (last five years)

•   AngloGold Ashanti Limited (January 2019 to present)

•   Nutrien Ltd., formerly Potash Corp. (2014 to 2018)

Mr. Tilk has been a Director since July 2018. He was appointed to the Management Resources and Compensation Committee in May 2019 and the Nominating and Corporate Governance Committee in May 2021. He was appointed Chair of the newly established Risk and Sustainability Committee in September 2021. He served as a member of the Audit Committee from November 2018 until May 2021.

Mr. Tilk is a corporate director and the former Executive Chair of Nutrien Ltd., a Canadian global supplier of agricultural products and services based in Saskatoon, Saskatchewan. He is the former President and Chief Executive Officer of Potash Corporation of Saskatchewan. Previously, Mr. Tilk spent 25 years with Inmet Mining Corporation, a Canadian-based, international metals company, with five of those years as the company’s President and Chief Executive Officer.

Mr. Tilk is a Director of AngloGold Ashanti Limited, a publicly listed international gold mining company headquartered in Johannesburg, South Africa. He is also Vice-Chair of the Princess Margaret Cancer Foundation, a not-for-profit organization. He is the former Chair of the Board of Directors of Canpotex Limited and a former Director of the Fertilizer Institute and the International Fertilizer Association.

He received his master’s in mining engineering from Rheinisch-Westfälische Technische Hochschule, a research university located in Aachen, North Rhine-Westphalia, Germany.

Mr. Tilk’s record of growing companies and leading multi-billion-dollar capital expenditure programs makes him an important contributor to Emera.

 

Board and Committee membership

   Attendance      Total  

•   Board

     11 of 11        100 % 

•   Management Resources and Compensation Committee

     3 of 3        100 % 

•   Risk and Sustainability Committee (Chair)

     4 of 4        100 % 

•   Nominating and Corporate Governance Committee

     5 of 5        100 % 

 

Total compensation

 

Fees earned in 2022 ($)

     All other compensation ($)      Total ($)  
  303,534        Nil        303,534  

 

DSUs awarded and held

 

2022 share-based

        awards ($)         

     Total 2022 change in value
of all DSUs held ($)
    Market value of total
DSU holdings ($)
 
  303,534        (189,519 )      1,148,399  

 

Emera Securities held

 
     2020      2021      2022  

Common shares

     Nil        Nil        Nil  

DSUs

     10,775        16,523        22,191  

Value of shares and DSUs ($)

     582,928        1,044,584        1,148,399  

Status under share ownership guideline

    

Mr. Tilk has met the
requirement under the share
ownership guideline.
 
 
 
 

 

  EMERA INCORPORATED   29


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

SKILLS AND EXPERIENCE

The table below shows the skills and experience of each Director nominee in areas identified as necessary for effective oversight of Emera given its current operations and strategy. These qualifications are considered in reviewing Board succession and recruiting new Board members.

 

Name of Director Nominees

   LOGO

 

   LOGO

 

   LOGO

 

   LOGO

 

   LOGO

 

   LOGO

 

   LOGO

 

   LOGO

 

   LOGO

 

   LOGO

 

Scott Balfour

   ✓    ✓    ✓    ✓    ✓    ✓    ✓    ✓    ✓    ✓

James Bertram

   ✓    ✓    ✓       ✓    ✓    ✓    ✓      

Henry Demone

   ✓    ✓    ✓       ✓       ✓    ✓      

Paula Gold-Williams

   ✓    ✓    ✓    ✓    ✓    ✓    ✓    ✓    ✓    ✓

Kent Harvey

   ✓    ✓    ✓    ✓       ✓    ✓       ✓    ✓

Lynn Loewen

   ✓    ✓    ✓    ✓    ✓       ✓    ✓    ✓   

Ian Robertson

   ✓    ✓    ✓    ✓    ✓    ✓    ✓    ✓    ✓    ✓

Andrea Rosen

   ✓    ✓    ✓    ✓          ✓       ✓    ✓

Jackie Sheppard

   ✓    ✓    ✓    ✓    ✓    ✓    ✓    ✓    ✓    ✓

Karen Sheriff

   ✓    ✓    ✓    ✓    ✓    ✓    ✓    ✓    ✓    ✓

Jochen Tilk

   ✓    ✓    ✓    ✓          ✓    ✓      
  

 

  

 

  

 

  

 

  

 

  

 

  

 

  

 

  

 

  

 

Total Number of Directors with Skills

   11    11    11    9    8    7    11    9    8    7
  

 

  

 

  

 

  

 

  

 

  

 

  

 

  

 

  

 

  

 

DESCRIPTION OF SKILLS AND EXPERIENCE

CEO/Senior Executive – CEO or senior executive experience with a large organization.

Sustainability/ESG – Experience as a senior executive leading, or as a director with oversight responsibilities for, a significant number of Environmental, Social and Governance programs, sustainable practices and policies, corporate social responsibility programs and/or diversity, equity and inclusion initiatives.

Governance – Experience with corporate governance practices and principles at a major organization.

Risk Management – Experience overseeing the various risks facing an organization, with oversight of appropriate policies and procedures to effectively manage risk.

Customer/Stakeholder – Experience as a senior executive in a customer-centric product or service company.

Energy Sector or Utility Sector – Has been a senior executive of a public utility or energy company.

Strategic Planning, M&A or Growth Strategy – Experience defining and driving strategic direction and growth, including leading complex M&A transactions, or leading the growth or transformation of a company.

Talent Management and Executive Compensation – Experience in oversight of executive compensation and incentive- based compensation programs. Experience with talent recruitment and management, workplace culture, equity, diversity and inclusion, succession planning, leadership development, executive recruitment, management of organized labour in a large operating company.

Financial Literacy and Accounting – Experience in corporate finance, overseeing complex financial transactions; experience in financial accounting and reporting, auditing, and internal controls.

Government Relations, Public Policy and Regulatory – Experience in the workings of government and public policy in Canada or the United States, and/or experience within a public or major private corporation with complex legal and regulatory regimes in Canada or the United States.

 

28   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Compensation of Directors in 2022

The compensation of Directors is designed to:

 

  •  

Recognize the substantial time commitments required to oversee management of the Company;

 

  •  

Attract and retain highly skilled and experienced individuals to serve on Emera’s Board;

 

  •  

Ensure alignment with shareholders’ long-term interests; and

 

  •  

Support Directors’ independence from management.

For more information about the process of determining Director compensation, see Director Compensation in the Statement of Corporate Governance Practices later in the Circular.

DEFERRED SHARE UNITS

In 2022, the annual retainer for each Director was $252,500, of which $160,000 was payable in deferred share units (“DSUs”) and the balance was payable in cash. Subject to Emera’s share ownership guideline, Directors can elect to receive some or all of their cash compensation in the form of additional DSUs. More information about the Directors’ DSU Plan is provided later in this Circular under the Directors’ DSU Plan section. The Company does not offer option-based awards, non-equity incentive plan participation, or participation in a Company pension plan to its non-executive Directors.

BOARD CHAIR’S ALL-INCLUSIVE RETAINER

The annual Chair’s retainer is an all-inclusive fee, meaning the Board Chair receives no meeting fees or any other retainer for serving as Emera’s Board Chair. The all-inclusive annual retainer of the Board Chair in 2022 was $450,000. This was comprised of $225,000 in DSUs, and the remainder in cash.

COMPENSATION RATES FOR DIRECTORS

Listed below are the annual compensation rates for non-executive Directors. Mr. Balfour does not receive director compensation because he is compensated in the role of President and CEO.

 

Annual retainers for Directors in 2022

   Cash amount ($)      DSUs ($)      Total ($)  

Annual Chair’s retainer

     225,000        225,000        450,000  

Annual Director’s retainer

     92,500        160,000        252,500  

Annual Audit Committee Chair’s retainer

     27,500        N/A        27,500  

Annual Audit Committee member’s retainer

     12,500        N/A        12,500  

Annual Management Resources and Compensation Committee Chair’s retainer

     22,500        N/A        22,500  

Annual Management Resources and Compensation Committee member’s retainer

     10,500        N/A        10,500  

Annual Nominating and Corporate Governance Committee Chair’s retainer

     22,500        N/A        22,500  

Annual Nominating and Corporate Governance Committee member’s retainer

     10,500        N/A        10,500  

Annual Health, Safety and Environment Committee Chair’s retainer

     22,500        N/A        22,500  

Annual Health, Safety and Environment Committee member’s retainer

     10,500        N/A        10,500  

Annual Risk and Sustainability Committee Chair’s retainer

     22,500        N/A        22,500  

Annual Risk and Sustainability Committee member’s retainer

     10,500        N/A        10,500  

Each Director is entitled to an annual travel allowance of $10,000.

Members of ad hoc committees of the Board receive meeting fees ($1,750 in-person meeting fee; $1,250 videoconference/ telephone meeting fee) for their participation in each committee meeting, but typically receive no annual retainer for being a member of an ad hoc committee because of the nature of the committee’s existence, having generally been established for a specific purpose and a temporary period of time. For further information on the Company’s committees, see Committees of the Board of Directors in the Statement of Corporate Governance Practices later in this Circular.

 

  EMERA INCORPORATED   29


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

TOTAL DIRECTOR COMPENSATION IN 2022

Compensation is made up of applicable retainers and the annual $10,000 travel allowance. The travel allowance was determined to not be payable to Directors in the first quarter of 2022 as a result of Directors not travelling due to the COVID-19 pandemic. Directors met in person in the second, third and fourth quarters of 2022 and, as such, earned a proportion of the travel allowance attributable to those quarters.

Mr. Balfour is not included in the table as his compensation for service as Emera’s President and CEO is disclosed in the Statement of Executive Compensation. He does not receive any additional compensation for his services as a member of the Board of Emera or as a member of the Board of any of Emera’s subsidiaries or investments.

In the table below, the columns under the headings “DSUs awarded” and “DSUs held” show detailed information about DSUs received by Directors as compensation.

Total Compensation

 

                                 DSUs awarded            DSUs held  

Director

   Fees earned
in 2022 ($) (1)
     All other
compensation
($)
     Total ($)      2022
Share-based
awards ($) (2)
     Value of DSUs
vested during
2022 ($) (3)
     Change in value
of DSUs held
in 2022 ($) (4)
    Market value
of total DSU
holdings ($) (5)
 

James Bertram

     293,034        N/A        293,034        293,034        289,932        (214,753 )      1,258,842  

Henry Demone

     293,034        N/A        293,034        160,000        215,793        (387,262 )      1,963,047  

Paula Gold-Williams (6)

     277,035        N/A        277,035        275,132        230,280        N/A       230,280  

Kent Harvey (6)

     339,400        N/A        339,400        339,400        320,964        (179,207 )      1,129,530  

Lynn Loewen

     293,534        N/A        293,534        293,534        359,337        (538,884 )      2,790,675  

John Ramil (6) (7)

     118,368        N/A        118,368        118,368        159,085        (362,326 )      675,862  

Ian Robertson

     245,534        N/A        245,534        243,547        202,453        N/A       202,453  

Andrea Rosen

     295,034        N/A        295,034        295,034        452,032        (968,527 )      4,821,821  

Richard Sergel (6) (8)

     319,910        12,993        332,903        160,000        202,622        (325,381 )      1,670,680  

Jackie Sheppard

     457,534        N/A        457,534        457,534        632,079        (1,178,049 )      5,947,179  

Karen Sheriff

     281,034        N/A        281,034        281,034        244,912        (50,227 )      471,535  

Jochen Tilk

     303,534        N/A        303,534        303,534        293,315        (189,519 )      1,148,399  

 

(1)

The “Fees earned in 2022” column is the amount of Directors’ fees, and includes the dollar value of that portion of their retainer paid in DSUs. All fees are in Canadian dollars.

(2)

This column shows the portion of Directors’ fees earned in 2022 that was allocated to DSUs. DSUs granted in 2022 are based on the value of the Emera common share closing price on December 31, 2021 of $63.22.

(3)

This column shows the value of all DSUs received in 2022, including received as dividend equivalents during the year, multiplied by the December 31, 2022 Emera common share closing price of $51.75.

(4)

This column shows the change in value of all DSUs held by each Director at the beginning of the year because of the change to the Emera common share closing price from $63.22 at the beginning of the year to $51.75 on December 30, 2022. Ms. Gold-Williams and Mr. Robertson joined the Board in February 2022, and therefore did not hold any DSUs at the beginning of the year.

(5)

This column shows the value of all DSUs held by each Director at the end of 2022 based on the December 31, 2022 Emera common share closing price of $51.75.

(6)

As US-domiciled Directors, the annual cash retainer, committee retainers, and travel allowance were paid to Ms. Gold-Williams, Mr. Harvey, Mr. Ramil and Mr. Sergel in US dollars, using a one-to-one conversion rate to the Canadian dollar.

(7)

Mr. Ramil retired from the Board on May 26, 2022. He redeemed 21,603 DSUs following his retirement in 2022, leaving a balance of 13,060 DSUs as of December 31, 2022.

(8)

Mr. Sergel also received compensation for serving as a Director of Emera US Holdings Inc.

The table above includes compensation earned by Emera Directors who served on the Board of Directors of Emera subsidiaries. What follows is more information about Emera’s Directors who served on the Boards of its subsidiaries.

 

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Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

COMPENSATION OF EMERA DIRECTORS ON OPERATING COMPANY BOARDS

The Emera Board of Directors, on the recommendation of the Nominating and Corporate Governance Committee (“NCGC”), determines the compensation to be received by Emera Directors who serve on the Boards of Emera’s subsidiaries. Such compensation received by each Emera Director that serves as a Director on the Board of an Emera operating company is reported under “All other compensation” and “Total” in the Total Compensation table on the previous page.

Mr. Sergel was a member of the Board of Directors of Emera US Holdings Inc., a US holding company that holds certain US-based investments of Emera. He receives an annual retainer of $10,000 USD for serving on the Emera US Holdings Inc. Board, plus $1,000 USD for any Board meetings.

DIRECTORS’ SHARE OWNERSHIP GUIDELINE

To align the interests of Directors and shareholders, the Directors are subject to a share ownership guideline (see Director Share Ownership Guideline in the Statement of Corporate Governance Practices) requiring them to own common shares and/or DSUs with a value of at least three times the annual Director’s retainer. This threshold for each Director is currently $757,500. The threshold ownership requirement for the Chair of the Board is currently $1,350,000. For the status of each Director nominee under the Director Share Ownership Guideline, see their biographies presented earlier in this Circular under Director Nominees Information.

DIRECTORS’ DSU PLAN

Under the Directors’ Deferred Share Unit and Share Purchase Plan (the “Directors’ DSU Plan”), non-employee Directors may elect to receive all or any portion of their cash compensation in DSUs in lieu of that cash compensation, subject to the requirement to receive a minimum portion of their annual retainer in DSUs and subject to the Emera Director Share Ownership Guideline.

Directors’ fees are paid on a quarterly basis and, at the time of each quarterly payment, the applicable amount is converted to DSUs. The number of DSUs to be credited is determined by dividing (a) the quarterly portion of the Director’s annual fee that the Director is required to receive in DSUs, together with the portion the Director elected to be paid in DSUs by (b) the fair market value of an Emera common share on the last trading day of the preceding calendar year, with fractions computed to three decimal places.

A DSU is a unit that has a value based upon the value of one Emera common share. When a dividend is paid on Emera’s common shares, the Director’s DSU account is credited with additional DSUs computed by dividing: (a) the amount obtained by multiplying the amount of the dividend declared and paid per common share by the number of DSUs recorded in the Director’s account on the record date for the payment of such dividend by (b) the market price of a common share as of the dividend payment date.

To further encourage Directors to acquire Emera shares, the Directors’ DSU Plan was amended in September 2022 to provide them with the opportunity to elect to receive market-purchased shares. Under the amended Directors’ DSU Plan, Directors may elect in advance to receive DSUs, common shares of Emera, or a combination of DSUs and shares, in lieu of their cash compensation. Any portion of a Director’s fees that the Director elects to receive in the form of shares would not be deferred compensation (as is the case when a Director receives fees in the form of DSUs) and, therefore, would be subject to applicable income tax withholdings. Thus, compensation net of tax withholdings would be used to purchase shares. Under the amended Directors’ DSU Plan, Directors may request that Company shares acquired on their behalf be (i) sold or (ii) withdrawn from the revised Directors’ DSU Plan and delivered in accordance with such Director’s instructions. Absent special instructions, the custodian would hold the shares in an account maintained by the custodian for the benefit of the Director. Any dividends earned on such shares would be automatically reinvested in shares acquired on the market and credited to the Director’s account.

 

  EMERA INCORPORATED   31


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

CERTAIN PROCEEDINGS

To the knowledge of the Company, none of the proposed nominees for election as Directors of the Company:

 

  (a)

Are, as at the date of this Circular, or have been, within 10 years before the date of this Circular, a director, chief executive officer or chief financial officer of any company that:

 

  (i)

Was subject to a cease trade order, an order similar to a cease trade order or an order that denied the relevant company access to any exemption under securities legislation that was in effect for a period of more than 30 consecutive days (an “Order”) that was issued while the proposed nominee was acting in the capacity as director, chief executive officer or chief financial officer; or

 

  (ii)

Was subject to an Order that was issued after the proposed nominee ceased to be a director, chief executive officer or chief financial officer and which resulted from an event that occurred while that person was acting in the capacity as director, chief executive officer or chief financial officer;

 

  (b)

Are, as at the date of this Circular, or have been within 10 years before the date of this Circular, a director or executive officer of a company that, while that person was acting in that capacity, or within a year of that person ceasing to act in that capacity, became bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency or was subject to or instituted any proceedings, arrangements or compromise with creditors or had a receiver, receiver manager or trustee appointed to hold its assets; or

 

  (c)

Have, within the 10 years before the date of this Circular, become bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency, or become subject to or instituted any proceedings, arrangement or compromise with creditors, or had a receiver, receiver manager or trustee appointed to hold the assets of the proposed nominee.

 

32   EMERA INCORPORATED  


LOGO

IN THIS SECTION:

34 STATEMENT OF CORPORATE GOVERNANCE PRACTICES

 

  EMERA INCORPORATED   33


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Governance at Emera

Emera’s commitment to strong governance forms the foundation of our business and our commitment to shareholders.

 

BOARD

COMPOSITION

 

•   Director Independence

 

•   Board and Committee Leadership

 

•   Director Recruitment

 

•   Board and Director Performance Assessments

  

STRATEGIC OVERSIGHT

 

•   Oversight of Strategy

 

•   Strategy and ESG

 

•   Committees of the Board

 

  

RISK MANAGEMENT

 

•   Oversight of Risk

 

•   Cybersecurity Oversight

  

ETHICAL

BUSINESS

CONDUCT

 

•   Culture of Integrity

 

•   Code of Conduct

 

•   Ethics Hotline

  

TRANSPARENCY

AND DISCLOSURE

 

•   Shareholder Engagement

 

•   Disclosure Policy and Practices

Statement of Corporate Governance Practices

 

Corporate governance at a glance
Emera’s Board of Directors annually reviews its approach to corporate governance. It monitors governance best practices, emerging trends of proxy advisors and other sources of governance thought leadership with a view to aligning Emera’s strategy with its governance practices to create and preserve long-term shareholder value. Details of Emera’s corporate governance practices may be found in this Statement of Corporate Governance Practices.

Governance highlights

  

For details see

Director Independence. All Emera Directors are independent from management except for Emera’s President and Chief Executive Officer.   

Director and Chair Independence

Page 36

Board and Committee Leadership. The Charter of the Chair of the Board of Directors and position descriptions for each of the Committee Chairs describe the roles and responsibilities for these leadership positions.   

Position Descriptions

Page 37

Director Recruitment. New Directors are recruited on the basis that they will make a strong contribution and have the background, diversity, skills and experience needed by the Board in view of the Company’s strategy and long-term business plans.   

Nomination of Directors and Director Recruitment Process

Page 38

Board and Director Performance Assessments. The Board annually assesses its performance and that of the Chair, individual Directors and the Board Committees.   

Board and Director Performance Assessments

Page 41

Director Compensation. The Company maintains compensation for Directors designed to recognize the substantial time commitment required to oversee management of the Company and to align Directors’ interests with the long-term interests of shareholders.   

Director Compensation

Page 43

Director Orientation and Ongoing Education. Directors receive an in-depth orientation when they become Board members. Regular site visits are organized for operating facilities and offices. Directors participate in virtual training and education on special topics by videoconference. In addition, special topics of focus or interest are addressed at Board dinners and meetings. Board members are encouraged to continue to pursue education opportunities of relevance to Emera and its business to familiarize themselves with the Company’s business, investments and key Company personnel.   

Orientation of Directors and Continuing Education for Directors

Page 45

 

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Governance highlights

  

For details see

Oversight of Strategy. The Board oversees the Company’s strategy and considers the Company’s strategic goals and objectives as part of all of its deliberations. Additionally, the Board reviews the Company’s strategic planning process and, on an annual basis, formally approves the Company’s strategic plan after considering, among other things, the opportunities and risks of the business.   

Strategic Oversight

Page 46

Strategy and ESG. In conjunction with the Board and Director assessment work, Directors reflect on strategy advancements over the year and recommend actions to be undertaken in the following year to carry out the strategy. Emera’s strategy incorporates Emera’s ESG priorities. As part of assessing the Company’s progress on its strategic goals and objectives, Emera monitors its ESG progress throughout the year.   

Strategic Oversight

Page 46

Committees of the Board. Five standing Committees assist the Board in carrying out its responsibilities: the Audit Committee; the Management Resources and Compensation Committee; the Nominating and Corporate Governance Committee; the Health, Safety and Environment Committee; and the Risk and Sustainability Committee. Ad hoc special committees are struck from time to time as needed for specific matters.   

Committees of the Board of Directors

Pages 36 and 55

Oversight of Risk. The Board and, on certain matters by delegation, its Committees oversee the Company’s risk management.   

Risk Management

Page 50

Cybersecurity Oversight. Cybersecurity risk and mitigation plans are overseen by the Board, with a report on the status of Emera’s cybersecurity program provided to the Risk and Sustainability Committee at each meeting.   

Information Security Oversight and Cybersecurity

Page 50

Culture of Integrity. Creating a culture of integrity begins with the tone at the top. Directors, Officers and employees are required to annually acknowledge that they have reviewed and understand the Emera Code of Conduct, which itself is overseen by the Nominating and Corporate Governance Committee. The MRCC reviews culture indices including employee surveys and other cultural metrics.   

Ethical Business Conduct

Page 52

Shareholder Engagement. Emera Directors are always interested in receiving shareholders’ views about the Company. Shareholders can communicate directly with the Chair of the Board or other independent Directors through private and confidential correspondence.   

Engagement

Page 54

Please read Emera’s entire Statement of Corporate Governance Practices on the following pages for additional important details about the Company’s governance practices.

 

  EMERA INCORPORATED   35


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

About Emera Inc.’s Board

BOARD OF DIRECTORS CHARTER

The Emera Board is responsible for overseeing the management of the business of the Company and for providing stewardship and governance for the long-term success of the Company.

The Board of Directors Charter (included in Appendix A) is reviewed annually and sets out the duties and responsibilities of the Board in the areas of:

 

  •  

Strategic Planning

 

  •  

Culture

 

  •  

Risk Responsibility

 

  •  

Leadership and Succession

 

  •  

Financial Performance

 

  •  

Corporate Communications and Public Disclosure

 

  •  

Governance Responsibility

OPERATING COMPANY GOVERNANCE

Emera’s operating subsidiaries also have robust and disciplined governance processes that have been developed to reflect Emera’s governance principles. In our largest operating subsidiaries, external, independent and local Directors are added to the operating company Board until they form a majority on the Board. Local Directors bring an additional connection to the community where the business is located.

The Chair of each operating company Board is elected in accordance with the operating company’s organizational documents and is typically Emera’s CEO or an Emera executive based on the CEO’s recommendation. Additional Emera and operating company executives may also be Directors but combined would typically form a minority of the Board. Emera’s operating companies seek to achieve and maintain a Board comprised of talented and dedicated Directors with a diverse mix of experience, skills and backgrounds.

As the parent holding company, Emera provides certain corporate-wide services to its operating companies. These corporate- wide services include safety, environment, compliance, internal audit, insurance, corporate security and treasury services. Enterprise-wide policies such as Emera’s safety management system are either expressly adopted by an operating company Board, or the impact is considered by Emera through consultation with the operating company, which may result in operating company specific adjustments.

COMMITTEES OF THE BOARD OF DIRECTORS

The Board of Directors has five standing Committees to assist it in carrying out its duties. They are the:

 

  •  

Risk and Sustainability Committee (“RSC”);

 

  •  

Audit Committee;

 

  •  

Management Resources and Compensation Committee (“MRCC”);

 

  •  

Nominating and Corporate Governance Committee (“NCGC”); and

 

  •  

Health, Safety and Environment Committee (“HSEC”).

From time to time, the Board may establish ad hoc committees to assist the Board on specific matters of a temporary nature. For the full text of the RSC, Audit Committee, MRCC, NCGC and HSEC Charters, visit www.emera.com/governance.

DIRECTOR AND CHAIR INDEPENDENCE

Ms. Sheppard, the Chair of the Board, is an independent Director. The Articles of Association of the Company require that the Chair of the Board and the President and CEO be separate individuals.

All Emera Directors are independent from management, except for Mr. Balfour, who is President and CEO of Emera. All of the Board Committees must be comprised entirely of independent Directors, except for the HSEC and the RSC, which are required to be majority independent.

 

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Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Use of the term “independent” in relation to a Director means a Director is independent as defined under applicable Canadian securities laws and, in particular, is free of any direct or indirect material relationship, which could, in the view of the Board of Directors, be reasonably expected to interfere with the Director’s independent judgment.

Except for Mr. Sergel, who receives a retainer for being a member of the Board of Emera’s subsidiary, Emera US Holdings Inc., Directors receive no other remuneration from Emera other than Directors’ retainers, fees or retainers for service as a Director or Chair of the Board or Chair or member of a Committee. Ms. Sheppard receives an all-inclusive annual retainer as Chair of the Board of Emera. As noted earlier in the Circular under the section Compensation of Directors in 2022, Mr. Balfour does not receive any additional compensation for his services as a member of the Board of Emera or as a member of the Board of any of Emera’s subsidiaries or investments, beyond his compensation as Emera’s President and CEO.

The Company’s Articles of Association provide that no more than two Directors may be employees of the Company or one of its operating companies. Mr. Balfour, as President and CEO of the Company, is the only Director employed by the Company.

POSITION DESCRIPTIONS

Chair of the Board

The Chair provides leadership to the Board, in order that it may fulfil its duties effectively, efficiently and independent of management. The Chair’s role is to ensure the Board and shareholder meetings function effectively. The Chair leads the Board discussions and represents the Board in providing additional advice and counsel to the President and CEO, and senior leadership. Under the leadership of the Nominating and Corporate Governance Committee, the Chair participates in the recruitment and retention of Directors and oversees appropriate processes to determine that the Board of Directors has the requisite skill sets needed by the Company. The Chair also leads the conduct of an annual assessment of the effectiveness of the overall Board and its members. The Board has adopted a Chair of the Board of Directors Charter which delineates the role of the Chair and their responsibilities. A copy of the Chair of the Board of Directors Charter can be found at www.emera.com.

Committee Chairs

The Board has adopted written position descriptions for each Committee Chair, which detail the duties of the Committee Chairs. Each Committee Chair is required to provide leadership to the Committee members and support the Committee’s effective fulfilment of its mandate. The position descriptions for each Committee Chair can be found at www.emera.com.

President and Chief Executive Officer

The President and CEO is responsible for leadership of the Company and its employees. He or she is responsible for defining, communicating and implementing the direction, goals and core values of the Company, including:

 

  •  

Leading the development of Emera’s vision and strategic plans;

 

  •  

Delivering Emera’s financial performance;

 

  •  

Developing senior leadership succession planning and development as detailed in the section later in this Circular entitled Succession Planning and Leadership Development; and

 

  •  

Managing Board relations.

The roles and responsibilities of the President and CEO are contained in his or her employment contract. The President and CEO’s employment contract is reviewed by the Chair of the Board of Directors and the MRCC, and is approved by the Board of Directors.

Among the various responsibilities of the Board, CEO selection is of critical importance. The Board oversees the succession planning program for the CEO.

BOARD SIZE

The Articles of Association provide that the number of Directors on the Company’s Board must not be less than eight and not more than 15. Eleven Director nominees are being proposed for election at the 2023 Annual Meeting.

 

  EMERA INCORPORATED   37


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

NOMINATION OF DIRECTORS AND DIRECTOR RECRUITMENT PROCESS

The NCGC is responsible for providing the Company with a list of nominees for election as Directors at the Company’s Annual Meeting of Shareholders. The NCGC develops a list of nominees after carefully considering the mix of skills and experience of its Directors and the feedback received through the Board Assessment. The NCGC also evaluates the size of the Board, and its diversity having regard to its Board Diversity Policy. This includes considering the level of representation of women and men on the Board. As a result of the recent amendment of the Board Diversity Policy, women and men must comprise not less than 40 per cent of the independent Board members.

To support the Board’s diversity objectives outlined in the Board Diversity Policy, during the process of identifying and considering the selection of qualified nominees for the Board, the NCGC will include active consideration of candidates on the basis of Indigenous heritage, and ethnic, racial or visible minority status, and other diversity characteristics. See the section in this Circular entitled Board Diversity for more information about Emera’s Board Diversity Policy.

Director nominees must, in the opinion of the members of the NCGC, be able to fully discharge their duties as Directors and contribute to the broad range of issues that come before the Board for consideration. They must be able to devote the time necessary to prepare for and attend meetings of the Board and Committees of the Board to which they may be appointed. The NCGC regularly evaluates the expected turnover of Directors in advance of their retirement from the Board and develops an effective succession plan.

Working with the Board Chair, the NCGC considers recruitment in the context of the age and tenure of current members and considers the Board’s overall policy of ensuring renewal and orderly Board succession.

The NCGC considers the likely potential tenure of a Director candidate before making a selection.

DIRECTORS’ MEMBERSHIP ON OTHER PUBLIC COMPANY BOARDS

Public company board membership for each Director nominee during the last five years is set forth in their biographies in the section entitled Director Nominees Information. Current Director Rick Sergel, who is retiring from the Board and is not standing for re-election, serves on the Board of Directors of State Street Corporation.

COMMON MEMBERSHIPS ON BOARDS OF PUBLIC COMPANIES

There are currently no Emera Directors who sit on the board of another public company with one or more other Emera Directors.

BOARD RENEWAL

The Board oversees processes for renewal of the Board, which balance many factors, and have as their ultimate objective the fulfillment of the fundamental responsibility of the Board to provide stewardship and good governance for the Company. Those processes address Board renewal in a deliberate manner and primarily include: a robust Director recruitment process, internal governance practices that regularly assess each of the Board’s desired skills, and the conduct of an annual performance assessment of the Board, its Committees and individual Board members. While Emera has no formal term or age limits for its Directors, absent certain circumstances as determined by the Board, in the normal course a Director would not be nominated who will be 72 years of age at the Annual Meeting of Shareholders or who has served as a Director for more than 15 years, in accordance with the Guideline on Board Tenure.

Emera’s governance practices prescribe that planned departures of Board members in any one year will not exceed two Directors. This practice contributes to Board renewal in a responsible manner while ensuring continuity.

A rigorous annual performance assessment takes place under the leadership of the Board Chair with support from the NCGC and is described in greater detail under Board and Director Performance Assessments. The annual performance assessment provides information that is relevant for Board renewal.

 

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Board Renewal Principles

When recommending the nomination of Directors for election, the NCGC members must consider certain principles:

 

Board renewal principle

  

Principle explained

Age    As Directors approach 70 years of age, the NCGC assesses the needs of the Board, based on the Board’s complement and other relevant factors. Where a determination is made that such Director will be retiring, the NCGC begins the replacement process.
Tenure    The length of time that a nominee has served on the Company’s Board of Directors is considered, subject to the Guideline on Board Tenure which established a general Director tenure guideline of 15 years, with a view to the Board having Directors with an appropriate mixture of tenures.
Average age    The average age of all of the Company’s Director nominees is determined and considered.
Average tenure    The average tenure of all of the Company’s Director nominees is determined and considered.
Other relevant factors    The NCGC considers any other factor Committee members determine to be relevant in the promotion of orderly succession and balanced renewal of membership on the Board, having as its ultimate objective the constitution of a Board of Directors that fulfills the fundamental responsibility of providing stewardship and good governance for the Company.

Application of Board Renewal Principles

The NCGC applied the Board renewal principles to the Director nominees for Emera’s 2023 Annual Meeting of Shareholders. In addition to the other Board renewal principles, the Committee considered the average age and average tenure of all the Company’s Director nominees for election at the 2023 Annual Meeting of Shareholders, as represented by the diagrams below.

 

 

LOGO

By comparison, the average age and average tenure of Directors in prior years was as follows:

 

Renewal principle

   2020      2021      2022  

Average age

     63.52 years        64.35 years        64.07 years  

Average tenure

     6.34 years        6.68 years        6.26 years  

In applying the Board Renewal Principles as described, the NCGC has recommended to the Board of Directors all the Director nominees presented earlier in this Circular under the Director Nominees Information section. It concluded the proposed slate of Directors represents an appropriate mix of longer-serving Directors with a history on the Emera Board, and Directors that are newer to Emera, who bring a fresh perspective and approach to the Company’s Board.

 

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   BOARD TENURE GUIDELINE
   In support of the Board Renewal Principles, the Board has established a general Director tenure guideline of 15 years. In applying this guideline when considering re-nominations for Directors, the NCGC shall take into consideration the needs of the Board at the time, the best interests of Emera given its strategic objectives and the results of the annual Board and Director performance assessment.
As of the date of Emera’s 2023 Annual Meeting, all but one of the Director nominees shall have served on the Board for less than 15 years.    Andrea Rosen joined the Emera Board in January 2007, over 16 years ago. While she has served on the Board for longer than the 15-year tenure of our guideline, the Board has determined that she be re-nominated for election as a Director based on the recommendation of the NCGC. The Committee considered a number of factors including the determination by other Board members that Ms. Rosen remains an effective independent member of the Board who continues to rigorously hold management to account as a Board and Committee member. Another factor considered was the contribution of her deep governance experience and financial expertise to the continuity and stability of the Board. This factor was regarded as important during a time of several changes to the Board, coupled with the impacts of the COVID-19 pandemic on Board meetings in the context of integration of newer Board members. Ms. Rosen, who is Chair of the NCGC, did not participate in the decision to make the recommendation of her nomination.

DIRECTOR’S OCCUPATION

The Directors have also instituted a policy that requires them to submit their resignation as a Director if there is a significant change in their principal occupation. The resignation is then considered by the Board, which determines if the circumstances warrant acceptance of the resignation, whether due to a conflict of interest arising by virtue of a new principal occupation or otherwise.

BOARD AND COMMITTEE MEETINGS IN 2022

There were 31 Emera Board and Committee meetings during 2022.

 

Type of meeting

   Number of meetings  

Board

     11  

Audit Committee

     5  

Health, Safety and Environment Committee (“HSEC”)

     3  

Management Resources and Compensation Committee (“MRCC”)

     3  

Nominating and Corporate Governance Committee (“NCGC”)

     5  

Risk and Sustainability Committee (“RSC”)

     4  

The Board and each Committee have adopted the practice of, each meeting, holding an in-camera session, during which the President and CEO and all other members of management are excluded. The Board and each Committee held an in-camera session at each meeting of the Board and each Committee meeting, respectively.

The Board generally holds an evening session before each regularly scheduled Board meeting and prior to the Board’s annual strategy meeting. As a governance practice, at least once a year, the independent Directors conduct such an evening session that excludes the President and CEO and all other management.

 

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BOARD AND DIRECTOR PERFORMANCE ASSESSMENTS

The Board annually assesses its effectiveness in an effort to improve its performance.

Each year, the NCGC, in consultation with the Board Chair, determines the process by which assessments of the Board, individual Directors, and Committees will be conducted in respect of their effectiveness and contribution. The process includes the use of questionnaires and one-on-one interviews with each Director by the Board Chair. A written report from the Board Chair on the assessment is provided to the Board members. The Board considers the report, its findings and a set of priority actions for the year at a Directors-only session, which is attended by the President and CEO for only a portion of the session. Progress is then monitored throughout the year with oversight on that process by the NCGC.

The NCGC determined in 2020 that while the traditional annual assessment process conducted by the Chair is robust and effective, from time to time the assessment process may be supplemented with the engagement of a third-party consultant to assist with the process of conducting the assessment in order to provide additional insights. While a consultant was engaged to assist with the 2020 Board and Director performance assessment, it was determined that it was not necessary to engage a consultant to assist with the 2021 or 2022 assessments.

2021 Assessment

Overall, the 2021 assessment found that the Board and Director performance and effectiveness were very strong. Board members take pride in the Company’s strong governance. The 2021 assessment resulted in several priority actions for 2022 in the areas of the Company’s strategy and business, its organizational structure and capacity and with respect to Board and Committee effectiveness. With the assistance of the NCGC, the Board Chair reviewed and reported to the Board on progress made in 2022 to address those priorities.

2022 Assessment

The Chair of the Board interviewed each non-executive Director as part of the 2022 Board and Director performance assessment. A series of questions was sent to each Director for advance consideration. The questions pertained to several themes, including:

 

  •  

Emera’s strategy and business;

 

  •  

Organizational structure and capacity;

 

  •  

Board and Committee effectiveness;

 

  •  

Corporate governance;

 

  •  

Board composition and succession;

 

  •  

Individual Director effectiveness, including the Director’s self-assessment of their own performance as a Director and an assessment of their peer Directors on the Board; and

 

  •  

The CEO’s 2022 evaluation, and his 2023 CEO goals and objectives.

The assessment of the Chair of the Board was conducted in a meeting of all Directors that excluded the Board Chair and the President and CEO and was led by the Chair of the NCGC. Directors were also given an opportunity to provide their assessment of the Chair of the Board in a one-on-one format with the Chair of the NCGC in advance of the meeting.

2022 Assessment Findings

The prevalent themes that emerged from the 2022 Board and Director performance assessment related to strategy and organizational capacity. We continued to advance our strategic thinking, our assessment of risk, and the Company’s organizational requirements to meet the strategic goals of the business. In light of the energy transition and evolving government policy, we examined their fundamental impact for our strategy, risks and organizational capacity, which will all be in focus for continuing assessment, discussion and strategic action in 2023. There will be a process and program in 2023 to address the implications.

All Directors believe the Board functions well from a governance perspective and exercises the right level of oversight. Board renewal will continue to be advanced in accordance with our governance practices and in alignment with the Board’s succession plan. Board members appreciate the additional diversity of thought brought by our newest Directors. They are pleased with the work of all Committees and, in particular, with the progress and work of the RSC, which was established in September 2021.

 

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2023 Objectives

While performing the Board and Director performance assessments, Directors assessed 2022 progress and proposed areas of future focus for 2023 as they relate to strategy and management performance. These included:

 

  •  

Execute our utility focused growth strategy by making the investments required to meet our customers’ demand for cleaner and reliable energy, delivered cost-effectively.

 

  •  

In the context of the energy transition and evolving government policy and incentives, look to capture incremental growth opportunities while continuing to identify and mitigate material risks.

 

  •  

Continue to strengthen the Company’s financial and credit metrics, thus maintaining Emera’s investment grade credit ratings and positioning the business for future growth and resiliency.

 

  •  

Managing the impact on costs, rate requirements and customer affordability arising from the energy transition as well as from general inflationary pressures.

 

  •  

Continue to assess and address potential organizational capacity requirements in the context of the energy transition.

 

  •  

Continue to bolster the depth and breadth of executive talent, and ensure clear short-, medium- and long-term management development and succession plans are in place across the business.

BOARD DIVERSITY

Emera believes that Board diversity is a strategic objective, leading to a broadening of perspectives in Board discussions, fostering more effective decision-making, and ultimately strengthening Board governance. Emera is focused on establishing and maintaining a Board with a diverse mix of experience, skills and backgrounds.

Emera’s Board has adopted a Board Diversity Policy (“Diversity Policy”) which sets out a framework for promoting diversity on the Board. The Diversity Policy was reviewed by the NCGC in February 2023, and the Board accepted its recommendation that it be amended to increase to 40 per cent (from 30 per cent) the minimum number of independent Directors who are women or men comprising the Board.

In accordance with the Diversity Policy, when identifying candidates for nomination to the Board, the NCGC will consider:

 

  •  

Emera’s diversity objectives. For more about diversity, equity and inclusion at Emera, see the Inclusion and Diversity section in this Circular.

 

  •  

The diverse nature of the business environment in which Emera operates.

 

  •  

The need to maintain flexibility to effectively address succession planning and ensure that Emera continues to attract and retain highly qualified individuals to serve on the Board.

 

  •  

The benefits of diversity of gender, age, Indigenous heritage, and ethnic, racial or visible minority status and other diversity characteristics among Board members.

 

  •  

With respect to gender diversity, the requirement that the minimum level of representation of women and men among independent Directors on the Board not fall below 40 per cent.

As provided for under the Diversity Policy, the NCGC annually discusses and reviews the effectiveness of the Diversity Policy and agrees on the relevant measurable objectives for promoting diversity on the Board. While progress has been made, the Board remains focused on continued promotion of diversity on the Board. The Diversity Policy can be found at www.emera.com.

Diversity is incorporated into the Board’s succession planning and recruitment processes in the following ways:

 

1.

When recruiting new Directors, the NCGC assesses the needs of the Board in the context of the mix of current Directors in terms of age, tenure, gender and other diversity characteristics as reflected in the Diversity Policy.

 

2.

The NCGC considers the Board renewal principles, anticipated retirements of Directors and the Board’s succession planning, balancing the need to maintain flexibility to ensure that Emera continues to attract and retain highly qualified individuals to serve on the Board.

 

3.

When implementing its responsibilities under the Diversity Policy, the NCGC will take into account Emera’s diversity objectives and the diverse nature of the business environment in which Emera operates.

 

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4.

On behalf of the Board, the NCGC periodically retains independent qualified recruiters to assist with Director recruiting by helping to identify candidates of diverse backgrounds. These recruiters are mandated to seek diverse candidates reflecting gender, age, Indigenous heritage, ethnic, racial or visible minority status and other diversity characteristics and who also reflect the skills and experience determined to be required by the NCGC following the assessments outlined in 1, 2 and 3 above.

The Board members voluntarily participate in an annual survey to provide self-identification data in support of the objectives in the Diversity Policy. Based on that survey:

 

  •  

One Director nominee identifies as having an ethnic, racial or visible minority status.

 

  •  

One Director nominee identifies as a member of the LGBTQ+ community.

 

  •  

Five Director nominees are women and six are men (including the CEO). This exceeds the minimum requirement of 40 per cent women or men independent Directors under Emera’s Diversity Policy.

 

  •  

None of the Director nominees identified as being of Indigenous heritage or persons having a disability.

 

 

LOGO

Operating Company Board Diversity

Emera has made significant progress in respect of diversity on our subsidiary boards. Of the 21 external directors that serve on the Boards of our four largest operating companies (Tampa Electric, Nova Scotia Power, Peoples Gas and New Mexico Gas), 47 per cent are female and 33 per cent are Black, Hispanic or Indigenous. Diversity on our operating company boards remains an ongoing focus.

DIRECTOR COMPENSATION

The NCGC makes recommendations to the Board on all components of non-employee Director compensation, including the Board Chair and Committee Chairs. For more information about Director compensation, see Compensation of Directors in 2022 earlier in the Circular.

Annual Review

The NCGC annually reviews the compensation of Directors to ensure it is appropriate.

The NCGC reviews the compensation practices of publicly traded companies similar in size and complexity to Emera to determine whether the Directors are appropriately compensated for the responsibilities and risks involved in being a member of the Company’s Board. The review is based upon publicly available information concerning Directors’ compensation and the advice of Mercer (Canada) Limited, a third-party compensation consultant.

The NCGC has adopted the 50th percentile as a target for Director compensation and has determined it would be appropriate for Emera to continue to position total compensation of Directors at approximately the median of its peer group, which is the average of the Canadian and United States sub-groups. The peer group used for Director compensation purposes is the same as the benchmarking comparator group used for senior executive compensation purposes and disclosed in the Statement of Executive Compensation later in the Circular.

 

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Based on the approach to Director compensation and on such annual review, the Board, on the recommendation of the NCGC, found Emera’s non-executive Board Chair and average Director are close to the 50th percentile of the comparator groups, and determined they did not see a need for any adjustment in Director compensation at this time.

Director Share Ownership Guideline

Director common share and DSU ownership is viewed by Emera as an important means of enhancing the alignment of Director and shareholder interests. Under Emera’s Director Share Ownership Guideline, each Director must own three times the total cash and equity-based annual Board retainer in Emera common shares or DSUs, or a combination of the two. New Directors must meet the ownership requirement of the Share Ownership Guideline within three years of joining the Board and are required to take 100 per cent of their compensation in DSUs until they have met the Share Ownership Guideline (Directors appointed before November 2022 have five years to meet the guideline).

Based on the annual cash ($92,500) and equity-based ($160,000) retainer compensation in effect for Emera Directors, each Director must own Emera shares or DSUs, or a combination of the two, worth $757,500. The ownership requirement for the Chair of the Board, based on the Chair’s annual cash ($225,000) and equity-based ($225,000) retainer compensation, is $1,350,000.

Details of each Director’s share and DSU ownership, and status under the Share Ownership Guideline, is shown in each Director nominee biography featured in the Director Nominees Information section of this Circular. All of Emera’s Director nominees are in compliance with the Share Ownership Guideline.

Directors Are Increasing Their Share/DSU Ownership Over Time

By virtue of the compensation payable in DSUs, more than 63 per cent of the annual retainer for Emera Directors will be paid in DSUs, which mirror the value of Emera common shares. The Directors increase their DSU ownership by at least $160,000 per annum. Most of the Director nominees have elected to receive DSUs in lieu of cash compensation they would otherwise be entitled to as Emera Directors.

MAJORITY VOTING FOR ELECTION OF DIRECTORS

The confidence of shareholders in the actions of the Board and management is important. In order to provide a mechanism for shareholders to express that confidence in each Director and in compliance with Subsection 461.3 of the TSX Company Manual, the Board has adopted a Majority Voting Policy for Directors.

 

Majority Voting Policy

Should a Director nominee, in an uncontested election at a meeting of shareholders of Emera Inc. at which Directors are to be elected, receive a majority of “withheld” votes from his or her election as a Director (a “Majority Withheld Vote”), the individual shall submit his or her resignation to the Board for consideration immediately following such shareholders’ meeting.

 

The votes determining a Majority Withheld Vote shall be the total votes cast by ballot by shareholders and proxyholders, or if a ballot vote was not conducted, shall be the total votes represented by proxies validly deposited prior to the shareholders’ meeting.

 

The Directors who received a majority “For” vote at the shareholders’ meeting shall consider whether or not to accept the resignation.

 

If there are less than three such Directors, the entire Board shall meet to consider the appropriate actions to be taken. The resignation of a Director who received a Majority Withheld Vote shall be accepted absent exceptional circumstances and is effective when accepted by the Directors. The determination shall be made within 90 days following the date of the shareholders’ meeting and a news release disclosing such determination shall be issued promptly following such determination. If the resignation is rejected, the news release shall include the reasons for rejecting the resignation. A copy of the press release shall be provided to the Toronto Stock Exchange.

Since the adoption of the Majority Voting Policy in 2008, all Director nominees have received a majority “For” vote at the Company’s meetings of shareholders.

 

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ORIENTATION OF DIRECTORS

In order to best bring their skills and experience to the operation of the Board, new Directors receive an in-depth orientation to the Company’s executive leaders, business, strategy, principal risks, financial information and governance practices. This allows them to effectively and efficiently step into their new role as Director and discharge the responsibilities of that role. The Board and management have built and continue to expand a long-term program of training and information sharing for Directors to enhance their effectiveness and reinforce a collegial working relationship among members of the Board.

Orientation sessions are attended by the President and CEO and other executive officers or leaders of key subsidiaries. The Chair also attends the orientation with a new Director. A reference manual is provided in advance of the session that includes:

 

  (a)

Recent annual and interim management’s discussion & analysis and financials, Management Information Circular and Annual Information Form;

 

  (b)

Board and Committee Charters;

 

  (c)

Strategic Plan and Business Plan and Budget;

 

  (d)

Guide to the Company’s management structure;

 

  (e)

Insider trading guidelines;

 

  (f)

Emera’s Code of Conduct; and

 

  (g)

Minutes of previous Board meetings.

CONTINUING EDUCATION FOR DIRECTORS

The Board, with the support and oversight of the NCGC, regularly seeks opportunities to update, educate and inform the Directors in areas they request or that management determines are relevant to issues facing the Company.

The Board and Committees receive regular presentations from Management updating Directors about market and industry conditions and trends that may impact the Company’s business and influence its strategy. Additionally, the Board aims to receive at least three specialized presentations on various matters of significance to the Company.

Annually, the Board has also been provided with opportunities to visit operational facilities to help Directors get to know leaders, understand management structure and more fully understand the business. Given the combination of the impact of the ongoing global COVID-19 pandemic in the first half of 2022 and the impact of Hurricane Fiona and Hurricane Ian and restoration efforts required following these weather events, the Emera Board postponed visits to operational facilities in the second half of 2022. Site visits of Emera’s Florida utilities are being scheduled for mid-2023.

Emera adopted a Guideline for Directors’ Attendance at Education Sessions, which is designed to encourage Directors to participate in education sessions from time to time that are directly related to the business of the Company and the performance of their duties as a Director of the Company. The Guideline provides that independent Directors who wish to attend an education session request the approval of the Board Chair to attend a particular education session and receive reimbursement of expenses in accordance with the Guideline. In 2022, Emera Directors participated in relevant education that included sessions presented by the Institute of Corporate Directors in Canada.

 

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Directors participated in education sessions and received education materials about specific topics in 2022, as follows below:

 

Topic

  

Date

  

Participants

Business and operations      
Rate Design    January    Board members
Capital Markets Update    May    Board members
Economic Overview    June    Board members
Climate Change Governance: Directors’ Duties    June    Board members
ESG Reporting    June    Board members
Gas Emergency Preparedness    September    HSEC members and Board Chair
Market trends and regulatory updates      
Climate Change    April    Board members
CSA and SEC Climate Change Disclosure Proposal    May    Audit Committee members and Board Chair

Presentation on Hydrogen Energy Generation Technology and Carbon Capture Technology

   June    Board members

A Presentation by EY with respect to ESG Impacts on Financial Reporting and Governance

   August    Audit Committee members and Board Chair
Executive Compensation and Governance Trends    September    MRCC members and Board Chair

The Board of Directors encourages, and the Company pays the out-of-pocket costs for, Directors to pursue education sessions provided by third parties that are related to the business of the Company and the performance of their duties as a Director of the Company.

STRATEGIC OVERSIGHT

Emera’s strategy is focused on driving growth and value for shareholders by investing to meet our customers’ demand for cleaner and reliable energy delivered as cost effectively as possible. Government policy, customer demand and technology advancements are driving rate regulated investments across our utility businesses in cleaner energy sources, system hardening and other reliability investments, and digital and other system and technology investments, in addition to investing to replace aging infrastructure as well as system expansion to meet new customer growth.

Led by the President and CEO, the Management team works with the Board to set the strategy agenda for the year. The Board and Management meet regularly to discuss strategy, including annual individual interviews with each Director.

A dedicated and significant component of every scheduled Board meeting includes an update and discussion on strategy and related matters, including trends in the industry, growth initiatives, financial forecast updates and new risks and opportunities. These updates serve to keep the Board aware of changes in the market, industry and within Emera, as well as giving the Board an opportunity to provide insight and direction throughout the year on strategy.

Each year, at least one Board meeting is wholly dedicated to corporate strategy. In 2022, the Board held a meeting in June that was entirely focused on strategy, with a focus in particular in the area of decentralization and on our digital strategy. A significant portion of the Board meeting in September was also dedicated to strategy. These meetings included the annual strategic update on industry trends including the company’s strategic positioning related to the customer-driven trends of decarbonization, decentralization and digitalization. They also included an updated long-term financial forecast, a review and analysis of industry peers, an overview of strategic signposts that management is regularly monitoring in its ongoing assessment and review of strategy, and updates on specific components of strategy.

Environmental, Social and Governance (“ESG”)

ESG is core to Emera’s strategy. Our Environmental commitments continue to be key drivers of our growth, and our approach to Social and Governance matters shapes Emera’s culture and how we operate.

 

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Strong ESG Governance

Strong ESG governance is the foundation of Emera’s ESG performance. In 2022, the Sustainability Management Committee (“SMC”) and Risk and Sustainability Committee (“RSC”) of the Board continued to guide our ESG performance. The SMC, consisting of senior leaders from across the business and chaired by our President and CEO, provides executive oversight of our sustainability function and ESG progress.

The role of the RSC is to assist the Board by overseeing Emera’s risk management framework and allocation of responsibilities for risk management, and by also overseeing the Company’s approach to sustainability and its performance relative to its sustainability objectives.

ESG Materiality and Disclosures

Emera is committed to transparency, accountability, understanding stakeholder expectations and improving disclosures on the material ESG priorities that matter most to stakeholders.

We draw on a range of resources to determine the most material risks and opportunities for our stakeholders and business. These resources include third-party materiality assessments, industry standards, guidance from our SMC and RSC as well as our Enterprise Risk Management (“ERM”) Program. Our assessment of materiality also considers best practice guidance from:

 

  •  

Global Reporting Initiative (“GRI”) Standards;

 

  •  

Sustainability Accounting Standards Board (“SASB”) Standards for Electric Utilities and Power Generators, and Gas Utilities and Distributors; and

 

  •  

Task Force on Climate-related Financial Disclosures (“TCFD”) Recommendations.

Material ESG Priorities

Emera has established a set of core ESG priorities that are regularly tracked by the SMC and have been formally integrated into Emera’s Enterprise Risk Management Program, which is overseen by the RSC.

ENVIRONMENT • Air emissions • CO2 emissions • Methane emissions • Climate adaptation • Coal unit closures • Low-carbon transition • Waste management • Water management • Biodiversity

SOCIAL • Community investment • Customer affordability • Diversity, equity and inclusion • Indigenous relations • Safety • Talent management • System reliability and grid resiliency

GOVERNANCE • Business ethics and transparency • Corporate governance • Cybersecurity • ESG governance • Political and regulatory requirements

Task Force on Climate-related Financial Disclosures (“TCFD”)

Emera has been aligning with TCFD for four years and is continually enhancing our climate disclosures, making it easier for our stakeholders to fully understand our plans for building a clean energy future. This ongoing alignment work is helping prepare us for the anticipated mandatory climate disclosures currently under consideration by certain North American securities regulators.

The four core TCFD elements that ground our climate disclosures include:

 

LOGO

 

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Climate Commitment and 2050 Net-Zero Vision

Building on its strong decarbonization track record, Emera is continuing its efforts with clear carbon reduction goals and a vision to achieve net-zero carbon emissions by 2050.

In 2022, we achieved a 41 per cent reduction in CO2 over 2005 levels. With existing technologies and resources and the benefit of supportive government and regulatory decisions, we are working to achieve the following goals compared to corresponding 2005 levels(1):

 

  •  

A 55 per cent reduction in carbon emissions by 2025

 

  •  

An 80 per cent reduction in carbon emissions by 2040

 

  •  

The retirement of our last existing coal unit no later than 2040

Emera seeks to achieve these goals and realize our net-zero by 2050 vision by adopting emerging technologies and working constructively with policymakers, regulators, partners, investors and our communities, while staying focused on enhancing reliability and seeking to minimize the cost impacts for customers. Emera tracks its progress towards achieving such goals using a Climate Commitment Tracking Tool it developed, which is managed and updated based on the work of its enterprise-wide Climate Commitment Tracking Committee, which meets regularly to assess such progress.

Inclusion and Diversity

Emera is committed to diversity, equity and inclusion (“DEI”) and these values are embedded throughout our business. We strive for a workplace that:

 

  •  

Reflects its communities and diverse customer base, enabling us to better understand the needs of our customers and the communities we serve;

 

  •  

Attracts, retains and engages diverse high-performing talent;

 

  •  

Builds inclusive leadership practices; and

 

  •  

Fosters better decision-making with the benefit of more diverse perspectives and experiences.

Emera and its operating companies are advancing a multi-year DEI Strategy:

 

  •  

Creating a Global Affiliate DEI Council to align and share best practices;

 

  •  

Continuing to celebrate, educate and communicate on DEI topics to bring awareness at all levels of the organization;

 

  •  

Supporting strong DEI employee networks and employee resource groups that build awareness and support across the business;

 

  •  

Adopting the Global Diversity, Equity, and Inclusion Benchmarks (“GDEIB”) to measure our progress;

 

  •  

Gathering employee self-identification data to measure our diversity and to reflect our communities;

 

  •  

Including questions on employee survey requesting feedback on diversity and inclusion; and

 

  •  

Connecting with communities to provide support through a $5 million fund to advance diversity and inclusion.

Gender Diversity and Women in Executive Roles

Management monitors and encourages the development and progression of women into leadership positions within Emera and its operating companies. Management believes that diversity among the senior executive team within the Emera group of companies serves the best interests of the Company, and the relative representation of women is considered when making

executive officer appointments. It is also critical that each selection of executive officers be made and be perceived to be made on the merits of the individual and the needs of the Company at the relevant time. With these considerations in mind, Emera has not yet set specific targets for the representation of women in executive officer positions. However, as part of our DEI journey, targets for the representation of women in executive officer positions are under consideration.

At Emera Inc., 11 individuals, representing 46 per cent of executive officers, are female. Across all Emera companies, an average of 25 individuals, representing 31 per cent of executive officers, are female. Among the executive officers(2) of Emera and its major subsidiary(3), Tampa Electric Company, 18 are female, representing 45 per cent (in 2022 there were 17 female executive officers, representing 37 per cent, and in 2021 there were 18 female executive officers, representing 39 per cent). Currently, three of our companies are led by women (Peoples Gas, Emera Energy, and Grand Bahama Power Company).

 

(1)

Achieving our climate goals on these timelines is subject to our regulatory obligations and other external factors beyond our control.

(2)

The term executive officer is defined under applicable securities law to mean the Company’s Board Chair, president, CEO, CFO, a vice president in charge of a principal business unit, division or function, or any person who performed a policy-making function in respect of the issuer.

(3)

“major subsidiary” refers to an Emera operating company of which the assets or revenue are 30 per cent or more of the consolidated assets or revenue of the Company as included in the financial statements of the Company for a relevant period. Only Tampa Electric Company meets this definition.

 

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Management continues to be focused on ensuring Emera’s hiring and pay practices promote equity between men and women. Progress is being made and we continue to be committed to:

 

  1.

Analyzing pay equity annually to:

 

  a.

Monitor the rates of women in leadership and senior leadership roles;

 

  b.

Undertake regular wage gap analysis to track progress and identify challenges by operating company;

 

  c.

Exercise selective pay increases if wage disparity exists; and

 

  d.

Examine our recruitment strategies to ensure equity in pay at entry into the organization.

 

  2.

Developing and promoting programs that are focused on increasing female participation in our industry, particularly for traditionally male-dominated roles.

 

  3.

Considering diversity in the development of talent pools to enhance our diversity for the future at all levels.

Our Commitment to Safety

Safety is Emera’s number one priority and we are committed to fostering a strong safety culture. Our goal is the elimination of serious injuries and fatalities (“SIFs”) across the Company.

Last year, we continued to improve our Total Recordable Incident Rate (OSHA) as well as the Lost Time Injury Rate, which were both below our five-year rolling average. However, we experienced a fatality. We believe one SIF is “one too many”, and we are relentlessly focused on pursuing a safety culture where all people return home safely to their families at the end of each workday.

In 2022, Emera implemented an energy-based hazard identification program to both employees and contractors that was focused on SIF prevention. Other program focus areas included contractor safety, safety leadership training, and behavioural aspects of safety management.

Operating an electric or gas utility comes with significant inherent risk. Therefore, using a best practice approach to mitigate safety risk is imperative. As a learning organization we continually strive to discover World Class best practice approaches and learn from all incidents. To this end, we regularly bring our collective organizations and contractors together to discuss issues and share ideas. Ultimately, we require that all operating companies and contractors continuously improve their practices to be the best they can be when it comes to safety.

In 2023, the Company continues to focus on contractor safety, safety leadership training, behavioural aspects of safety management, and improving hazard identification for all people associated with our work. It’s important that all people involved in our business care about safety and have the permission to only do something if they can do it safely.

It is noteworthy that in 2023 we will be completing the rollout of standardized HSE software across all operating companies to provide improved reporting and identify strategic focus areas.

Investing in Our Communities

Through Emera’s Community Investment Program, we are committed to supporting meaningful programs and initiatives in the communities where our employees live and work. Our program focuses on youth opportunities, innovation and safety. In 2022, Emera invested over $18 million in community initiatives in these areas and our employees volunteered over 31,532 non-working, self-reported volunteer hours to charitable organizations. In our Canadian businesses, employees reported approximately 6,200 volunteer hours through the Good Neighbour Program. These reported hours were “matched” with Emera donations to these organizations.

Within our program’s strategic focus areas, we consider opportunities through a lens of DEI. Recognizing the important value this lens adds, the Emera group of companies launched the $5 million DEI Fund in 2021. Together with our operating companies in 2022, Emera invested over $2 million to specifically support organizations and initiatives advancing inclusion and diversity in our communities.

To capture our community investment value and impact, Emera works with the London Benchmarking Group (“LBG”) Canada. The LBG model provides the global standard for reporting community investment, presenting a consistent and credible framework for impact measurement. You can read more about our community investment program on our website (www.emera.com/community).

 

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Information Security Oversight and Cybersecurity

Emera increasingly relies on information technology (“IT”) systems, as well as network and cloud infrastructure, to manage its business and safely operate its assets, including controls for interconnected systems of generation, distribution and transmission as well as financial, billing and other business systems.

Our reliance on technology exposes Emera to potential risks of business interruption or the unavailability, release, destruction or misuse of critical, sensitive or confidential information due to cyberattacks.

We seek to manage these risks by aligning to a common set of cybersecurity standards and policies derived, in part, from the National Institute of Standards and Technology’s Cybersecurity Framework, through periodic security testing, establishing program maturity objectives, by the development and updating of robust cybersecurity incident readiness and response programs, and by employee communication and training. With respect to certain of its assets, the Company is required to comply with rules and standards relating to cybersecurity and IT including, but not limited to, those mandated by bodies such as the North American Electric Reliability Corporation, Northeast Power Coordinating Council, and Department of Homeland Security.

The status of key elements of our cybersecurity program is reported to the Risk and Sustainability Committee on a quarterly basis and the Board receives reports on that work through the Risk and Sustainability Committee. In addition, the Board oversees the risk and mitigation plans in relation to these risks, as updated and reported quarterly in a risk dashboard provided to Directors at each regularly scheduled Board meeting.

Information Technology

Emera relies on various IT systems to manage its operations. This subjects Emera to inherent costs and risks associated with maintaining, upgrading, replacing and changing these systems. Emera’s digital transformation strategy, including investment in infrastructure modernization and customer focused technologies, is driving increased investment in IT solutions, resulting in increased project risks associated with the implementation of these solutions. Emera manages these IT risks through IT asset lifecycle planning and management, governance, internal auditing and testing of systems, and executive oversight. Highlights of Emera’s digital transformation strategy are reported to the Board annually.

Risk Management

The Emera Board has a comprehensive and multi-faceted approach to risk oversight and is responsible for overseeing risk. It is also responsible for overseeing the implementation by management of appropriate systems to identify, report and manage the principal risks of Emera’s business. It is responsible for overseeing the development of Emera’s risk management framework and allocation of responsibilities for risk management, which it does with support from the Risk and Sustainability Committee (“RSC”). The Board has endorsed a risk statement that articulates Emera’s risk appetite. The risk statement sets out the risk appetite across a number of areas and is intended to provide general guidance for decisions of the Company. The Board considers Emera’s risk profile and oversees Emera’s risk management by reviewing:

 

  (a)

The annual identification and assessment of the principal risks of Emera;

 

  (b)

The process for ongoing monitoring, updating and reporting of the principal risks of Emera;

 

  (c)

The effectiveness of Emera’s mitigation response to its principal risks; and

 

  (d)

The alignment of risk management with Emera’s risk profile, its strategy and its organizational objectives, including capital and resources allocation.

Further, a comprehensive and ongoing risk assessment is part of every major project the Company undertakes. The Board is also responsible for reviewing Emera’s annual insurance program and its uninsured exposure.

 

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Under the Board’s oversight, management undertakes a robust, in-depth analysis of certain of its top high-impact enterprise risks where teams identify and assess the likelihood and impact of the risk, and maturity of control systems, for a number of the Company’s major risks and identifies further opportunities for risk mitigation. Risks are categorized as primary, evolving or mature, and are tracked and reported on through a Risk Dashboard. Deeper risk assessments into certain principal risks are periodically undertaken, reported to the Board (through the RSC, or directly) and mapped to the oversight responsibilities of Board Committees for such risks as are within their respective Committee mandates. Each primary risk is rated as to its likely velocity of onset, which is used to develop mitigation plans and response protocols appropriate to such velocity rating. In addition, the Dashboard identifies risk interdependencies by identifying those risks which, if materialized, may then trigger the onset of other risks, as well as risks that may be triggered by the materialization of the initial risk.

The Board annually evaluates the operation and effectiveness of the Board of Directors, its Committees and the Chair of the Board. That evaluation includes consideration of whether the Board has examined the key risks to the Company’s strategy and business plan. It also invites suggestions for improving the risk management process. More information about this process is included under Board and Director Performance Assessments in the Circular.

The Board has delegated certain risk oversight to the Committees as set forth in their Charters. Notwithstanding such delegation, the Board retains its oversight function and ultimate responsibility for these delegated functions.

Risk and Sustainability Committee (“RSC”)

The Board of Directors established the RSC in September 2021. The RSC is responsible for assisting the Board in carrying out its risk and sustainability oversight responsibilities and includes oversight of the Company’s Enterprise Risk Management framework, including the identification, assessment and monitoring of enterprise risks. It also includes the responsibility for oversight of the Company’s approach to sustainability and its performance relative to its sustainability objectives. The RSC risk mandate includes the oversight of cybersecurity risk.

Management Resources and Compensation Committee (“MRCC”)

The MRCC is responsible for evaluating the compensation programs to determine that they do not reward executive officers for taking inappropriate risks that may harm the interests of the Company and its shareholders. The MRCC conducts a compensation risk review annually to ensure that the compensation policies are designed to take account of and mitigate (a) the incentive opportunities that inadvertently encourage excessive and unnecessary risk-taking, (b) pay structures that inadvertently encourage behaviour that destroys or diminishes long-term value, (c) a lack of appropriate alignment between pay and performance, and (d) payouts that are not aligned with Emera’s business strategy. In respect of succession risk, the MRCC also supports and contributes to the Board’s succession planning process in respect of the President and Chief Executive Officer of the Company, and annually reviews the succession planning process for senior management and other potential senior management candidates, including its subsidiaries, and oversees and contributes to that process.

Audit Committee

The Audit Committee of the Board of Directors assists the Board in discharging its oversight responsibilities concerning the integrity of Emera’s financial statements, its internal control systems, the internal audit and assurance process, the external audit process and its compliance with legal and regulatory requirements. The Audit Committee has oversight responsibilities for trading and credit risk. It receives the annual update on trading and credit risk activities, and reports to the Board.

Health, Safety and Environment Committee (“HSEC”)

The HSEC reviews actions taken by the Company to identify and manage risks related to health, safety and environmental matters that may have the potential to adversely impact the Company’s operations, customers, employees, strategy or reputation.

 

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Ethical Business Conduct

The Board is committed to sustaining a culture of integrity and ethical business practices throughout the Company.

CODE OF CONDUCT

The Board promotes a culture of ethical business conduct and has implemented annual Code of Conduct (“Code”) training for all employees to support compliance and requires Directors, officers and employees of Emera and its subsidiaries to acknowledge they have read, understand, are currently in compliance with and agree to comply with our Code when they join the Company, and annually thereafter. In addition, Emera and its subsidiaries expect each of its contractors, suppliers, business partners, consultants and agents to act in a manner consistent with the Code.

The Code is available on Emera’s website at www.emera.com/governance, or a copy may be obtained by contacting the Chief Human Resources Officer, Emera Inc., P.O. Box 910, Halifax, Nova Scotia B3J 2W5.

The Board regularly reviews the Code and makes revisions to update the content in keeping with best practices. Individuals are encouraged under the Code to, in good faith, seek advice, raise concerns, and report suspected misconduct related to Emera’s business. Emera will not tolerate retaliation, threats of retaliation, termination from an Emera Company, or discrimination that is directly or indirectly related to the good faith disclosure of suspected unethical activities or violations of laws, regulations or policies.

The Board monitors compliance with the Code of Conduct, including as detailed in Related Party Transactions. In addition, the Board has oversight of the Company’s Ethics Hotline in the manner described below.

RESPECTFUL WORKPLACE

The Code is supported by other key policies including Emera’s Respectful Workplace Policy. The Respectful Workplace Policy applies to all Directors, officers and employees of Emera and its subsidiaries and is focused on providing a respectful and inclusive environment that is free from discrimination, harassment, sexual harassment, and bullying in the workplace and such conduct outside the workplace that contributes to a hostile work environment.

Comprehensive mandatory training is required when an employee joins the Company which includes modules on harassment, sexual harassment, discrimination and bullying, and outlines available resources for employee support or to raise concerns. In addition, the Respectful Workplace Policy is included as part of annual Code training.

ETHICS HOTLINE

The Company has established a confidential and anonymous Ethics Hotline hosted by an independent external service provider. The Ethics Hotline is available to employees, contractors and third parties to report allegations of non-compliance with the Code. The internal audit department (“Audit Services”) is responsible for administering the Ethics Hotline process and ensuring all reports are investigated by the Company. Committees of the Board receive periodic updates on Hotline reports that fall within the scope of the Committee’s mandate based on the nature of the matter. For example, the Audit Committee receives updates related to financial reporting, accounting, auditing and business integrity matters; the MRCC receives updates related to people, wellness and workplace culture matters; and the HSEC receives updates related to safety and environment matters.

CORPORATE DISCLOSURE POLICY

The Board has approved a Disclosure Policy to ensure that communications to investors and potential investors are timely, factual and accurate, and that the information is disseminated in accordance with all applicable legal and regulatory requirements to the investing public, analysts and the media. For the full text of the Corporate Disclosure Policy, visit www.emera.com/governance.

CONFLICTS OF INTEREST

Directors are required to declare any conflict of interest that they may have in a matter before the Board. In any matter requiring approval of the Board, a Director is prohibited by the Company’s Articles of Association from voting in respect of the matter in which the Director is interested.

 

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RELATED PARTY TRANSACTIONS

Transactions between Emera and related parties are monitored in several ways to determine that such transactions comply with applicable laws, regulatory rules, and Emera’s Code. In particular:

 

  •  

The Audit Committee oversees the disclosure in Emera’s financial statements of related party transactions that are required to be disclosed pursuant to United States Generally Accepted Accounting Principles. In the ordinary course of business, Emera provides energy and other services and enters into transactions with its subsidiaries, associates and other related companies on terms similar to those offered to non-related parties. All material amounts are under normal interest and credit terms. Additional disclosure is provided in Emera’s financial statements regarding more significant transactions between Emera and its associated companies.

 

  •  

Under Emera’s Articles of Association, any Director who has an interest in a transaction with the Company must disclose the existence and nature of the interest to the Board of Directors and such Director may not participate or vote on the matter.

 

  •  

Under Emera’s Code, Directors, officers and employees of Emera cannot own more than a 10 per cent interest in, or act in the capacity of a director, officer, partner, consultant, employee or agent for a supplier, contractor, sub-contractor, Emera customer, competitor or any other person or organization with which Emera has a similar relationship, without the express prior approval of Emera’s President, Board Chair or its Board of Directors, as the case may be. They must also seek similar approval when a company, partnership or business in which they, or a member of their family, own more than a 10 per cent interest, or in which they are a director, partner, officer, consultant, employee or agent seeking to do business with Emera.

 

  •  

Also, as described in Emera’s Code, Emera’s operating companies are regulated by several Canadian, US and Caribbean energy regulators. Certain of these regulators have imposed specific codes and standards of conduct that address matters such as undue discrimination and preferential treatment between regulated companies and their affiliates. These rules may apply to and restrict arrangements between operating companies to conduct business or share employees. Emera’s operating companies have created separate codes and standards of conduct addressing these matters. Directors, officers and employees are required by the Code to be aware of, and comply with, these operating company rules at all times.

 

  •  

The NCGC oversees the management of any conflicts of interest or potential conflicts of interest involving Directors.

The Audit Committee is responsible for annually receiving and reviewing a report on executive officers’ compliance with the Code and receives quarterly reports on the Company’s ethics program, including reports received through the Ethics Hotline (see Ethics Hotline, above) or submitted directly to the Company’s Audit Services group.

TRANSPARENCY AND DISCLOSURE

Disclosure Policy and Practices

The Board has adopted a Disclosure Policy to ensure all communications of material information to the investing public about the Company are accurate, that they fairly present in all material respects the Company’s financial condition and its results of operations and are made on a timely basis.

Emera has established an executive Disclosure Committee responsible for overseeing the Company’s disclosure practices. The Company’s CEO and CFO, the leaders of its businesses, and senior management responsible for legal, finance, investor relations, and communications functions are members of the Disclosure Committee, which meets at least quarterly. Members of the Disclosure Committee are responsible for reviewing all core disclosure documents containing material information, including the Company’s management’s discussion and analysis and financial statements prior to their being presented to the Audit Committee and Board for approval. The Disclosure Committee is responsible for taking reasonable measures to ensure the education of Directors, officers and employees about disclosure issues and the Disclosure Policy. The Disclosure Policy defines the Company’s designated spokespersons and outlines the role of employees in Company disclosure. It also defines procedures for contact with analysts, investors and the media and guidelines for the disclosure of forward-looking information in continuous disclosure documents, speeches and conference calls.

 

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Engagement

Emera has a mature and robust program of engaging with financial analysts, investors and other stakeholders through direct meetings, investor events, quarterly analyst calls and other initiatives. In 2022, Emera’s executives met with many of the Company’s shareholders, including nearly all of Emera’s active top 20 investors. An investor day is targeted to be held every 12 to 18 months, most recently on March 2, 2023. Shareholders can also participate in our annual meeting via live webcast. Directors receive detailed reports on the shareholder engagement activity by management at each regularly scheduled meeting of the Board.

The Directors are interested in shareholders’ views about the Company, its governance and its operations. The Board oversees systems for receiving feedback from shareholders and it monitors feedback received by the Company.

 

Shareholders are encouraged to provide feedback to management and/or the Board

  

Contact information

To reach management:   

•   President and CEO

   Email: Scott.Balfour@emera.com

•   Chief Financial Officer

   Email: Greg.Blunden@emera.com

•   Chief Risk and Sustainability Officer

   Email: Bruce.Marchand@emera.com

•   Corporate Secretary

   Email: Stephen.Aftanas@emera.com
To reach the Board: (1)   

•   Chair of the Board

   Email: info@emera.com

•   Chair of a Committee

   Email: info@emera.com

 

(1)

Confidential communications with the Chair of the Board or another Board member should be mailed to the address below marked “Private and Confidential”.

The Board Chair and other Directors engage with shareholders upon request. In 2022, the Board Chair along with members of management met with one of our largest shareholders. The meeting’s discussion topics included Emera’s corporate governance practices and disclosure, Board oversight of risk and the Company’s approach to sustainability and ESG.

The Board recognizes that shareholder engagement is an evolving practice and plans to review its practices annually with a view to enhancing their effectiveness.

 

Shareholder engagement process

  

Contact information

Shareholders may communicate with the Chair of the Board or other independent Directors by sending them a letter using regular mail or other means of delivery. If the envelope is marked “Private and Confidential”, it will be delivered, unopened, to the Chair of the Board of Directors, or such other independent Director to whom it is addressed.   

Attention: Chair of the Board of Directors of Emera Inc. (or Name of Independent Director)

P.O. Box 910, Halifax, Nova Scotia B3J 2W5

in a sealed envelope marked “Private and Confidential”

Shareholder Proposals

Shareholders can submit proposals to be considered at an annual meeting of the Company provided they are duly submitted in advance and included in the Management Information Circular for the meeting. A shareholder intending to submit a proposal for consideration at an annual meeting must comply with the applicable provisions of the Nova Scotia Companies Act and the Company’s Articles of Association (“Articles”). This includes compliance with the requirements for Director nominations contained in the Articles where the proposal includes a nomination for the election of an individual to the Board of Directors. In accordance with and subject to the requirements of the Companies Act, the Company will include a shareholder proposal in its Management Information Circular prepared for an annual meeting provided such proposal was received by the Company at least 90 days before the anniversary date of the previous annual meeting and provided such proposal is required by the Companies Act to be included in such Management Information Circular. Regardless of whether you are submitting a proposal, the nomination of Directors is still subject to compliance with the Articles, which require notice of the nomination not less than 30 days prior to the date of the annual meeting. Should you have any questions about shareholder proposals or Director nominations, please contact Emera’s Corporate Secretary using the contact information in the Notice of Meeting at the beginning of this Circular.

 

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Committees of the Board of Directors

 

RISK AND SUSTAINABILITY COMMITTEE (“RSC”)

Jochen Tilk (Chair)

Lynn Loewen

Ian Robertson

Karen Sheriff

  

ROLE OF THE RSC

 

The role of the RSC is to assist the Board with the matters relating to risk and sustainability and making recommendations to the Board as appropriate.

 

The Committee oversees Emera’s risk management framework and allocation of responsibilities for risk management. It does this by receiving and reviewing with management:

 

(a)   The Company’s Enterprise Risk Management function, governance and the program framework that management employs to identify, assess, monitor and manage enterprise risk;

 

(b)   The quarterly Risk Dashboard and Heat Map to assess whether the appropriate key enterprise risks have been identified and are being addressed;

 

  

(c)   The Company’s assessments of identified High-Impact Risks and its prevention and mitigation strategies and plans to address them;

  

(d)   The Company’s Risk Statement;

  

(e)   The annual report of the Company’s insurance risk transfer program;

  

(f)   The quarterly reports on the Company’s cybersecurity program; and

  

(g)   Periodic reports on the Company’s business continuity programs.

   The Committee also oversees the Company’s approach to sustainability and its performance relative to its sustainability objectives. To do this, it:
  

(a)   Reviews the sustainability governance and program framework and policies that management employs to monitor, manage and report on sustainability risks;

  

(b)   Receives and reviews periodic reports of management’s Sustainability Management Committee on the status of material sustainability risks identified by that Committee;

  

(c)   Receives and reviews the Company’s annual Sustainability Report;

  

(d)   Reviews and, where appropriate, recommends to the Board, management’s proposed public sustainability commitments; and

  

(e)   Monitors and reports to the Board on emerging sustainability risks and trends.

   ACTIVITIES OF THE RSC IN 2022
   The RSC held four meetings in 2022 and, in accordance with its mandate, performed the following key functions:
  

1.  Reviewed the Committee’s Charter and revised its annual work plan reflecting the Committee’s mandate as set forth in the RSC Charter;

  

2.  Received and reviewed regular cybersecurity updates;

  

3.  Reviewed Emera’s Risk Management Governance Framework;

  

4.  Received and reviewed the Risk Dashboard and Heat Map, which captures the major enterprise risks, as determined by management, and provides an assessment of the potential likelihood, impact, interdependencies and velocity of each risk, together with a summary of the mitigation strategy and mitigation plans for each;

 

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5.  Oversaw changes to the Risk Dashboard and Heat Map, reviewed the mapping of the oversight responsibility for each such enterprise risk to a Committee of the Board of Directors or the Board itself;

  

6.  Reviewed plans to conduct deep dives into selected high-impact risks;

  

7.  Reviewed emerging risks;

  

8.  Received and reviewed an annual insurance report;

  

9.  Reviewed Emera’s sustainability governance and program framework;

  

10.  Reviewed Environmental, Social and Governance (“ESG”) reports, oversaw Emera’s progress on key ESG matters and reviewed identified ESG trends;

  

11.  Received and reviewed a Climate Commitment tracking tool, which tracks the Company’s progress on our climate goals and legislative requirements;

  

12.  Reviewed for comments the draft 2021 Emera Sustainability Report;

  

13.  Oversaw the conduct of Director education sessions on climate change science, climate change governance and ESG disclosure requirements; and

  

14.  Received a summary of proposed securities regulations respecting new mandatory disclosure of climate-related matters.

AUDIT COMMITTEE   

Kent Harvey (Chair)

Lynn Loewen

Ian Robertson

Paula Gold-Williams

Andrea Rosen

Richard Sergel

  

ROLE OF THE AUDIT COMMITTEE

 

The Audit Committee assists the Board in discharging its oversight responsibilities concerning the integrity of Emera’s financial statements, its internal control systems, the internal audit and assurance process, the external audit process and its compliance with legal and regulatory requirements.

 

The Committee is responsible for reviewing and recommending to the Board the annual and interim financial statements and all related management’s discussion and analysis.

   The Committee evaluates and recommends to the Board the appointment of the external auditors and the compensation of such external auditors. Once appointed, the external auditors report directly to the Committee, and the Committee oversees the work of the external auditors concerning the preparation or issuance of the Auditors’ reports or the performance of other audit, review or attest services for Emera.
   The Committee reviews and discusses Emera’s major financial risk exposures and the policy steps management has taken to monitor and control such exposures, including the use of financial derivatives, hedging activities, credit and trading risks.
   The Committee reviews management controls and processes concerning the administration of investment activities, financial reporting, and financial performance and funding of the pension plans. The Company’s lead internal auditor also reports directly to the Audit Committee, and the Committee approves the appointment, removal and replacement of the lead internal auditor, and approves the remuneration of the lead internal auditor on appointment.

 

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  ACTIVITIES OF THE AUDIT COMMITTEE IN 2022
  The Audit Committee met five times in 2022. In accordance with its mandate set forth in the Audit Committee Charter, the Audit Committee performed the following key functions in 2022:
 

1.  Regularly received and reviewed updates on accounting and disclosure issues;

 

2.  Reviewed developments in securities regulation and financial oversight;

 

3.  Received and reviewed an annual credit and market price risk report;

 

4.  Received and reviewed an annual tax update;

 

5.  Reviewed and approved an external auditor hiring policy formalizing its policy on hiring present or former employees of its external auditors;

 

6.  Received and reviewed an annual report and quarterly reports of the Chief Compliance Officer;

 

7.  Reviewed quarterly reports of material litigation;

 

8.  Reviewed and recommended to the Board of Directors for approval the audited 2021 year-end financial statements;

 

9.  Reviewed and approved interim financial statements, management’s discussion and analysis, and press releases;

 

10.  Oversaw the CFO’s quarterly reports on the Company’s financial results and forecasts;

 

11.  Oversaw the work of management’s Disclosure Committee;

 

12.  Received and reviewed regular reports by management about the Company’s compliance program under National Instrument 52-109 and Sarbanes-Oxley Act;

 

13.  Oversaw quarterly reports of Internal Audit Services and reviewed quarterly reports on the Company’s Ethics Program, including fraud investigations, delivered by the Senior Director Auditor Services;

 

14.  Reviewed and approved the assurance and advisory plan, including resource structure and budget for the Audit Services function;

 

15.  Reviewed pension plan performance in 2021;

 

16.  Performed a comprehensive review of the external auditors using the guidance provided for such reviews published by the Chartered Professional Accountants Canada, the Canadian Public Accountability Board and the Institute of Corporate Directors;

 

17.  Reviewed the 2022 Audit Plan of the external auditors, Ernst & Young, LLP (“EY”);

 

18.  Reviewed and approved the 2023 audit and non-audit services fees of EY;

 

19.  Reviewed the Senior Director of Audit Services 2021 Performance Evaluation;

 

20.  Reviewed Emera’s Ethics Escalation, Investigation and Reporting processes; and

 

21.  Reviewed the Audit Committee Charter and Work Plan, and recommended amendments to the Charter that were reviewed by the Nominating and Corporate Governance Committee and then were approved by the Board of Directors. Revisions to the Work Plan were also approved by the Committee reflecting amendments to the Charter.

 

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HEALTH, SAFETY AND ENVIRONMENT COMMITTEE (“HSEC”)

James Bertram (Chair)

Paula Gold-Williams

Kent Harvey

Lynn Loewen

  

ROLE OF THE HSEC

 

The purpose of the HSEC is to assist the Board in carrying out its responsibilities relating to oversight and coordination of Emera’s health, safety and environmental programs, and making recommendations to the Board as appropriate.

 

The Committee’s role is to review the performance of the Company on health, safety and environmental matters, including the Company’s compliance with legislation, and conformance with industry standards and best practices. It reviews emergency response plans and programs.

 

The HSEC oversees the Company’s health, safety and environmental systems and policies. It reviews actions taken by the Company to identify and manage risks. This oversight extends to Emera’s subsidiaries.

   Any significant safety or environmental incidents respecting the Company’s assets or operations will be reviewed by the HSEC, including those involving personnel safety, contractor safety, public safety or environmental damage. The Committee oversees management’s response to any significant regulatory findings, orders, reports and/or recommendations related to health, safety and the environment.
   ACTIVITIES OF THE HSEC IN 2022
   The HSEC met three times in 2022 and, in line with its mandate, undertook the following key activities:
  

1.  Reviewed Emera’s Occupational Safety & Health Policy Statement;

  

2.  Received and reviewed regular reports on the environmental performance of Emera’s businesses;

  

3.  Received and reviewed an update on the impact of the COVID-19 pandemic and the status of Emera’s response plan, workplace re-entry plan and related data on vaccination and testing;

  

4.  Received and reviewed regular reports on the safety performance of Emera’s businesses;

  

5.  Oversaw Emera’s health, safety and environmental auditing program;

  

6.  Received and reviewed regular reports on safety and environmental incidents, including root cause analysis and corrective action plans;

  

7.  Oversaw changes in the organizational structure of Emera’s safety and environment team to create efficiencies and enhance accountability;

  

8.  Received and reviewed a report on enterprise risks within the oversight responsibility of the HSEC;

  

9.  Received and reviewed an overview of Emera’s Gas Operations Management System;

  

10.  Reviewed the safety and environment objectives and measures for the Company’s 2022 incentive compensation Scorecard;

  

11.  Reviewed the emergency response plans and programs for Emera and its businesses;

  

12.  Received an overview of Emera’s Ethics Escalation and Investigation Procedures; and

  

13.  Reviewed the HSEC Charter and Work Plan.

 

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MANAGEMENT RESOURCES AND COMPENSATION COMMITTEE (“MRCC”)

Henry Demone (Chair)

James Bertram

Jochen Tilk

Karen Sheriff

  

ROLE OF THE MRCC

 

The Committee reviews overall compensation, including salary and benefits policies, and recommends such policies to the Board of Directors for approval.

 

The MRCC supports the Chair of the Board in conducting a review of corporate goals and objectives relevant to the President and CEO’s compensation and supports the Chair of the Board in recommending such goals and objectives for the current year to the Board of Directors. The Committee ensures that an assessment of the President and CEO’s performance in relation to these goals and objectives is completed. It makes recommendations to the Board of Directors relating to the President and CEO’s total compensation, including participation in incentive compensation and equity-based plans. It also makes recommendations about senior management’s total compensation and incentive compensation plans and equity- based plans. It approves grants of stock options, performance share units (“PSUs”), restricted share units (“RSUs”) and deferred share units (“DSUs”) in accordance with the provisions of the respective plans. It reviews executive compensation disclosure prior to the Company releasing such information to the public.

   The Committee recommends executive officer appointments to the Board of Directors for approval. It supports and contributes to the Board’s succession planning process in respect of the President and CEO of the Company. It annually reviews the succession planning process for senior management and other potential senior management candidates, including for Emera’s subsidiaries, and oversees and contributes to that process. It reviews share ownership guidelines for executive officers. It satisfies itself that there are appropriate labour relations strategies in place and it regularly reviews management’s direction and decisions made in support of labour and employee relations. It also reviews the design of pension plans for the Company’s employees.
   The MRCC is responsible for evaluating the compensation programs to determine that they do not reward executive officers for taking inappropriate risks that may harm the interests of the Company and its shareholders. Under its Charter, the Committee must conduct a compensation risk review annually to ensure that the compensation policies are designed to take account of and mitigate:
  

(a)   incentive opportunities that inadvertently encourage excessive and unnecessary risk-taking;

  

(b)   pay structures that inadvertently encourage behaviour that negatively impacts long-term value;

  

(c)   misalignment of pay and performance; and

  

(d)   payouts that are not aligned with Emera’s business strategy.

   ACTIVITIES OF THE MRCC IN 2022
   The MRCC met three times in 2022 and in accordance with its mandate, performed the following key functions:
  

1.  Reviewed the 2021 Scorecard results for Emera and its operating companies and recommended approval by the Board of Directors;

  

2.  Reviewed executive performance in 2021 and recommended 2022 executive compensation to the Board of Directors;

 

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3.  Reviewed and recommended Emera’s 2022 Corporate Scorecard to the Board of Directors;

  

4.  Reviewed operating company Scorecards for 2022;

  

5.  Reviewed and approved long-term incentive plan payouts in respect of 2021 and grants for 2022;

       

6.  Reviewed and recommended to the Board of Directors for approval amendments to the Senior Management Stock Option Plan, the Performance Share Unit Plan and the Restricted Share Unit Plan to provide for a new definition of regular retirement and introduce a definition for early retirement based on market practice; allow for full continued vesting of outstanding long-term incentive awards for regular retirement and prorated payments for early retirement; and increase the vesting schedule for stock options from four to five years;

  

7.  Reviewed and recommended to the Board of Directors for approval amendments to the Executive Deferred Share Unit (“DSU”) Plan removing the ability to settle in shares of Emera and updating the DSU redemption process to provide more flexibility for participants;

  

8.  Reviewed and recommended to the Board of Directors for approval amendments to the Employee Common Share Purchase Plan to clarify the plan’s operation;

  

9.  Oversaw the establishment of a program providing for RSU grants to significant contributors;

  

10.  Reviewed and recommended to the Board of Directors the 2022 compensation of the CEO;

  

11.  Received and reviewed updates on trends in executive compensation and an analysis of gender equity within Emera;

  

12.  Reviewed reports on Emera’s talent strategy and on managing talent risk;

  

13.  Reviewed an annual compensation design risk assessment;

  

14.  Oversaw compensation related disclosure in Emera’s 2022 Management Information Circular;

  

15.  Received and reviewed a diversity, equity and inclusion (“DEI”) dashboard setting forth data and analysis on the DEI strategies established by Emera;

  

16.  Received regular updates in respect of Emera’s Ethics Program and Respectful Workplace Program;

  

17.  Reviewed annual succession plans for senior management;

  

18.  Received an overview of Emera’s Ethics Escalation and Investigation Procedures;

  

19.  Reviewed the Committee’s Charter;

  

20.  Issued a request for proposals for compensation advisor services to test the market for such services, and re-engaged the incumbent; and

  

21.  Reviewed and approved the 2023 Work Plan of the Committee’s compensation consultants.

 

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NOMINATING AND CORPORATE GOVERNANCE COMMITTEE (“NCGC”)

Andrea Rosen (Chair)

Henry Demone

Richard Sergel

Jochen Tilk

  

ROLE OF THE NCGC

 

The NCGC assists the Board with a variety of matters relating to corporate governance. One of its primary duties is to provide the Company with a list of nominees for election as Directors to be included in the Company’s Management Information Circular prior to each Annual Meeting of Shareholders of the Company. The Committee is responsible for identifying, considering and recruiting people qualified to become Directors, having regard to the skills, experience and qualifications of possible candidates, the key selection criteria approved by the Board, and taking into account the considerations outlined in Emera’s Board Diversity Policy.

   The NCGC oversees the succession of Directors in accordance with the Board’s Renewal Principles and following a full skills assessment, having regard to the anticipated retirement of Directors and, where applicable, the Chair of the Board and Committee Chairs.
   The NCGC is responsible for developing and communicating the Company’s approach to corporate governance issues, and reviews and approves Emera’s disclosure of corporate governance practices, including the Statement of Corporate Governance Practices. The Committee keeps abreast of best governance practice benchmarks and regularly evaluates the governance practices of Emera. It reviews any disclosure of the Company’s corporate governance practice in accordance with applicable rules and regulations.
   The Committee is responsible for assisting the Board and its Committees in determining Committee composition, as well as reviewing and updating the mandate of each Committee, for submission to the Board. It also makes recommendations to the Board on all components of non-employee Director compensation, including the Board Chair and Committee Chairs. Another area of responsibility includes determining the process by which performance assessments are to be conducted, which evaluate the performance of the Board, the Board Chair, individual Directors, Board Committee Chairs and Board Committee members.
   ACTIVITIES OF THE NCGC IN 2022
   The NCGC met five times in 2022 and, in accordance with its mandate, undertook the following activities:
  

1.  Reviewed the plan for Director succession;

  

2.  Reviewed the Board Renewal Principles and the application of those Principles considering the average age and tenure of each member of the Board of Directors;

  

3.  Recommended to the Board of Directors for approval Director nominees for election at Emera’s 2022 Annual Meeting of Shareholders;

  

4.  Recommended to the Board of Directors the re-election of the Chair of the Board;

  

5.  Recommended to the Board of Directors the selection of Audit Committee financial experts for the purpose of Emera’s Form 40-F filed with the United States Securities and Exchange Commission;

  

6.  Reviewed and recommended to the Board of Directors for approval disclosure in respect of Director nominees, Director compensation and the statement of corporate governance practices for Emera’s 2022 Management Information Circular;

 

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7.  Received and reviewed a report on the market competitiveness of the compensation of Emera Directors;

 

8.  Oversaw the conduct of a survey of Emera Directors to seek voluntarily self- identification for diversity attributes;

 

9.  Reviewed and recommended to the Board of Directors changes to the Share Ownership Guideline for Directors;

 

10.  Reviewed the Board of Directors Charter;

 

11.  Monitored the Company’s corporate governance practices against relevant best practices at leading corporations;

 

12.  Received and reviewed a report on the program for Director education sessions and site visits;

 

13.  Reviewed reports on operating company governance;

 

14.  Reviewed reports on the compensation of non-employee Directors of Tampa Electric Company and New Mexico Gas Company;

 

15.  Reviewed and recommended to the Board of Directors for approval amendments to the limits of delegated authority for capital spending by subsidiaries;

 

16.  Reviewed the program of Directors and Officers insurance coverage and the adoption of an updated form of indemnity agreement for Directors;

 

17.  Received and reviewed amendments to Emera’s Code of Conduct;

 

18.  Reviewed compliance with Emera’s Director Share Ownership Guideline;

 

19.  Recommended to the Board of Directors for approval amendments to the Deferred Share Unit Plan for Non-Employee Directors to add a share purchase component to the plan;

 

20.  Reviewed and recommended to the Board of Directors for approval amendments to the Emera Pension Oversight Framework reflecting the removal of Dominica Electricity Services Limited as a result of the sale of this utility;

 

21.  Received and reviewed an analysis of the shareholder voting results at the 2022 Annual Meeting of Shareholders;

 

22.  Reviewed and recommended to the Board of Directors for approval amendments to the Senior Executive Air Travel Policy;

 

23.  Received an overview of Emera’s Ethics Escalation and Investigation Procedures;

 

24.  In consultation with the Chair of the Board, determined the process for conducting the annual Board and Director performance assessment;

 

25.  Reviewed and recommended to the Board of Directors amendments to the Charters of the Audit Committee, the MRCC, the NCGC and the HSEC to reflect revisions to the periodic reporting on Emera’s Ethics Program; and

 

26.  Reviewed and recommended to the Board of Directors revisions to the Audit Committee and the NCGC Charters to reflect the establishment of the Risk and Sustainability Committee.

Additional Information

Additional information relating to the Company may be found on the System for Electronic Document Analysis and Retrieval (“SEDAR”) at www.sedar.com. The Company’s financial information is contained in its comparative financial statements and management’s discussion and analysis for the financial year ended December 31, 2022.

For copies of the Company’s financial statements and management’s discussion and analysis, you may also contact the Office of the Corporate Secretary at:

Corporate Secretary

P.O. Box 910, Halifax, Nova Scotia B3J 2W5

Telephone: 902-428-6096; Facsimile: 902-428-6171; email: Stephen.Aftanas@emera.com.

 

62   EMERA INCORPORATED  


LOGO

 

IN THIS SECTION:

64 MESSAGE FROM THE MANAGEMENT RESOURCES AND COMPENSATION COMMITTEE TO OUR SHAREHOLDERS

66 STATEMENT OF EXECUTIVE COMPENSATION

73 COMPENSATION DISCUSSION AND ANALYSIS

88 PERFORMANCE GRAPH

90 NEO SUMMARY COMPENSATION TABLE

 

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Message from the Management Resources and Compensation Committee to Our Shareholders

Dear Shareholder,

In 2022, the team at Emera made significant progress in advancing the corporate strategy and continued to deliver strong growth and shareholder value.

All aspects of Emera’s compensation programs, including executive compensation, are overseen by the Management Resources and Compensation Committee of the Board (the “Committee” or “MRCC”). We are pleased to provide an overview of our approach to executive compensation, the Board’s assessment of Emera’s 2022 performance, and our decisions relating to executive compensation.

Emera’s approach to executive compensation is to align pay with performance. We do this through having a significant portion of the compensation we pay to executives directly linked to the achievement of corporate objectives and share price performance. Additionally, our share ownership guidelines require our executives to hold significant equity in Emera. The MRCC carefully assesses and makes recommendations to the Board to ensure performance measures and targets reflect Emera’s core values and our short- and long-term strategic priorities. The targets must be achieved within the principles of prudent risk management, good corporate governance, our corporate values, and compliance with relevant standards and regulations. Guided by these principles, along with input from other members of the Board and independent consultants, the MRCC guides and oversees the establishment of the Company’s performance goals, which are based on Board approved financial objectives and budgets, and assesses our executive compensation programs, including incentive payouts for the executive team, while continuously seeking to enhance our practices and approach to maintain our ability to attract the skills and talent required to operate our assets and deliver on our strategy.

2022 COMPENSATION

Our compensation philosophy is guided by the median level of compensation paid by our peer group, which is made up of companies of a similar size, scope and complexity as Emera. In addition to the market competitive data, the Committee considers experiences, uniqueness of responsibilities and performance of the Named Executive Officers (“NEOs”) in setting the level of target compensation. At the end of 2021, the Committee reviewed benchmarking analyses from both Hugessen Consulting Inc., the Board’s independent compensation advisor, and Mercer (Canada) Limited, management’s external compensation advisor, using the Company’s benchmarking comparator group.

Based on the comparative positioning of Emera’s target compensation to market, the Committee is satisfied that our Named Executive Officers are compensated competitively and in alignment with our compensation philosophy. The Committee will continue to monitor market trends to maintain our competitive positioning and our ability to attract the skills and talent required to operate our assets and deliver on our strategy.

The Committee also conducted its annual risk assessment to identify potential risks associated with Emera’s compensation design and policies. The assessment concluded that there are no material risks associated with the compensation programs and the Company has an appropriate system of checks and balances in place to mitigate the level of risk undertaken by management. The Committee will continue to diligently monitor programs to maintain high governance standards.

Recognizing Emera’s performance against objectives established for the 2022 Emera Corporate Scorecard, the Board approved an annual Short-Term Incentive Plan payout of 98.7 per cent of target for the NEOs. A full description of the 2022 Scorecard metrics and results is provided in 2022 Short-Term Incentive Results on page 79.

 

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Our 2022 Long-term Incentive Program, which consisted of performance share units (“PSUs”), restricted share units (“RSUs”) and stock options, is also closely aligned with our performance objectives. PSUs are linked to performance metrics that are measured over a three-year period. The 2020 PSU grant, which had a performance period from January 1, 2020 to December 31, 2022, measured Emera’s growth in adjusted earnings per share for compensation purposes (“compensation EPS”) and adjusted operating cash flow, pre-working capital for compensation purposes (“compensation cash flow, pre-working capital”), as well as measured Emera’s Total Shareholder Return (“TSR”) against that of the S&P/TSX Capped Utilities Index. Emera’s compensation EPS growth exceeded stretch level performance and compensation cash flow, pre-working capital exceeded target, which led to a performance factor of 140 per cent. A full description of the 2020 PSU grant result is provided on page 82. Our long-term incentives are also linked to Emera’s share price. Compensation EPS and compensation cash-flow, pre-working capital are non-GAAP measures and do not have standardized meaning under United States Generally Accepted Accounting Principles (“USGAAP”). A reconciliation of these non-GAAP measures to the nearest GAAP measures is discussed on page 83.

The Committee carefully reviews the metrics chosen for our incentive plans each year to ensure they continue to reflect the Company’s key strategic objectives.

The Committee engaged Hugessen Consulting Inc. to conduct the annual pay-for-performance analysis of the compensation paid to the President and CEO. The review looked at the compensation paid to Mr. Balfour from 2018 to 2022 and compared the investment returns experienced by shareholders over the same period. The analysis included both realized pay (consisting of amounts paid) and realizable pay (consisting of the value of any outstanding equity-based awards). The analysis concluded there was appropriate alignment between the President and CEO’s realized/realizable pay and shareholders’ investment return experience over the long term. Please see Total Shareholder Return and President and CEO Compensation for more information on the analysis.

Based on the Company’s performance in 2022 and the impact of that performance on the compensation we pay our executives, we remain confident that our incentive plans and resulting payouts are closely aligned with the interests of our shareholders.

SHAREHOLDER FEEDBACK

We held our annual “Say on Pay” advisory vote at our 2022 Annual Meeting that allowed shareholders to indicate whether they agreed with Emera’s compensation practices and policies. Shareholders voted 94.64 per cent in favour of our approach to executive compensation. At this year’s Annual Meeting of Shareholders, we will again be presenting a “Say on Pay” non- binding advisory resolution. As part of our continued commitment to shareholder engagement, it is important for us to receive direct feedback from our shareholders and have constructive dialogue about our compensation decisions and other governance matters. Shareholders can contact the Chair of the Committee or the Chair of the Board at the address listed at the end of this letter.

As always, we welcome your review of our compensation programs and results, which are described in more detail in the Statement of Executive Compensation that follows. We encourage you to take part in our “Say on Pay” vote and we welcome your questions and feedback, which can be provided directly to the Chair of the Committee or the Chair of the Board by mailing (through regular mail or other means of delivery) to:

 

Attention: Chair of the MRCC    Attention: Chair of the Board
P.O. Box 910, Halifax, Nova Scotia B3J 2W5    P.O. Box 910, Halifax, Nova Scotia B3J 2W5
in a sealed envelope marked “Private and Confidential – Attention, Chair of the MRCC of Emera Inc.”    in a sealed envelope marked “Private and Confidential – Attention, Chair of the Board of Directors of Emera Inc.”

 

Henry Demone    James Bertram    Karen Sheriff    Jochen Tilk

Director and Chair of the

Management Resources and

Compensation Committee

  

Director and Member of the

Management Resources and

Compensation Committee

  

Director and Member of the

Management Resources and

Compensation Committee

  

Director and Member of the

Management Resources and

Compensation Committee

 

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Emera’s approach to executive compensation is designed to achieve results, drive growth and deliver value to customers and shareholders. We are committed to:

 

  •  

aligning the financial interests of executives with Emera’s broader strategic and business interests and the related interests of Emera’s shareholders, customers and other stakeholders;

 

  •  

rewarding Emera’s executives for sustained growth in shareholder value, paying competitively with our North American peers;

 

  •  

balancing short- and long-term incentive plans that reflect our pay-for-performance philosophy; and

 

  •  

managing risk through good governance.

Statement of Executive Compensation

MARKET COMPETITIVENESS

Emera benchmarks executive compensation to ensure the Company pays competitively in the markets where it operates, and to motivate, attract and retain high-quality talent. Emera’s executive compensation program is designed to generally provide total target compensation at the median of compensation paid by comparable companies whose operations are of a similar size and complexity as Emera. Pay positioning, in some specific cases, may be above or below the median based on experience, uniqueness of responsibilities and performance. “Total target compensation” for senior management, including the named executive officers, is comprised of base salary, target short-term incentive and target long-term incentives linked to creating shareholder value.

PAY-FOR-PERFORMANCE PHILOSOPHY

A core principle of Emera’s executive compensation philosophy is that a significant portion of executive compensation is at risk and linked to the achievement of objectives that measure whether shareholders are receiving strong return for their investment. The at-risk components include both short- and long-term incentives, which establish measurable financial, organizational, environment, social and governance objectives including safety that, if achieved, add value to the Company.

The incentive compensation plans are designed to pay greater amounts for superior performance and lesser amounts if target performance is not achieved. Emera must achieve a threshold level of performance for any payment against a particular objective or there is no payment against that objective. Executives’ performance against those objectives is measured and rated by the President and CEO with a recommendation to the MRCC, which in turn discusses the assessments with the Board of Directors for approval. The Board Chair, in collaboration with the MRCC and the Board as a whole, assesses the performance of the President and CEO.

Generally, the at-risk compensation component of total compensation increases in conjunction with the individual executive’s level of responsibility. The Company considers many factors when developing the incentive plans, including current compensation trends, plan costs (including maximum payout values), expected value to be delivered to participants, and analysis of threshold, target and stretch payouts. Both short- and long-term incentive plans are modelled using historical and prospective performance scenarios. This stress testing provides the MRCC and the Board with reasonable assurance that the plan payouts will be appropriately aligned with shareholder and Company objectives. The Company conducts analyses every year to determine how actual payouts compare to expected payouts and whether the plan components and design require any changes.

The MRCC and Board reserve the right to exercise discretion in adjusting compensation payouts up or down to align with Company results, which may include refraining from paying out any amounts under the incentive compensation plans where circumstances warrant.

The MRCC has previously approved a set of guiding principles to govern when discretion is applied to ensure consistency and fairness when adjustments are made to incentive compensation. These guidelines are detailed on page 80.

 

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COMPENSATION PROGRAM

Emera’s compensation program includes the following components:

 

Base Salary (page 78): Salaries are benchmarked against companies of similar size and scope as Emera or the respective affiliate and are set to reflect the degree of special skills and knowledge required now and in the future for the position and the performance and contribution of the individual.
Short-term Incentive Plan (page 78): Short-term incentive objectives are set forth in scorecards and consist of key annual objectives linked to the Company’s corporate strategy. These scorecards establish measurable financial, organizational, environment, social and governance objectives including safety that, if achieved, add value to the Company.
Long-term Incentive Program (page 81): Consists of performance share units (“PSUs”), restricted share units (“RSUs”) and stock options. Levels are determined based on competitive benchmarking data and the degree of the executive’s responsibility within the Company. They are intended to align executive performance with a long-term focus on creating and preserving shareholder value.
Pension Plan Benefits (page 92): The Pension Plan consists of either defined benefit or defined contribution components and a supplemental employee retirement plan, all of which are governed by a pension oversight governance framework.
Other Executive Benefits (page 88): The Company offers market competitive non-cash compensation components such as group benefits, vacation, wellness incentives and an employee common share purchase plan.

Management Resources and Compensation Committee

The Board has assigned responsibility to the MRCC to review, recommend and oversee the determination of the compensation for Emera’s executive officers and the administration of all the Company’s executive compensation plans and programs. Current members of the MRCC are:

 

  •  

Mr. Henry Demone (Chair);

 

  •  

Mr. James Bertram;

 

  •  

Ms. Karen Sheriff; and

 

  •  

Mr. Jochen Tilk.

All members of the MRCC are independent Directors. Each member of the MRCC has experience with human resources issues and compensation matters. More detailed information on each member’s qualifications and experience is contained in Director Nominees Information.

 

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The MRCC considers best practices in determining and monitoring executive compensation as discussed in this circular. We are guided by the following key practices, which we believe promote good governance and serve the interests of our shareholders:

 

What we do
Align the Company’s compensation programs with its corporate strategy through the use of financial and non-financial performance metrics that support both short- and long-term strategic goals.
Perform an annual risk assessment to identify risks associated with our pay structure.
Retain an independent compensation advisor for the MRCC that does not provide any services directly to management.
Allow for the reduction or withholding of payouts under the short-term and equity-based incentive plans for results below expectations, at the MRCC and Board’s discretion.
Provide shareholders with the opportunity to vote on a “Say on Pay” resolution at the Company’s Annual Meeting, which allows shareholders to indicate whether they are in agreement with Emera’s compensation practices and policies (94.64 per cent of votes cast last year were in favour of the Company’s approach).
Use double-trigger change of control agreements.
Test compensation awards for appropriate alignment between pay and performance under a number of different outcome scenarios.
Provide detailed information on those companies used in the Company’s comparator group for benchmarking purposes.
Align executive pay with shareholders’ interests by having a significant component at risk and tied to both short- and long-term performance.
Have significant share ownership requirements in place for NEOs, which include a one-year post-retirement hold period.
Defer a substantial portion of long-term incentives for the majority of the senior executives and for other employees whose actions may have a material impact on the Company’s risk profile to discourage the taking of short-term or excessive risks.
Conduct pay equity analyses to help ensure the Company’s hiring and pay practices promote equity.
Have a pension oversight governance framework in place for pension benefits.
Monitor the ratio of the Company’s NEOs’ total compensation to the median employee’s total compensation.
Have a clawback policy that allows the Company to recoup short- and long-term incentive payments made to senior executives.
Disclose a lookback table showing how much the President and CEO has received in compensation over the past five years, factoring in long-term incentive payouts and changes in value.

Translate USD earnings to CAD earnings using a budgeted foreign exchange rate to ensure that fluctuations in the foreign exchange rate do not positively or negatively impact the measurement of the Company’s performance results against

its targets.

Conduct an extensive succession planning process where successor readiness over one, three, and five years is reviewed.
What we don’t do
Allow for the repricing or backdating of stock options.
Use single-trigger change of control agreements.
Allow the payment of dividends on share awards prior to vesting.
Count unvested awards that are subject to performance criteria, or unexercised stock options, toward share ownership requirements.
Allow executives to limit their economic risk with respect to any Emera securities they hold through hedging, pledging or other such transactions.
Grant additional years of credited service to NEOs under the Company’s pension plan or supplemental employee retirement plan.
Compensate executives for sitting on or chairing the Boards of any of Emera’s operating companies.

 

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MRCC GOVERNANCE

The MRCC is responsible for reviewing the alignment of Emera’s compensation programs, including incentive pay programs, with Emera’s strategic plans, performance and risk management principles. The Committee annually reviews compensation for the President and CEO and senior management of the Company. The MRCC oversees the administration of the incentive plans providing for the award of short-term incentives, stock options, PSUs, RSUs and deferred share units (“DSUs”) in accordance with the provisions of the respective plans.

The Committee reviews, and recommends to the Board of Directors, compensation policies and processes, any new incentive and the equity compensation plans and any changes to such plans.

The Board Chair specifically discusses the President and CEO’s performance with each Director individually and provides feedback to the MRCC, the Board and the President and CEO on at least an annual basis. In addition, the CEO reports, and the Committee reviews, the progress toward annual objectives at every Board meeting.

RISK MANAGEMENT AND COMPENSATION

As part of the Board and MRCC’s oversight responsibilities for the design and administration of Emera’s executive compensation programs, the MRCC identifies and discusses design features or processes that may potentially represent conflicts of interest or inducements for unnecessary or excessive risk-taking by senior executives.

The MRCC also regularly monitors industry trends with respect to risk management and conducts an annual risk assessment in consultation with an external compensation consultant. Emera’s compensation programs and policies are designed to incorporate the Company’s view on appropriate risk, as demonstrated by the elements shown below, which are discussed in greater detail in the sections that follow:

 

The Company regularly reviews its executive compensation programs with third-party compensation advisors to confirm the programs continue to align with shareholder and stakeholder interests, comply with regulatory requirements, and are consistent with sound principles of risk management and governance. The MRCC retains an independent compensation advisor that does not provide any services directly to management.
The Company has a pay-for-performance philosophy and the mix of short- and long-term programs assists in mitigating excessive risk-taking.
Vesting requirements, stress testing of potential payouts, clawback provisions, an anti-hedging policy and share ownership requirements are part of the Company’s overall plan design to mitigate risk. For more information, please see the Executive Share Ownership Requirements and Anti-Hedging Policy section on page 96.
The Company’s compensation governance structure involves the Board, the MRCC, the MRCC’s external compensation advisor, management, and management’s external compensation advisors.
All members of the MRCC are knowledgeable individuals who have the necessary background and expertise in human resources issues and compensation matters to fulfil their obligations to the Board and to shareholders.

 

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Annual Compensation Risk Assessment

In 2022, the MRCC conducted its annual compensation risk review of our executive compensation programs and policies. To assist in the review, management engaged Mercer to evaluate the previous year’s comprehensive risk assessment that Mercer conducted for any material changes over the course of the year. Mercer again concluded that Emera has risk mitigation policies in place that are aligned with market best practices and did not identify any material risks arising from Emera’s compensation policies and practices. Based on this assessment, the MRCC determined that:

 

  •  

Total compensation is appropriately balanced between short- and long-term horizons, and the mix of base salary and short- and long-term incentives does not create an inducement to take inappropriate risk to the detriment of the Company’s shareholders;

 

  •  

The use of multiple performance measures in the incentive plans (including non-financial measures) helps to avoid undue focus on any one particular metric;

 

  •  

The Short-term Incentive Plan focuses on growth of annual earnings and cash flow, but caps incentive payouts in a manner consistent with market practice, thereby reducing risk;

 

  •  

Risks associated with the Long-term Incentive Plan are mitigated by annual grants (versus front-loading grants) of PSUs, RSUs and stock options. Risks that incentive plans may incentivize activities that are inconsistent with Emera’s strategy are mitigated by choosing metrics aligned with key areas of financial and strategic performance;

 

  •  

The MRCC and Board’s discretion to reduce or withhold payment under the short-term and equity-based incentive plans for results below expectations decreases the risks associated with those plans;

 

  •  

Emera’s executive share ownership requirements decrease risk in the compensation program by encouraging alignment between the interests of senior officers and the interests of shareholders. In addition, the Company’s anti-hedging policy helps maintain that alignment by prohibiting senior officers from reducing their economic risk with respect to any Emera securities they hold through hedging, pledging or other such transactions. The ownership requirement includes a one-year hold period post-retirement for NEOs;

 

  •  

The vesting conditions on retirement are an important retention tool for designated executives of the Company;

 

  •  

The clawback policy contributes to the Company’s risk mitigation efforts and is currently under review in conjunction with the recent changes made to Securities and Exchange Commission requirements. The clawback policy allows the Company to recoup short- and long-term incentive payments made to senior executives in cases where: (a) the payments were based on reported financial results that were subsequently corrected or restated as a result (or partial result) of the executive’s gross negligence, misconduct or fraud and the reward received would have been lower had the financial results been properly reported; or (b) the executive commits a serious breach of the Company’s Code of Conduct; and

 

  •  

The inclusion of double-trigger provisions in senior executives’ employment contracts and the absence of enhanced benefits in a change of control situation mitigates the risk arising from a change in control of the Company.

Accordingly, based on the governance practices in place and the results of the risk assessment, the MRCC concluded that Emera’s compensation programs do not pose a material risk to the Company because an appropriate system of checks and balances is in place to mitigate the level of risk undertaken by management. The MRCC satisfies itself as to the adequacy of the information it receives regarding risk, the independence of the risk assessment, and the reporting of financial results on which certain important compensation decisions (such as incentive payouts) are based.

The MRCC and Board will continue to review the relationship between enterprise risk and the Company’s executive compensation plans and policies to confirm they continue to be optimally aligned with shareholder interests while maintaining an acceptable level of risk exposure.

 

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SUCCESSION PLANNING AND LEADERSHIP DEVELOPMENT

The MRCC assists the Board in the succession planning process for the President and CEO and has responsibility for overseeing succession planning for senior management of the Company and its operating companies. At Emera, succession planning is a dynamic, ongoing process of identifying, assessing and developing leadership competencies and business skills. The purpose is to confirm the Company’s capacity to meet future strategic objectives and to replenish critical organizational roles over time. The Board and Committee undertake this process on an annual basis. The Board also has responsibility for approving the appointment of the Company’s officers.

As part of the comprehensive succession planning process at Emera, management and the MRCC review, on an annual basis, the detailed management succession and development plans, and potential candidates for the CEO and senior management positions throughout the Company and its operating companies. The Committee oversees the management succession planning process and developmental strategy, which includes assessments of the senior leadership at all operating companies to leverage the entire talent pool across Emera. The Board receives a related progress report from the CEO at every Board meeting during the in-camera session. In addition, the process also involves an annual discussion between the Chair and every member of the Board.

The succession planning process includes the identification of successors for all executive roles on a temporary or urgent basis in the event of an unexpected vacancy. This will help ensure that any impact on the Company’s operations is minimized until such time that a permanent successor is in place.

The Company’s leadership competencies model is aligned with our business strategy and connected to our values. These leadership competencies support our people in delivering results in a way that demonstrates Emera’s commitment to customers, shareholders, communities and each other. Our leadership competencies require our people to:

 

1.

Speak up on safety, health and the environment

 

2.

Take ownership and act with integrity

 

3.

Drive operational excellence for customers

 

4.

Build strong, collaborative relationships

 

5.

Develop people and teams

 

6.

Cultivate innovation and embrace change

 

7.

Think strategically and exercise sound judgment

These leadership competencies apply not only to management employees, but to every employee at Emera. The alignment of all employees to a common set of competencies provides the foundation from which we develop our people.

Emera is committed to developing leaders at all levels and has a comprehensive annual assessment process and framework to coordinate leadership development across the Company. This assessment process identifies areas of development for individuals as well as the leadership team related to identified core leadership capabilities. Personal development plans and overall Company leadership development programs, which reflect the above competencies, are in place for both existing and potential leaders. The Company focuses on ensuring challenging work assignments are offered, secondments to operating companies are made where appropriate, regular leadership development training occurs, and mentors are assigned where beneficial.

Emera will continue these focused efforts to build leadership capacity throughout the organization in support of its long-term growth strategy.

 

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COMPENSATION ADVISORS

The MRCC retains the services of independent compensation advisors to assist in discharging its duties, including determining the compensation payable to the President and CEO and other senior officers.

Since 2007, the MRCC has engaged Hugessen as its principal advisor to provide independent advice, compensation analysis and other information for compensation recommendations. Hugessen provides advice on the competitiveness and appropriateness of compensation practices and comparator groups for Emera. In addition, Hugessen advises the MRCC on policy recommendations made by management, and reviews and provides commentary on the Company’s Statement of Executive Compensation. As independent advisors to the MRCC, Hugessen does not provide any professional services to management.

The MRCC:

 

  •  

Annually reviews the advisor’s performance and fees.

 

  •  

With input from Company management and the advisor, annually, or on an as-needed basis, determines the specific work the advisor is to undertake and the fees associated with this work.

 

  •  

Prior to undertaking any work, ensures the advisor provides an outline of the scope of work and related fees, and the MRCC Chair must provide written pre-approval.

 

  •  

Does not approve any work that, in its view, could compromise the advisor’s independence in serving the MRCC.

In addition to the MRCC’s compensation advisor, Emera engaged the services of Mercer and LifeWorks in 2022 to assist in executive compensation matters.

In making its decisions on the compensation program, the MRCC reviews information and recommendations provided by Hugessen, Mercer and LifeWorks, but all decisions remain the responsibility of the MRCC and the Board.

The table below summarizes the fees paid to all external compensation advisors in 2021 and 2022.

 

     2022      2021  

Advisor

   MRCC work ($)      Other work ($) (1)      MRCC work ($)      Other work ($)  

Hugessen Consulting Inc.

     128,655        Nil        185,133        Nil  

LifeWorks

     Nil        75,415        Nil        117,105  

Mercer (Canada) Limited

     Nil        200,285        Nil        114,791  

 

(1)

Mercer (Canada) Limited was retained by the Nominating and Corporate Governance Committee in 2021 and 2022 to review Directors’ compensation; the fees for that review are included in the amount shown.

 

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Compensation Discussion and Analysis

NAMED EXECUTIVE OFFICER COMPENSATION

The NEOs whose compensation is disclosed in this Compensation Discussion and Analysis are the President and CEO, the CFO and the next three most highly compensated executive officers of the Company, or its operating companies, as defined by Canadian securities legislation:

 

  •  

Scott Balfour, President and Chief Executive Officer, Emera Inc. (“President and CEO”);

 

  •  

Greg Blunden, Chief Financial Officer, Emera Inc. (“CFO”);

 

  •  

Bruce Marchand, Chief Risk and Sustainability Officer, Emera Inc.;

 

  •  

Karen Hutt, Executive Vice President, Business Development and Strategy, Emera Inc.; and

 

  •  

Richard Janega, Chief Operating Officer, Electric Utilities, Canada and Caribbean, Emera Inc.

Scott Balfour, President and Chief Executive Officer, Emera Inc.

Mr. Balfour was appointed President and CEO of Emera Inc. in March 2018. He serves as Chair of the Boards of Tampa Electric Company, Peoples Gas System Inc. and Nova Scotia Power Inc. 2022 was a strong year in advancing Emera’s strategy and in delivering value for customers and earnings growth for shareholders. This is despite unexpected challenges including rising inflation, global supply chain disruptions and two record-breaking hurricanes. The introduction of Bill 212 in Nova Scotia was not a good outcome for customers or shareholders, but the settlement agreement that was subsequently achieved helped to mitigate impacts. Under Mr. Balfour’s leadership, Emera has advanced its carbon reduction goals and is increasingly recognized as a leader in ESG. Successful execution of a $2.6 billion rate base investment and the forward-looking 8–9% capital plan focused on delivering cleaner and more reliable energy for customers, supporting continued growth in earnings for shareholders. Noteworthy is the completion of the complex Big Bend modernization project, which was safely completed on time and on budget during 2022. While Mr. Balfour has demonstrated his strong leadership toward the goal of world-class safety culture and performance, the tragic loss of a team member in a workplace accident in early 2022 is a reminder that this is an area requiring ongoing focus notwithstanding the significant progress and safety performance milestones achieved to date. Prior to his current role, Mr. Balfour served as Chief Operating Officer and Chief Financial Officer at Emera.

Greg Blunden, Chief Financial Officer, Emera Inc.

Mr. Blunden became CFO in 2016 and has accountability for financial leadership across Emera. In 2022, Mr. Blunden continued to make substantial progress on Emera’s capital investment funding plan and supporting corporate financing plans and led the relationship with capital market stakeholders. His extensive financial and regulated utility experience makes him a valuable resource to leaders across the business in their pursuit of appropriate rate case outcomes. Mr. Blunden is a Fellow Chartered Professional Accountant and has previously served in a number of financial, business development and strategy roles at Emera and its affiliates.

Bruce Marchand, Chief Risk and Sustainability Officer, Emera Inc.

In 2022, Mr. Marchand moved from his previous role of Chief Legal and Compliance Officer to assume a new role as Emera’s Chief Risk and Sustainability Officer. In addition to continuing his accountability for Emera’s enterprise risk function, Mr. Marchand has applied his deep industry knowledge to leading Emera’s sustainability priorities and reporting work, including support for the recently formed Risk and Sustainability Committee of the Board. Under his leadership, Emera has developed and maintains robust risk and sustainability policies, assessments, action plans, reporting and tracking tools. During the year, Mr. Marchand seamlessly transitioned his corporate legal, internal audit and regulatory oversight responsibilities to his successor in those roles.

Karen Hutt, Executive Vice President, Business Development and Strategy, Emera Inc.

Ms. Hutt was appointed Executive Vice President, Business Development and Strategy in 2019 and became accountable for government relations in 2021. She brings expert leadership and process discipline to the development and execution of business development, as well as a very robust strategic planning process – driving our focus on continued growth. During the year, Ms. Hutt assumed additional responsibilities as Chair of Emera Caribbean and the corporate communications and stakeholder relations function for Emera. Previously, Ms. Hutt was appointed President and Chief Executive Officer of NSPI in August 2016.

 

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Richard Janega, Chief Operating Officer, Electric Utilities, Canada and Caribbean, Emera Inc.

Mr. Janega was appointed Chief Operating Officer, Electric Utilities, Canada and Caribbean of Emera and a Director of NSPI in 2018 and retired from Emera at the end of 2022. During the year, Mr. Janega successfully led and eventually transitioned his leadership responsibility for Safety & Environment to successors and handed his role as Chair of Emera Caribbean to Ms. Hutt. The approval of the Maritime Link’s final cost application successfully caps off Mr. Janega’s extraordinary leadership of this highly complex multi-year project.

The total target compensation for each NEO in 2022 is outlined below:

 

Name

   Base salary ($)      Short-term
incentive
at target (% of
base salary)
     Short-term
incentive
at target ($)
     Long-term
incentive
at target (% of
base salary)
     Long-term
incentive
at target ($)
     Total target
compensation ($)
 

Scott Balfour

     1,100,000        100        1,100,000        515        5,665,000        7,865,000  

Greg Blunden

     600,000        80        480,000        220        1,320,000        2,400,000  

Bruce Marchand

     545,000        70        381,500        160        872,000        1,798,500  

Karen Hutt

     510,000        70        357,000        180        918,000        1,785,000  

Richard Janega

     525,000        70        367,500        125        656,250        1,548,750  

The following charts show the percentage weighting of each component of the total target compensation for the NEOs. In keeping with the Company’s pay-for-performance philosophy, the 2022 compensation plan design resulted in 86 per cent at-risk pay for our President and CEO and an average for the five NEOs of 74 per cent.

 

LOGO

Figures in charts have been rounded to the nearest percentage.

 

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COMPENSATION PROCESS

Benchmarking Data

The MRCC is responsible for annually reviewing the composition and use of comparator groups to assist in determining the compensation recommendations for the Company’s senior officers, including the President and CEO and other NEOs. The recommendations are then brought to the Board for approval. The MRCC undertakes periodic reviews of compensation design and total compensation opportunities for the senior management team, which helps ensure the programs are current and that they are fair comparisons for particular roles, recognizing varying responsibility and scope of executive positions within Emera and its operating companies.

Emera management engages the services of Mercer to compile market information on senior management compensation relating to base salary, and short- and long-term incentives. The MRCC also uses its independent compensation advisor, Hugessen, to assist in providing benchmarking data and advice when setting executive compensation levels and making changes to the Company’s compensation programs.

A complete benchmarking review takes place annually, and the scope of services includes competitive market reviews of senior executive compensation levels; review and observations of current executive compensation philosophy, policies and practices; and a review of pay and performance comparators.

The Company’s comparator group for senior executives consists of two sub-groups: (1) a Canadian group of companies in the Canadian energy, utility and general industry sectors; and (2) a US group of US energy and utility companies. It consists of the following companies:

 

LOGO  

Canadian comparators

  

US comparators

 

Energy & Utility Industry

Algonquin Power & Utilities Corp.

AltaGas Ltd.

ATCO Ltd.

Fortis Inc.

Hydro One Ltd.

Keyera Corp.

Inter Pipeline

Pembina Pipeline Corp.

TC Energy Corp.

TransAlta Corp.

 

General Industry

Air Canada

Canadian Pacific Railway

Canadian Tire Corp. Ltd.

Loblaw Companies Ltd.

Nutrien Ltd.

Restaurant Brands International LP Rogers Communications Inc.

TELUS Corp.

  

Energy & Utility Industry

Alliant Energy Corp.

Ameren Corp.

Atmos Energy Corp.

Avangrid Inc.

Black Hills Corporation

CenterPoint Energy, Inc.

CMS Energy Corp.

DTE Energy Company

Evergy, Inc.

Eversource Energy

NiSource Inc.

OGE Energy Corp.

Pinnacle West Capital Corp.

Sempra Energy

UGI Corp.

WEC Energy Group, Inc.

The inclusion of US companies reflects that approximately 74 per cent of Emera’s assets are US-based and approximately 70 per cent of Emera’s revenues came from US operations in 2022. It also factors in the talent market for the executive team and that most of Emera’s executives have significant oversight over US operations. While the benchmarking group assists in determining the appropriate compensation ranges for base salaries, target short-term incentives and target long-term incentives for the senior executive team, the Committee does not believe in a “one size fits all” approach and looks at the circumstances of each executive when determining whether to benchmark using the full comparator group or whether a different approach is warranted. The Committee considers the corporate and geographical scope of each executive when setting benchmark comparator groups. When benchmarking executives who are paid in Canadian dollars against roles that are paid in US dollars, the Company uses the five-year average exchange rate between Canada and the US to smooth out the impact of currency fluctuations.

 

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The following chart shows where Emera was positioned compared to the companies in both the Canadian and the US comparator groups based on selected key financial metrics – market capitalization, total enterprise value, assets, revenues, and earnings before interest, taxes, depreciation and amortization (“EBITDA”).

 

 

LOGO

 

(1)

As at date of analysis, February 9, 2022.

(2)

As at December 31, 2021.

(3)

Last 12 months as at December 31, 2021.

Note: The above table was prepared by Hugessen Consulting Inc. using data from S&P Capital IQ.

In addition to using publicly disclosed compensation data from the companies in the comparator group, the MRCC also considers Mercer’s Total Compensation Survey for the Energy Sector in assessing executive compensation using data from energy and services companies with similar revenues to Emera. To provide sufficient data in some cases, the Mercer Benchmark Database Survey, which is a general industry database, is also used to expand the survey scope to include Canadian general industry companies of similar size to Emera.

With the assistance of Hugessen and Mercer, the Committee conducted a compensation benchmarking review of the executive team at the end of 2021 to set 2022 pay using the comparator group and survey data, and undertook a review of the competitiveness and appropriateness of Emera’s compensation programs. More details on the results of the review are provided in the next section.

 

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ANNUAL COMPENSATION REVIEW PROCESS

For each executive position, a range for base salary, target short-term incentive and target long-term incentive is established annually, using the benchmarking data along with other information on industry trends for positions of similar scope and responsibility.

The President and CEO conducts an annual performance assessment of each member of the executive leadership team, including the NEOs, which shape the annual salary adjustment recommendations. Based on the performance assessments and the benchmarking data, the President and CEO then recommends total target compensation for each senior leader, including the NEOs (but excluding himself) to the MRCC for review and approval. With respect to the President and CEO, the Board conducts an annual performance assessment and the MRCC reviews benchmark data and other information on industry trends for positions of similar scope.

Following this process, the MRCC makes recommendations for total target compensation for the senior management team, including the President and CEO and the other NEOs, to the Board of Directors. As part of the annual compensation review process, the MRCC reviews emerging best practices and risk considerations.

At the end of 2021, both management’s compensation advisor, Mercer, and the Committee’s compensation advisor, Hugessen, provided the results of their benchmarking reviews, which assisted in setting the compensation levels for the NEOs for 2022.

In light of Mr. Balfour’s below-market positioning against other CEOs in the Company’s peer group and given his strong performance as President and CEO, Mr. Balfour’s total compensation was adjusted to $7.9 million. In keeping with the Company’s pay-for-performance approach, the entirety of Mr. Balfour’s 2022 increase was allocated to his long-term incentive target, which increased from 500 per cent to 515 per cent, further linking his incentive payouts to the achievement of key objectives that advance Emera’s corporate strategy and performance metrics that measure long-term shareholder value.

To reflect Mr. Blunden’s positioning against other CFOs and his continued growth and performance, he received a 2.6 per cent increase to base salary. To maintain Mr. Marchand and Mr. Janega’s proximity to market, they both received a 1.9 per cent increase to base salary. In consideration of Ms. Hutt’s expanded role and market position, Ms. Hutt received an overall 17.6 per cent increase, which consisted of an increase to her base salary and long-term incentive target.

The compensation changes from 2021 to 2022 are summarized below. All changes were effective January 1, 2022:

 

    

Base salary

   Short-term
incentive target
(% of base salary)
    

Long-term

incentive target

(% of base salary)

   Total target
compensation
(% increase)
    

Proportion of

compensation at risk

Scott Balfour

   No change      No change      Increase from 500 per cent to 515 per cent      2.1      No material change (86 per cent)

Greg Blunden

   Increase from $585,000 to $600,000      No change      No change      2.6      No change (75 per cent)

Bruce Marchand

   Increase from $535,000 to $545,000      No change      No change      1.9      No change (70 per cent)

Karen Hutt

   Increase from $460,000 to $510,000      No change      Increase from 160 per cent to 180 per cent      17.8      Increase from 70 per cent to 71 per cent

Richard Janega

   Increase from $515,000 to $525,000      No change      No change      1.9      No change (66 per cent)

As a result of the changes, the variable or at-risk component of the NEOs’ compensation averaged 74 per cent in 2022, a 1 per cent increase from 2021. The changes made to the compensation of the respective NEOs in 2022 are also reflected in the NEO Summary Compensation Table.

 

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ELEMENTS OF COMPENSATION

Base Salary

While the MRCC focuses on total compensation, base salary remains an important part of the overall compensation package the Company offers its executives. See the table above for 2022 base salary increases, which were intended to better align base salary positioning relative to the market.

Short-term Incentive Plan

The compensation awarded under the Short-Term Incentive Plan links a portion of an executive’s compensation to the achievement of predetermined levels of performance in support of corporate and business unit objectives. These objectives are designed to focus on short-term goals (typically on an annual basis) that are intended to deliver value to customers and contribute to increased shareholder value in the longer term. Emera has adopted the scorecard approach to translate corporate strategies into measurable incentive plan goals. Target payouts under the scorecards are generally set as a percentage of salary and are benchmarked against the median for positions with similar responsibilities in comparator companies.

On the recommendation of the MRCC, the Board of Directors of Emera approves scorecards that set forth corporate objectives and related threshold, target and stretch performance levels to be achieved each year. Short-term incentive payouts for senior management, including the NEOs, are based on scorecard results with potential payouts ranging from 0 to 200 per cent of target.

Short-term incentive payouts for all NEOs are calculated based on results achieved through a corporate scorecard.

2022 Short-term Incentive Results

2022 Emera Corporate Scorecard

The scorecard for Emera (“Emera Corporate Scorecard”) was developed by management and approved by the Emera Board of Directors, on the recommendation of the MRCC, at the beginning of 2022. It was used to determine the short-term incentive payout for all NEOs.

The Emera Corporate Scorecard objectives were based on the Company’s Business Plan for the year and include threshold, target and stretch performance measures for each objective. To reach target level performance, all threshold and target measures must be achieved, and to reach stretch level performance, all threshold, target and stretch measures must be achieved.

 

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The following table shows the elements and results of the Emera Corporate Scorecard for 2022.

 

Emera corporate

objective              

   Weighting
(%)
    

Threshold ($)

   Target ($)      Stretch ($)      Actual result ($)      Percentage
payout (%) (1)
 

Compensation Net Income (2)

     40      700M      824M        948M        854M        49.7  

Compensation Cash Flow (2)

     30      1,494M      1,868M        2,242M        1,593M        19.0  

Safety

     10     

Objectives included:

 

•   Threshold: Update the Contractor Safety Program to incorporate the Serious Injuries and Fatalities (SIF) Prevention Framework, recent Affiliate learnings, and industry best practices; and 50% of employees complete applicable modules from the University of Colorado Energy Series safety training.

 

•   Target: Update Emera/Affiliate safety assurance programs (audits & compliance monitoring) to improve consistency and objectivity and implement recommendations; and achieve a 15% reduction in high energy serious injuries across the business.

 

•   Stretch: Update Field Safety Engagement processes to incorporate SIF Prevention concepts and deliver associated training to 90% of Emera Inc. Leaders; and achieve a 50% reduction in high energy serious injuries across the business.

 

    

    

    

    









Threshold
achieved;
however, upon
recommendation
of management,
reduced to zero
for Emera senior
executives due
to an employee

fatality at Nova
Scotia

Power

 
 
 
 
 
 
 
 
 

 
 

 

     0.0  

Environment

     10     

Objectives included:

 

•   Threshold: Complete Phase 2 of Uncontrolled Releases Prevention initiative; completion of Cority Release II training modules by 50% of Emera Inc. employees.

 

•   Target: Implement system to manage and track Emera-wide CO2 climate commitments to support internal and external reporting requirements; 70% of Emera Inc. employees complete CO2 climate commitments awareness training.

 

•   Stretch: Conduct review of regulatory approval and permitting processes across Emera companies and develop best practices guide; select Affiliate Environmental Management System (EMS) Critical Targets for climate- related initiatives completed in 2022; and achieve no significant environment events.

 

    

    

    

     Target achieved        10.0  

People

     10     

Objectives included:

 

•   Threshold: Host three Diversity, Equity and Inclusion (DEI) events within Emera Inc. 75% of Emera Inc. employees share a DEI moment within a meeting.

 

•   Target: 90% of Emera Inc. people leaders complete a course on how to have performance and career discussions with their employees. 90% of all Emera Inc. employees complete a new performance review.

 

•   Stretch: Increase the number of new hires from underrepresented groups for external postings by 10% year over year. Increased training and awareness of cybersecurity as measured by achieving cyber training completion results of 90% or higher AND phishing “test click rate” results of 5% or lower, averaged across all Affiliates for 2022.

 

    

    

    

     Stretch achieved        20.0  
                 

 

 

 
     100              Total: 98.7  
                 

 

 

 

 

(1)

Percentage payouts, below or above target for financial measures, are interpolated on a scale between each level of performance (50 per cent for threshold, 100 per cent for target and capped at 200 per cent for stretch).

(2)

Adjusted net income attributable to common shareholders for compensation purposes (“compensation net income”) and cash flow from operations for compensation purposes (“compensation cash flow”) are non-GAAP financial measures and do not have a standardized meaning as prescribed by USGAAP. Calculation of these measures and reconciliation to the nearest GAAP measures are discussed on page 80.

 

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The financial targets reflected in the scorecard are established in linkage to per share outcomes but are set at absolute levels to avoid the risk of incentive impacts influencing the timing of financing decisions within the year. Compensation cash flow fell between threshold and target and compensation net income fell between the target and stretch levels of performance.

Regrettably, Nova Scotia Power experienced a workplace fatality. As a result, on the recommendation of management and with the support of the HSE Committee of the Board, the safety measure was reduced to zero per cent for the NEOs.

The compensation cash flow and compensation net income figures that are shown in the Emera corporate scorecard are adjusted for incentive purposes from the Company’s reported figures. The Company considers the following general principles when determining whether it should adjust financial results for incentive plan purposes:

 

  •  

The Company adjusts the reported figures for specific items the Company believes are significant, but not reflective of underlying operations in the period.

 

  •  

Incentive compensation should be directly linked to the performance of the core business and delivering on the plan of record. Meaningful accounting gains or losses are generally the result of strategically or financially driven transactions in which there has been direct involvement and support of the Board; therefore, the impacts of the transactions should typically be excluded from incentive compensation, except as noted below. The Company does not want its strategically or financially driven decisions to be influenced by compensation impacts.

 

  •  

The Company should, however, consider including all or some portion of the gain (positive impact) or loss (negative impact) if such gain or loss appropriately reflects the value creation or value destruction and overall performance of management in the decision or execution of the transaction leading to such gain or loss.

 

  •  

Perfect alignment of performance and compensation can be elusive from year to year. Therefore, the Board reserves the right to adjust incentive payouts in either direction to satisfy itself that there is close alignment between performance and compensation.

The substantial rise in fuel costs and harsh winter storms in 2022 had significant impacts on the Company’s Compensation Cash Flow metrics in the Emera corporate scorecard as well as the 2020 PSU grant. These unexpected costs will ultimately be recovered in subsequent years following established regulatory processes and incorporated into respective future budgets and targets. As such, the 2022 Compensation Cash Flow results have been adjusted to remove these additional costs. The table that follows shows the reconciliation between the reported and adjusted figures used in the Emera corporate scorecard. Adjustments in respect of the 2020 PSU grant are disclosed on page 83.

 

Compensation net income reconciliation (in millions $)

   2022  

Reported net income attributable to common shareholders

     945  

Less: mark-to-market gain, after tax (1)

     (175 ) 

Add: Impairment charge

     73  

Add: NSP Maritime Link Inc. unrecoverable costs (2)

     7  

Add: Adjustment to translate USD earnings to budgeted foreign exchange rate

     4  
  

 

 

 

Compensation net income

     854  
  

 

 

 

 

Compensation cash flow reconciliation (in millions $)

   2022  

Reported operating cash flow

     913  

Add: Adjustment to translate USD earnings to budgeted foreign exchange rate

     11  

Add: Adjustment for extraordinary fuel costs to be recovered in subsequent years

     572  

Add: Adjustment for extraordinary storm costs to be recovered in subsequent years

     97  
  

 

 

 

Compensation cash flow

     1,593  
  

 

 

 

 

(1)

Net of income tax expense of $73 million.

(2)

Emera accounts for NSPML as an equity investment, and therefore the after-tax unrecoverable costs were recorded in “Income from equity investments” on Emera’s Consolidated Statements of Income.

 

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Long-term Incentive Program

In 2022, there were three primary components of long-term incentive compensation for senior management, including the NEOs: the Performance Share Unit Plan (the “PSU Plan”), the Restricted Share Unit Plan (“RSUs”) and the Senior Management Stock Option Plan (the “Stock Option Plan”). The MRCC is responsible for granting PSUs, RSUs and stock options.

The number of PSUs, RSUs and stock options granted to senior management is determined after considering competitive benchmarking data and the individual’s level of responsibility within the Company. Grants are calculated each year based on each executive’s long-term incentive target percentage and base salary and, generally, the grant amount increases with the level of responsibility. The values of PSUs, RSUs and stock options increase or decrease over the term of a particular grant based on increases or decreases in Emera’s common share price.

The MRCC considers previous grants and looks at a history of total compensation each year before approving any new PSU, RSU or stock option grants for senior management (including the NEOs). This helps to ensure grants remain reasonable in light of market data, the performance of the Company and the performance of the individual.

In 2022, PSUs made up 50 per cent of the target long-term incentive compensatory value for each of Emera’s most senior executive officers, with the remaining 50 per cent divided equally between RSUs and stock options. This mix is aligned with market practice and provides for a balance between company performance and retention, while maintaining the Company’s pay-for-performance strategy by closely linking a significant portion of the executive’s compensation to that of the shareholder experience.

The table below provides a summary of the 2022 long-term incentive grants awarded to the NEOs.

 

     Options granted
(#)
     Options grant
value
($) (1)
     PSUs
granted (#)
     PSUs grant
value
($) (2)
     RSUs
granted
(#)
     RSUs grant
value 
($) (2)
     Total LTIP
value
($)
 

Scott Balfour

     204,400        1,416,492        47,390        2,832,500        23,691        1,416,011        5,665,003  

Greg Blunden

     47,600        329,868        11,042        659,980        5,524        330,169        1,320,017  

Bruce Marchand

     31,500        218,295        7,295        436,022        3,642        217,682        871,999  

Karen Hutt

     33,100        229,383        7,679        458,974        3,842        229,636        917,993  

Richard Janega

     23,700        164,241        5,490        328,137        2,742        163,889        656,267  

 

(1)

Stock options are granted based on the Black-Scholes methodology. Please see the Senior Management Stock Option Plan section on page 85 for details on the Black-Scholes results and the Company’s use of a floor value ratio.

(2)

PSU and RSU grant values were calculated using the 50-day average closing share price of an Emera common share for the last 50 trading days of 2021, which was $59.77.

More details about the PSU Plan, the RSU Plan and the Stock Option Plan are set forth below.

Performance Share Unit Plan

The PSU Plan is designed to retain and incentivize employee participants by allowing senior management and key employees in specific roles to participate in the long-term success of the Company. A PSU is a notional share unit that is based on the value of an Emera common share – the value of a PSU changes directly in correlation to the value of an Emera share. PSUs also earn dividends like Emera shares; when a dividend is paid on Emera’s common shares, each participant is allocated additional PSUs based on the dividend paid on an equivalent number of Emera common shares.

Each year, designated senior leaders are awarded PSUs based on a pre-determined target of their base salary and the average 50 trading-day Emera common share price immediately preceding the effective grant date (the average is used to smooth out any short-term fluctuations in the share price). Each PSU grant has a three-year performance period. In addition to being affected by fluctuations in the Emera share price, the value of a PSU is also dependent on the achievement of financial objectives that help measure the increase in shareholder value. The MRCC establishes these financial objectives at the beginning of the performance period. By linking the value of the PSUs to Emera’s financial performance over the three-year vesting period, the plan aligns the interests of senior leaders with the interests of Emera’s shareholders and helps ensure that payouts are consistent with Company performance and shareholder experience. All PSU grants and payouts must be approved by the MRCC.

 

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At the end of the performance period, a performance factor is applied to the PSU grant based on the achievement of the financial objectives. If the Company fails to meet the performance objectives for a particular PSU grant, the Plan may pay out at less than target, or may not pay out any amounts at all. Even if targets are exceeded, the maximum performance factor is 200 per cent.

Accordingly, the amount payable to participants, including NEOs, at the end of the three-year performance period is determined by:

 

PSU Payout    =    OriginalGrant+NotionalDividends    ×    Performance    ×    Closing Share

Like the methodology on the grant, the payout is based on the average 50-trading-day closing price for Emera common shares at the end of the three-year performance period to smooth out short-term price fluctuations. Payments are made in cash.

Performance Share Unit Plan Results

The 2020 PSU grant had a performance period of January 1, 2020 to December 31, 2022 and was subject to two performance metrics:

 

1.

Compensation EPS growth weighted at 75 per cent, which is a fundamental measure of the increase in profitability of the Company; and

 

2.

Compensation cash flow, pre-working capital weighted at 25 per cent, which measures the Company’s success in focusing on cash generation and is a key driver of long-term value for shareholders.

Adjusted EPS for compensation purposes (“compensation EPS”) and adjusted operating cash flow, pre-working capital for compensation purposes (“compensation cash flow, pre-working capital”) are non-GAAP financial measures and do not have a standardized meaning as prescribed by USGAAP. Calculation of these measures and reconciliation to the nearest GAAP measure are discussed on page 83.

In addition to the above metrics, the 2020 PSU grant was subject to a TSR modifier, which could increase or decrease the performance factor resulting from the two performance metrics by 25 per cent based on Emera’s TSR compared to the TSR of the S&P/TSX Capped Utilities Index over the three-year performance period. If Emera’s TSR was positioned in the top quartile of performance of companies in the S&P/TSX Capped Utilities Index, the performance factor would be increased by 25 per cent; if Emera’s TSR was positioned in the bottom quartile, the performance factor would be reduced by 25 per cent. There is no adjustment if Emera’s TSR is in the second or third quartile of performance. This allowed the Company to focus on its specific business objectives, but still manage shareholder expectations by adjusting the results for relative performance.

The performance factor could range from 0 per cent to 200 per cent. The maximum performance factor is 200 per cent, even with the impact of the TSR modifier. If the performance metric results multiplied by the TSR modifier exceed 200 per cent, the performance factor would be capped at 200 per cent. In addition, if Emera’s TSR is negative on an absolute basis, then the TSR payout multiplier cannot be above 1.0 (100 per cent), regardless of whether the Company is in the top quartile of performance. This scenario could arise in situations where general market performance of the companies in the S&P/TSX Capped Utilities Index is negative and Emera’s TSR is higher while still being negative. This provision helps ensure payouts are reasonable when shareholders experience low returns on their investment.

The threshold, target and stretch levels and results are shown in the table below:

 

2020 PSU grant metric

   Weighting     Threshold (50%)     Target (100%)     Stretch (200%)  

Compensation EPS (1): three-year compound annual growth rate

     75 %      2 %      6 %      10 % 

Compensation cash flow, pre-working capital (1): three-year compound annual growth rate

     25 %      2 %      6 %      10 % 

 

(1)

Compensation EPS and compensation cash flow, pre-working capital, are non-GAAP financial measures that do not have standardized meaning under USGAAP. A reconciliation to the nearest GAAP measure is discussed further below.

 

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The results were as follows:

 

2020 PSU grant metric

   2019      2022      Three-year
compound annual
growth rate
    Weighted
performance
result
 

Compensation EPS (1)

   $ 2.35      $ 3.20        10.8 %      150 % 

Compensation cash flow, pre-working capital (1)

   $ 1,501M      $ 1,886M        7.9 %      37 % 
        Performance factor       187 % 
        Relative TSR Modifier       75 % 
        Modified Performance Factor       140 % 

 

(1)

Compensation EPS and compensation cash flow, pre-working capital, are non-GAAP financial measures that do not have standardized meaning under USGAAP. A reconciliation to the nearest GAAP measure is discussed further below.

Compensation EPS and compensation cash flow, pre-working capital figures that are shown in the table above are adjusted from the Company’s reported figures as reconciled below. Like the approach used for determining the corporate scorecard results, and similar to 2021 when a portion of a large gain on sale was adjusted out of compensation EPS for PSU performance factor calculations, the Company adjusted the reported figures for specific items that the Company believes are significant, but not reflective of underlying operations in the period. During the performance period, Emera made the strategic decision to divest certain assets, namely NEGG and Emera Maine. To ensure comparability of beginning and ending performance periods, the EPS impact of these assets was removed from the 2019 compensation EPS baseline. The input is outlined in the 2019 compensation EPS reconciliation. The table below shows the reconciliation between 2019 and 2022 reported adjusted EPS figures and the compensation EPS figures used for incentive plan purposes.

 

Compensation EPS reconciliation ($)

   2019      2022  

Adjusted EPS (basic) (1)

     2.59        3.20  

Less: Earnings from NEGG and Emera Maine

     (0.28 )       —    

Add: Loss on sale of Bayside and EUS

     0.01        —    

Add: Emera Maine transaction costs

     0.03        —    
  

 

 

    

 

 

 

Compensation EPS

     2.35        3.20  
  

 

 

    

 

 

 

 

Compensation cash flow, pre-working capital reconciliation ($)

   2019      2022  

Reported operating cash flow

     1,525        913  

Add: Change in working capital

     73        234  

Less: Divested operations of NEGG and Emera Maine

     (115 )       —    

Add: NEGG and Emera Maine transaction costs

     18        —    

Add: Tampa fuel under recovery

     –          580  

Add: Tampa named storm costs

     –          159  
  

 

 

    

 

 

 

Compensation cash flow, pre-working capital

     1,501        1,886  
  

 

 

    

 

 

 

 

(1)

Adjusted EPS (basic) and adjusted EPS for compensation purposes are non-GAAP financial ratios that do not have standardized meanings under USGAAP. A reconciliation of adjusted net income to reported net income and the resulting calculation of adjusted EPS (basic) for 2019 and 2022 are included in the “Non-GAAP Financial Measures” section of Emera’s Management’s Discussion and Analysis as at February 14, 2020 and the “Non-GAAP Financial Measures and Ratios” section of Emera’s Management’s Discussion and Analysis as at February 23, 2023, respectively, which sections are incorporated by reference herein and as filed on the company website at www.emera.com and on SEDAR at www.sedar.com.

The Committee applied the principles laid out in the 2022 Emera Corporate Scorecard in determining the adjustments to the reported figures.

The resulting overall performance factor applied to the 2020 PSU grant was 140 per cent (or 1.4), based on Emera’s compensation EPS growth rate exceeding stretch performance and the growth in compensation cash flow, pre-working capital exceeding target. Since Emera’s TSR was in the bottom quartile of performance of the companies in the S&P/TSX Capped Utilities Index for 2020 to 2022, the relative TSR modifier was triggered, resulting in a 25 per cent reduction to the overall performance factor.

The total payout for all PSU Plan participants in respect of the 2020 PSU grant was approximately $18.5 million. The payout for each participant was 152 per cent of the original grant value (other than participants whose payouts were prorated due to retirement or leave of absence), which factors in share price appreciation, notional dividend reinvestment and the performance factor.

 

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Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

2022 PSU Grant Performance Metrics

The Company’s long-term focus continues to be on EPS growth and long-term shareholder value creation. Accordingly, the Company used the following two weighted metrics for the 2022 PSU grant:

 

1.

Compensation EPS growth, which continues to be a fundamental measure of the increase in profitability of the Company; and

 

2.

Relative Total Shareholder Return (“TSR”), a key measure of Emera’s relative performance against a Canadian custom peer group.

The TSR metric is new for the 2022 PSU grant and will measure Emera’s TSR against the average of the below Canadian custom peer group, which is comprised of close industry peers who Emera competes with for capital.

Relative Total Shareholder Return Custom Peer Group

 

Company name

  

Industry classification

Fortis Inc.

Hydro One Limited

Canadian Utilities Limited

Algonquin Power & Utilities Corp.

AltaGas Ltd.

Enbridge Inc.

TC Energy Corporation

  

Electric Utilities

Electric Utilities

Multi-Utilities

Multi-Utilities

Gas Utilities

Oil, Gas and Consumable Fuels

Oil, Gas and Consumable Fuels

The combination of the two metrics effectively measures management’s contributions to the creation of long-term value for shareholders.

The performance period for PSUs granted in 2022 is from January 1, 2022 to December 31, 2024 and the table below shows the performance factor levels:

 

Metric

   Weighting     Threshold (50%)     Target (100%)     Stretch (200%)  

Average annual growth in compensation EPS

     75 %      3 %      6 %      9 % 

Relative Total Shareholder Return

     25 %     


Equal to -25% (i.e.,
2,500 bps) of Peer
Group

Average

 
 
 

 

   


Equal to
Peer
Group
Average
 
 
 
 
   


Greater than or equal
to +25% (i.e., 2,500
bps) of Peer Group

Average

 
 
 

 

The threshold, target and stretch levels of performance are consistent with those for previous grants, and are calibrated against a combination of the Company’s five-year business plan projections, dividend growth rate, actual and forecasted performance levels of peers, and overall assessment of the expectations of shareholders.

The performance targets for the PSU awards are used for compensation purposes only and are not suitable for any other purpose. There is no assurance that any performance level will be met. The targets may also constitute forward-looking information. Forward-looking statements are based upon a number of assumptions and are subject to a number of known and unknown risks and uncertainties, any of which are beyond Emera’s control, which could cause actual results to differ materially from the performance targets. Please see the cautionary statement in Emera’s 2022 Annual Report with respect to risks and assumptions relevant to Emera’s determination of performance targets for compensation purposes.

Restricted Share Unit Plan

The Restricted Share Unit Plan was introduced in 2020 after a market review determined that Emera had a higher weighting of PSUs than most of its peers. The plan is designed to achieve more balance between risk and leverage in Emera’s long-term incentive programs, while remaining consistent with our pay-for-performance philosophy.

An RSU is a notional share unit that is based on the value of an Emera common share – the value of an RSU changes directly in correlation to the value of an Emera share. RSUs also earn dividends similar to Emera shares; when a dividend is paid on Emera’s common shares, each participant is allocated additional RSUs based on the dividend paid on an equivalent number of Emera common shares.

 

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Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Similar to PSUs, designated senior leaders are awarded RSUs annually based on a pre-determined target of their base salary and the average 50 trading-day Emera common share price immediately preceding the effective grant date (the average is used to smooth out any short-term fluctuations in the share price). Each RSU grant has a three-year vesting period.

At the end of the three-year period, RSUs are valued and paid out in cash calculated by multiplying the original number of RSUs granted and all additional notional dividends by the average 50 trading-day closing price for Emera common shares at the end of the three-year period. The calculation is as follows:

 

RSU Payout    =    Original Grant + Notional Dividends    ×    Closing Share

Restricted Share Unit Plan Results

The 2020 RSU grant had a vesting period of January 1, 2020 to December 31, 2022 and is the first grant under the RSU plan to pay out since its inception in 2020.

The total payout for all RSU Plan participants in respect of the 2020 RSU grant was approximately $10 million. The payout for each participant was 108 per cent of the original grant value (other than participants whose payouts were prorated due to retirement or leave of absence), which factors in share price appreciation and notional dividend reinvestment.

Senior Management Stock Option Plan

The Board of Directors has delegated the administration of the Stock Option Plan to the MRCC. The MRCC is responsible for approving, based on management’s recommendation, which employees of the Company and its operating companies will be eligible to participate in the Stock Option Plan.

Stock options are designed to deliver a percentage of the long-term incentive opportunity for senior management, including the NEOs, and are an important component of competitive executive compensation. Grants are calculated each year based on each executive’s long-term incentive target percentage and base salary and, generally, the grant amount increases with the level of responsibility. The Company considers stock options to be in alignment with long-term shareholder interests and the MRCC continues to review the use of options annually. All NEOs participate in the Stock Option Plan and have received stock options in 2022 as part of their long-term incentive.

The Company has historically valued stock options based on the Black-Scholes valuation methodology. However, the Committee adopted a floor value ratio of 10 per cent in 2015, following a review of market practices on valuation methodologies. If the Black- Scholes methodology leads to a value ratio that is less than 10 per cent, the floor of 10 per cent will apply. All other factors being equal, the use of a higher value ratio leads to fewer options. The Committee considers the application of a 10 per cent floor to be a prudent step to maintaining stock options as a part of the Long-term Incentive Program, while reflecting prevailing market conditions. The exercise price for stock options is the closing price of an Emera common share on the day immediately preceding the effective grant date. Options have a 10-year term and must be exercised before the expiry date and any unexercised options are forfeited upon expiry.

For the 2022 stock option grant, the Black-Scholes valuation resulted in a value ratio ranging from 11.9 per cent to 3.3 per cent. The range was dependent on the number of months over which the volatility calculation was measured, from 12 to 120 months. Because the valuation was 11.9 per cent over a 36-month period, the floor value ratio was not applied. Accordingly, the value of each option granted in 2022 was $6.93, which was 11.9 per cent of the closing Emera common share price of $58.26 on February 15, 2022, the trading day immediately preceding the grant date. The share price of $58.26 is also the exercise price for the 2022 grant.

 

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Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Commencing with the 2022 stock option grant, stock options vest in 20 per cent increments on the first, second, third, fourth and fifth anniversaries of the grant date. Unless a stock option has expired, vested options may be exercised by the earlier of either six months following the date of termination without cause or the expiry of the option in accordance with its terms and by the earlier of either 60 days following the date of termination for cause or resignation or the expiry of the option in accordance with its terms. If stock options are not exercised within such time, they expire. In the event of death, any unvested options that would vest within 12 months of the date of death will vest immediately and all vested options may be exercised by the option holder’s beneficiary or legal representative by the earlier of either six months from the date of death or the expiry date of the option. Any unvested options that are not scheduled to vest within 12 months of the option holder’s death will expire. Senior executives are entitled to an early retirement provision, as defined in the Stock Option Plan, which allows vested options that are held at the time of retirement to remain exercisable until the end of the option’s term. In the case of early retirement, unvested options held as of the retirement date will expire. The Stock Option Plan also provides for a normal retirement provision, which allows unvested stock options to continue to vest in full and in normal course and be exercised until the end of the option’s term. In both retirement scenarios and in consideration of the continued vesting, the executive must agree and adhere to non-compete and non-solicit restrictive covenants for a period of (1) 24 months in the case of the CEO and (2) 18 months in the case of all other option holders (or a shorter period if the MRCC considers it appropriate) from the retirement date. If the option holder fails to comply with any of the restrictive covenants, then all unvested and vested options will expire as of the date of such a breach. If a change of control occurs and an executive is terminated within 24 months of the change of control and for “good reason” as defined in the plan text and in this Circular under Termination and Change of Control Benefits, unvested options held at the time of termination vest immediately and must be exercised by the earlier of either six months from the termination date or the expiry date of the option. Continued compliance with any obligations under the executive’s terms of employment, including non-compete and non-solicit covenants in favour of the Company is required. In the event of a change of control, the Board may, without the consent of the option holder, (1) convert or exchange any outstanding options for rights or other securities of substantially equal value in any entity participating in or resulting from the change of control, (2) accelerate the vesting of options or terminate options upon or immediately prior to the change of control, (3) substitute shares of the entity resulting from the change of control for shares of the Company, or (4) terminate options in exchange for an amount of cash and/or property equal to the shares underlying the options, less the exercise price, as of the date of the change of control. If the Board determines in good faith that the options would have no value upon exercise, the Board may terminate the options without payment. Please see Termination and Change of Control Benefits for the NEOs’ entitlements on departure.

The maximum percentage of shares under all security-based compensation arrangements (including the Stock Option Plan and the Employee Common Share Purchase Plan) issuable to insiders of the Company at any time is 10 per cent of the issued and outstanding shares of the Company. The maximum number of shares to be optioned to any one person under the Stock Option Plan is 5 per cent of the issued and outstanding shares of the Company at the date of the grant of the option. The number of shares issued to insiders, within any one-year period, under all security-based compensation arrangements, will not exceed 10 per cent of the issued and outstanding shares of the Company.

Under the Stock Option Plan, options may be granted in respect of authorized and unissued common shares of the Company to a maximum of 14.7 million shares, or approximately 5.45 per cent of the total issued and outstanding common shares of the Company as of December 31, 2022.

There have been 8,704,711 common shares issued under the Stock Option Plan since its inception, which represents approximately 3.22 per cent of the total issued and outstanding common shares of the Company as of December 31, 2022, leaving 5,995,289 common shares reserved for issuance under the Plan, representing 2.22 per cent of the total issued and outstanding common shares as at December 31, 2022. There are 2,853,879 common shares issuable under actual grants of options, which represent approximately 1.06 per cent of the total issued and outstanding common shares of the Company as of December 31, 2022 and, of that amount, 1,505,479 are vested and 1,348,400 are unvested.

 

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Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

The Board of Directors of the Company may amend or discontinue the Stock Option Plan by resolution at any time and may, without shareholder approval, make amendments such as changes to vesting provisions and other minor changes of a housekeeping nature; however, shareholder approval is required for any amendment that:

 

  •  

Increases the number of common shares reserved for issuance, except an increase made in proportion to an increase in the number of common shares outstanding due to a stock dividend, stock split, amalgamation, reorganization, merger or similar event;

 

  •  

Extends eligibility to participate to non-employee Directors;

 

  •  

Permits rights under the Stock Option Plan to be transferred other than for normal estate settlement purposes;

 

  •  

Permits awards to be granted under the Stock Option Plan in addition to options;

 

  •  

Increases either of the 10 per cent insider participation limits;

 

  •  

Reduces the option price of an option except for the purpose of maintaining option value in connection with a change of control or pursuant to the provisions in the Stock Option Plan, which permit equitable adjustments to be made to the option price in connection with a stock dividend, stock split, share reclassification, amalgamation, reorganization, merger or similar event;

 

  •  

Extends the term of a stock option beyond the original expiry date;

 

  •  

Permits the expiry of a stock option to be beyond 10 years from its date of grant (except in the case of the automatic extension of the expiry date of an option as a result of the expiry date falling within a blackout period or within five business days of the blackout period being lifted); or

 

  •  

Deletes or reduces the range of amendments that require shareholder approval under this paragraph.

The table below summarizes certain ratios regarding the Stock Option Plan, namely dilution, burn rate and overhang as defined in the table.

 

     2022 (%)      2021 (%)      2020 (%)  

Dilution

        

(number of options outstanding, divided by the weighted average total issued and outstanding common shares for the applicable fiscal year)

     1.08        1.01        0.92  

Burn rate

        

(number of options granted in an applicable fiscal year, divided by the weighted average total issued and outstanding common shares for the applicable fiscal year)

     0.18        0.25        0.20  

Overhang

        

(shares available for issuance, plus options outstanding, divided by the weighted average total issued and outstanding common shares for the applicable fiscal year)

     2.26        2.41        1.42  

The stock options issued under the Stock Option Plan are non-assignable, though the Plan permits transfers from the estate of a deceased option holder to the ultimate beneficiaries. The option can then be exercised by such beneficiaries.

The Company does not provide financial assistance to participants to facilitate the purchase of shares through the Stock Option Plan.

Amendment to the Senior Management Stock Option Plan

The Company has proposed an amendment to the Senior Management Stock Option Plan to allow for an extension of the option term if an option is scheduled to expire during, or shortly following, a Company imposed trading blackout period. The amendment provides that if an option is to expire during a blackout period or within five business days of the blackout period being lifted, the option expiry date will be extended by 10 business days immediately following the end of the blackout period. This amendment provides additional flexibility to our option holders and mitigates any risk of options expiring during a period when the option holder is unable to trade in Company securities due to a trading blackout period. A corresponding change was made to the amendment provision of the Plan. As amended, shareholder approval will be required to extend the term of an option beyond the original expiry date except in the case of the automatic extension of the expiry date of an option as a result of the expiry date falling within a blackout period or within five business days of the blackout period being lifted.

 

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Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Other Executive Benefits

The Company provides executives with additional benefits in accordance with the compensation program objectives. As part of their compensation and consistent with market practice, executives, including the NEOs, are eligible to receive an annual perquisite allowance, which is paid in equal bi-weekly cash instalments over the course of the year and is reviewed on an annual basis. In 2022, Mr. Balfour received an annual perquisite allowance of $30,000 and the other NEOs received an annual perquisite allowance of $20,000. The annual perquisite allowance is designed to cover additional benefits, such as:

 

  •  

Monthly car allowance plus mileage, as applicable; and

 

  •  

Annual wellness/fitness allowance.

These benefits, including company paid parking, are considered taxable benefits and are reported in the Summary Compensation Table for the NEOs.

Performance Graph

The following performance graph compares Emera’s cumulative total shareholder return or “TSR” (assuming an investment of $100 and reinvestment of dividends) for its common shares with that of the S&P/TSX Capped Utilities Index and the S&P/TSX Composite Index.

 

LOGO

 

As at December 31

   2017 ($)      2018 ($)      2019 ($)      2020 ($)      2021 ($)      2022 ($)  

LOGO

 

Emera Inc.

     100.00        98.21        131.27        133.04        162.73        139.47  
LOGO  

S&P/TSX Capped Utilities Total Return

     100.00        92.31        126.91        146.31        163.35        146.10  
LOGO  

S&P/TSX Composite Total Return

     100.00        91.11        111.96        118.23        147.89        139.25  
LOGO  

TDC ($ thousands)

     12,869        13,136        13,540        15,608        15,263        15,360  

Emera’s cumulative TSR for the five-year period from December 31, 2017 to December 31, 2022 was 39 per cent, compared to the 46 per cent return of the S&P/TSX Capped Utilities Index and 39 per cent return of the S&P/TSX Composite Index. Emera’s TSR decreased 14 per cent from 2021 to 2022. The above graph also shows total compensation for our NEOs over the past six years, which includes annual base salary, long-term incentive grant value, and annual short-term incentive payouts. As demonstrated, the trend in NEO compensation continues to align with the trend in TSR.

 

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Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

TOTAL SHAREHOLDER RETURN AND PRESIDENT AND CEO COMPENSATION

As noted in the Message from the Management Resources and Compensation Committee to Our Shareholders, a fundamental principle of Emera’s compensation philosophy is to align pay with performance, by linking a significant portion of the compensation the Company pays its executives to the achievement of objectives measuring whether shareholders are experiencing strong value for their investment.

Considering this principle, at the end of 2022 the Company undertook its annual analysis of the alignment between the President and CEO’s compensation and the experience of shareholders. The analysis reviewed the compensation of the President and CEO over the past five years and compared the results to the shareholder experience, as measured by TSR, over the same periods. The review included both realized pay (which consists of amounts paid out for a particular performance year) and realizable pay (which consists of the value of any outstanding equity-based awards).

The analysis looked at the shareholders’ experience using five different measurement periods, recognizing that shareholders have acquired their shares at different times. Each period had the same end point (December 31, 2022) but started at a different beginning period, from January 1, 2018 to January 1, 2022. The analysis measured the dollar return per $100 of investment over each period as compared to the President and CEO’s economic experience, measured by the dollars realized and realizable per $100 of target compensation awarded over the same periods.

The following lookback table shows the results of the review:

 

Pay year

  

Target total

direct
compensation ($) (1)(2)

  

Total realized/
realizable value at

Dec. 31, 2022 ($) (3)

  

Measurement period

   Realized/
realizable value of
$100 target pay
awarded to CEO ($) (3)
     Value of
$100 shareholder
investment as of
Dec. 31, 2022 ($) (4)
     Difference ($)  

2018

   4,800,000    8,203,408    Jan. 1, 2018 – Dec. 31, 2022      171        139        -32  

2019

   5,900,000    6,975,374    Jan. 1, 2019 – Dec. 31, 2022      118        142        24  

2020

   7,000,000    7,601,492    Jan. 1, 2020 – Dec. 31, 2022      109        106        -3  

2021

   7,700,000    6,777,165    Jan. 1, 2021 – Dec. 31, 2022      88        105        17  

2022

   7,865,000    6,037,246    Jan. 1, 2022 – Dec. 31, 2022      77        86        9  
           

 

 

    

 

 

    

 

 

 
         Average      113        116        3  
           

 

 

    

 

 

    

 

 

 

 

(1)

The lookback table shows the compensation of the President and CEO, Scott Balfour, for 2018 and 2022.

(2)

Includes salary, short-term incentive at target and the grant value of long-term incentives.

(3)

Factors in salary, short-term incentive payout, PSU payout, value realized from exercised stock options and the market value of any outstanding PSUs, DSUs and in-the-money unexercised stock options as of December 31, 2022.

(4)

Represents the cumulative value of a $100 investment in Emera common shares made on the first day of the period indicated, assuming dividends are reinvested.

The analysis concluded that Emera’s compensation framework provided appropriate alignment between the President and CEO’s compensation and the shareholder experience over the long term. This analysis also assists the MRCC in considering various compensation outcomes when assessing compensation changes for the President and CEO each year.

In keeping with Emera’s compensation philosophy, a significant component of NEO compensation consists of long-term incentives (PSUs, RSUs and stock options), which are designed to focus executives on the long-term success of the Company. These long- term incentives are directly affected by changes in Emera’s common share price and TSR. This helps create a direct correlation between the shareholder experience and the compensation the Company pays its senior executives.

As described in Performance Share Unit Plan, each PSU grant is subject to the achievement of financial objectives and, at the end of the performance period, a performance factor is applied, which is determined based on the extent to which the Company has met those objectives. The performance factors for the PSU Plan, expressed in terms of a percentage, for the past five years were 65 per cent for the period ended in 2018, 100 per cent for the period ended in 2019, 112 per cent for the period ended in 2020, 74 per cent for the period ended in 2021 and 140 per cent for the period ended in 2022.

The total annual salary, short-term incentive and PSU payouts in 2022 for the five NEOs totalled $12 million, which represents 1.27 per cent of the Company’s net earnings attributable to common shareholders of $945 million. The MRCC is comfortable that the payout totals for 2022 are reasonable based on the Company’s performance and demonstrate that the Company’s compensation programs are aligned with the interests of our shareholders.

 

  EMERA INCORPORATED   89


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

NEO Summary Compensation Table

The table below shows the compensation awarded to the Company’s NEOs for the last three fiscal years.

 

Name and principal position

   Year      Salary ($) (1)      Share-based
awards ($) (2)
     Option-
based
awards ($) (3)
     Non-equity
incentive plan
compensation
Annual
incentive
plans ($) (4)
     Pension
value
($)
     All other
compensation
($) (5)
     Total
compensation
($)
 

Scott Balfour

     2022        1,100,000        4,248,511        1,416,492        1,085,700        361,651        35,656        8,248,010  

President and Chief Executive Officer

     2021        1,098,077        4,124,917        1,375,101        1,288,100        357,000        37,349        8,280,544  
     2020        1,038,461        3,750,209        1,249,800        1,420,000        293,000        36,546        7,788,016  

Greg Blunden

     2022        599,654        990,150        329,868        473,760        105,847        25,656        2,524,935  

Chief Financial Officer

     2021        584,519        965,077        321,930        548,028        88,000        27,749        2,535,303  
     2020        581,039        755,995        252,000        556,640        97,000        27,398        2,270,072  

Bruce Marchand

     2022        544,769        653,704        218,295        376,541        150,062        21,656        1,965,027  

Chief Risk and Sustainability Officer

     2021        534,519        641,872        214,109        438,540        171,000        23,749        2,023,789  
     2020        529,115        612,017        204,000        434,520        199,000        33,738        2,012,390  

Karen Hutt

     2022        508,846        688,610        229,383        352,359        52,748        22,376        1,854,322  

EVP, Business Development & Strategy

     2021        459,327        552,066        183,960        377,062        49,000        24,469        1,645,884  
     2020        441,096        366,336        122,400        362,100        39,000        25,246        1,356,178  

Richard Janega

     2022        524,769        492,027        164,241        362,723        138,666        286,205        1,968,631  

COO, Elec. Util., Canada & Caribbean

     2021        515,000        482,812        160,965        422,146        26,000        25,349        1,632,272  
     2020        534,058        482,950        160,800        511,910        565,000        26,627        2,281,345  

 

(1)

The figure shown represents the actual base earnings paid each year.

(2)

The figure shown is the value of PSU and RSU grants as of the effective grant date. The grant value of PSUs and RSUs granted in 2022 was based on the average 50-trading day closing share price up to December 31, 2021 ($59.77). The 50-day share price average is used for PSU and RSU grants to smooth out any short-term fluctuations in share price immediately preceding the grant date. The value of PSUs on payout is subject to the achievement of specific performance objectives over the respective three-year performance period. If those objectives are not met, payouts may be less than the initial value of the grant noted in this column, and if performance objectives are exceeded, payouts may be higher than the amount noted in this column.

(3)

The value of each stock option granted to the NEOs in 2022 was determined to be equal to 11.9 per cent of the February 15, 2022 closing share price of $58.26 or $6.93 per option. The Company has adopted a floor value ratio of 10 per cent; if the Black-Scholes methodology leads to a value ratio that is less than 10 per cent, the floor of 10 per cent will apply. The Black-Scholes valuation for 2022 resulted in a value ratio of 11.9 per cent to 3.3 per cent, using an estimated dividend yield of 4.2 per cent, and a risk-free interest rate of 1.47 per cent. The range was dependent on the number of months over which the volatility calculation was measured, from 12 to 120 months, which led to volatility measurements from 22.1 per cent to 11.1 per cent. Because the Black-Scholes valuation was above 10 per cent when calculated over a 36-month period, the actual result was used.

(4)

In 2022, all NEOs participated in the Emera Corporate Scorecard, which had a result of 98.7 per cent. The Short-Term Incentive Plan and the 2022 results are described in greater detail in Short-Term Incentive Plan. The figures shown reflect amounts earned in the 2022 performance year and paid in 2023. Mr. Balfour and Mr. Blunden elected to receive 50 per cent of their payout in the form of DSUs and Mr. Janega elected to receive 30 per cent of his payout in the form of DSUs.

(5)

All other compensation in 2022 consists of: for Mr. Balfour, a cash perquisite allowance of $30,000 and other taxable benefits; for Mr. Blunden, a cash perquisite allowance of $20,000 and other taxable benefits; and for Mr. Marchand, a cash perquisite allowance of $20,000 and other taxable benefits; for Ms. Hutt, a cash perquisite allowance of $20,000 and other taxable benefits; for Mr. Janega, a cash perquisite allowance of $20,000, a cash retirement award valued at $262,500 and other taxable benefits.

 

90   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Outstanding Share-based Awards and Option-based Awards

The following table describes all option-based and share-based awards outstanding as of December 31, 2022 for each NEO:

 

     Option-based awards (1)
(stock options)
     Share-based awards
(performance share units (“PSUs”), restricted share units (“RSUs”)
and deferred share units (“DSUs”))
 

Name

   Number of
securities
underlying
unexercised
option (#)
     Option
exercise
price ($)
     Option
expiration
date
     Value of
unexercised
in-the-money
options ($)  (2)
     Number of
shares or units of
shares that have
not vested (#) (3)
     Market or payout
value of share-
based awards
that have
not vested ($) (4)
     Market or payout
value of vested
share-based awards
that have not been
paid out ($) (5)
 

Scott Balfour

     34,800        32.35        2/11/2024        675,120        157,126        8,117,114        6,309,473  
     40,400        42.71        2/11/2025        365,216           
     52,100        46.19        2/17/2026        289,676           
     66,300        45.16        2/14/2027        436,917           
     175,400        39.93        2/13/2028        2,073,228           
     210,100        46.39        2/20/2029        1,126,136           
     208,300        60.03        2/19/2030        —             
     269,100        51.12        2/17/2031        169,533           
     204,400        58.26        2/15/2032        —             

Greg Blunden

     9,325        45.16        2/14/2027        61,452        36,694        1,895,624        2,863,135  
     23,500        39.93        2/13/2028        277,770           
     36,675        46.39        2/20/2029        196,578           
     42,000        60.03        2/19/2030        —             
     63,000        51.12        2/17/2031        39,690           
     47,600        58.26        2/15/2032        —             

Bruce Marchand

     9,090        42.71        2/11/2025        82,174        24,320        1,256,395        1,897,390  
     19,500        46.19        2/17/2026        108,420           
     32,500        45.16        2/14/2027        214,175           
     30,675        39.93        2/13/2028        362,579           
     39,100        46.39        2/20/2029        209,576           
     34,000        60.03        2/19/2030        —             
     41,900        51.12        2/17/2031        26,397           
     31,500        58.26        2/15/2032        —             

Karen Hutt

     8,500        46.19        2/17/2026        47,260        23,131        1,194,970        1,007,742  
     11,900        45.16        2/14/2027        78,421           
     13,875        39.93        2/13/2028        164,003           
     19,400        46.39        2/20/2029        103,984           
     20,400        60.03        2/19/2030        —             
     36,000        51.12        2/17/2031        22,680           
     33,100        58.26        2/15/2032        —             

Richard Janega

     2,500        42.71        2/11/2025        22,600        18,299        945,336        3,155,017  
     12,500        46.19        2/17/2026        69,500           
     14,300        45.16        2/14/2027        94,237           
     37,200        39.93        2/13/2028        439,704           
     33,700        46.39        2/20/2029        180,632           
     26,800        60.03        2/19/2030        —             
     31,500        51.12        2/17/2031        19,845           
     23,700        58.26        2/15/2032        —             

 

(1)

Option-based awards include both vested and unvested options.

(2)

The value of all unexercised option-based awards was calculated using a December 30, 2022 closing share price of $51.75.

(3)

Unvested share-based awards include PSUs, RSUs and any additional PSUs and RSUs from dividend reinvestment relating to such grants as of December 31, 2022.

(4)

The market or payout value of share-based awards was calculated based on an assumed performance factor of 1.0 and the average closing share price for the last 50 trading days of 2022 ($51.66).

(5)

These figures represent only vested DSUs, as PSUs and RSUs are paid out upon vesting, and are based on the average closing share price for the last 50 trading days of 2022 ($51.66).

 

  EMERA INCORPORATED   91


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Incentive Plan Awards – Value Vested or Earned During the Year

The following table describes all option-based awards, share-based awards and non-equity incentives that vested, or were earned, during 2022 for each NEO:

 

Name

   Option-based awards value
vested during 2022 ($) (1)
     Share-based awards
(performance share units (“PSUs”)
and  restricted share units (“RSUs”))
value vested during 2022 ($) (2)
     Non-equity incentive plan
compensation – value earned
during the year ($) (3)
 

Scott Balfour

     1,995,080        5,145,883        1,085,700  

Greg Blunden

     494,160        1,037,349        473,760  

Bruce Marchand

     394,497        839,794        376,541  

Karen Hutt

     216,490        502,741        352,359  

Richard Janega

     340,339        662,652        362,723  

 

(1)

Represents the aggregate dollar value that would have been realized if stock options had been exercised on the applicable vesting (eligibility) date in 2022.

(2)

The value of PSUs and RSUs vested in 2022 is based on the 2020 PSU and RSU grants, which both had three-year vesting periods from January 1, 2020 to December 31, 2022. The payout is calculated based on the original grant with accumulated dividends, multiplied by the performance factor (only applied to PSUs), multiplied by the average closing share price for the last 50 trading days of 2022 ($51.66). The performance factor for the 2020 PSU grant was based on Emera’s growth in EPS and cash flow over the three-year performance and vesting period as well as Emera’s TSR relative to the TSR of the S&P/ TSX Capped Utilities Index. The performance factor result was 140 per cent. More details on the PSU Plan and results can be found in Performance Share Unit Plan.

(3)

This amount represents the 2022 incentive payouts as disclosed in the NEO Summary Compensation Table and includes any amounts that were deferred into DSUs.

Aggregate Option Exercise During 2022 and 2022 Option Values

The following table summarizes the number of common shares, if any, each NEO acquired pursuant to the exercise of stock options in 2022, the aggregate value realized upon exercise, and the number of common shares covered by unexercised options under the Stock Option Plan as of December 31, 2022. The aggregate value realized upon exercise is the difference between the fair market value of the common shares on the exercise date and the exercise price of the option. The value of unexercised in-the-money options at year-end is the difference between the exercise price of the options and the fair market value of the common shares on December 30, 2022, which was $51.75.

 

                   Unexercised options at
December 31, 2022
     Value of unexercised in-the-money
options at December 31, 2022
 

Name

   Securities acquired
on exercise (#)
     Aggregate value
realized ($)
     Exercisable (#)      Unexercisable (#)      Exercisable ($)      Unexercisable ($)  

Scott Balfour

     0        0        698,000        562,900        4,727,142        408,684  

Greg Blunden

     0        0        94,025        128,075        480,196        95,294  

Bruce Marchand

     0        0        148,565        89,700        931,128        72,192  

Karen Hutt

     0        0        68,025        75,150        373,342        43,006  

Richard Janega

     34,600      $ 945,597        113,050        69,150        766,476        60,042  

Pension Plan Benefits

Emera has adopted a pension governance framework that sets out the structure and processes for overseeing the management and administration of all pension plans sponsored or administered by Emera and its operating companies to ensure that the liabilities associated with such pension plans are being appropriately managed.

The NEOs are members of the Canadian corporate pension plan (“Pension Plan”) and participate on either a defined benefit basis or a defined contribution basis. For 2022, four NEOs participated in the defined benefit component of the Pension Plan and two NEOs participated in the defined contribution component of the Pension Plan.

 

92   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Defined Benefit

The following table shows years of credited service, estimated pension amounts and changes to accrued obligations from January 1, 2022 to December 31, 2022 for the NEOs who participated in the Pension Plan on a defined benefit basis.

 

            Annual benefits payable                             

Name

   Number of
years credited
service (#)
     At year-end
($) (1)
     At age 65
($)
     Accrued
obligation
at the start of
the year ($)
     Compensatory
change ($) (2)
     Non-
compensatory
change ($) (2)
    Accrued
obligation at
year-end ($) (3)
 

Scott Balfour

     10.7        318,173        515,280        4,549,423        361,651        (945,106 )      3,965,968  

Greg Blunden (4)

     1.3        19,317        19,317        640,011        21,199        (93,539 )      567,671  

Bruce Marchand

     11.0        139,394        139,394        2,227,581        150,062        (351,592 )      2,026,051  

Rick Janega

     33.1        428,476        453,345        8,724,743        138,666        (1,839,869 )      7,023,540  

 

(1)

All NEOs were eligible for an immediate pension at year-end. The amount shown is the accrued pension starting at the NEO’s unreduced retirement date if the NEO terminated employment at December 31, 2022.

(2)

The compensatory and non-compensatory changes are described in more detail below.

(3)

The accrued pension obligation is calculated following the method prescribed under USGAAP (section 715 of the standards of the Financial Accounting Standards Board) and by the Canadian Institute of Chartered Accountants and is based on management’s best estimate of future events that affect the cost of pensions, including assumptions about future salary adjustments and short-term incentive awards.

(4)

Mr. Blunden accrues future benefits under the defined contribution component of the Pension Plan and has frozen service under the defined benefit component of the Pension Plan.

The accrued obligation of a pension entitlement is the present value of the expected future annual benefits payable taking into account service accrued to date and the expected salaries used to determine the annual benefit payable at retirement. Each year, the value of the accrued obligation changes as a result of compensatory changes and non-compensatory changes, which are shown in the table above.

Compensatory changes are caused by changes in the annual benefit payable and result primarily from three factors: (i) new accrued service (the employer current service cost); (ii) the impact of salary increases greater than expected on past benefits (estimated increases are already built into the accrued benefit obligation); and (iii) plan changes impacting, for example, accrued service or when benefits are payable. There were no Pension Plan changes that materially affected the above figures in 2022.

Non-compensatory changes are caused by interest on the accrued obligation and current service cost, employee required contributions and changes in the assumptions used to calculate the present value of the future annual benefit payment stream. These assumptions include the mortality table, salary scale, retirement assumption and the inflation assumption used for calculating indexing and the discount rate. The non-compensatory changes in 2022 were driven largely by changes in actuarial assumptions as well as interest on the accrued obligation and current service cost. The assumption changes from December 31, 2021 to December 31, 2022 were a change in the discount rate from 3.26 per cent to 5.17 per cent for the Pension Plan, 3.22 per cent to 5.17 per cent for the Supplementary Retirement Plan, and 2.48 per cent to 5.13 per cent for the retirement award. The net effect of the discount rate change is a decrease to obligations.

The defined benefit component of the Pension Plan entitles members to pension benefits based on 2 per cent of the average of the member’s five highest years of pensionable earnings, multiplied by each year of credited service to a maximum of 35 years credited service. For the NEOs, pensionable earnings include base salary plus up to 50 per cent of their target short-term incentive. Upon a member reaching age 65, pension benefits under the Pension Plan are reduced by an amount approximately equal to the amount payable under the Canada Pension Plan. For members who retire from active service, the pension is payable on an unreduced basis upon the earlier of age 60 or age 55, provided that age and years of service add to at least 85. For members who joined the Pension Plan on or after July 1, 2004, the age 60 unreduced retirement age condition is replaced by age 62 with 15 years of service. A member may also retire on a reduced formula if the member has attained age 55, but does not qualify for an unreduced pension. Spousal benefits are paid on the death of a member at the rate of 60 per cent of regular pension benefits. Pensions are indexed to the consumer price index to a maximum of 6 per cent per annum.

Under the terms of Mr. Balfour’s employment agreement, his average five highest years of pensionable earnings is capped at $1.75 million for purposes of calculating his pension.

 

  EMERA INCORPORATED   93


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

For 2022, members of the defined benefit component of the plan contributed 7.4 per cent of eligible earnings up to the year’s maximum pensionable earnings (“YMPE”) under the Canada Pension Plan, and 9.5 per cent of earnings between the YMPE and the amount on which pension benefits may be earned under a registered pension plan as permitted by the Income Tax Act (Canada).

Due to Canada Revenue Agency limitations on the maximum pension benefit that may be paid under the Pension Plan, a portion of the pension the NEOs earned after January 1, 1992 is provided under the terms of a supplemental employee retirement plan (“Supplementary Retirement Plan”), which is unfunded but secured by a letter of credit deposited in a retirement compensation trust. The Supplementary Retirement Plan is non-contributory. The Supplementary Retirement Plan generally mirrors the terms of the Pension Plan, with the exception that benefits earned on service in the Supplementary Employee Retirement Plan (“SERP”) after December 31, 2017 are not indexed on retirement. The Company does not grant additional years of credited service to NEOs under the Pension Plan or Supplementary Retirement Plan.

The defined benefit component of the Pension Plan was closed to new non-union employees hired after January 8, 2013 and to new union employees hired after October 31, 2014. The defined benefit component of the Supplementary Retirement Plan was closed to new entrants as of December 31, 2017. Any employees who become eligible to participate in the Supplementary Retirement Plan after December 31, 2017 will participate in the defined contribution component.

The compensatory and non-compensatory change figures for Mr. Blunden and Mr. Janega include the increase in value of a potential retirement award. Certain employees of the Company hired before August 1, 2007 are eligible for a retirement award if they continue working with the Company until their unreduced retirement date. The retirement award is calculated by multiplying the employee’s weekly base salary immediately preceding retirement by the employee’s number of years of service at retirement, to a maximum of 26 weeks of salary, and is payable as a lump sum on retirement. If the employee terminates employment with the Company prior to his or her unreduced retirement date, no retirement award is payable. Mr. Blunden will be entitled to the retirement award if he continues working for an Emera company until his unreduced retirement date. Mr. Balfour and Mr. Marchand are not eligible for a retirement award.

Defined Contribution

The following table shows the changes to accumulated value from January 1, 2022 to December 31, 2022 for the NEOs who participated in the Pension Plan on a defined contribution basis.

 

Name

   Accumulated value at
start of year ($)
     Compensatory
change ($) (1)
     Non-compensatory
change ($) (2)
     Accumulated value
at end of year ($)
 

Greg Blunden (3)

     1,331,780        84,648        (86,972 )       1,329,457  

Karen Hutt (4)

     1,070,871        52,748        (105,410 )       1,018,209  

 

(1)

The compensatory change is the value of Company contributions made based on the defined contribution component of the Pension Plan.

(2)

The non-compensatory change is the value of employee contributions to the Pension Plan, along with investment earnings.

(3)

Mr. Blunden accrues future benefits under the defined contribution component of the Pension Plan and has frozen service under the defined benefit component of the Pension Plan.

(4)

The compensatory and non-compensatory change figures for Ms. Hutt include the increase in value of a potential defined benefit retirement award, as described in the section above this table. Ms. Hutt will be entitled to the retirement award if she continues working for an Emera company until her unreduced retirement date. The accumulated values at the start and end of year also include this potential retirement award.

Under the defined contribution component of the Pension Plan, the Company contributes a base amount of 3 per cent of the participant’s eligible earnings into the participant’s account each pay period. Plan participants can also make contributions of up to six per cent of their eligible earnings to the defined contribution component, with the Company matching half of these contributions. Accordingly, the maximum Company contribution to each participant’s defined contribution account, factoring in the base amount and the matching contribution, is 6 per cent of the participant’s eligible earnings. Canada Revenue Agency limits apply to limit the amount of contributions that can be made under the defined contribution component and, as with the defined benefit component, a portion of the pension a NEO earns in the defined contribution component may be provided under the terms of a Supplementary Retirement Plan.

 

94   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Mr. Blunden and Ms. Hutt participated in the defined contribution component of the Pension Plan in 2022. They and the Company each contributed 6 per cent of their base salary into the Pension Plan up to the total amount permitted under the Income Tax Act, which equated to $15,390 each in 2022. In addition, the Company maintains an account for any Company contributions which would be made in the absence of the Income Tax Act limits, through the Supplementary Retirement Plan. For 2022, the additional Company contribution for Mr. Blunden was $69,258 and for Ms. Hutt was $30,282.

Upon ending active employment with the Company at any age between 55 and 65, plan participants in the defined contribution component of the Pension Plan may start receiving retirement income through the purchase of a life annuity or by converting their account to a life income fund.

The defined contribution component of the Pension Plan is administered on behalf of the Company by a major Canadian insurance company, which acts in accordance with the provisions of the defined contribution component of the Pension Plan, the Income Tax Act and the Nova Scotia Pension Benefits Act.

Deferred Share Unit Plan

The Deferred Share Unit (“DSU”) Plan is another component of Emera’s Long-term Incentive Program for senior leaders. A DSU is a notional share unit that is based on the value of an Emera common share – the value of a DSU changes directly in correlation to an Emera share and earns dividend equivalents in the form of additional DSUs. When a dividend is paid on Emera’s common shares, each participant’s DSU account is allocated additional DSUs based on the dividend paid on an equivalent number of Emera common shares. DSUs are not paid out until such time as the participant is no longer employed by the Company or any of its operating companies. When redeemed, the value of a participant’s DSUs is equivalent to the fair market value of an equal number of common shares of the Company.

The DSU Plan is intended to facilitate achievement of share ownership guidelines (discussed in Executive Share Ownership Requirements) without diluting the shareholder base. Prior to the start of each performance year, each plan participant may elect to defer some or all of the short-term incentive payout associated with that performance year in the form of DSUs. When the short-term incentive is paid to the NEOs, the portion elected is allocated to DSUs rather than paid in cash. Since DSUs are principally an income deferral mechanism, there are no performance metrics attributable to DSUs.

Following a participant’s departure from the Company, on a date selected by the participant not later than December 15 of the next calendar year after departure, the value of the participant’s DSUs is calculated by multiplying the number of DSUs in the participant’s account by the average closing Emera common share price for the 50 trading days preceding the payout date (the 50-day average is used to smooth out any short-term price fluctuations). The after-tax amount is paid to the participant. If a participant is a US taxpayer, payment is made six months following the termination date.

In addition, special DSU awards may be made from time to time by the MRCC to selected executives and senior management to recognize singular achievements or the achievement of certain corporate objectives. The MRCC made no such awards to the NEOs in 2022.

2022 DSU Plan Allocations

The table below identifies how much of the short-term incentive for 2022 that each NEO elected to allocate to DSUs:

 

Name

   Percentage of 2022 annual incentive
elected to deferred share units (%)
     Dollar amount of 2022 annual incentive
elected to deferred share units ($) (1)
 

Scott Balfour

     50        542,850  

Greg Blunden

     50        236,880  

Bruce Marchand

     0        0  

Karen Hutt

     0        0  

Richard Janega

     30        108,817  

 

(1)

The DSU allocations are rounded to the nearest whole unit, so the value of DSUs may vary slightly from the amount of short-term incentive payout allocated.

 

  EMERA INCORPORATED   95


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Executive Share Ownership Requirements and Anti-Hedging Policy

To align the interests of senior management with the interests of shareholders, the Company established share ownership guidelines in 2003 that require designated executives to meet the required ownership level within five years of becoming subject to the guidelines. Mr. Balfour is required to hold shares equal to at least five times his base salary, and all other NEOs are required to hold shares equal to at least three times their respective base salaries. Commencing in 2023, RSUs will no longer contribute to ownership levels. In consideration of this change, impacted executives will have an additional two years to obtain their ownership requirement.

All NEOs are also subject to a one-year post-retirement hold period, which requires the NEOs to maintain a material financial stake in the Company after retirement by holding at least the minimum ownership level of Emera shares for one year after they retire from the Company. This helps maintain a focus on long-term sustainable value and prevents executives from timing their departure to maximize the cash-out value of their equity stake in the Company.

Share ownership is calculated based on: (1) the number of Emera shares an executive owns; and (2) the number of DSUs acquired pursuant to the DSU Plan, which are considered share equivalents.

PSUs, RSUs and stock options do not count for purposes of the share ownership guidelines. Executives have five years to reach the required ownership level and are required to allocate at least 25 per cent of their short-term incentive payout into DSUs in the first year, and at least 50 per cent every year following, until they meet their target share ownership. If an executive does not meet their ownership target within the required time, the MRCC has the ability to allocate some or all of the executive’s short- term incentive payout to DSUs until the ownership target is met.

Since the purpose of the share ownership requirements is to strengthen the alignment between the interests of senior management and shareholders, the Company has established a robust policy restricting executives from taking any steps that break or otherwise interfere with that alignment. All executives are subject to the Company’s anti-hedging policy, which prohibits them from hedging, pledging, monetizing, or otherwise reducing or limiting their economic risk with respect to any Emera securities they hold, directly or indirectly, including DSUs, RSUs, PSUs, and stock options. These prohibited transactions include short-selling, options, puts and calls, as well as derivatives such as forward contracts, equity swaps, collars and futures, or entering into limited recourse loans secured by securities of Emera.

The share ownership levels for the NEOs are set out below. The values shown are based on the closing price of Emera’s common shares on December 30, 2022 of $51.75 (units have been rounded). The table does not include the DSUs that will be allocated as part of the 2022 short-term incentive payout, as described in 2022 DSU Plan Allocations.

 

Name

   Required
ownership
level as a
multiple of
base salary
     Required
ownership
level ($)
     DSUs
held (#)
     Value of DSUs
held ($)
     Common
shares
held (#)
     Value of
common
shares
held ($)
     Total share
and share
equivalent
ownership ($)
     Multiple
of base
salary (1)
     Status
of share
ownership
requirements
 

Scott Balfour

     5.0        5,500,000        122,135        6,320,465        72,392        3,746,311        10,066,776        9.2        Met  

Greg Blunden

     3.0        1,800,000        55,423        2,868,123        2,406        124,511        2,992,634        5.0        Met  

Bruce Marchand

     3.0        1,635,000        36,728        1,900,696        3,804        196,857        2,097,553        3.8        Met  

Karen Hutt

     3.0        1,530,000        19,507        1,009,497        2,476        128,128        1,137,625        2.2        On Track  

Richard Janega

     3.0        1,575,000        61,073        3,160,514        14,553        753,107        3,913,621        7.5        Met  

 

(1)

Based on executive’s respective base salary as of December 31, 2022.

All NEOs, except for one, have met their required ownership levels. Considering the changes to the share ownership calculations, Ms. Hutt will receive a two-year extension to reach her ownership requirement.

 

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Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Employee Common Share Purchase Plan

Executives are also eligible to participate in the Employee Common Share Purchase Plan, which allows employees of Emera and its operating companies to purchase Emera common shares through regular payroll deductions or lump-sum payments. Participants can contribute up to $20,000 CAD/$15,000 USD per year, and the Company will match 20 per cent on employee contributions up to the contribution limit. The purchase price of the common shares under the Plan is the average of the daily high and low board lot trading price on the TSX for the five trading days prior to the purchase date. At Emera’s option, shares may be purchased instead on the market at prevailing market prices. All common shares purchased under the Plan are immediately vested. Executives participate on the same terms as all other eligible employees.

There are 2,729,615 common shares that remain available for issuance under the Employee Common Share Purchase Plan, which represents approximately 1.03 per cent of the weighted average total issued and outstanding common shares of the Company in 2022.

The table below shows the burn rate ratio for the Employee Common Share Purchase Plan, as defined in the table and measured as a percentage of the weighted average number of shares outstanding for the respective year.

 

     2022 (%)      2021 (%)      2020 (%)  

Burn rate

        

(number of common shares granted in a fiscal year, divided by the weighted average total number of shares outstanding)

     0.15        0.16        0.13  

The Board may, from time to time, without notice and without shareholder approval, amend, modify, change, suspend or terminate the Employee Common Share Purchase Plan as it, in its absolute discretion, determines appropriate; however, shareholder approval shall be required for any amendment, modification or change that:

 

  •  

Increases the number of common shares reserved for issuance, except an increase made in proportion to an increase in the number of common shares outstanding due to a stock dividend, stock split, amalgamation, reorganization, merger or similar event;

 

  •  

Extends eligibility to participate to non-employee Directors;

 

  •  

Permits rights under the Employee Common Share Purchase Plan to be transferred other than for normal estate settlement purposes;

 

  •  

Permits awards to be granted under the Employee Common Share Purchase Plan in addition to the purchase of common shares using contributions from participants and the Company;

 

  •  

Increases either of the 10 per cent insider participation limits; or

 

  •  

Deletes or reduces the range of amendments that require shareholder approval under this paragraph.

The maximum number of shares issuable to insiders of the Company under all security-based compensation arrangements (including the Stock Option Plan and the Plan) at any time is 10 per cent of the issued and outstanding shares of the Company. The maximum number of shares issued to insiders, within any one-year period, under all security-based compensation arrangements, will not exceed 10 per cent of the issued and outstanding shares of the Company.

The benefits under the Plan are not assignable, and if a Plan participant ceases to be an employee of an Emera Company, their eligibility to participate in the Plan ceases.

 

  EMERA INCORPORATED   97


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Termination and Change of Control Benefits

The following table provides the estimated amounts of incremental payments, payables and benefits to which each NEO would be entitled based on differing departure scenarios – resignation, termination for cause, termination without cause, separation from the Company in circumstances of a change of control, and retirement, assuming the triggering event took place on December 31, 2022. Incremental benefits in connection with a change of control are realized only in the event of a termination of employment following a change of control and no incremental benefit is realized solely on a change of control.

 

Name

 

Departure

scenario (1)

  Cash
severance ($)
    Short-term
incentive ($)
    Performance
share units
(“PSUs”) ($) (2)
    Restricted
share units
(“RSUs”) ($) (2)
    Stock
options
($) (3)
    Continuation
of benefits
(present
value) ($) (4)
    Total ($)  

Scott Balfour

  Resignation     —         —         —         —         —         —         —    
 

Termination for cause

    —         —         —         —         —         —         —    
 

Termination without cause

    2,200,000       2,200,000       —         —         —         5,400       4,405,400  
  Control change     2,200,000       2,200,000       5,411,610       2,705,504       408,684       5,400       12,931,198  
  Retirement     —         —         —         —         —         —         —    

Greg Blunden

  Resignation     —         —         —         —         —         —         —    
  Termination for cause     —         —         —         —         —         —         —    
 

Termination without cause

    900,000       720,000       —         —         —         6,983       1,626,983  
  Control change     900,000       720,000       1,263,773       631,851       95,294       6,983       3,617,901  
  Retirement     —         —         —         —         —         —         —    

Bruce Marchand

  Resignation     —         —         —         —         —         —         —    
  Termination for cause     —         —         —         —         —         —         —    
 

Termination without cause

    817,500       572,250       427,049       102,587       —         2,091       1,921,477  
  Control change     817,500       572,250       837,871       418,525       72,192       2,091       2,720,429  
  Retirement     —         —         —         —         —         —         —    

Karen Hutt

  Resignation     —         —         —         —         —         —         —    
  Termination for cause     —         —         —         —         —         —         —    
 

Termination without cause

    765,000       535,500       —         —         —         1,868       1,302,368  
  Control change     765,000       535,500       796,538       398,432       43,006       1,868       2,540,344  
  Retirement     —         —         —         —         —         —         —    

 

(1)

Please see the tables following for a description of the entitlements of each NEO under the various departure scenarios.

(2)

Payouts for PSUs assume a performance factor of 1.0 and both PSUs and RSUs are valued using the average closing share price for the last 50 trading days of 2022 ($51.66).

(3)

Stock options are valued using the closing share price on December 30, 2022 of $51.75.

(4)

Continuation of benefits may reflect amounts for health and dental benefits and insurance benefits, pursuant to the terms of the NEOs’ employment contracts, as applicable.

(5)

Mr. Janega retired on December 31, 2022 and has therefore been excluded from the above table. His entitlements on retirement are outlined in the table on page 101.

 

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Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

The following is a summary of each NEO’s entitlements on departure, based on his or her employment contract or the applicable plans as of December 31, 2022.

 

Scott Balfour
Resignation    All unvested PSUs, RSUs and stock options are forfeited.
Terminated for cause    All unvested PSUs, RSUs and stock options are forfeited.
Terminated without cause    Entitled to a lump sum equal to 24 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs are prorated to the date of termination and paid out at the end of the respective performance period, subject to the achievement of the applicable performance criteria. Unvested stock options are forfeited.
Change of control    If there is a change of control of the ownership of the Company, such that any one party acquires 50 per cent or more of voting securities, Mr. Balfour may elect to terminate employment for “good reason”, as defined below, within 24 months of the change of control, and receive 24 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs that were granted prior to the change of control are deemed to vest on the termination date and are paid out assuming a performance factor of 1.0. Unvested stock options that were granted prior to the change of control are deemed to vest on the termination date and must be exercised by the earlier of (a) six months from the termination date; and (b) 10 years from the original grant date.
Retirement    Mr. Balfour becomes eligible to retire with an unreduced pension as of April 30, 2027. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs and RSUs continue to be eligible to vest in full following retirement and PSUs remain subject to the applicable performance criteria. Unvested stock options granted prior to 2022 continue to be eligible to vest for two years past retirement and any unvested stock options granted in 2022 or later will continue to vest in full. Any stock options granted prior to 2022 that do not vest within two years of retirement are forfeited. All vested stock options granted prior to 2022 must be exercised by the earlier of (a) two years from the date of retirement; and (b) 10 years from the original grant date. Stock options granted in 2022 or later will remain exercisable for the entire term of the option.

 

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Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Greg Blunden
Resignation    All unvested PSUs, RSUs and stock options are forfeited.
Terminated for cause    All unvested PSUs, RSUs and stock options are forfeited.
Terminated without cause    Entitled to a lump sum equal to 18 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs are prorated to the date of termination and paid out at the end of the respective performance period, subject to the achievement of the applicable performance criteria. Unvested stock options are forfeited.
Change of control    If there is a change of control of the ownership of the Company, such that any one party acquires 50 per cent or more of voting securities Mr. Blunden may elect to terminate employment for “good reason” (1), as defined below, within 24 months of such changes and receive 18 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs that were granted prior to the change of control are deemed to vest on the termination date and are paid out assuming a performance factor of 1.0. Unvested stock options that were granted prior to the change of control are deemed to vest on the termination date and must be exercised by the earlier of (a) six months from the termination date; and (b) 10 years from the original grant date.
Retirement    Mr. Blunden becomes eligible to retire with an unreduced pension as of December 31, 2024. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs and RSUs continue to be eligible to vest in full following retirement and PSUs remain subject to the applicable performance criteria. Unvested stock options granted prior to 2022 continue to be eligible to vest for two years past retirement and any unvested stock options granted in 2022 or later will continue to vest in full. Any stock options granted prior to 2022 that do not vest within two years of retirement are forfeited. All vested stock options granted prior to 2022 must be exercised by the earlier of (a) two years from the date of retirement; and (b) 10 years from the original grant date. Stock options granted in 2022 or later will remain exercisable for the entire term of the option.
Bruce Marchand
Resignation    All unvested PSUs, RSUs and stock options are forfeited.
Terminated for cause    All unvested PSUs, RSUs and stock options are forfeited.
Terminated without cause    Entitled to a lump sum equal to 18 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs are prorated to the date of termination and paid out based on an estimated future value. Unvested stock options are forfeited.
Change of control    If there is a change of control of the ownership of the Company, such that any one party acquires 50 per cent or more of voting securities, Mr. Marchand may elect to terminate employment for “good reason” (1), as defined below, within 24 months of such changes and receive 18 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs that were granted prior to the change of control are deemed to vest on the termination date and are paid out assuming a performance factor of 1.0. Unvested stock options that were granted prior to the change of control are deemed to vest on the termination date and must be exercised by the earlier of (a) six months from the termination date; and (b) 10 years from the original grant date.
Retirement    Mr. Marchand became eligible to retire with an unreduced pension as of June 30, 2022. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs and RSUs continue to be eligible to vest in full following retirement and PSUs remain subject to the applicable performance criteria. Unvested stock options granted prior to 2022 continue to be eligible to vest for two years past retirement and any unvested stock options granted in 2022 or later will continue to vest in full. Any stock options granted prior to 2022 that do not vest within two years of retirement are forfeited. All vested stock options granted prior to 2022 must be exercised by the earlier of (a) two years from the date of retirement; and (b) 10 years from the original grant date. Stock options granted in 2022 or later will remain exercisable for the entire term of the option.

 

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Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Karen Hutt
Resignation    All unvested PSUs, RSUs and stock options are forfeited.
Terminated for cause    All unvested PSUs, RSUs and stock options are forfeited.
Terminated without cause    Entitled to a lump sum equal to 18 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs are prorated to the date of termination and paid out at the end of the respective performance period, subject to the achievement of the applicable performance criteria. Unvested stock options are forfeited.
Change of control    If there is a change of control of the ownership of the Company and Ms. Hutt’s employment is terminated without cause or Ms. Hutt terminates her employment for “good reason”, as defined in her employment agreement and below, within 24 months of the change of control, Ms. Hutt is entitled to receive 18 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs that were granted prior to the change of control are deemed to vest on the termination date and are paid out assuming a performance factor of 1.0. Unvested stock options that were granted prior to the change of control are deemed to vest on the termination date and must be exercised by the earlier of (a) six months from the termination date; and (b) 10 years from the original grant date.
Retirement   

Ms. Hutt participates in the Defined Contribution pension plan and is eligible to retire any time after age

55. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs and RSUs continue to be eligible to vest in full following retirement and PSUs remain subject to the applicable performance criteria. Unvested stock options granted prior to 2022 continue to be eligible to vest for two years past retirement and any unvested stock options granted in 2022 or later will continue to vest in full. Any stock options granted prior to 2022 that do not vest within two years of retirement are forfeited. All vested stock options granted prior to 2022 must be exercised by the earlier of (a) two years from the date of retirement; and (b) 10 years from the original grant date. Stock options granted in 2022 or later will remain exercisable for the entire term of the option.

Richard Janega
Retirement    Mr. Janega retired from the Company on December 31, 2022. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs and RSUs continue to be eligible to vest in full following retirement and PSUs remain subject to the applicable performance criteria. Unvested stock options granted prior to 2022 continue to be eligible to vest for two years past retirement and any unvested stock options granted in 2022 or later will continue to vest in full. Any stock options granted prior to 2022 that do not vest within two years of retirement are forfeited. All vested stock options granted prior to 2022 must be exercised by the earlier of (a) two years from the date of retirement; and (b) 10 years from the original grant date. Stock options granted in 2022 or later will remain exercisable for the entire term of the option.
   In consideration of Mr. Janega’s service with the Company, Mr. Janega was entitled to a Retirement Award of $262,500, which is a lump sum cash payment equal to one week’s base salary for each year of service (to a maximum of 26 weeks).

 

(1)

“Good reason” is described as any of the following events occurring without the NEO’s consent:

 

  •  

the Company materially diminishes the NEO’s position, authority, duties or responsibilities;

 

  •  

the Company requires the NEO to be based at a location more than 50 km from his or her current work location or to travel to a significantly greater extent; or

 

  •  

the Company materially reduces the NEO’s annual base salary or their target incentive awards.

 

  EMERA INCORPORATED   101


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Shares Authorized for Issuance Under Equity-based Compensation Plans

The following table shows shares authorized for issuance under the Stock Option Plan and the Employee Common Share Purchase Plan as of December 31, 2022. There are no equity-based compensation plans that were not approved by shareholders.

 

     (A)      (B)      (C)  

Plan category

   Number of shares to be
issued upon exercise of
outstanding options
     Weighted average
exercise price of
outstanding options ($)
     Number of shares available
for future issuance under
equity compensation plans
(excluding column (A))
 

Equity-based compensation plans approved by shareholders

        

•  Senior Management Stock Option Plan

     2,853,879        50.41        3,141,410  

•  Employee Common Share Purchase Plan

     N/A        N/A        2,729,615  
  

 

 

    

 

 

    

 

 

 

Total

     2,853,879        50.41        5,871,025  
  

 

 

    

 

 

    

 

 

 

Loans to Directors and Officers

No current or former Directors, officers or employees of Emera, or any of its subsidiaries, had any loans with Emera or any of its subsidiaries since the beginning of the most recently completed financial year, other than routine indebtedness as defined under Canadian securities laws.

Material Transactions

During the most recently completed financial year, insiders of the Company and its affiliates, including Directors, executive officers, proposed Director nominees or their associates or corporations they controlled, did not have any material interest, direct or indirect, in any transaction or in any proposed transaction that has materially affected or will materially affect the Company.

Management Contracts

There are no functions of management that are performed by a person or company other than the Directors, executive officers or other employees of the Company.

Audit Committee Information

For information regarding Emera’s Audit Committee, including its Charter, composition, relevant education and experience of its members, Audit Committee oversight, policies and procedures for the approval of non-audit services and Auditors’ service fees, please refer to the “Audit Committee” section and to “Appendix ‘D’ – Emera Incorporated Audit Committee Charter” of Emera’s Annual Information Form, for the year ended December 31, 2022, available under Emera’s profile on SEDAR at www.sedar.com, or by contacting the Corporate Secretary of the Company.

 

102   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

Appendix A

Emera Incorporated Board of Directors Charter

The fundamental responsibility of the Board of Directors (the “Board”) is to provide stewardship and governance to Emera Incorporated (“Emera”) for the long-term success of the Company by overseeing management of the business.

In addition to the powers set out in Emera’s Articles of Association, the Board shall have the following duties and responsibilities.

STRATEGIC PLANNING

The Board shall provide oversight and guidance on the strategic issues facing Emera.

The Board shall oversee a strategic planning process resulting in a strategic plan which shall be approved on an annual basis and will take into account, among other things, the opportunities and risks of the business.

The Board shall regularly consider Emera’s strategy, evaluate progress made in pursuing that strategy, and consider any adjustments to the strategy that may be required from time to time.

The Board shall review and approve the Company’s financial objectives, plans and actions, including significant capital allocations and expenditures.

The Board shall review and approve all material acquisitions, dispositions, projects, business plans, and budgets.

CULTURE

The Board shall oversee management’s approach to addressing Emera’s Environmental, Social and Governance (“ESG”) impacts, risks and opportunities that are most important to its business performance and to key stakeholders.

The Board shall be comprised of a majority of “independent directors” as defined from time to time under applicable legislation and the rules of any stock exchange on which Emera’s securities are listed for trading.

The Chair shall be an “independent director” as defined above.

The Board shall review and approve standards for ethical business conduct for employees, officers and Directors of Emera and its subsidiaries and affiliates and a procedure for monitoring compliance with such code throughout the Company.

The Board shall satisfy itself as to the integrity of the Chief Executive Officer and executive officers and management’s creation of an integrity-based culture throughout the Company.

RISK RESPONSIBILITY

The Board shall oversee the implementation by management of appropriate systems to identify, report and manage the principal risks of Emera’s business. The Board will consider Emera’s risk profile and oversee Emera’s risk management by reviewing:

 

  (a)

the regular identification and assessment of the principal risks of Emera;

 

  (b)

the process for ongoing monitoring and reporting of the principal risks of Emera;

 

  (c)

the effectiveness of Emera’s mitigation response to its principal risks;

 

  (d)

the alignment of risk management with Emera’s risk profile, its strategy, and its organizational objectives, including capital and resources allocation.

The Board shall also review Emera’s annual insurance program and uninsured exposure and Emera’s business continuity and disaster recovery plans.

The Board shall receive regular updates on the status of risk management activities and initiatives.

The Board shall review management’s processes that provide reasonable assurance of compliance with applicable legal and regulatory requirements.

 

  EMERA INCORPORATED   103


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

LEADERSHIP AND SUCCESSION

The Board shall oversee policies and practices to enable the Company to attract, develop and retain the human resources required by the Company to meet its business objectives.

The Board shall appoint executive officers and delegate the necessary authority for the conduct of the business.

The Board shall establish annual performance expectations and corporate goals and objectives for the Chief Executive Officer and monitor progress against those expectations.

The Board shall evaluate the performance, and, following a review of recommendations from the Management Resources and Compensation Committee, approve compensation for executive officers.

The Board shall oversee the succession planning program for the Chief Executive Officer and other key executive positions from time to time.

FINANCIAL

The Board shall oversee the financial reporting and disclosure obligations imposed on the Company by laws, regulations, rules, policies and other applicable requirements.

The Board will review the financial performance of the Company and declare dividends as appropriate.

The Board shall approve for release to the public as necessary the Company’s financial statements, management’s discussion and analysis (“MD&A”) and earnings releases prepared by management and oversee the Company’s compliance with applicable audit, accounting and reporting requirements.

The Board shall review the quality and integrity of Emera’s internal controls and management information systems.

CORPORATE COMMUNICATIONS AND PUBLIC DISCLOSURE

The Board shall review and approve a formal corporate disclosure policy and oversee policies and processes for accurate, timely and appropriate public disclosure.

The Board shall oversee systems for receiving feedback from stakeholders and review such feedback received by the Company.

GOVERNANCE RESPONSIBILITY

The Board is responsible for overseeing the Company’s corporate governance policies and practices and shall maintain a set of corporate governance practices that are specifically appropriate to the Company.

Pursuant to the Articles, the Directors shall appoint one of the Directors as Chair of the Board and such Director shall not be an employee of Emera or any of its affiliates or subsidiaries.

The Board shall establish appropriate structures and procedures to allow the Board to function independently of management and in the interests of the Company and its shareholders.

The Board, in carrying out its mandate, shall appoint committees of the Board and delegate certain functions to those committees, each of which shall have its own written charter. Notwithstanding such delegation, the Board retains its oversight function and ultimate responsibility for these delegated functions.

The Board shall oversee a process for the selection of qualified individuals for Board nomination and shall approve selection criteria for identifying Director candidates taking into account the competencies and skills the Board as a whole should possess.

The Board shall undertake regular evaluation of the Board, the Chair of the Board, the Board committees and individual Directors.

The Board shall undertake regular evaluation of Directors’ compensation.

The Board shall review this Charter annually to ensure it appropriately reflects the Board’s stewardship responsibilities.

 

104   EMERA INCORPORATED  


Notice of Annual Meeting of Common Shareholders and Management Information Circular

 

APPENDIX B

Emera Incorporated

(The “Company”)

Resolution Amending the Senior Management Stock Option Plan

RESOLVED THAT:

 

1.

The Senior Management Stock Option Plan (the “Plan”) of the Company be amended to provide that if an option should expire during a Company trading blackout period or within five (5) business days of the end of a such blackout period, the expiry date of the option will be extended to ten (10) business days following the end of the applicable trading blackout period, and to make a corresponding change in the amendment provision of the Plan.

 

2.

Any Director or Officer of the Company be and is hereby authorized and directed to execute, whether under the corporate seal of the Company or otherwise, and to deliver all documents or instruments in writing and to do all such other acts and things as may be determined necessary or appropriate to carry out the terms of this resolution, the making of such determination to be conclusive evidence of the necessity or appropriateness.

 

  EMERA INCORPORATED   105


LOGO

Exhibit 99.2

 

LOGO


LOGO


1 EMERA AT A GLANCE   2  OUR STRATEGY   4 WHY INVEST IN EMERA   5  LETTER TO SHAREHOLDERS   9  FINANCIAL REVIEW


Emera at a Glance

Data is as of December 31, 2022, unless otherwise indicated.

From our origins as a single electric utility, Emera has grown into an energy leader serving customers in Canada, the US and the Caribbean.

Our companies include electric and natural gas utilities, gas pipelines, and energy marketing and trading operations.

 

LOGO

 

*

Adjusted net income is a non-GAAP measure which does not have standardized meaning under USGAAP. For more information and a reconciliation to the nearest GAAP measure, refer to “Non-GAAP Financial Measures and Ratios” in Emera’s Q4 2022 MD&A.

 

  EMERA 2022 ANNUAL REPORT   1


Our Strategy

Our world is changing quickly, and we’re ready. For nearly two decades, we’ve been focused on safely delivering cleaner, reliable energy at a pace that’s balanced against cost impacts for our customers. We’re delivering solutions to the key challenges facing our industry: decarbonization, decentralization and digitalization.

 

LOGO    LOGO    LOGO

 

EXPERT

TEAMS

  

DELIVERING FOR

OUR CUSTOMERS

  

DRIVING GROWTH

AND REINVESTMENT

We’re a team of experts leading the way to a cleaner energy future as we work toward our 2050 net-zero vision.    Every day, we’re safely and cost-effectively delivering cleaner, more reliable energy for our customers.    Delivering for our customers drives predictable returns and steady growth for our investors, enabling us to reinvest in our teams, companies and communities.

 

LOGO

 

2   EMERA 2022 ANNUAL REPORT  


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  EMERA 2022 ANNUAL REPORT   3


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4   EMERA 2022 ANNUAL REPORT  


Letter from the Chair and the CEO

 

FELLOW SHAREHOLDERS,

In 2022, the Emera team advanced our strategy of safely delivering cleaner, more reliable energy for our customers with a focus on growth and long-term value for our shareholders. Despite significant challenges like increasingly intense weather, rising inflation rates and supply chain disruptions, Emera’s overall performance in 2022 is a testament to the strength of our strategy, our team and our diversified portfolio.

STRATEGY IN ACTION

Our role as leaders in the energy transition is driving growth as we invest strategically to reduce emissions, add more renewable energy to our generation and improve grid resiliency to enhance reliability for our customers.

In 2022, the execution of our strategy was realized in our $2.6 billion capital plan that was largely focused on cleaner energy and reliability investments. Last year, we achieved a 41 per cent reduction in CO2 emissions across Emera, compared to 2005 levels.

Here are just some of the projects our teams advanced last year that highlight our environmental priorities and how our strategy continues to drive growth and value for our customers and shareholders:

 

•   The Big Bend Modernization project at Tampa Electric was completed in December 2022 on time, on budget and with a world-class level of safety performance. In addition to reducing CO2 emissions, the facility is now one of the most efficient natural gas generation units in North America. It’s also estimated that this modernization project will save customers more than $700 million over the 30-year life of the plant.

 

 

 

LOGO

 

  EMERA 2022 ANNUAL REPORT   5


•   Tampa Electric continued its investment in solar generation in 2022, completing the installation of three new solar sites and bringing its total solar generation in service to more than 1,000 MW. With this achievement, Tampa Electric continues to have the highest proportion of solar generation per customer of any utility in Florida. Our investments in solar have allowed us to decrease the carbon intensity of our generation mix, and saved customers over $80 million USD in avoided fuel costs in 2022.

 

•   The Maritime Link is a transformational energy project that is a key part of the solution for reducing the use of coal at Nova Scotia Power. By replacing high-carbon generation
   

with clean hydroelectric energy, the Link saved customers in Nova Scotia almost $100 million last year and will continue to deliver significant value for decades to come.

 

•   The team at Barbados Light & Power brought the Clean Energy Bridge (CEB) into service in June 2022. Supplying roughly 27 per cent of the island’s energy needs, this 33 MW medium-speed diesel generating plant is enhancing reliability and grid resiliency for customers. The CEB replaces older, less-efficient infrastructure, reducing fuel costs and providing critical baseload energy as the country transitions to 100 per cent renewable energy.
 

 

LOGO

 

6   EMERA 2022 ANNUAL REPORT  


SAFETY

Safety is our number one priority, and we are deeply committed to building a strong safety culture. We continued to implement comprehensive enterprise-wide safety systems, and in 2022 the team achieved a ten per cent improvement in our Occupational Safety and Health Administration (OSHA) injury rate and a 17 per cent improvement in our lost-time frequency rate compared to our average over the last five years — both better than the industry average. This improvement is particularly notable given that our teams in Nova Scotia and Florida also responded to two historic hurricanes in 2022 — in both cases without any lost-time injuries.

Despite our efforts and progress, we lost a colleague at Nova Scotia Power in 2022. This tragic loss was profoundly felt across our entire organization and has served to strengthen our resolve to build an Emera where no one gets hurt.

 

DIVERSITY, EQUITY AND INCLUSION (DEI)

A strong, diverse team makes our business better. Our Emera-wide DEI strategy guides our efforts in building and maintaining a healthy, diverse and inclusive workplace and culture.

Our Emera DEI Council drives common focus while also supporting our operating companies in addressing their unique DEI journeys. Across the organization, voluntary Employee Resource Groups (ERGs) are in place for Black employees, Latinx employees, veterans, employees in the LGBTQ+ community, women engineers, and women in trades and technology.

We are also committed to building more diverse and inclusive communities where we live and work. In 2022, we invested more than $18 million in our communities, with over $2 million invested from Emera’s DEI Fund.

 

 

The Emera team was the driving force behind our achievements in 2022. The work they do delivers for customers, fuels our growth and positions Emera to continue to provide predictable, sustainable earnings and long-term value to our shareholders.”

 

  EMERA 2022 ANNUAL REPORT   7


FINANCIAL RESULTS

For 2022, we reported $850 million in annual adjusted net income1 and adjusted earnings per share (EPS)1 of $3.20. Excluding the impact of a litigation award received2 in the fourth quarter, annual adjusted earnings1 of $805 million is our highest ever adjusted annual earnings1 and represents an increase of 11 per cent over the previous year. The equivalent annual adjusted EPS1 of $3.03 was an eight per cent increase over the previous year.

Last year, we also increased our dividend by four per cent, in line with our four to five per cent dividend growth target through 2025. We are proud of our track record of long-term dividend growth, having provided 5.4 per cent growth on an annualized basis since 2000.

THANK YOU

The Emera team was the driving force behind our achievements in 2022. The work they do delivers for customers, fuels our growth and positions Emera to continue to provide predictable, sustainable earnings and long-term value to our shareholders.

Thank you to Emera’s Board of Directors and the entire Emera team for your continued commitment and extraordinary work on behalf of our customers, communities and shareholders.

While our Total Shareholder Return (TSR) has historically been strong relative to our energy industry peers, the introduction and passage of Bill 212 in Nova Scotia directly and indirectly impacted our share price performance in 2022. We are focused on addressing this underperformance, and we are confident in our ability to return to superior performance for our shareholders. Looking forward, we believe that we are well positioned to continue our track record of providing strong and predictable earnings and dividend growth for our shareholders.

To our valued shareholders, thank you for your ongoing confidence in Emera.

 

LOGO   LOGO

 

Jackie Sheppard

Chair, Emera Inc. Board of Directors

 

 

Scott Balfour

President and Chief Executive Officer, Emera Inc.

 

 

 

 

1

Adjusted net income and adjusted EPS are a non-GAAP measure and a non-GAAP ratio, respectively, which do not have standardized meaning under USGAAP. For more information and a reconciliation to the nearest GAAP measure, refer to “Non-GAAP Financial Measures and Ratios” in Emera’s Q4 2022 MD&A.

2

2022 results include the impact of a $45 million after-tax litigation award recognized in the fourth quarter. The impact is $0.17 on adjusted EPS.

 

8   EMERA 2022 ANNUAL REPORT  


Financial Review

 

Forward-looking Information

     11  

Introduction and Strategic Overview

     11  

Non-GAAP Financial Measures and Ratios

     13  

Consolidated Financial Review

     15  

Significant Items Affecting Earnings

     15  

Consolidated Financial Highlights

     15  

Consolidated Income Statement Highlights

     17  

Business Overview and Outlook

     19  

Florida Electric Utility

     19  

Canadian Electric Utilities

     20  

Gas Utilities and Infrastructure

     23  

Other Electric Utilities

     24  

Other

     26  

Consolidated Balance Sheet Highlights

     27  

Oher Developments

     28  

Financial Highlights

     29  

Florida Electric Utility

     29  

Canadian Electric Utilities

     30  

Gas Utilities and Infrastructure

     33  

Other Electric Utilities

     35  

Other

     36  

Liquidity and Capital Resources

     38  

Consolidated Cash Flow Highlights

     39  

Working Capital

     40  

Contractual Obligations

     40  

Forecasted Gross Consolidated Capital Expenditures

     41  

Debt Management

     41  

Credit Ratings

     43  

Guaranteed Debt

     43  

Outstanding Stock Data

     44  

Pension Funding

     45  

Off-Balance Sheet Arrangements

     45  

Dividend Payout Ratio

     46  

Transactions with Related Parties

     46  

Enterprise Risk and Risk Management

     47  

Risk Management including Financial Instruments

     57  

Disclosure and Internal Controls

     59  

Critical Accounting Estimates

     59  

Changes in Accounting Policies and Practices

     63  

Future Accounting Pronouncements

     63  

Summary of Quarterly Results

     64  

Management Report

     65  

Independent Auditor’s Report

     66  

Report of Independent Registered Public Accounting Firm

     70  

Consolidated Financial Statements

     73  

Notes to the Consolidated Financial Statements

     79  

Emera Leadership and Board

     139  

Shareholder Information

     140  
 

 

  EMERA 2022 ANNUAL REPORT   9


Management’s Discussion & Analysis

As at February 23, 2023

Management’s Discussion & Analysis (“MD&A”) provides a review of the results of operations of Emera Incorporated and its subsidiaries and investments during the fourth quarter of 2022 relative to the same quarter in 2021; for the full year of 2022 relative to 2021 and selected financial information for 2020; and its financial position as at December 31, 2022 relative to December 31, 2021. Throughout this discussion, “Emera” and “Company” refer to Emera Incorporated and all of its consolidated subsidiaries and investments. The Company’s activities are carried out through five reportable segments: Florida Electric Utility, Canadian Electric Utilities, Gas Utilities and Infrastructure, Other Electric Utilities, and Other.

This discussion and analysis should be read in conjunction with the Emera annual audited consolidated financial statements and supporting notes as at and for the year ended December 31, 2022. Emera follows United States Generally Accepted Accounting Principles (“USGAAP” or “GAAP”).

The accounting policies used by Emera’s rate-regulated entities may differ from those used by Emera’s non-rate-regulated businesses with respect to the timing of recognition of certain assets, liabilities, revenues and expenses. At December 31, 2022, Emera’s rate-regulated subsidiaries and investments include:

 

Emera Rate-Regulated Subsidiary or Equity Investment
Subsidiary

 

Accounting Policies Approved/Examined By

Tampa Electric – Electric Division of Tampa Electric Company (“TEC”) (1)

  Florida Public Service Commission (“FPSC”) and the Federal Energy Regulatory Commission (“FERC”)

Nova Scotia Power Inc. (“NSPI”)

  Nova Scotia Utility and Review Board (“UARB”)

Peoples Gas System (“PGS”) – Gas Division of TEC (1)

  FPSC

New Mexico Gas Company, Inc. (“NMGC”)

  New Mexico Public Regulation Commission (“NMPRC”)

SeaCoast Gas Transmission, LLC (“SeaCoast”)

  FPSC

Emera Brunswick Pipeline Company Limited (“Brunswick Pipeline”)

  Canadian Energy Regulator (“CER”)

Barbados Light & Power Company Limited (“BLPC”)

  Fair Trading Commission, Barbados (“FTC”)

Grand Bahama Power Company Limited (“GBPC”)

  The Grand Bahama Port Authority (“GBPA”)

Equity Investments

 

NSP Maritime Link Inc. (“NSPML”)

  UARB

Labrador Island Link Limited Partnership (“LIL”)

  Newfoundland and Labrador Board of Commissioners of Public Utilities (“NLPUB”)

Maritimes & Northeast Pipeline Limited Partnership and Maritimes & Northeast Pipeline, LLC (“M&NP”)

  CER and FERC

St. Lucia Electricity Services Limited (“Lucelec”)

  National Utility Regulatory Commission (“NURC”)

 

(1)

Effective January 1, 2023, Peoples Gas System ceased to be a division of TEC and the gas utility was reorganized, resulting in a separate legal entity called Peoples Gas System, Inc., a wholly owned direct subsidiary of TECO Gas Operations, Inc.

All amounts are in Canadian dollars (“CAD”), except for the Florida Electric Utility, Gas Utilities and Infrastructure, and Other Electric Utilities sections of the MD&A, which are reported in United States dollar (“USD”) unless otherwise stated.

Additional information related to Emera, including the Company’s Annual Information Form, can be found on SEDAR at www.sedar.com.

 

10   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

Forward-looking Information

This MD&A contains “forward-looking information” and statements which reflect the current view with respect to the Company’s expectations regarding future growth, results of operations, performance, carbon dioxide emissions reduction goals, business prospects and opportunities, and may not be appropriate for other purposes within the meaning of applicable Canadian securities laws. All such information and statements are made pursuant to safe harbour provisions contained in applicable securities legislation. The words “anticipates”, “believes”, “budget”, “could”, “estimates”, “expects”, “forecast”, “intends”, “may”, “might”, “plans”, “projects”, “schedule”, “should”, “targets”, “will”, “would” and similar expressions are often intended to identify forward-looking information, although not all forward-looking information contains these identifying words. The forward-looking information reflects management’s current beliefs and is based on information currently available to Emera’s management and should not be read as guarantees of future events, performance or results, and will not necessarily be accurate indications of whether, or the time at which, such events, performance or results will be achieved.

The forward-looking information is based on reasonable assumptions and is subject to risks, uncertainties and other factors that could cause actual results to differ materially from historical results or results anticipated by the forward-looking information. Factors that could cause results or events to differ from current expectations include, without limitation: regulatory and political risk; operating and maintenance risks; changes in economic conditions; commodity price and availability risk; liquidity and capital market risk; future dividend growth; timing and costs associated with certain capital investments; expected impacts on Emera of challenges in the global economy; estimated energy consumption rates; maintenance of adequate insurance coverage; changes in customer energy usage patterns; developments in technology that could reduce demand for electricity; global climate change; weather; unanticipated maintenance and other expenditures; system operating and maintenance risk; derivative financial instruments and hedging; interest rate risk; inflation risk; counterparty risk; disruption of fuel supply; country risks; environmental risks; foreign exchange (“FX”); regulatory and government decisions, including changes to environmental, financial reporting and tax legislation; risks associated with pension plan performance and funding requirements; loss of service area; risk of failure of information technology (“IT”) infrastructure and cybersecurity risks; uncertainties associated with infectious diseases, pandemics and similar public health threats, such as the COVID-19 novel coronavirus (“COVID-19”) pandemic; market energy sales prices; labour relations; and availability of labour and management resources.

Readers are cautioned not to place undue reliance on forward-looking information, as actual results could differ materially from the plans, expectations, estimates or intentions and statements expressed in the forward-looking information. All forward-looking information in this MD&A is qualified in its entirety by the above cautionary statements and, except as required by law, Emera undertakes no obligation to revise or update any forward-looking information as a result of new information, future events or otherwise.

Introduction and Strategic Overview

Based in Halifax, Nova Scotia, Emera owns and operates cost-of-service rate-regulated electric and gas utilities in Canada, the United States and the Caribbean. Cost-of-service utilities provide essential electric and gas services in designated territories under franchises and are overseen by regulatory authorities. Emera’s strategic focus continues to be safely delivering cleaner, affordable and reliable energy to its customers.

The majority of Emera’s investment in rate-regulated businesses are located in Florida with other investments in Nova Scotia, New Mexico and the Caribbean. Emera’s portfolio of regulated utilities provides reliable earnings, cash flow and dividends. Earnings opportunities in regulated utilities are generally driven by the magnitude of net investment in the utility (known as “rate base”), and the amount of equity in the capital structure and the return on that equity (“ROE”) as approved through regulation. Earnings are also affected by sales volumes and operating expenses.

 

  EMERA 2022 ANNUAL REPORT   11


Management’s Discussion & Analysis

 

Emera’s capital investment plan is $8 – 9 billion over the 2023-to-2025 period (including a $240 million equity investment in the LIL in 2023), mainly focused in Florida. This results in a forecasted rate base growth of approximately 7 per cent to 8 per cent through 2025. The capital investment plan continues to include significant investments across the portfolio in renewable and cleaner generation, reliability and integrity investments, infrastructure modernization, and customer-focused technologies. Emera’s capital investment plan is being funded primarily through internally generated cash flows and debt raised at the operating company level. Equity requirements in support of the Company’s capital investment plan are expected to be funded through the issuance of preferred equity and the issuance of common equity through Emera’s dividend reinvestment plan (“DRIP”) and at-the-market program (“ATM program”). Maintaining investment-grade credit ratings is a priority of the Company.

Emera has provided annual dividend growth guidance of four to five per cent through 2025. The Company targets a long-term dividend payout ratio of adjusted net income of 70 to 75 per cent and, while the payout ratio is likely to exceed that target through and beyond the forecast period, it is expected to return to that range over time. For further information on the non-GAAP measure “Dividend Payout Ratio of Adjusted Net Income”, refer to the “Non-GAAP Financial Measures and Ratios” section.

Seasonal patterns and other weather events affect demand and operating costs. Similarly, mark-to-market adjustments and foreign currency exchange can have a material impact on financial results for a specific period. Emera’s consolidated net income and cash flows are impacted by movements in the USD relative to the Canadian dollar. Emera may hedge both transactional and translational exposure. These impacts, as well as the timing of capital investments and other factors, mean results in any one quarter are not necessarily indicative of results in any other quarter, or for the year as a whole.

Energy markets worldwide are facing significant change and Emera is well positioned to respond to shifting customer demands, digitization, decarbonization, complex regulatory environments, and decentralized generation.

Customers are looking for more choice, better control, and enhanced reliability in a time where costs of decentralized generation and storage have become more competitive in some regions. Advancing technologies are transforming the way utilities interact with their customers and generate and transmit energy. In addition, climate change and extreme weather are shaping how utilities operate and how they invest in infrastructure. There is also an overall need to replace aging infrastructure and further enhance reliability. Emera will play a role in all of these trends. Emera’s strategy is to fund investments in renewable energy and technology assets which protect the environment and benefit customers through fuel or operating cost savings.

For example, significant investments to facilitate the use of renewable and low-carbon energy include the Maritime Link in Atlantic Canada, and the ongoing construction of solar generation and modernization of the Big Bend Power Station at Tampa Electric. Emera’s utilities are also investing in reliability projects and replacing aging infrastructure. All of these projects demonstrate Emera’s strategy of safely delivering cleaner, reliable, and affordable energy for its customers.

Building on its decarbonization progress, Emera is continuing its efforts by establishing clear carbon reduction goals and a vision to achieve net-zero carbon dioxide emissions by 2050.

This vision is inspired by Emera’s strong track record, the Company’s experienced team, and a clear path to Emera’s interim carbon goals. With existing technologies and resources, and subject to supportive government and regulatory decisions, Emera is working to achieve the following goals compared to corresponding 2005 levels:

 

  •  

A 55 per cent reduction in carbon dioxide emissions by 2025.

 

  •  

The retirement of Emera’s last existing coal unit no later than 2040.

 

  •  

An 80 per cent reduction in carbon dioxide emissions by 2040.

Achieving the above climate goals on these timelines is subject to the Company’s regulatory obligations and other external factors beyond Emera’s control.

Emera seeks to deliver on its Climate Commitment while maintaining its focus on investing in reliability and staying focused on the cost impacts for customers. Emera is also committed to identifying emerging technologies and continuing to work constructively with policymakers, regulators, partners, investors and customers to achieve these goals and realize its net-zero vision.

Emera is committed to world-class safety, operational excellence, good governance, excellent customer service, reliability, being an employer of choice, and building constructive relationships.

 

12   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

Non-GAAP Financial Measures and Ratios

Emera uses financial measures and ratios that do not have standardized meaning under USGAAP and may not be comparable to similar measures presented by other entities. Emera calculates the non-GAAP measures and ratios by adjusting certain GAAP measures for specific items. Management believes excluding these items better distinguishes the ongoing operations of the business and allows investors to better understand and evaluate the business. These measures and ratios are discussed and reconciled below.

Adjusted Net Income Attributable to Common Shareholders, Adjusted Earnings (Loss) Per Common Share (“EPS”) – Basic and Dividend Payout Ratio of Adjusted Net Income

Emera calculates an adjusted net income attributable to common shareholders (“adjusted net income”) measure by excluding the effect of mark-to-market (“MTM”) adjustments, impairment charges, the impact of the NSPML unrecoverable costs, and the 2020 gain on sale of Emera Maine.

Management believes excluding from net income the effect of these MTM valuations and changes thereto, until settlement, better aligns the intent and financial effect of these contracts with the underlying cash flows, and therefore excludes these MTM adjustments for evaluation of performance and incentive compensation. The MTM adjustments are related to the following:

 

  •  

held-for-trading (“HFT”) commodity derivative instruments, including adjustments related to the price differential between the point where natural gas is sourced and where it is delivered, and the related amortization of transportation capacity recognized as a result of certain Emera Energy marketing and trading transactions;

 

  •  

the business activities of Bear Swamp Power Company LLC (“Bear Swamp”) included in Emera’s equity income;

 

  •  

equity securities held in BLPC and a captive reinsurance company in the Other segment; and

 

  •  

FX hedges entered into to hedge USD denominated operating unit earnings exposure.

For further detail on MTM adjustments, refer to the “Consolidated Financial Review”, “Financial Highlights – Other Electric Utilities”, and “Financial Highlights – Other” sections.

In Q4 2022, the Company recognized a $73 million non-cash goodwill impairment charge related to GBPC due to a decline in the fair value of the reporting unit. The fair value decline was driven by the effects of macro-economic factors on the discount rate calculation, including the risk-free rate assumption. Management believes excluding from net income the effect of this charge better distinguishes ongoing operations of the business and allows investors to better understand and evaluate the Company. For further details on this GBPC impairment charge, refer to “Significant Items Impacting Earnings”, and “Financial Highlights – Other” sections.

In February 2022, the UARB issued a decision to disallow the recovery of $9 million in costs ($7 million after-tax) included in NSPML’s final capital cost application. The after-tax unrecoverable costs were recognized in “Income from equity investments” in Emera’s Consolidated Statements of Income. Management believes excluding these unrecoverable costs from the calculation of adjusted net income better reflects the underlying operations in the period. For further details on the NSPML unrecoverable costs, refer to the “Business Overview and Outlook – Canadian Electric Utilities” and “Financial Highlights – Canadian Electric Utilities” sections.

In 2020, the Company recognized a gain on the sale of Emera Maine and certain non-cash impairment charges. Management believes excluding these from net income better distinguishes ongoing operations of the business and allows investors to better understand and evaluate the business.

Adjusted EPS – basic and dividend payout ratio of adjusted net income are non-GAAP ratios which are calculated using adjusted net income, as described above. For further details on dividend payout ratio of adjusted net income, see the “Dividend Payout Ratio” section.

Emera calculates adjusted net income for the Canadian Electric Utilities, Other Electric Utilities, and Other segments. Reconciliation to the nearest GAAP measure is included in each segment. Refer to “Financial Highlights – Canadian Electric Utilities”, “Financial Highlights – Other Electric Utilities” and “Financial Highlights – Other” sections.

 

  EMERA 2022 ANNUAL REPORT   13


Management’s Discussion & Analysis

 

The following reconciles net income attributable to common shareholders to adjusted net income:

 

For the

millions of dollars (except per share amounts)

  

Three months ended

December 31

                

Year ended

December 31

 
   2022     2021      2022     2021     2020  

Net income attributable to common shareholders

   $ 483     $ 324      $ 945     $ 510     $ 938  

MTM gain (loss), after-tax (1)

     307       156        175       (213 )      (10 ) 

Impairment charges, after-tax (2)

     (73 )      —          (73 )      —         (26 ) 

NSPML unrecoverable costs (3)

     —         —          (7 )      —         —    

Gain on sale, after tax and transaction costs (4)

     —         —          —         —         309  
  

 

 

   

 

 

    

 

 

   

 

 

   

 

 

 

Adjusted net income attributable to common shareholders

   $ 249     $ 168      $ 850     $ 723     $ 665  
  

 

 

   

 

 

    

 

 

   

 

 

   

 

 

 

EPS – basic

   $ 1.80     $ 1.24      $ 3.56     $ 1.98     $ 3.78  
  

 

 

   

 

 

    

 

 

   

 

 

   

 

 

 

Adjusted EPS – basic

   $ 0.93     $ 0.64      $ 3.20     $ 2.81     $ 2.68  
  

 

 

   

 

 

    

 

 

   

 

 

   

 

 

 

 

(1)

Net of income tax expense of $124 million for the three months ended December 31, 2022 (2021 – $63 million expense) and $73 million expense for the year ended December 31, 2022 (2021 – $86 million recovery) (2020 – $8 million recovery).

(2)

Net of income tax expense of nil for the three months and year ended December 31, 2022 (2021 – nil) (2020 – $1 million expense).

(3)

Emera accounts for NSPML as an equity investment and therefore the after-tax unrecoverable costs were recorded in “Income from equity investments” on Emera’s Consolidated Statements of Income.

(4)

Net of income tax expense of $276 million for the year ended December 31, 2020.

EBITDA and Adjusted EBITDA

Earnings before interest, income taxes, depreciation and amortization (“EBITDA”) and adjusted EBITDA are non-GAAP financial measures used by Emera. These financial measures are used by numerous investors and lenders to better understand cash flows and credit quality. EBITDA is useful to assess Emera’s operating performance and indicates the Company’s ability to service or incur debt, invest in capital, and finance working capital requirements.

Similar to adjusted net income calculations described above, adjusted EBITDA represents EBITDA absent the income effect of MTM adjustments, impairment charges, the NSPML unrecoverable costs, and the 2020 gain on sale of Emera Maine.

The following is a reconciliation of net income to EBITDA and Adjusted EBITDA:

 

For the

millions of dollars

  

Three months ended

December 31

                

Year ended

December 31

 
   2022     2021      2022     2021     2020  

Net income (1)

   $ 499     $ 338      $ 1,009     $ 561     $ 984  

Interest expense, net

     206       151        709       611       679  

Income tax expense (recovery)

     154       85        185       (6 )      341  

Depreciation and amortization

     254       227        952       902       881  
  

 

 

   

 

 

    

 

 

   

 

 

   

 

 

 

EBITDA

   $ 1,113     $ 801      $ 2,855     $ 2,068     $ 2,885  
  

 

 

   

 

 

    

 

 

   

 

 

   

 

 

 

MTM gain (loss), excluding income tax

     431       219        248       (299 )      (18 ) 

Impairment charges, excluding income tax

     (73 )      —          (73 )      —         (25 ) 

NSPML unrecoverable costs (2)

     —         —          (7 )      —         —    

Gain on sale, net of transaction costs (excluding income tax)

     —         —          —         —         585  
  

 

 

   

 

 

    

 

 

   

 

 

   

 

 

 

Adjusted EBITDA

   $ 755     $ 582      $ 2,687     $ 2,367     $ 2,343  
  

 

 

   

 

 

    

 

 

   

 

 

   

 

 

 

 

(1)

Net income is before Non-controlling interest in subsidiaries and Preferred stock dividends.

(2)

Emera accounts for NSPML as an equity investment and therefore the after-tax unrecoverable costs were recorded in “Income from equity investments” on Emera’s Consolidated Statements of Income.

 

14   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

Consolidated Financial Review

SIGNIFICANT ITEMS AFFECTING EARNINGS

GBPC Impairment Charge

In Q4 2022, Emera recognized a goodwill impairment charge of $73 million ($0.27 per common share) for GBPC due to a decline in the fair value of the reporting unit. Although the cash flows of GBPC have not changed significantly compared to previous periods, the decline in the fair value was driven by the effects of macro-economic factors on discount rate calculations, including the risk-free rate assumption. This non-cash charge was recorded in “Impairment charge” on the Consolidated Statements of Income and reduced the GBPC goodwill balance to nil. For further details, refer to note 22 in the consolidated financial statements.

TECO Guatemala Holdings (“TGH”) International Arbitration and Award

On December 15, 2022, a payment of $63 million ($45 million after tax and legal costs, or $0.17 per common share), was made by the Republic of Guatemala to TECO Energy in satisfaction of the second and final award issued by the International Centre of the Settlement of Investment Disputes tribunal regarding a dispute over an investment of TGH, a wholly owned subsidiary of TECO Energy. The dispute related to the 2007 intervention by the government of Guatemala in an ongoing independent rate- setting process to unilaterally set a new and lower tariff. The payment was recognized in “Other income, net” on the Consolidated Statements of Income. For further details, refer to note 27 in the consolidated financial statements.

Earnings Impact of MTM Gain (Loss), After-Tax

MTM gain, after-tax increased $151 million to $307 million in Q4 2022, compared to $156 million in Q4 2021, and for the year ended December 31, increased $388 million to $175 million compared to a MTM loss, after-tax of $213 million for the same period in 2021. These increases were due to changes in existing positions and reversal of losses in 2022, partially offset by higher amortization in 2022 of gas transportation assets at Emera Energy.

CONSOLIDATED FINANCIAL HIGHLIGHTS

 

For the

millions of dollars

  

Three months ended

December 31

               

Year ended

December 31

 

Adjusted net income

   2022     2021     2022     2021     2020  

Florida Electric Utility

   $ 124     $ 85     $ 596     $ 462     $ 501  

Canadian Electric Utilities

     46       67       222       241       221  

Gas Utilities and Infrastructure

     72       55       221       198       162  

Other Electric Utilities

     8       5       29       20       33  

Other

     (1 )      (44 )      (218 )      (198 )      (252 ) 
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Adjusted net income

   $ 249     $ 168     $ 850     $ 723     $ 665  
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

MTM gain (loss), after-tax

     307       156       175       (213 )      (10 ) 

Impairment charges, after-tax

     (73 )      —         (73 )      —         (26 ) 

NSPML unrecoverable costs

     —         —         (7 )      —         —    

Gain on sale, after tax and transaction costs

     —         —         —         —         309  
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Net income attributable to common shareholders

   $ 483     $ 324     $ 945     $ 510     $ 938  
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 

  EMERA 2022 ANNUAL REPORT   15


Management’s Discussion & Analysis

 

The following table highlights the significant changes in adjusted net income from 2021 to 2022:

 

For the

millions of dollars

   Three months ended
December 31
     Year ended
December 31
 

Adjusted net income – 2021

   $ 168      $ 723  

Operating Unit Performance

     

Increased earnings at Tampa Electric due to higher revenues as a result of rate increases effective January 2022, customer growth, and the impact of a weakening CAD. These were partially offset by higher operating, maintenance and general expenses (”OM&G”), increased interest expense, and higher depreciation. Year-over-year also increased due to favourable weather

     39        134  

Increased earnings at Emera Energy Services (“EES”) due to favourable market conditions

     21        21  

Increased earnings at PGS due to higher off-system sales and customer growth, partially offset by higher OM&G. Year-over-year also increased due to reversal of accumulated depreciation as a result of the rate case settlement

     2        10  

Increased earnings at Seacoast due to commencement of a 34-year pipeline lateral lease in 2022

     2        9  

Increased earnings at NMGC were primarily due to higher asset optimization revenues. Year-over-year increased earnings were partially offset by higher OM&G and increased depreciation

     11        4  

Decreased earnings at NSPI due to higher OM&G primarily due to increased costs for storm restoration, IT, power generation, regulatory affairs, and higher depreciation. This was partially offset by higher sales volumes. Quarter-over-quarter also decreased due to unfavourable weather

     (20 )       (10 ) 

Corporate

     

TGH award, after tax and legal costs, in Q4 2022. Refer to the ”Significant Items Affecting Earnings” section

     45        45  

Increased income tax recovery primarily due to increased losses before provision for income taxes

     17        34  

Increased OM&G, pre-tax, due to the timing of long-term compensation and related hedges

     (19 )       (55 ) 

Increased FX loss, pre-tax, primarily due to realized gains in 2021 on FX hedges entered into to hedge USD denominated operating unit earnings exposure

     (9 )       (28 ) 

Increased interest expense, pre-tax, due to higher interest rates and increased total debt

     (17 )       (27 ) 

Increased preferred stock dividends due to issuance of preferred shares in 2021

     (2 )       (13 ) 

Other Variances

     11        3  
  

 

 

    

 

 

 

Adjusted net income – 2022

   $ 249      $ 850  
  

 

 

    

 

 

 

For further details of reportable segments contributions, refer to the “Financial Highlights” section.

 

For the

millions of dollars

                

Year ended

December 31

 
   2022      2021      2020  

Operating cash flow before changes in working capital

   $ 1,147      $ 1,337      $ 1,420  

Change in working capital

     (234 )       (152 )       217  
  

 

 

    

 

 

    

 

 

 

Operating cash flow

   $ 913      $ 1,185      $ 1,637  
  

 

 

    

 

 

    

 

 

 

Investing cash flow

   $ (2,569 )     $ (2,332 )     $ (1,224 ) 
  

 

 

    

 

 

    

 

 

 

Financing cash flow

   $ 1,555      $ 1,311      $ (372 ) 
  

 

 

    

 

 

    

 

 

 

 

16   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

For further discussion of cash flow, refer to the “Consolidated Cash Flow Highlights” section.

 

As at

millions of dollars

                 December 31  
   2022      2021      2020  

Total assets

   $ 39,742      $ 34,244      $ 31,234  
  

 

 

    

 

 

    

 

 

 

Total long-term debt (including current portion)

   $ 16,318      $ 14,658      $ 13,721  
  

 

 

    

 

 

    

 

 

 

CONSOLIDATED INCOME STATEMENT HIGHLIGHTS

 

For the

millions of dollars

  

Three months ended

December 31

                 

Year ended

December 31

          

Year ended

December 31

 

(except per share amounts)

   2022      2021      Variance     2022      2021      Variance     2020  

Operating revenues

   $ 2,358      $ 1,868      $ 490     $ 7,588      $ 5,765      $ 1,823     $ 5,506  

Operating expenses

     1,638        1,352        (286 )      5,959        4,835        (1,124 )      4,359  

Income from operations

   $ 720      $ 516      $ 204     $ 1,629      $ 930      $ 699     $ 1,147  

Net income attributable to common shareholders

   $ 483      $ 324      $ 159     $ 945      $ 510      $ 435     $ 938  

Adjusted net income

   $ 249      $ 168      $ 81     $ 850      $ 723      $ 127     $ 665  

Weighted average shares of common stock outstanding (in millions) (1)

     269.0        260.8        8.2       265.5        257.2        8.3       247.8  

EPS – basic

   $ 1.80      $ 1.24      $ 0.56     $ 3.56      $ 1.98      $ 1.58     $ 3.78  

EPS – diluted

   $ 1.80      $ 1.20      $ 0.60     $ 3.55      $ 1.98      $ 1.57     $ 3.78  

Adjusted EPS – basic

   $ 0.93      $ 0.64      $ 0.29     $ 3.20      $ 2.81      $ 0.39     $ 2.68  

Adjusted EBITDA

   $ 755      $ 582      $ 173     $ 2,687      $ 2,367      $ 320     $ 2,343  

Dividends per common share declared

   $ 0.6900      $ 0.6625      $ 0.0275     $ 2.6775      $ 2.5750      $ 0.1025     $ 2.4750  

Dividends per first preferred shares declared:

                  

Series A

           $ 0.5456      $ 0.5456      $ —       $ 0.6155  

Series B

           $ 0.6869      $ 0.4873      $ 0.1996     $ 0.6965  

Series C

           $ 1.1802      $ 1.1802      $ —       $ 1.1802  

Series E

           $ 1.1250      $ 1.1250      $ —       $ 1.1250  

Series F

           $ 1.0505      $ 1.0505      $ —       $ 1.0535  

Series H

           $ 1.2250      $ 1.2250      $ —       $ 1.2250  

Series J

           $ 1.0625      $ 0.6470      $ 0.4155     $ —    

Series L

           $ 1.1500      $ 0.1638      $ 0.9862     $ —    

 

(1)

Effective February 10, 2022, deferred share units are no longer able to be settled in shares and are therefore excluded from weighted average shares of common stock outstanding.

Operating Revenues

For Q4 2022, operating revenues increased $490 million compared to Q4 2021 and, absent increased MTM gains of $195 million, increased $295 million. For the year ended December 31, 2022, operating revenues increased $1,823 million compared to 2021 and, absent increased MTM gains of $555 million, increased by $1,268 million. The increases in both periods were due to: higher fuel revenues at NMGC, Tampa Electric PGS and BLPC; new rates effective January 2022 and customer growth at Tampa Electric; the impact of a weaker CAD; higher off-system sales and customer growth at PGS; and increased marketing and trading margin due to favourable market conditions at EES. Year-over-year also increased due to increased sales volumes at NSPI and favourable weather at Tampa Electric.

 

  EMERA 2022 ANNUAL REPORT   17


Management’s Discussion & Analysis

 

Operating Expenses

For Q4 2022, operating expenses increased $286 million compared to Q4 2021 and, absent the GBPC impairment charge of $73 million, increased by $213 million. For the year ended December 31, 2022, operating expenses increased $1,124 million compared to 2021 and, absent the GBPC impairment charge of $73 million, increased by $1,051 million. The increases in both periods were due to: higher natural gas prices at NMGC and PGS; the impact of a weaker CAD; and increased OM&G at Tampa Electric, Corporate, NSPI, NMGC and PGS. Year-over-year also increased due to higher natural gas and fuel prices at Tampa Electric and BLPC.

Other Income, Net

Other income, net increased for Q4 2022 and the year ended December 31, 2022, compared to the same periods in 2021, primarily due to the TGH award in Q4 2022.

Net Income and Adjusted Net Income

Net income attributable to common shareholders for Q4 2022, as compared to Q4 2021, was favourably impacted by the $151 million increase in MTM gains, after-tax and unfavourably impacted by the $73 million GBPC impairment charge. Absent these changes, adjusted net income increased $81 million. The increase was primarily due to: the TGH award in Q4 2022; higher earnings contribution from Tampa Electric, Emera Energy and NMGC; and the impact of a weaker CAD. These were partially offset by lower earnings contribution from NSPI and increased corporate OM&G due to the timing of long-term compensation and related hedges, and higher corporate interest expense.

Net income attributable to common shareholders for the year ended 2022, as compared to the same period in 2021, was favourably impacted by the $388 million increase in MTM gains, after-tax and unfavourably impacted by the $73 million GBPC impairment charge as well as the $7 million in NSPML unrecoverable costs. Absent these changes, adjusted net income increased $127 million. The increase was primarily due to: higher earnings contributions from Tampa Electric, Emera Energy, PGS and Seacoast; the TGH award in Q4 2022; and the impact of a weaker CAD. These were partially offset by increased corporate OM&G due to the timing of long-term compensation and related hedges, higher corporate interest expense, realized gains on corporate FX hedges in 2021, increased preferred stock dividends and lower earnings contribution from NSPI.

EPS and Adjusted EPS – Basic

EPS and Adjusted EPS – basic were higher for Q4 2022, and for the year ended December 31, 2022, due to the impact of higher earnings as discussed above, partially offset by the impact of the increase in weighted average shares of common stock outstanding.

Effect of Foreign Currency Translation

Emera operates in Canada, the United States and various Caribbean countries and, as such, generates revenues and incurs expenses denominated in local currencies which are translated into CAD for financial reporting. Changes in translation rates, particularly in the value of the USD against the CAD, can positively or adversely affect results.

In general, Emera’s earnings benefit from a weakening CAD and are adversely impacted by a strengthening CAD. The impact in any period is driven by rate changes, the timing and percentage of earnings from foreign operations, and the impact of FX hedges entered into to hedge USD denominated operating unit earnings exposure.

 

18   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

Results of foreign operations are translated at the weighted average rate of exchange, and assets and liabilities of foreign operations are translated at period end rates. The relevant CAD/USD exchange rates for 2022 and 2021 are as follows:

 

    

Three months ended

December 31

           

Year ended

December 31

 
     2022      2021      2022      2021  

Weighted average CAD/USD

   $ 1.37      $ 1.26      $ 1.34      $ 1.26  

Period end CAD/USD exchange rate

   $ 1.35      $ 1.27      $ 1.35      $ 1.27  

The table below includes Emera’s significant segments whose contributions to adjusted net income are recorded in USD currency.

 

For the   

Three months ended

December 31

           

Year ended

December 31

 

millions of USD

   2022      2021      2022      2021  

Florida Electric Utility

   $ 91      $ 67      $ 458      $ 369  

Other Electric Utilities

     7        4        23        16  

Gas Utilities and Infrastructure (1)

     45        37        143        130  

Other segment (2)

     30        (20 )       (50 )       (98 ) 
  

 

 

    

 

 

    

 

 

    

 

 

 

Total (3)

   $ 173      $ 88      $ 574      $ 417  
  

 

 

    

 

 

    

 

 

    

 

 

 

 

(1)

Includes USD net income from PGS, NMGC, SeaCoast and M&NP.

(2)

Includes Emera Energy’s USD adjusted net income from EES, Bear Swamp and interest expense on Emera Inc.’s USD denominated debt.

(3)

Excludes $222 million USD in MTM gain, after-tax, for the three months ended December 31, 2022 (2021 – $122 million USD MTM gain, after-tax) and MTM gain, after-tax of $130 million USD for the year ended December 31, 2022 (2021 – $164 million USD MTM loss, after-tax) and the GBPC impairment charge of $54 million USD for the three months and year ended December 31, 2022 (2021 – nil).

The impact of the weakening CAD, partially offset by the unrealized losses on FX hedges increased net income by $42 million in Q4 2022 and $30 million for the year ended December 31, 2022, compared to the same periods in 2021. Weakening of the CAD increased adjusted net income by $14 million in Q4 2022 and $28 million for the year ended December 31, 2022, compared to the same periods in 2021. Impacts of the weakening CAD include the impacts of corporate FX hedges in the Other segment.

Business Overview and Outlook

FLORIDA ELECTRIC UTILITY

Florida Electric Utility consists of Tampa Electric, a vertically integrated regulated electric utility engaged in the generation, transmission and distribution of electricity, serving customers in West Central Florida. Tampa Electric has $12.1 billion USD of assets and approximately 827,000 customers at December 31, 2022. Tampa Electric owns 6,549 megawatts (“MW”) of generating capacity, of which 78 per cent is natural gas-fired, 15 per cent is solar and 7 per cent is coal. Tampa Electric owns 2,171 kilometres of transmission facilities and 19,916 kilometres of distribution facilities. Tampa Electric meets the planning criteria for reserve capacity established by the FPSC, which is a 20 per cent reserve margin over firm peak demand.

Tampa Electric’s approved regulated ROE range is 9.25 per cent to 11.25 per cent, based on an allowed equity capital structure of 54 per cent. An ROE of 10.20 per cent will be used for the calculation of the return on investments for clauses.

Tampa Electric anticipates earning within its ROE range in 2023. New base rates effective January 1, 2023, as a result of the 2021 settlement agreement, will result in higher 2023 USD earnings than in 2022. Normalizing 2022 for weather, Tampa Electric sales volumes in 2023 are projected to be higher than in 2022 due to customer growth. Tampa Electric expects customer growth rates in 2023 to be comparable to 2022, reflective of the current expected economic growth in Florida.

On January 23, 2023, Tampa Electric requested an adjustment to its fuel charges to recover the 2022 fuel under-recovery of $518 million USD over a period of 21 months. The request also included an adjustment to 2023 projected fuel costs to reflect the reduction in natural gas prices since September 2022 for a projected reduction of $170 million USD for the balance of 2023. The proposed changes will be decided by the FPSC in March 2023, and recovery is expected to begin in April 2023.

 

  EMERA 2022 ANNUAL REPORT   19


Management’s Discussion & Analysis

 

On September 28, 2022, Hurricane Ian made landfall in Southwest Florida as a Category 4 hurricane and, as a result, approximately 291,000 customers lost power. The majority of Hurricane Ian restoration costs were charged against Tampa Electric’s FPSC approved storm reserve, resulting in minimal impact to earnings for 2022. The total cost of restoration was $126 million USD, with approximately $119 million USD charged to the storm reserve. Total restoration costs charged to the storm reserve have exceeded the reserve balance and have been deferred as a regulatory asset for future recovery. On January 23, 2023, Tampa Electric petitioned the FPSC for recovery of the storm reserve regulatory asset and the replenishment of the balance in the reserve to the previous approved reserve level of $56 million USD, for a total of approximately $131 million USD. The proposed changes will be decided by the FPSC in March 2023, and recovery is expected to begin in April 2023 through March 2024.

The mid-course fuel adjustment requested by Tampa Electric on January 19, 2022, was approved on March 1, 2022. The rate increase, effective with the first billing cycle in April 2022, covered higher fuel and capacity costs of $169 million USD and was spread over customer bills from April 1, 2022 through December 2022.

In 2023, capital investment in the Florida Electric Utility segment is expected to be $1.3 billion USD (2022 – $1.1 billion USD), including allowance for funds used during construction (“AFUDC”). Capital projects include solar investments, grid modernization and storm hardening investments.

CANADIAN ELECTRIC UTILITIES

Canadian Electric Utilities includes NSPI and ENL. NSPI is a vertically integrated regulated electric utility engaged in the generation, transmission and distribution of electricity and the primary electricity supplier to customers in Nova Scotia. ENL is a holding company with equity investments in NSPML and LIL: two transmission investments related to the development of an 824 MW hydroelectric generating facility at Muskrat Falls on the Lower Churchill River in Labrador.

NSPI

With $6.8 billion of assets and approximately 541,000 customers, NSPI owns 2,420 MW of generating capacity, of which approximately 44 per cent is coal-fired; 28 per cent is natural gas and/or oil; 19 per cent is hydro and wind; 7 per cent is petcoke and 2 per cent is biomass-fueled generation. In addition, NSPI has contracts to purchase renewable energy from independent power producers (“IPPs”), which own 546 MW of capacity. NSPI also has rights to 153 MW of Maritime Link capacity, representing Nalcor Energy’s (“Nalcor”) Nova Scotia Block (“NS Block”) delivery obligations, as discussed below. NSPI owns approximately 5,000 kilometres of transmission facilities and 28,000 kilometres of distribution facilities.

NSPI’s approved regulated ROE range is 8.75 per cent to 9.25 per cent, based on an actual five-quarter average regulated common equity component of up to 40 per cent of approved rate base.

NSPI anticipates earning near the low end of its allowed ROE range in 2023, and below the allowed range in 2024. NSPI expects earnings and sales volumes to be higher in 2023 than 2022.

NSPI operated under a three-year fuel stability plan which resulted in an average annual overall rate increase of 1.5 per cent to recover fuel costs for the period of 2020 through 2022. These rates include recovery of Maritime Link costs (discussed below in the “ENL, NSPML” section).

 

20   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

On November 9, 2022, the Nova Scotia provincial government enacted Bill 212, “Public Utilities Act (amended)”. The legislation limits non-fuel rate increases in NSPI’s 2022 General Rate Application (“GRA”) to the UARB, excluding increases relating to demand side management (“DSM”) costs, to a total of 1.8 per cent between the effective date of the UARB’s decision and the end of 2024. The legislation also:

 

  •  

requires revenue generated from the non-fuel rate increase to be used only to improve the reliability of service to ratepayers,

 

  •  

limits NSPI’s return on equity to 9.25 per cent and equity ratio to 40 per cent, and

 

  •  

limits the rate used to accrue interest on regulatory deferrals to the Bank of Canada policy interest rate plus 1.75 per cent, unless otherwise directed by the UARB.

Actions required to address the impact of Bill 212, “Public Utilities Act (amended)”, include a material reduction in NSPI’s planned capital investments and operating costs over the 2023 through 2024 period. Such deferral of capital investment and operating costs may result in higher customer costs in future periods. The legislation will have a direct and negative impact on the financial performance of NSPI and has had a negative impact on NSPI’s credit quality. For more information on this risk, refer to the “Risk Management and Financial Instruments – Regulatory and Political Risk” section.

On November 24, 2022, NSPI filed with the UARB a comprehensive settlement agreement between NSPI, key customer representatives and participating interest groups (“NSPI Settlement Agreement”) in relation to its GRA filed in January 2022. The NSPI Settlement Agreement was structured to be consistent with the amendments to the Public Utilities Act made under Bill 212, which included a 1.8 per cent cap on non-fuel rate increases for 2023 and 2024. Bill 212, “Public Utilities Act (amended),” is described further above. The NSPI Settlement Agreement also addresses the recovery of fuel costs over the settlement period and establishes a DSM rider. This will result in a combined fuel and non-fuel rate increase of 6.9 per cent each year for 2023 and 2024 and annualized incremental revenue (fuel and non-fuel) of $105 million in 2023 and $115 million in 2024. In addition, any under or over recovery of fuel costs will be addressed through the UARB’s established FAM process. NSPI’s ROE range will continue to be 8.75 per cent to 9.25 per cent, based on an actual five-quarter average regulated common equity component of up to 40 per cent. The NSPI Settlement Agreement also establishes a storm rider for each of 2023, 2024 and 2025, which gives NSPI the option to apply to the UARB for recovery of costs if major storm restoration expense exceeds approximately $10 million in a given year. On February 2, 2023, NSPI received the UARB’s decision, which substantially approved the NSPI Settlement Agreement as filed. Approved rate increases will be effective as of the date of the decision.

On September 24, 2022, Nova Scotia was struck by Hurricane Fiona, which made landfall as a post-tropical storm equivalent to a Category 2 hurricane. The storm had sustained winds of over 100 kilometres per hour and peak gusts of approximately 180 kilometres per hour. This historic storm for Nova Scotia caused significant and widespread damage to NSPI’s transmission and distribution system and at the height of the storm approximately 415,000 customers lost power. The total cost of the restoration was approximately $115 million, of which $91 million was capitalized to Property, plant and equipment (“PP&E”) and $24 million deferred to Other long-term assets for future amortization, subject to UARB approval. NSPI intends to submit an application to the UARB requesting to defer the recognition of incremental operating costs related to storm restoration. If the deferral is approved, this balance will be reclassified to “Regulatory assets” and amortized over the UARB approved recognition period.

Energy from renewable sources has increased with Nalcor’s NS Block delivery obligations from the Muskrat Falls hydroelectric project (“Muskrat Falls”) commencing in 2021. Nalcor is obligated to provide NSPI with approximately 900 GWh of energy annually over 35 years. In addition, for the first five years of the NS Block, Nalcor is obligated to provide approximately 240 GWh of additional energy from the Supplemental Energy Block transmitted through the Maritime Link. Nalcor’s final commissioning of the LIL has experienced delays and it’s expected that final commissioning of the LIL will be completed in 2023. During these final stages of commissioning, there will be interruptions in supply, with any resultant delivery shortfalls being delivered on a timely basis in accordance with the Energy and Capacity Agreement. NSPI has the option of purchasing additional market-priced energy from Nalcor through the Energy Access Agreement. The Energy Access Agreement enables NSPI to access a market-priced bid from Nalcor for up to 1.8 Terawatt hours (“TWh”) of energy in any given year and, on average, 1.2 TWh of energy per year through August 31, 2041.

Capital investment for 2023, including AFUDC, is expected to be approximately $375 million (2022 – $540 million). NSPI is primarily investing in capital projects required to support power system reliability and reliable service for customers.

 

  EMERA 2022 ANNUAL REPORT   21


Management’s Discussion & Analysis

 

Environmental Legislation and Regulations

NSPI is subject to environmental laws and regulations set by both the Government of Canada and the Province of Nova Scotia. NSPI continues to work with both levels of government to comply with these laws and regulations to maximize efficiency of emission control measures and minimize customer cost. NSPI anticipates that costs prudently incurred to achieve legislated compliance will be recoverable under NSPI’s regulatory framework. NSPI faces risks associated with achieving climate-related and environmental legislative requirements, including the risk of non-compliance, which could adversely affect NSPI’s operations and financial performance. For further discussion on these risks and environmental legislation and regulations, refer to the “Enterprise Risk and Risk Management” section. Recent developments related to provincial and federal environmental laws and regulations are outlined below.

Nova Scotia Cap-and-Trade Program Regulations:

NSPI is a participant in the Nova Scotia Cap-and-Trade Program (“Cap-and-Trade Program”) and is subject to the 2019 through 2022 compliance period. NSPI received granted emissions allowances under the Cap-and-Trade Program and is permitted to purchase up to five per cent of the credits available at provincial auctions. Any remaining allowance shortfall requires the purchase of reserve credits directly from the provincial government, which are anticipated to be priced at a premium to provincial auction pricing. Compliance is forecast to be achieved through granted emissions allowances and credit purchases under the Cap-and-Trade Program, including reserve credits. Lower than forecast Muskrat Falls energy received during the compliance period has resulted in the increased deployment of higher carbon-emitting generation sources. The Province of Nova Scotia has agreed to provide approximately $165 million of relief from the 2019 through 2022 compliance costs, which was equal to the total cost of compliance forecast at the time of the fuel update submitted by NSPI to the UARB in September 2022 as part of the GRA. Discussions related to the final amount of relief and how this relief will be provided are ongoing. Further, NSPI’s regulatory framework provides for the recovery of costs prudently incurred to comply with the Cap-and-Trade Program Regulations pursuant to NSPI’s FAM.

Carbon Pricing Regulations:

On November 9, 2022, the Nova Scotia provincial government enacted Bill 208, “Environment Act (amended)”. The legislation provides the framework for Nova Scotia’s system to comply with the federal government’s 2023 through 2030 carbon pollution pricing regulations laid out in the Pan-Canadian Framework on Clean Growth and Climate Change. Nova Scotia’s proposed system utilizes an output-based pricing system that will implement performance standards for large industrial greenhouse gas emitters to achieve emission reduction goals. Subsequent regulations will be required to detail how the pricing system will operate. The Province of Nova Scotia’s proposed output-based pricing system is subject to the approval of the federal government. If an agreement is not reached between the federal and provincial governments on a Nova Scotia system that meets the federal compliance criteria, Nova Scotia will be subject to the federal carbon pollution pricing backstop which uses emissions performances standards that vary by fuel type, and a carbon price that will start at $65 per tonne in 2023 and increase by $15 per tonne annually, reaching $170 per tonne by 2030. NSPI’s regulatory framework provides for the recovery of costs prudently incurred to comply with carbon pricing programs pursuant to NSPI’s FAM.

Nova Scotia Renewable Energy Regulations:

Under the provincially legislated Renewable Energy Regulations, 40 per cent of electric sales must be generated from renewable sources. This standard was predicated on receipt of the full NS Block. Due to the delay of the NS Block, the provincial government provided NSPI with an alternative compliance plan that requires NSPI to achieve 40 per cent of electric sales generated from renewable sources over the 2020 through 2022 period. With delivery of the NS Block commencing later than anticipated, as well as further interruptions in supply due to delays in the LIL, NSPI did not achieve the requirements of the alternative compliance plan. The Renewable Energy Regulations require NSPI to have acted in a duly diligent manner. If NSPI is found not to have acted in a duly diligent manner, it could be subject to a maximum penalty of $10 million.

 

22   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

ENL

Total equity earnings from NSPML and LIL are expected to be higher in 2023, compared to 2022. Both the NSPML and LIL investments are recorded as “Investments subject to significant influence” on Emera’s Consolidated Balance Sheets.

NSPML

Equity earnings from the Maritime Link are dependent on the approved ROE and operational performance of NSPML. NSPML’s approved regulated ROE range is 8.75 per cent to 9.25 per cent, based on an actual five-quarter average regulated common equity component of up to 30 per cent.

The Maritime Link assets entered service on January 15, 2018, enabling the transmission of energy between Newfoundland and Nova Scotia, improved reliability and ancillary benefits, supporting the efficiency and reliability of energy in both provinces. Nalcor continues to advance towards completion of the LIL, and it’s expected final commissioning will be achieved in 2023. Nalcor’s NS Block delivery obligations commenced on August 15, 2021, and the NS Block will be delivered over the next 35 years pursuant to the project agreements. As Nalcor is in the final stages of commissioning the LIL, there will be commissioning related interruptions in supply with any resultant delivery shortfalls being delivered on a timely basis in accordance with the Energy and Capacity Agreement.

In February 2022, the UARB issued its decision and Board Order approving NSPML’s requested rate base of approximately $1.8 billion less $9 million of costs ($7 million after-tax) that would not have otherwise been recoverable if incurred by NSPI. NSPML also received approval to collect up to $168 million (2021 – $172 million) from NSPI for the recovery of costs associated with the Maritime Link in 2022. This was subject to a holdback of up to $2 million per month, beginning April 2022, contingent on receiving at least 90 per cent of NS Block deliveries, including Supplemental Energy deliveries.

In December 2022, NSPML received UARB approval to collect up to $164 million from NSPI for the recovery of costs associated with the Maritime Link in 2023. This continues to be subject to a holdback of up to $2 million a month, as discussed above. On December 22, 2022, the UARB clarified its earlier direction regarding the holdback and NSPI can now release the holdback to NSPML when 90 per cent of NS Block deliveries, including Supplemental Energy deliveries, is achieved. This enabled NSPI to pay NSPML approximately $4 million of the 2022 holdback. As of December 31, 2022, an additional $14 million in aggregate has been held back by NSPI. Determination of allocation of the $14 million between NSPML and NSPI will be subject to a regulatory process that is expected to commence in early 2023 to review the holdback mechanism.

NSPML does not anticipate any significant capital investment in 2023.

LIL

ENL is a limited partner with Nalcor in LIL. Construction of the LIL is complete and Nalcor is forecasting it will achieve final commissioning in 2023.

Equity earnings from the LIL investment are based upon the book value of the equity investment and the approved ROE. Emera’s current equity investment is $740 million, comprised of $410 million in equity contribution and $330 million of accumulated equity earnings. Emera’s total equity contribution in the LIL, excluding accumulated equity earnings, is estimated to be approximately $650 million after the Lower Churchill projects are completed.

Cash earnings and return of equity will begin after commissioning of the LIL by Nalcor, which is anticipated in 2023, and until that point Emera will continue to record AFUDC earnings.

GAS UTILITIES AND INFRASTRUCTURE

Gas Utilities and Infrastructure includes PGS, NMGC, SeaCoast, Brunswick Pipeline and Emera’s non-consolidated investment in M&NP. PGS is a regulated gas distribution utility engaged in the purchase, distribution and sale of natural gas serving customers in Florida. NMGC is an intrastate regulated gas distribution utility engaged in the purchase, transmission, distribution and sale of natural gas serving customers in New Mexico. SeaCoast is a regulated intrastate natural gas transmission company offering services in Florida. Brunswick Pipeline is a regulated 145-kilometre pipeline delivering re-gasified liquefied natural gas from Saint John, New Brunswick, to markets in the northeastern United States.

 

  EMERA 2022 ANNUAL REPORT   23


Management’s Discussion & Analysis

 

Peoples Gas System

With $2.5 billion USD of assets and approximately 468,000 customers, the PGS system includes 24,300 kilometres of natural gas mains and 13,500 kilometres of service lines. Natural gas throughput (the amount of gas delivered to its customers, including transportation-only service) was 2 billion therms in 2022.

The approved ROE range for PGS is 8.9 per cent to 11.0 per cent, based on an allowed equity capital structure of 54.7 per cent. An ROE of 9.9 per cent is used for the calculation of return on investments for clauses.

New Mexico Gas Company, Inc.

With $2.0 billion USD of assets and approximately 545,000 customers, NMGC’s system includes approximately 2,426 kilometres of transmission pipelines and 17,781 kilometres of distribution pipelines. Annual natural gas throughput was approximately 926 million therms in 2022.

The approved ROE for NMGC is 9.375 per cent, on an allowed equity capital structure of 52 per cent.

Gas Utilities and Infrastructure Outlook

Gas Utilities and Infrastructure USD earnings are anticipated to be higher in 2023 than 2022, primarily due to a base rate increase at NMGC, effective January 2023.

PGS expects 2023 rate base growth and USD earnings to be consistent with 2022 as higher revenues from customer growth offset increased interest expenses and the effect of inflation. Increased residential and commercial sales volumes and customer growth are anticipated in 2023. PGS anticipates earning below its allowed ROE range in 2023 primarily due to rate base growth. As a result, on February 3, 2023, PGS notified the FPSC that it is planning to file a base rate proceeding in April 2023 for new rates effective January 2024.

The PGS rate case settlement, which was approved in November 2020, provides the ability to reverse a total of $34 million USD of accumulated depreciation through 2023. Through December 31, 2022, PGS reversed $14 million USD accumulated depreciation. The reversal of the remaining accumulated depreciation is expected to occur over 2023.

NMGC expects 2023 rate base and USD earnings to be higher in 2023 than 2022 due to base rate increases effective January 2023, as discussed below, and rate base growth to expand the distribution system and to continue to reliably serve customers. NMGC anticipates earning near its authorized ROE in 2023 and expects customer growth rates to be consistent with historical trends. NMGC’s asset optimization revenues for 2022 were well above the historical average, and may not recur in 2023.

On December 13, 2021, NMGC filed a rate case with the NMPRC for new rates to become effective January 2023. On May 20, 2022, NMGC filed an unopposed settlement agreement with the NMPRC for an increase of $19 million USD in annual base revenues. The rates reflect the recovery of increased operating costs and capital investments in pipelines and related infrastructure. The NMPRC approved the settlement agreement on November 30, 2022.

In 2018, SeaCoast executed a 34-year agreement to provide long-term firm gas transportation service via a 21-mile, 30-inch pipeline lateral. The lease of the pipeline lateral commenced January 1, 2022.

In 2023, capital investment in the Gas Utilities and Infrastructure segment is expected to be approximately $475 million USD (2022 – $436 million USD), including AFUDC. PGS will make investments to expand its system and support customer growth. NMGC will continue to make investments to maintain the reliability of its system and support customer growth.

OTHER ELECTRIC UTILITIES

Other Electric Utilities includes Emera (Caribbean) Incorporated (“ECI”), a holding company with regulated electric utilities. ECI’s regulated utilities include vertically integrated regulated electric utilities of BLPC on the island of Barbados, GBPC on Grand Bahama Island, and a 19.5 per cent interest in Lucelec on the island of St. Lucia, which is accounted for on the equity basis.

On March 31, 2022, Emera completed the sale of its 51.9 per cent interest in Dominica Electricity Services Ltd. (“Domlec”) for proceeds which approximated carrying value. Domlec was included in the Other Electric Utilities segment in Q1 2022. The sale did not have a material impact on earnings.

 

24   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

BLPC

With $505 million USD of assets and approximately 133,000 customers, BLPC owns 276 MW of generating capacity, of which 96 per cent is oil-fired and four per cent is solar. BLPC owns approximately 188 kilometres of transmission facilities and 3,789 kilometres of distribution facilities. BLPC’s approved regulated return on rate base for 2022 was 10 per cent.

GBPC

With $338 million USD of assets and approximately 19,000 customers, GBPC owns 98 MW of oil-fired generation, approximately 90 kilometres of transmission facilities and 670 kilometres of distribution facilities. GBPC’s approved regulatory return on rate base for 2023 is 8.32 per cent (2022 – 8.23 per cent).

Other Electric Utilities Outlook

Absent the impact of the GBPC impairment charge in Q4 2022, Other Electric Utilities’ USD earnings in 2023 are expected to increase over the prior year primarily as a result of higher earnings due to higher base rates at BLPC.

BLPC currently operates pursuant to a franchise to generate, transmit and distribute electricity on the island of Barbados until 2028. In 2019, the Government of Barbados passed legislation amending the number of licenses required for the supply of electricity from a single integrated license which currently exists, to multiple licenses for Generation, Transmission and Distribution, Storage, Dispatch and Sales. In March 2021, BLPC reached commercial agreement with the Government of Barbados for each of the license types, subject to the passage of implementing legislation. The new licenses are expected to take effect in 2023 on completion of the legislative process. The Dispatch license will have a term of five years with the remaining licenses having terms ranging from 25-30 years. BLPC anticipates that any increased costs associated with the implementation of the new multi-licensed structure will be recoverable through BLPC’s regulatory framework. BLPC is awaiting final enactment and will work towards implementation of the licenses once received.

On October 4, 2021 BLPC submitted a general rate review application to the FTC. The application seeks a rate adjustment and the implementation of a cost reflective rate structure that will facilitate the changes expected in the newly reformed electricity market and the country’s transition toward 100 per cent renewable energy generation. The application seeks recovery of capital investment in plant, equipment and related infrastructure and results in an increase in annual non-fuel revenue of approximately $23 million USD upon approval. The application includes a request for an allowed regulatory ROE of 12.50 per cent on an allowed equity capital structure of 65 per cent. On September 16, 2022, the FTC granted BLPC interim rate relief, allowing an increase in base rates of approximately $3 million USD for the remainder of 2022 and approximately $1 million USD per month for 2023. Interim rate relief is effective from September 16, 2022 until the implementation of final rates. The hearing concluded in October 2022. On February 15, 2023, the FTC issued a decision on the BLPC rate review application which included the following significant items: an allowed regulatory ROE of 11.75 per cent, an equity capital structure of 55 per cent, a directive to update the major components of rate base to September 16, 2022, and a directive to establish regulatory liabilities of approximately $70 million USD related to the self-insurance fund, accumulated depreciation, and taxes. The impacts to BLPC’s rate base and final rates are not yet determinable but management does not expect the decision to have a material impact on Emera’s adjusted net income. BLPC will seek to clarify aspects of the FTC decision in its compliance filing and is also considering filing a submission to the FTC for a review of the decision. BLPC expects a decision on final rates from the FTC in 2023.

On January 14, 2022, the GBPA issued its decision on GBPC’s rate application. The decision, which became effective April 1, 2022, allows for an increase in revenues of $3.5 million USD. The new rates include a regulatory ROE of 12.84 per cent.

Effective November 1, 2022, GBPC’s fuel pass through charge was increased due to an increase in global oil prices impacting the unhedged fuel cost. In 2023, the fuel pass through charge will be adjusted monthly, in-line with actual fuel costs.

In 2023, capital investment in the Other Electric Utilities segment is expected to be approximately $65 million USD (2022 – $48 million USD), primarily in more efficient and cleaner sources of generation, including renewables and battery storage.

 

  EMERA 2022 ANNUAL REPORT   25


Management’s Discussion & Analysis

 

OTHER

The Other segment includes those business operations that in a normal year are below the required threshold for reporting as separate segments; and corporate expense and revenue items that are not directly allocated to the operations of Emera’s subsidiaries and investments.

Business operations in the Other segment include Emera Energy and Emera Technologies LLC (“ETL”). Emera Energy consists of EES, a wholly owned physical energy marketing and trading business and an equity investment in a 50 per cent joint venture ownership of Bear Swamp, a 660 MW pumped storage hydroelectric facility in northwestern Massachusetts. ETL is a wholly owned technology company focused on finding ways to deliver renewable and resilient energy to customers.

Corporate items included in the Other segment are certain corporate-wide functions including executive management, strategic planning, treasury services, legal, financial reporting, tax planning, corporate business development, corporate governance, investor relations, risk management, insurance, acquisition and disposition related costs, gains or losses on select assets sales, and corporate human resource activities. It includes interest revenue on intercompany financings and interest expense on corporate debt in both Canada and the United States. It also includes costs associated with corporate activities that are not directly allocated to the operations of Emera’s subsidiaries and investments.

Earnings from EES are generally dependent on market conditions. In particular, volatility in natural gas and electricity markets, which can be influenced by weather, local supply constraints and other supply and demand factors, can provide higher levels of margin opportunity. The business is seasonal, with Q1 and Q4 usually providing the greatest opportunity for earnings. EES is generally expected to deliver annual adjusted net income within its guidance range of $15 to $30 million USD ($45 to $70 million USD of margin).

Absent the TGH award in Q4 2022, the adjusted net loss from the Other segment is expected to be higher in 2023, based on EES returning to its normal earnings range in 2023 and increased interest expense. The increase is expected to be partially offset by decreased taxes due to a higher net loss.

The Other segment does not anticipate any significant capital investment in 2023.

 

26   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

Consolidated Balance Sheet Highlights

Significant changes in the Consolidated Balance Sheets between December 31, 2021 and December 31, 2022 include:

 

millions of dollars

   Increase
(Decrease)
   

Explanation

Assets

    

Cash and cash equivalents

   $ (84 )    Decreased due to increased investment in PP&E at regulated utilities and dividends on common stock. These were partially offset by proceeds from short-term debt issuance at Emera and Tampa Electric, increased proceeds under committed credit facilities at NSPI and Emera, cash from operations, and issuance of common stock

Inventory

     231     Increased due to higher commodity prices at Emera Energy and NSPI, increased materials inventory at Tampa Electric and the effect of the FX translation of Emera’s foreign affiliates

Derivative instruments (current and long-term)

     95     Increased due to reversal of 2021 contracts at Emera Energy

Regulatory assets (current and long-term)

     1,054     Increased due to higher fuel cost recovery clauses at Tampa Electric, increased FAM deferrals, driven mainly by increased Cap-and Trade emissions compliance charges, and increased deferred income tax regulatory assets at NSPI, the effect of the FX translation of Emera’s foreign affiliates, recognition of storm reserve asset at Tampa Electric due to restoration costs from Hurricane Ian in excess of the storm reserve liability, and increased pension and post-retirement plan deferrals at Tampa and NSPI. These were partially offset by recovery of gas costs from the NMGC 2021 winter event

Receivables and other assets (current and long-term)

     1,165     Increased due to higher gas transportation assets and higher trade receivables due to higher commodity prices at Emera Energy, fuel option receivable at NMGC and the effect of the FX translation of Emera’s foreign affiliates

PP&E, net of accumulated depreciation and amortization

     2,643     Increased due to the effect of the FX translation of Emera’s foreign affiliates, and capital additions. These were partially offset by reclassification of Seacoast’s pipeline lateral on commencement of the lease in 2022

Net investment in direct finance and sales type leases

     101     Increased due to commencement of the pipeline lease at Seacoast in 2022

Goodwill

     316     Increased due to the effect of the FX translation of Emera’s foreign affiliates, partially offset by the GBPC impairment

 

  EMERA 2022 ANNUAL REPORT   27


Management’s Discussion & Analysis

 

millions of dollars

  

Increase

(Decrease)

  

Explanation

Liabilities and Equity

     

Short-term debt and long-term debt (including current portion)

   $ 2,644   

Increased due to the effect of the FX translation of Emera’s foreign affiliates, issuance of short-term debt at Emera and Tampa Electric, and net borrowings

under the committed credit facility at NSPI and Emera

Accounts payable

   540   

Increased due to increased commodity prices at Emera Energy, Tampa Electric and NMGC, the effect of the FX translation of Emera’s foreign affiliates, higher cash collateral position on derivative instruments at NSPI, and timing of

payments at Tampa Electric and NSPI

Deferred income tax liabilities, net of deferred income tax assets

   386   

Increased due to tax deductions in excess of accounting depreciation related to PP&E, increase in net regulatory assets, decrease in net derivative liabilities, and the effect of the FX translation of Emera’s foreign affiliates, partially offset

by net increase in tax loss carryforwards

Derivative instruments (current and long-term)

   396   

Increased due to new contracts in 2022, partially offset by reversal of 2021

contracts and changes in existing positions at Emera Energy

Regulatory liabilities (current and long-term)

   218   

Increased due to NMGC gas hedge settlements and the effect of the FX translation of Emera’s foreign affiliates, partially offset by decreased storm

reserve at Tampa Electric due to restoration costs incurred from Hurricane Ian

Pension and post-retirement liabilities

   (89)   

Decreased due to favourable changes in actuarial assumptions, partially offset

by lower investment returns

Other liabilities (current and long-term)

   170   

Increased due to accrued emissions compliance charges at NSPI and the effect

of the FX translation of Emera’s foreign affiliates

Common stock

   520   

Increased due to Emera’s ATM equity program and shares issued under

the DRIP

Accumulated other comprehensive income

   553    Increased due to the effect of the FX translation of Emera’s foreign affiliates

Retained earnings

   236    Increased due to net income in excess of dividends paid

Other Developments

USGAAP Reporting Extension

Emera was granted exemptive relief by Canadian securities regulators on September 13, 2022, and under the Companies Act (Nova Scotia) on October 12, 2022, each allowing Emera to continue to report its financial results in accordance with USGAAP (collectively the “Exemptive Relief”). The Exemptive Relief will terminate on the earliest of: (i) January 1, 2027; (ii) if the Company ceases to have rate-regulated activities, the first day of the Company’s financial year that commences after the Company ceases to have rate-regulated activities; and (iii) the first day of the Company’s financial year that commences on or following the later of: (a) the effective date prescribed by the International Accounting Standards Board (“IASB”) for the mandatory application of a standard within IFRS specific to entities with rate-regulated activities (“Mandatory Rate-regulated Standard”); and (b) two years after the IASB publishes the final version of a Mandatory Rate-regulated Standard. The Exemptive Relief replaces similar relief that had been granted to Emera in 2018 and would have expired by no later than January 1, 2024.

Increase in Common Dividends

On September 22, 2022, the Emera Board of Directors approved an increase in the annual common share dividend rate to $2.76 from $2.65. The first payment was effective November 15, 2022. Emera also extended its dividend growth rate target of four to five per cent through 2025.

APPOINTMENTS

Effective July 1, 2022, Michael Barrett was appointed Executive Vice President and General Counsel for Emera. Mr. Barrett was most recently the General Counsel for Emera.

Effective June 30, 2022, Bruce Marchand was appointed Chief Risk and Sustainability Officer for Emera. Mr. Marchand was most recently the Chief Legal and Compliance Officer for Emera.

 

28   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

Financial Highlights

FLORIDA ELECTRIC UTILITY

All amounts are reported in USD, unless otherwise stated.

 

For the   

Three months ended

December 31

           

Year ended

December 31

 

millions of USD (except as indicated)

   2022      2021      2022      2021  

Operating revenues – regulated electric

   $ 597      $ 561      $ 2,523      $ 2,174  

Regulated fuel for generation and purchased power

   $ 201      $ 212      $ 832      $ 713  

Contribution to consolidated net income

   $ 91      $ 67      $ 458      $ 369  

Contribution to consolidated net income – CAD

   $ 124      $ 85      $ 596      $ 462  

Average fuel costs in dollars per MWh

   $ 41      $ 44      $ 39      $ 34  

The impact of the change in the FX rate increased CAD earnings for the three months and year ended December 31, 2022, by $10 million and $23 million, respectively.

Net Income

Highlights of the net income changes are summarized in the following table:

 

For the

millions of USD

   Three months ended
December 31
     Year ended
December 31
 

Contribution to consolidated net income – 2021

   $ 67      $ 369  

Increased operating revenues due to higher rates effective January 2022, higher fuel recovery clause revenue as a result of increased fuel costs, and customer growth. Year-over-year also increased due to favourable weather

     36        349  

Fuel for generation and purchased power decreased in Q4 due to lower natural gas prices quarter-over-quarter. Year-over-year, fuel increased due to higher natural gas prices

     11        (119 ) 

Increased OM&G due to timing of deferred clause recoveries. Year-over-year the increase is also due to higher transmission and distribution costs, higher benefit costs and higher insurance costs

     (6 )       (52 ) 

Increased depreciation and amortization due to additions to facilities and the in-service of generation projects

     (5 )       (15 ) 

Increased interest expense due to higher interest rates and higher borrowings to support Tampa Electric’s ongoing operations, including fuel under-recoveries, and capital investments

     (16 )       (32 ) 

Decreased AFUDC earnings due to timing of Big Bend modernization and solar projects

     (4 )       (10 ) 

Increased income tax expense year-over-year primarily due to increased income before provision for income taxes

     —          (36 ) 

Other

     8        4  
  

 

 

    

 

 

 

Contribution to consolidated net income – 2022

   $ 91      $ 458  
  

 

 

    

 

 

 

Operating Revenues – Regulated Electric

Annual electric revenues and sales volumes are summarized in the following table by customer class:

 

    

Electric Revenues

(millions of USD)

    

Electric Sales Volumes

(Gigawatt hours (“GWh”))

 
     2022      2021      2022      2021  

Residential

   $ 1,381      $ 1,156        10,109        9,941  

Commercial

     666        602        6,300        6,144  

Industrial

     176        172        2,111        2,122  

Other (1)

     300        244        2,352        2,000  
  

 

 

    

 

 

    

 

 

    

 

 

 

Total

   $ 2,523      $ 2,174        20,872        20,207  
  

 

 

    

 

 

    

 

 

    

 

 

 

 

(1)

Other includes sales to public authorities, off-system sales to other utilities and regulatory deferrals related to clauses.

 

  EMERA 2022 ANNUAL REPORT   29


Management’s Discussion & Analysis

 

Regulated Fuel for Generation and Purchased Power

Annual production volumes are summarized in the following table:

 

Production Volumes (GWh)  
     2022      2021  

Natural gas

     17,083        16,142  

Purchased power

     1,685        2,301  

Solar

     1,492        1,252  

Coal

     1,325        1,342  
  

 

 

    

 

 

 

Total

     21,585        21,037  
  

 

 

    

 

 

 

Tampa Electric’s fuel costs are affected by commodity prices and generation mix that is largely dependent on economic dispatch of the generating fleet, bringing the lowest cost options on first (renewable energy from solar), such that the incremental cost of production increases as sales volumes increase. Generation mix may also be affected by plant outages, plant performance, availability of lower priced short-term purchased power, availability of renewable solar generation, and compliance with environmental standards and regulations.

Regulatory Environment

Tampa Electric is regulated by the FPSC and is also subject to regulation by the FERC. The FPSC sets rates at a level that allows utilities such as Tampa Electric to collect total revenues or revenue requirements equal to their cost of providing service, plus an appropriate return on invested capital. Base rates are determined in FPSC rate setting hearings which can occur at the initiative of Tampa Electric, the FPSC or other interested parties. For further details on Tampa Electric’s regulatory environment, base rates and recovery mechanisms, refer to note 7 in the consolidated financial statements.

CANADIAN ELECTRIC UTILITIES

 

For the   

Three months ended

December 31

           

Year ended

December 31

 

millions of dollars (except as indicated)

   2022      2021      2022      2021  

Operating revenues – regulated electric

   $ 421      $ 389      $ 1,675      $ 1,501  

Regulated fuel for generation and purchased power (1)

   $ 173      $ 263      $ 950      $ 817  

Contribution to consolidated adjusted net income

   $ 46      $ 67      $ 222      $ 241  

NSPML unrecoverable costs

   $ —        $ —        $ (7 )     $ —    

Contribution to consolidated net income

   $ 46      $ 67      $ 215      $ 241  

Average fuel costs in dollars per MWh

   $ 61      $ 93      $ 85      $ 75  

 

(1)

Regulated fuel for generation and purchased power includes NSPI’s FAM and fixed cost deferrals on the Consolidated Statements of Income, however it is excluded in the segment overview.

Canadian Electric Utilities’ contribution to consolidated adjusted net income is summarized in the following table:

 

For the   

Three months ended

December 31

           

Year ended

December 31

 

millions of dollars

   2022      2021      2022      2021  

NSPI

   $ 23      $ 43      $ 131      $ 141  

Equity investment in LIL

     15        14        55        51  

Equity investment in NSPML (1)

     8        10        36        49  
  

 

 

    

 

 

    

 

 

    

 

 

 

Contribution to consolidated adjusted net income

   $ 46      $ 67      $ 222      $ 241  
  

 

 

    

 

 

    

 

 

    

 

 

 

 

(1)

Excludes $7 million in NSPML unrecoverable costs, after-tax, for the year ended December 31, 2022 (2021 – nil).

 

30   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

Net Income

Highlights of the net income changes are summarized in the following table:

 

For the

millions of dollars

   Three months ended
December 31
     Year ended
December 31
 

Contribution to consolidated net income – 2021

   $ 67      $ 241  

Increased operating revenues due to increased electric revenues related to recovery of fuel costs from an industrial customer, increased residential and commercial class sales volumes, and increased electricity pricing effective January 1, 2022. Quarter-over-quarter increase partially offset by unfavourable weather

     32        174  

Decreased regulated fuel for generation and purchased power quarter-over-quarter due to lower Cap-and-Trade Program provision and lower Maritime Link assessment costs. Increased regulated fuel for generation and purchased power year-over year due to increased Nova Scotia Cap-and-Trade program provision, increased commodity prices and higher sales volume, partially offset by a favourable change in generation mix

     90        (133 ) 

Decreased FAM and fixed cost deferrals year-over-year due to increased recovery of fuel costs, partially offset by increased Cap-and-Trade provision. Quarter-over-quarter decreased due to increased recovery of fuel costs and decreased Cap-and-Trade provision

     (120 )       (16 ) 

Increased OM&G due to higher costs for storm restoration, IT, power generation, and regulatory affairs

     (20 )       (47 ) 

Increased depreciation and amortization due to increased PP&E in-service

     (5 )       (13 ) 

Decreased income tax expense primarily due to increased tax deductions in excess of accounting depreciation and amortization related to PP&E and deferrals and decreased income before provision for income taxes. This was partially offset by the benefit of tax loss carryforwards recognized as a deferred income tax regulatory liability

     7        18  

Year-over-year decrease in net income from equity investment in NSPML primarily due to the Maritime Link holdback

     (2 )       (13 ) 

NSPML unrecoverable costs

     —          (7 ) 

Other

     (3 )       11  
  

 

 

    

 

 

 

Contribution to consolidated net income – 2022

   $ 46      $ 215  
  

 

 

    

 

 

 

NSPI

Operating Revenues – Regulated Electric

Annual electric revenues and sales volumes are summarized in the following tables by customer class:

 

    

Electric Revenues

(millions of dollars)

    

Electric Sales Volumes

(GWh)

 
     2022      2021      2022      2021  

Residential

   $ 834      $ 797        4,822        4,661  

Commercial

     427        407        3,006        2,902  

Industrial

     353        237        2,480        2,480  

Other

     28        27        148        153  
  

 

 

    

 

 

    

 

 

    

 

 

 

Total

   $ 1,642      $ 1,468        10,456        10,196  
  

 

 

    

 

 

    

 

 

    

 

 

 

 

  EMERA 2022 ANNUAL REPORT   31


Management’s Discussion & Analysis

 

Regulated Fuel for Generation and Purchased Power

Annual production volumes are summarized in the following table:

 

    

Production Volumes

(GWh)

 
     2022      2021  

Coal

     3,771        4,623  

Natural gas

     1,650        1,673  

Purchased power – other

     910        865  

Petcoke

     897        519  

Oil

     251        81  
  

 

 

    

 

 

 

Total non-renewables

     7,479        7,761  
  

 

 

    

 

 

 

Purchased power

     2,423        1,977  

Wind and hydro

     1,105        1,007  

Biomass

     127        160  
  

 

 

    

 

 

 

Total renewables

     3,655        3,144  
  

 

 

    

 

 

 

Total production volumes

     11,134        10,905  
  

 

 

    

 

 

 

NSPI’s fuel costs are affected by commodity prices and generation mix, which is largely dependent on economic dispatch of the generating fleet. NSPI brings the lowest cost options on stream first after renewable energy from IPPs, including Community Feed-in Tariff (“COMFIT”) participants, for which NSPI has power purchase agreements in place, and the NS Block of energy, including the Supplemental Energy Block. NSPI pays annual assessments approved by the UARB to NSPML for use of the Maritime Link, and therefore utilizes all transmitted NS Block and Supplemental Energy Block energy received which carries no additional fuel cost.

NSPI-owned hydro and wind have no fuel cost component. After hydro and wind, historically, petcoke and coal have the lowest per-unit fuel cost, followed by natural gas. Oil, biomass and purchased power have the next lowest fuel cost, depending on the relative pricing of each. Generation mix may also be affected by plant outages, availability of renewable generation, availability of energy from the NS Block, plant performance, and compliance with environmental standards including the Cap-and-Trade Program.

The generation mix has undergone significant transformation with the addition of non-dispatchable renewable energy sources such as wind, including from IPPs and COMFIT, which typically have a higher cost per MWh than NSPI-owned generation or other purchased power sources.

The provision for the Cap-and-Trade program was an $18 million recovery for the three months ended December 31, 2022 (2021 – $35 million expense) and a $134 million expense for the year ended December 31, 2022 (2021 – $38 million expense). For further information on this non-cash accrual, the estimated costs and the FAM regulatory balance, refer to note 7 in the consolidated financial statements.

Regulatory Environment – NSPI

NSPI is a public utility as defined in the Public Utilities Act and is subject to regulation under the Public Utilities Act by the UARB. The Public Utilities Act gives the UARB supervisory powers over NSPI’s operations and expenditures. Electricity rates for NSPI’s customers are subject to UARB approval. NSPI is not subject to a general annual rate review process, but rather participates in hearings held from time to time at NSPI’s or the UARB’s request. For further details on NSPI’s regulatory environment and recovery mechanisms, refer to note 7 in the consolidated financial statements.

 

32   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

GAS UTILITIES AND INFRASTRUCTURE

All amounts are reported in USD, unless otherwise stated.

 

For the   

Three months ended

December 31

           

Year ended

December 31

 

millions of USD (except as indicated)

   2022      2021      2022      2021  

Operating revenues – regulated gas (1)

   $ 372      $ 307      $ 1,296      $ 1,006  

Operating revenues – non-regulated

     2        2        12        12  

Total operating revenue

   $ 374      $ 309      $ 1,308      $ 1,018  

Regulated cost of natural gas

   $ 181      $ 139      $ 614      $ 375  

Contribution to consolidated net income

   $ 53      $ 44      $ 170      $ 157  

Contribution to consolidated net income – CAD

   $ 72      $ 55      $ 221      $ 198  

 

(1)

Operating revenues – regulated gas includes $13 million of finance income from Brunswick Pipeline (2021 – $12 million) for the three months ended December 31, 2022 and $47 million (2021 – $46 million) for the year ended December 31 2022; however, it is excluded from the gas revenues and cost of natural gas analysis below.

Gas Utilities and Infrastructure’s contribution to consolidated net income is summarized in the following table:

 

For the   

Three months ended

December 31

           

Year ended

December 31

 

millions of USD

   2022      2021      2022      2021  

PGS

   $ 17      $ 17      $ 82      $ 77  

NMGC

     22        15        35        33  

Other

     14        12        53        47  
  

 

 

    

 

 

    

 

 

    

 

 

 

Contribution to consolidated net income

   $ 53      $ 44      $ 170      $ 157  
  

 

 

    

 

 

    

 

 

    

 

 

 

The impact of the change in the FX rate increased CAD earnings for the three months and year ended December 31, 2022, by $4 million and $6 million, respectively.

Net Income

Highlights of the net income changes are summarized in the following table:

 

For the

millions of USD

   Three months ended
December 31
     Year ended
December 31
 

Contribution to consolidated net income – 2021

   $ 44      $ 157  

Increased gas revenues due to higher purchased gas adjustment clause revenues at NMGC and PGS as a result of higher gas prices, higher off-system sales, and customer growth at PGS

     55        280  

Increased asset optimization revenues at NMGC. In 2022, NMGC’s 30 per cent share of asset optimization revenues were well above the historical average, and may not reoccur in 2023

     10        10  

Increased cost of natural gas sold due to higher gas prices at NMGC and PGS, and higher off- system sales at PGS

     (42 )       (239 ) 

Increased OM&G primarily due to higher labour and benefits costs at NMGC and PGS, and higher contractor costs at PGS

     (3 )       (22 ) 

Increased depreciation and amortization due to asset growth at PGS and NMGC. Year-over-year, the increase was more than offset by the reversal of accumulated depreciation as a result of the rate case settlement at PGS

     (2 )       6  

Increased interest expense due to higher interest rates

     (4 )       (10 ) 

Increased income tax expense primarily due to increased income before provision for income taxes

     (2 )       (7 ) 

Other

     (3 )       (5 ) 
  

 

 

    

 

 

 

Contribution to consolidated net income – 2022

   $ 53      $ 170  
  

 

 

    

 

 

 

 

  EMERA 2022 ANNUAL REPORT   33


Management’s Discussion & Analysis

 

Operating Revenues – Regulated Gas

Annual gas revenues and sales volumes are summarized in the following tables by customer class:

 

    

Gas Revenues

(millions of USD)

           

Gas Volumes

(Therms)

 
     2022      2021      2022      2021  

Residential

   $ 614      $ 510        421        405  

Commercial

     354        301        836        799  

Industrial (1)

     64        53        1,429        1,434  

Other (2)

     217        96        227        137  
  

 

 

    

 

 

    

 

 

    

 

 

 

Total (3)

   $ 1,249      $ 960        2,913        2,775  
  

 

 

    

 

 

    

 

 

    

 

 

 

 

(1)

Industrial gas revenue includes sales to power generation customers.

(2)

Other gas revenue includes off-system sales to other utilities and various other items.

(3)

Total gas revenue excludes $47 million of finance income from Brunswick Pipeline (2021 – $46 million).

Regulated Cost of Natural Gas

PGS and NMGC purchase gas from various suppliers depending on the needs of their customers. In Florida, gas is delivered to the PGS distribution system through interstate pipelines on which PGS has firm transportation capacity for delivery by PGS to its customers. NMGC’s natural gas is transported on major interstate pipelines and NMGC’s intrastate transmission and distribution system for delivery to customers.

In Florida, natural gas service is unbundled for non-residential customers and residential customers who use more than 1,999 therms annually and elect the option. In New Mexico, NMGC is required, if requested, to provide transportation-only services for all customer classes. The commodity portion of bundled sales is included in operating revenues, at the cost of the gas on a pass-through basis, therefore no net earnings effect when a customer shifts to transportation-only sales.

Annual gas sales by type are summarized in the following table:

 

Gas Volumes by Type

(millions of Therms)

 
     2022      2021  

Transportation

     2,206        2,154  

System supply

     707        621  
  

 

 

    

 

 

 

Total

     2,913        2,775  
  

 

 

    

 

 

 

Regulatory Environments

PGS is regulated by the FPSC. The FPSC sets rates at a level that allows utilities such as PGS to collect total revenues or revenue requirements equal to their cost of providing service, plus an appropriate return on invested capital.

NMGC is subject to regulation by the NMPRC. The NMPRC sets rates at a level that allows NMGC to collect total revenues equal to its cost of providing service, plus an appropriate return on invested capital.

For further information on PGS and NMGC’s regulatory environment and recovery mechanisms, refer to note 7 in the consolidated financial statements.

 

34   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

OTHER ELECTRIC UTILITIES

All amounts are reported in USD, unless otherwise stated.

 

For the   

Three months ended

December 31

           

Year ended

December 31

 

millions of USD (except as indicated)

   2022      2021      2022      2021  

Operating revenues – regulated electric

   $ 98      $ 98      $ 398      $ 355  

Regulated fuel for generation and purchased power

   $ 54      $ 52      $ 223      $ 175  

Contribution to consolidated adjusted net income

   $ 7      $ 4      $ 23      $ 16  

Contribution to consolidated adjusted net income – CAD

   $ 8      $ 5      $ 29      $ 20  

GBPC Impairment charge

   $ 54      $ —        $ 54      $ —    

Equity securities MTM gain (loss)

   $ 1      $ 2      $ (4 )     $ 1  

Contribution to consolidated net income

   $ (46 )     $ 6      $ (35 )     $ 17  

Contribution to consolidated net income – CAD

   $ (62 )     $ 7      $ (48 )     $ 21  

Electric sales volumes (GWh)

     301        330        1,239        1,262  

Electric production volumes (GWh)

     336        357        1,340        1,359  

Average fuel cost in dollars per MWh

   $ 161      $ 146      $ 166      $ 129  

The impact of the change in the FX rate increased net loss by $3 million for the three months and year ended December 31, 2022 and had a minimal impact on adjusted net income for the same periods.

Other Electric Utilities’ contribution to consolidated adjusted net income is summarized in the following table:

 

For the   

Three months ended

December 31

           

Year ended

December 31

 

millions of USD

   2022      2021      2022      2021  

BLPC

   $ 5      $ 6      $ 11      $ 11  

GBPC

     1        —          10        8  

Other

     1        (2 )       2        (3 ) 
  

 

 

    

 

 

    

 

 

    

 

 

 

Contribution to consolidated adjusted net income

   $ 7      $ 4      $ 23      $ 16  
  

 

 

    

 

 

    

 

 

    

 

 

 

Net Income

Highlights of the net income changes are summarized in the following table:

 

For the

millions of USD

   Three months ended
December 31
     Year ended
December 31
 

Contribution to consolidated net income – 2021

   $ 6      $ 17  

Increased operating revenues – regulated electric year-over-year due to higher fuel revenue at BLPC as a result of higher fuel prices, partially offset by the sale of Domlec in Q1 2022

     —          43  

Increased fuel for generation and purchased power as a result of higher fuel prices at BLPC

     (2 )       (48 ) 

Decreased OM&G due to the sale of Domlec in Q1 2022 and lower generation costs at GBPC, partially offset by the recognition of Hurricane Dorian insurance proceeds at GBPC in 2021

     11        17  

Goodwill impairment charge at GBPC

     (54 )       (54 ) 

Decreased MTM gain on equity securities held in BLPC

     (1 )       (5 ) 

Other

     (6 )       (5 ) 
  

 

 

    

 

 

 

Contribution to consolidated net income – 2022

   $ (46 )     $ (35 ) 
  

 

 

    

 

 

 

 

  EMERA 2022 ANNUAL REPORT   35


Management’s Discussion & Analysis

 

Regulatory Environments

BLPC is regulated by the FTC, an independent regulator. Rates are set to recover prudently incurred costs of providing electricity service to customers plus an appropriate return on capital invested.

GBPC is regulated by the GBPA. Rates are set to recover prudently incurred costs of providing electricity service to customers plus an appropriate return on rate base.

For further details on BLPC and GBPC’s regulatory environments and recovery mechanisms, refer to note 7 in the consolidated financial statements.

OTHER

 

For the   

Three months ended

December 31

           

Year ended

December 31

 

millions of dollars

   2022      2021      2022      2021  

Marketing and trading margin (1) (2)

   $ 72      $ 39      $ 143      $ 102  

Other non-regulated operating revenue

     3        5        16        30  

Total operating revenues – non-regulated

   $ 75      $ 44      $ 159      $ 132  

Contribution to consolidated adjusted net income (loss)

   $ (1 )     $ (44 )     $ (218 )     $ (198 ) 

MTM gain (loss), after-tax (3)

     304        154        179        (214 ) 

Contribution to consolidated net income (loss)

   $ 303      $ 110      $ (39 )     $ (412 ) 

 

(1)

Marketing and trading margin represents EES’s purchases and sales of natural gas and electricity, pipeline and storage capacity costs and energy asset management services’ revenues.

(2)

Marketing and trading margin excludes a MTM gain, pre-tax of $430 million in Q4 2022 (2021 – $212 million gain) and a gain of $281 million for the year ended December 31, 2022 (2021 – $289 million loss).

(3)

Net of income tax expense of $124 million for the three months ended December 31, 2022 (2021 – $63 million expense) and $73 million expense for the year ended December 31, 2022 (2021 – $86 million recovery).

Other’s contribution to consolidated adjusted net income is summarized in the following table:

 

For the   

Three months ended

December 31

           

Year ended

December 31

 

millions of dollars

   2022      2021      2022      2021  

Emera Energy

   $ 41      $ 17      $ 70      $ 54  

Corporate – see breakdown of adjusted contribution below

     (37 )       (57 )       (267 )       (231 ) 

Emera Technologies

     (5 )       (4 )       (18 )       (17 ) 

Other

     —          —          (3 )       (4 ) 
  

 

 

    

 

 

    

 

 

    

 

 

 

Contribution to consolidated adjusted net income (loss)

   $ (1 )     $ (44 )     $ (218 )     $ (198 ) 
  

 

 

    

 

 

    

 

 

    

 

 

 

MTM Adjustments

Emera Energy’s “Marketing and trading margin”, “Non-regulated fuel for generation and purchased power”, “Income from equity investments” and “Income tax expense (recovery)” are affected by MTM adjustments. Management believes excluding the effect of MTM valuations, and changes thereto, from income until settlement better matches the financial effect of these contracts with the underlying cash flows. Variance explanations of the MTM changes for this quarter and for the year are explained in the chart below.

Emera Energy has a number of asset management agreements (“AMA”) with counterparties, including local gas distribution utilities, power utilities and natural gas producers in North America. The AMAs involve Emera Energy buying or selling gas for a specific term, and the corresponding release of the counterparties’ gas transportation/storage capacity to Emera Energy. MTM adjustments on these AMAs arise on the price differential between the point where gas is sourced and where it is delivered. At inception, the MTM adjustment is offset fully by the value of the corresponding gas transportation asset, which is amortized over the term of the AMA contract.

 

36   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

Subsequent changes in gas price differentials, to the extent they are not offset by the accounting amortization of the gas transportation asset, will result in MTM gains or losses recorded in income. MTM adjustments may be substantial during the term of the contract, especially in the winter months of a contract when delivered volumes and market pricing are usually at peak levels. As a contract is realized, and volumes reduce, MTM volatility is expected to decrease. Ultimately, the gas transportation asset and the MTM adjustment reduce to zero at the end of the contract term. As the business grows, and AMA volumes increase, MTM volatility resulting in gains and losses may also increase.

Emera Corporate has FX forwards to manage the cash flow risk of forecasted USD cash inflows. Fluctuations in the FX rate result in MTM gains or losses recorded in income.

Net Income

Highlights of the net income changes are summarized in the following table:

 

For the

millions of dollars

   Three months ended
December 31
     Year ended
December 31
 

Contribution to consolidated net income (loss) – 2021

   $ 110      $ (412 ) 

Increased marketing and trading margin due to weather driven market conditions that increased pricing and volatility, which created profitable opportunities for Emera Energy. Year-over-year increase also reflected sustained higher pricing and volatility

     33        41  

Increased OM&G, pre-tax, primarily due to the timing of long-term compensation and related hedges

     (19 )       (55 ) 

Increased interest expense, pre-tax, due to increased interest rates and increased total debt

     (17 )       (27 ) 

Increased FX loss, pre-tax, primarily due to realized gains in 2021 on FX hedges entered into to hedge USD denominated operating unit earnings exposure

     (9 )       (28 ) 

Increased income tax recovery primarily due to increased losses before provision for income taxes

     5        25  

Increased preferred stock dividends due to issuance of preferred shares in 2021

     (2 )       (13 ) 

TGH award, after tax and legal costs

     45        45  

Increased MTM gain, after-tax, due to change in existing positions and larger reversal of MTM losses in 2022, partially offset by higher amortization of gas transportation assets in 2022 at Emera Energy

     150        393  

Other

     7        (8 ) 
  

 

 

    

 

 

 

Contribution to consolidated net income (loss) – 2022

   $ 303      $ (39 ) 
  

 

 

    

 

 

 

Emera Energy

EES derives revenue and earnings from the wholesale marketing and trading of natural gas and electricity within the Company’s risk tolerances, including those related to value-at-risk (“VaR”) and credit exposure. EES purchases and sells physical natural gas and electricity, the related transportation and transmission capacity rights, and provides energy asset management services. The primary market area for the natural gas and power marketing and trading business is northeastern North America, including the Marcellus and Utica shale supply areas. EES also participates in the Florida, United States Gulf Coast and Midwest/Central Canadian natural gas markets. Its counterparties include electric and gas utilities, natural gas producers, electricity generators and other marketing and trading entities. EES operates in a competitive environment, and the business relies on knowledge of the region’s energy markets, understanding of pipeline and transmission infrastructure, a network of counterparty relationships and a focus on customer service. EES manages its commodity risk by limiting open positions, utilizing financial products to hedge purchases and sales, and investing in transportation capacity rights to enable movement across its portfolio.

 

  EMERA 2022 ANNUAL REPORT   37


Management’s Discussion & Analysis

 

Corporate

Corporate’s adjusted loss is summarized in the following table:

 

For the   

Three months ended

December 31

           

Year ended

December 31

 

millions of dollars

   2022      2021      2022      2021  

Operating expenses (1)

   $ 20      $ 1      $ 83      $ 28  

Interest expense

     83        65        291        264  

Income tax recovery

     (35 )       (18 )       (109 )       (75 ) 

Preferred dividends

     16        14        63        50  

TGH award, after tax and legal costs

     (45 )       —          (45 )       —    

Other (2) (3)

     (2 )       (5 )       (16 )       (36 ) 
  

 

 

    

 

 

    

 

 

    

 

 

 

Corporate adjusted net loss (4)

   $ (37 )     $ (57 )     $ (267 )     $ (231 ) 
  

 

 

    

 

 

    

 

 

    

 

 

 

 

(1)

Operating expenses include OM&G and depreciation. In Q4 2021, OM&G and depreciation were offset by a decrease in long-term incentive compensation. The value of long-term incentive compensation and related hedges are impacted by changes in Emera’s period end share price.

(2)

Other includes realized FX gains and losses on FX hedges entered into to hedge USD denominated operating unit earnings exposure.

(3)

Includes a realized, pre-tax net loss of $5 million (2021 – $5 million gain) quarter-to-date and a $6 million loss for the year ended December 31, 2022 (2021 – $18 million gain) on FX hedges, as discussed above.

(4)

Excludes a MTM gain, after-tax of $9 million for the three months ended December 31, 2022 (2021 – $3 million loss) and a MTM loss, after-tax of $12 million for the year ended December 31, 2023 (2021 – $14 million loss).

Liquidity and Capital Resources

The Company generates internally sourced cash from its various regulated and non-regulated energy investments. Utility customer bases are diversified by both sales volumes and revenues among customer classes. Emera’s non-regulated businesses provide diverse revenue streams and counterparties to the business. Circumstances that could affect the Company’s ability to generate cash include changes to global macro-economic conditions, downturns in markets served by Emera, impact of fuel commodity price changes on collateral requirements and timely recoveries of fuel costs from customers, the loss of one or more large customers, regulatory decisions affecting customer rates and the recovery of regulatory assets, and changes in environmental legislation. Emera’s subsidiaries are generally in a financial position to contribute cash dividends to Emera provided they do not breach their debt covenants, where applicable, after giving effect to the dividend payment, and maintain their credit metrics.

Emera’s future liquidity and capital needs will be predominately for working capital requirements, ongoing rate base investment, business acquisitions, greenfield development, dividends and debt servicing. Emera has an $8 – 9 billion capital investment plan over the 2023-to-2025 period (including a $240 million equity investment in the LIL in 2023), mainly focused in Florida. This plan includes significant rate base investments across the portfolio in renewable and cleaner generation, infrastructure modernization and customer-focused technologies. Capital investments at the regulated utilities are subject to regulatory approval.

Emera plans to use cash from operations and debt raised at the utilities to support normal operations, repayment of existing debt, and capital requirements. Debt raised at certain of the Company’s utilities is subject to applicable regulatory approvals. Equity requirements in support of the Company’s capital investment plan are expected to be funded through the issuance of preferred equity and the issuance of common equity through Emera’s DRIP and ATM program.

Emera has credit facilities with varying maturities that cumulatively provide $4.7 billion of credit, with approximately $1.1 billion undrawn and available at December 31, 2022. The Company was holding a cash balance of $332 million at December 31, 2022. For further discussion, refer to the “Debt Management” section below. For additional information regarding the credit facilities, refer to notes 23 and 25 in the consolidated financial statements.

 

38   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

CONSOLIDATED CASH FLOW HIGHLIGHTS

Significant changes in the Consolidated Statements of Cash Flows between the years ended December 31, 2022 and 2021 include:

 

millions of dollars

   2022      2021      $ Change  

Cash, cash equivalents and restricted cash, beginning of period

   $ 417      $ 254      $ 163  

Provided by (used in):

        

Operating cash flow before changes in working capital

     1,147        1,337        (190 ) 

Change in working capital

     (234 )       (152 )       (82 ) 
  

 

 

    

 

 

    

 

 

 

Operating activities

   $ 913      $ 1,185      $ (272 ) 

Investing activities

     (2,569 )       (2,332 )       (237 ) 

Financing activities

     1,555        1,311        244  

Effect of exchange rate changes on cash, cash equivalents and restricted cash

     16        (1 )       17  
  

 

 

    

 

 

    

 

 

 

Cash, cash equivalents, and restricted cash, end of period

   $ 332      $ 417      $ (85 ) 
  

 

 

    

 

 

    

 

 

 

Cash Flow from Operating Activities

Net cash provided by operating activities decreased $272 million to $913 million for the year ended December 31, 2022, compared to $1,185 million in 2021.

Cash from operations before changes in working capital decreased $190 million for the year ended December 31, 2022. This decrease was due to under-recovery of clause-related costs primarily due to higher natural gas prices at Tampa Electric, unfavourable changes in Tampa Electric’s storm reserve balance as a result of Hurricane Ian, increased fuel for generation and purchased power at NSPI, and decreased long-term payables due to the Nova Scotia Cap-and-Trade accrued emissions compliance charges being reclassified to other current liabilities as the liability is anticipated to be settled in 2023. This was partially offset by the 2021 deferral of gas costs at NMGC resulting from the extreme cold weather event, increased revenues at Tampa Electric and NSPI, favourable changes in regulatory liabilities due to the NMGC gas hedge settlement, TGH award, and increased marketing and trading margin at Emera Energy.

Changes in working capital decreased operating cash flows by $82 million for the year ended December 31, 2022. This decrease was due to unfavourable changes in accounts receivable at NMGC due to the gas hedge settlement, unfavourable changes in accounts receivable at NSPI, unfavourable changes in cash collateral positions on derivative instruments at NSPI, and the required prepayment of income taxes and related interest at NSPI. This was partially offset by the Nova Scotia Cap-and-Trade accrued emissions compliance charges, favourable changes in cash collateral positions at Emera Energy, and favourable changes in accounts payable at Tampa Electric and NMGC.

Cash Flow Used in Investing Activities

Net cash used in investing activities increased $237 million to $2,569 million for the year ended December 31, 2022, compared to $2,332 million in 2021. The increase was due to higher capital investment in 2022.

Capital expenditures for the year ended December 31, 2022, including AFUDC, were $2,646 million compared to $2,420 million in 2021. Details of 2022 capital spending by segment are shown below:

 

  •  

$1,481 million – Florida Electric Utility (2021 – $1,408 million);

 

  •  

$518 million – Canadian Electric Utilities (2021 – $374 million);

 

  •  

$578 million – Gas Utilities and Infrastructure (2021 – $522 million);

 

  •  

$63 million – Other Electric Utilities (2021 – $111 million); and

 

  •  

$6 million – Other (2021 – $5 million).

 

  EMERA 2022 ANNUAL REPORT   39


Management’s Discussion & Analysis

 

Cash Flow from Financing Activities

Net cash provided by financing activities increased $244 million to $1,555 million for the year ended December 31, 2022, compared to $1,311 million in 2021. This increase was due to higher proceeds of short-term debt at Tampa Electric, proceeds from committed credit facilities at NSPI, and term loan issuance at Emera in 2022. These were partially offset by the issuance of preferred shares in 2021, lower proceeds of long-term debt at Tampa Electric, and net proceeds of long-term debt at NMGC in 2021.

WORKING CAPITAL

As at December 31, 2022, Emera’s cash and cash equivalents were $310 million (2021 – $394 million) and Emera’s investment in non-cash working capital was $1,173 million (2021 – $491 million). Of the cash and cash equivalents held at December 31, 2022, $250 million was held by Emera’s foreign subsidiaries (2021 – $194 million). A portion of these funds are invested in countries that have certain exchange controls, approvals, and processes for repatriation. Such funds are available to fund local operating and capital requirements unless repatriated.

CONTRACTUAL OBLIGATIONS

As at December 31, 2022, contractual commitments for each of the next five years and in aggregate thereafter consisted of the following:

 

millions of dollars

   2023      2024      2025      2026      2027      Thereafter      Total  

Long-term debt principal

   $ 574      $ 1,613      $ 262      $ 3,110      $ 946      $ 9,937      $ 16,442  

Interest payment obligations (1)

     720        699        653        566        472        6,995        10,105  

Transportation (2)

     693        516        423        383        367        2,817        5,199  

Purchased power (3)

     269        243        237        228        243        2,145        3,365  

Fuel, gas supply and storage

     1,161        282        138        40        5        1        1,627  

Capital projects

     264        89        4        1        —          —          358  

Asset retirement obligations

     15        2        2        1        1        415        436  

Pension and post-retirement obligations (4)

     38        31        31        82        59        178        419  

Equity investment commitments (5)

     240        —          —          —          —          —          240  

Other

     154        142        132        49        42        189        708  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 
   $ 4,128      $ 3,617      $ 1,882      $ 4,460      $ 2,135      $ 22,677      $ 38,899  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

 

(1)

Future interest payments are calculated based on the assumption that all debt is outstanding until maturity. For debt instruments with variable rates, interest is calculated for all future periods using the rates in effect at December 31, 2022, including any expected required payment under associated swap agreements.

(2)

Purchasing commitments for transportation of fuel and transportation capacity on various pipelines. Includes a commitment of $144 million related to a gas transportation contract between PGS and SeaCoast through 2040.

(3)

Annual requirement to purchase electricity production from IPPs or other utilities over varying contract lengths.

(4)

The estimated contractual obligation is calculated as the current legislatively required contributions to the registered funded pension plans (excluding the possibility of wind-up), plus the estimated costs of further benefit accruals contracted under NSPI’s Collective Bargaining Agreement and estimated benefit payments related to other unfunded benefit plans.

(5)

Emera has a commitment to make a final equity contribution to the LIL upon its commissioning. Once commissioned, the commercial agreements between Emera and Nalcor require true ups to finalize the respective investment obligations of the parties in relation to the Maritime Link and LIL.

NSPI has a contractual obligation to pay NSPML for use of the Maritime Link over approximately 38 years from its January 15, 2018 in-service date. In February 2022, the UARB issued its decision and Board Order approving NSPML’s requested rate base of approximately $1.8 billion. In December 2022, the UARB approved the collection of $164 million from NSPI for the recovery of Maritime Link costs in 2023. The timing and amounts payable to NSPML for the remainder of the 38-year commitment period are subject to UARB approval.

Emera has committed to obtain certain transmission rights for Nalcor, if requested, to enable it to transmit energy which is not otherwise used in Newfoundland and Labrador or Nova Scotia. Nalcor has the right to transmit this energy from Nova Scotia to New England energy markets effective August 15, 2021, the date the NS Block delivery obligation commenced, and continuing for 50 years. As transmission rights are contracted, the obligations are included within “Other” in the above table.

 

40   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

FORECASTED GROSS CONSOLIDATED CAPITAL EXPENDITURES

The 2023 forecasted gross consolidated capital expenditures are as follows:

 

millions of dollars

   Florida
Electric Utility
     Canadian
Electric
Utilities
     Gas
Utilities and
Infrastructure
     Other Electric
Utilities
     Other      Total  

Generation

   $ 276      $ 120      $ —        $ 36      $ —        $ 432  

New renewable generation

     402        —          —          4        —          406  

Transmission

     100        74        —          —          —          174  

Distribution

     479        121        —          34        —          634  

Gas transmission and distribution

     —          —          639        —          —          639  

Facilities, equipment, vehicles, and other

     516        60        —          17        11        604  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 
   $ 1,773      $ 375      $ 639      $ 91      $ 11      $ 2,889  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

DEBT MANAGEMENT

In addition to funds generated from operations, Emera and its subsidiaries have, in aggregate, access to committed syndicated revolving and non-revolving bank lines of credit in either CAD or USD per the table below.

 

millions of dollars

   Maturity      Credit
Facilities
     Utilized      Undrawn
and
Available
 

Emera – Unsecured committed revolving credit facility

     June 2027      $ 900      $ 403      $ 497  

TEC (in USD) – Unsecured committed revolving credit facility (1)

     December 2026        800        620        180  

NSPI – Unsecured committed revolving credit facility

     December 2027        800        497        303  

Emera – Unsecured non-revolving facility

     December 2023        400        400        —    

Emera – Unsecured non-revolving facility

     August 2023        400        400        —    

TEC (in USD) – Unsecured non-revolving facility (2)

     December 2023        400        400        —    

TECO Finance (in USD) – Unsecured committed revolving credit facility

     December 2026        400        355        45  

NSPI – Unsecured non-revolving facility

     July 2024        400        400        —    

NMGC (in USD) – Unsecured revolving credit facility

     December 2026        125        45        80  

NMGC (in USD) – Unsecured non-revolving facility

     March 2024        80        80        —    

Other (in USD) – Unsecured committed revolving credit facilities

     Various        21        7        14  

 

(1)

This facility is available for use by Tampa Electric and PGS. At December 31, 2022, $554 million USD was used by Tampa Electric and $66 million USD was used by PGS.

(2)

This facility is available for use by Tampa Electric and PGS. At December 31, 2022, $300 million USD was used by Tampa Electric and $100 million USD was used by PGS.

Emera and its subsidiaries have certain financial and other covenants associated with their debt and credit facilities. Covenants are tested regularly, and the Company is in compliance with covenant requirements as at December 31, 2022. Emera’s significant covenant is listed below:

 

    

Financial Covenant

  

Requirement

   As at
December 31, 2022
 

Emera

        

Syndicated credit facilities

   Debt to capital ratio    Less than or equal to 0.70 to 1      0.57 : 1  

Recent significant financing activity for Emera and its subsidiaries are discussed below by segment:

Florida Electric Utilities

On December 13, 2022, TEC amended its 364-day non-revolving credit facility to extend the maturity date from December 16, 2022 to December 13, 2023 and reduced the facility amount from $500 million USD to $400 million USD. There were no other significant changes in commercial terms from the prior agreement.

 

  EMERA 2022 ANNUAL REPORT   41


Management’s Discussion & Analysis

 

On September 15, 2022, TEC repaid a $250 million USD note upon maturity. The note was repaid using existing credit facilities.

On July 12, 2022, TEC completed an issuance of $600 million USD senior notes. The issuance included $300 million USD senior notes that bear an interest rate of 3.875 per cent with a maturity date of July 12, 2024, and $300 million USD senior notes that bear an interest rate of 5 per cent with a maturity date of July 15, 2052. Proceeds from the issuance were used to repay TEC’s $470 million USD commercial paper, due in 2022, and for general corporate purposes.

Canadian Electric Utilities

On December 16, 2022, NSPI amended its revolving operating credit facility to extend the maturity date from December 16, 2026 to December 16, 2027 and increase the amount of the facility from $600 million to $800 million. There were no other significant changes in commercial terms from the prior agreement.

On July 15, 2022, NSPI entered into a $400 million non-revolving term credit facility which matures on July 15, 2024. The credit facility contains customary representation and warranties, events of default and financial and other covenants, and bears interest at Bankers’ Acceptances or prime rate advances, plus a margin. Proceeds from this facility were used for general corporate purposes.

Gas Utilities and Infrastructure

On September 23, 2022, NMGC amended its $80 million USD, unsecured, non-revolving term credit facility to extend the maturity from September 23, 2022, to March 22, 2024. There were no other changes in commercial terms from the prior agreement.

On June 30, 2022, Brunswick Pipeline amended its non-revolving credit agreement to extend the maturity from June 30, 2025 to June 30, 2026. There were no other changes in commercial terms from the prior agreement.

Other Electric Utilities

On March 25, 2022, ECI amended its amortizing floating rate notes to extend the maturity from March 25, 2022 to March 25, 2027. There were no other changes in commercial terms from the prior agreement.

Other

On December 16, 2022, Emera amended its $900 million revolving operating credit facility to extend the maturity date from June 30, 2026 to June 30, 2027. There were no other significant changes in commercial terms from the prior agreement.

On December 16, 2022, Emera amended its $400 million non-revolving term credit facility to extend the maturity from December 16, 2022 to December 16, 2023. There were no other significant changes in commercial terms from the prior agreement.

On August 2, 2022, Emera entered into a $400 million non-revolving term facility which matures on August 2, 2023. The credit agreement contains customary representation and warranties, events of default and financial and other covenants and bears interest at Bankers’ Acceptances or prime rate advances, plus a margin. Proceeds from this facility were used for general corporate purposes.

 

42   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

CREDIT RATINGS

Emera and its subsidiaries have been assigned the following senior unsecured debt ratings:

 

    

Fitch (1)

  

S&P (2) (3)

  

Moody’s (4) (5)

  

DBRS (6)

Emera Inc.

   BBB (Negative)    BBB- (Negative)    Baa3 (Negative)    N/A

TECO Energy/TECO Finance

   N/A    N/A    N/A    N/A

TEC

   A(Negative)    BBB+ (Negative)    A3 (Negative)    N/A

NMGC

   BBB+ (Negative)    N/A    N/A    N/A

NSPI

   N/A    BBB- (Negative)    N/A    BBB (high)(stable)

 

(1)

On November 21, 2022, Fitch Ratings (“Fitch”) affirmed its BBB issuer rating for Emera Inc. Fitch also affirmed the A- issuer and A unsecured debt ratings for TEC and BBB+ for NMGC. Emera and subsidiaries’ outlook was changed to negative from stable.

(2)

On November 21, 2022, S&P Global Ratings (“S&P”) affirmed its BBB issuer rating for Emera Inc. and TECO Energy, while affirming the BBB+ issuer credit ratings for TEC. S&P downgraded NSPI’s issue-level and senior unsecured debt ratings to BBB-. Emera and subsidiaries’ outlook remained at negative.

(3)

On October 24, 2022, S&P affirmed its BBB issuer rating for Emera Inc. S&P also affirmed ratings on NSPI, TECO Energy, and TEC affirming the BBB+ issuer credit ratings for NSPI and TEC. Emera and subsidiaries’ outlook was changed to negative from stable.

(4)

On November 2, 2022, Moody’s Investor Services (“Moody’s”) affirmed its Baa3 issuer rating for Emera Inc. Moody’s also affirmed ratings on TECO Finance and TEC, affirming the TECO Finance Baa1 issuer rating and A3 issuer rating for TEC. Emera and subsidiaries’ outlook was changed to negative from stable.

(5)

On June 2, 2022, Moody’s affirmed its Baa1 issuer rating for TECO Finance. Moody’s also affirmed TEC’s A3 issuer rating and changed the outlook to stable from positive.

(6)

On December 20, 2022, DBRS (“Dominion Bond Rating Service”) downgraded its issuer credit and senior unsecured rating for NSPI to BBB (high). NSPI’s outlook remained unchanged at stable.

The downgrades from both S&P and DBRS of NSPI were attributed to their view of the enactment of Bill 212, “Public Utilities Act (amended)”, as a political intervention in the regulatory process that resulted in an increase in political risk and a reduction in the stability and predictability of NSPI’s regulatory environment.

GUARANTEED DEBT

As of December 31, 2022, the Company had $2.75 billion USD senior unsecured notes (“U.S. Notes”) outstanding.

The U.S. Notes are fully and unconditionally guaranteed, on a joint and several basis, by Emera and Emera US Holdings Inc. (in such capacity, the “Guarantor Subsidiaries”). Emera owns, directly or indirectly, all of the limited and general partnership interests in Emera US Finance LP. Other subsidiaries of the Company do not guarantee the U.S. Notes (such subsidiaries are referred to as the “Non-Guarantor Subsidiaries”) however, Emera has unrestricted access to the assets of consolidated entities.

In compliance with Rule 13-01 of Regulation S-X, the Company is including summarized financial information for Emera, Emera US Holdings Inc., and Emera US Finance LP (together, the “Obligor Group”), on a combined basis after transactions and balances between the combined entities have been eliminated. Investments in and equity earnings of the Non-Guarantor Subsidiaries have been excluded from the summarized financial information.

The Obligor Group was not determined using geographic, service line or other similar criteria and, as a result the summarized financial information includes portions of Emera’s domestic and international operations. Accordingly, this basis of presentation is not intended to present Emera’s financial condition or results of operations for any purpose other than to comply with the specific requirements for guarantor reporting.

 

  EMERA 2022 ANNUAL REPORT   43


Management’s Discussion & Analysis

 

Summarized Statement of Income (loss)

The Company recognized income related to guaranteed debt under the following categories:

 

For the   

Year ended December 31

 

millions of dollars

   2022      2021  

Loss from operations

   $ (73 )     $ (21 ) 

Net losses (1)

   $ (131 )     $ (86 ) 

 

(1)

Includes $262 million in interest and dividend income, net, from non-guarantor subsidiaries.

Summarized Balance Sheet

The Company has the following categories on the balance sheet related to guaranteed debt:

 

As at           December 31  

millions of dollars

   2022      2021  

Current assets (1)

   $ 172      $ 329  

Goodwill

     6,012        5,628  

Other assets (2)

     6,402        6,027  
  

 

 

    

 

 

 

Total assets (3)

   $ 12,586      $ 11,984  
  

 

 

    

 

 

 

Current liabilities (4)

   $ 1,903      $ 888  

Long-term liabilities (5)

     6,431        6,403  
  

 

 

    

 

 

 

Total liabilities

   $ 8,334      $ 7,291  
  

 

 

    

 

 

 

 

(1)

Includes $144 million (2021 – $140 million) in amounts due from non-guarantor subsidiaries.

(2)

Includes $6,058 million (2021 – $5,749 million) in amounts due from non-guarantor subsidiaries.

(3)

Excludes investments in non-guarantor subsidiaries. Consolidated Emera total assets are $39,742 million (2021 – $34,244 million).

(4)

Includes $392 million (2021 – $346 million) due to non-guarantor subsidiaries.

(5)

Includes $769 million (2021 – $776 million) due to non-guarantor subsidiaries.

OUTSTANDING STOCK DATA

Common Stock

 

Issued and outstanding:

   millions of
shares
     millions of
dollars
 

Balance, December 31, 2021

     261.07      $ 7,242  

Issuance of common stock under ATM program (1)

     4.07        248  

Issued under the DRIP, net of discounts

     4.21        238  

Senior management stock options exercised and Employee Share Purchase Plan

     0.60        34  
  

 

 

    

 

 

 

Balance, December 31, 2022

     269.95      $ 7,762  
  

 

 

    

 

 

 

 

(1)

In Q4 2022, 278,545 common shares were issued under Emera’s ATM program at an average price of $54.06 per share for gross proceeds of $15 million ($15 million net of after-tax issuance costs). For the year ended December 31, 2022, 4,072,469 common shares were issued under Emera’s ATM program at an average price of $61.31 per share for gross proceeds of $250 million ($248 million net of after-tax issuance costs). As at December 31, 2022, an aggregate gross sales limit of $207 million remained available for issuance under the ATM program.

As at February 16, 2023, the amount of issued and outstanding common shares was 271.4 million.

If all outstanding stock options were converted as at February 16, 2023, an additional 2.9 million common shares would be issued and outstanding.

Preferred Stock

As at February 16, 2023, Emera had the following preferred shares issued and outstanding: Series A – 4.9 million; Series B – 1.1    million; Series C – 10.0 million; Series E – 5.0 million; Series F – 8.0 million; Series H – 12.0 million; Series J – 8.0 million, and Series L – 9.0 million. Emera’s preferred shares do not have voting rights unless the Company fails to pay, in aggregate, eight quarterly dividends.

 

44   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

Pension Funding

For funding purposes, Emera determines required contributions to its largest defined benefit pension plans based on smoothed asset values. This reduces volatility in the cash funding requirement as the impact of investment gains and losses are recognized over a three-year period. The cash required in 2023 for defined benefit pension plans is expected to be $44 million (2022 – $45 million). All pension plan contributions are tax deductible and will be funded with cash from operations.

Emera’s defined benefit pension plans employ a long-term strategic approach with respect to asset allocation, real return and risk. The underlying objective is to earn an appropriate return, given the Company’s goal of preserving capital with an acceptable level of risk for the pension fund investments.

To achieve the overall long-term asset allocation, pension assets are managed by external investment managers per the pension plan’s investment policy and governance framework. The asset allocation includes investments in the assets of Canadian and global equities, domestic and global bonds and short-term investments. Emera reviews investment manager performance on a regular basis and adjusts the plans’ asset mixes as needed in accordance with the pension plans’ investment policy.

Emera’s projected contributions to defined contribution pension plans are $44 million for 2023 (2022 – $41 million).

DEFINED BENEFIT PENSION PLAN SUMMARY

 

in millions of dollars

                           

Plans by region

   TECO Energy      NSPI      Caribbean      Total  

Assets as at December 31, 2022

   $ 880      $ 1,273      $ 10      $ 2,163  

Accounting obligation at December 31, 2022

   $ 902      $ 1,240      $ 16      $ 2,158  

Accounting expense during fiscal 2022

   $ 10      $ (3 )     $ 1      $ 8  

Off-Balance Sheet Arrangements

DEFEASANCE

Upon privatization in 1992, NSPI became responsible for managing a portfolio of defeasance securities that provide principal and interest streams to match the related defeased debt, which at December 31, 2022 totalled $200 million (2021 – $200 million). The securities are held in trust for an affiliate of the Province of Nova Scotia. Approximately 66 per cent of the defeasance portfolio consists of investments in the related debt, eliminating all risk associated with this portion of the portfolio; the remaining defeasance portfolio has a market value higher than the related debt, reducing the future risk of this portion of the portfolio.

GUARANTEES AND LETTERS OF CREDIT

Emera has guarantees and letters of credit on behalf of third parties outstanding. The following significant guarantees and letters of credit are not included within the Consolidated Balance Sheets as at December 31, 2022:

TECO Energy has issued a guarantee in connection with SeaCoast’s performance of obligations under a gas transportation precedent agreement. The guarantee is for a maximum potential amount of $45 million USD if SeaCoast fails to pay or perform under the contract. The guarantee expires five years after the gas transportation precedent agreement termination date, which was terminated on January 1, 2022. In the event that TECO Energy’s and Emera’s long-term senior unsecured credit ratings are downgraded below investment grade by Moody’s or S&P, TECO Energy would be required to provide its counterparty a letter of credit or cash deposit of $27 million USD.

TECO Energy issued a guarantee in connection with SeaCoast’s performance obligations under a firm service agreement, which expires on December 31, 2055, subject to two extension terms at the option of the counterparty with a final expiration date of December 31, 2071. The guarantee is for a maximum potential amount of $13 million USD if SeaCoast fails to pay or perform under the firm service agreement. In the event that TECO Energy’s long-term senior unsecured credit ratings are downgraded below investment grade by Moody’s or S&P, TECO Energy would need to provide either a substitute guarantee from an affiliate with an investment grade credit rating or a letter of credit or cash deposit of $13 million USD.

 

  EMERA 2022 ANNUAL REPORT   45


Management’s Discussion & Analysis

 

Emera Inc. has issued a guarantee of up to $35 million USD relating to outstanding notes of GBPC. The guarantee for the notes will expire in May 2023.

Emera Inc. has issued a guarantee of $66 million USD relating to outstanding notes of ECI. This guarantee will automatically terminate on the date upon which the obligations have been repaid in full.

NSPI has issued guarantees on behalf of its subsidiary, NS Power Energy Marketing Incorporated (“NSPEMI”), in the amount of $119 million USD (2021 – $118 million USD) with terms of varying lengths.

The Company has standby letters of credit and surety bonds in the amount of $145 million USD (December 31, 2021 – $148 million USD) to third parties that have extended credit to Emera and its subsidiaries. These letters of credit and surety bonds typically have a one-year term and are renewed annually as required.

Emera Inc., on behalf of NSPI, has a standby letter of credit to secure obligations under a supplementary retirement plan. The expiry date of this letter of credit was extended to June 2023. The amount committed as at December 31, 2022 was $63 million (December 31, 2021 – $64 million).

Dividend Payout Ratio

Emera has provided annual dividend growth guidance of four to five per cent through 2025. The Company targets a long-term dividend payout ratio of adjusted net income of 70 to 75 per cent, and while the payout ratio is likely to exceed that target through and beyond the forecast period, it is expected to return to that range over time. Emera’s common share dividends paid in 2022 were $2.6775 ($0.6625 in Q1, Q2, and Q3 and $0.6900 in Q4) per common share and $2.5750 ($0.6375 in Q1, Q2, and Q3 and $0.6625 in Q4) per common share for 2021, representing a dividend payout ratio of 75 per cent in 2022 (2021 – 129 per cent) and a dividend payout ratio of adjusted net income of 83 per cent in 2022 (2021 – 91 per cent).

On September 22, 2022, the Emera Board of Directors approved an increase in the annual common share dividend rate to $2.76 from $2.65. The first quarterly dividend payment at the increased rate was paid on November 15, 2022.

Transactions with Related Parties

In the ordinary course of business, Emera provides energy and other services and enters into transactions with its subsidiaries, associates and other related companies on terms similar to those offered to non-related parties. Intercompany balances and intercompany transactions have been eliminated on consolidation, except for the net profit on certain transactions between non- regulated and regulated entities in accordance with accounting standards for rate-regulated entities. All material amounts are under normal interest and credit terms.

Significant transactions between Emera and its associated companies are as follows:

 

  •  

Transactions between NSPI and NSPML related to the Maritime Link assessment are reported in the Consolidated Statements of Income. NSPI’s expense is reported in Regulated fuel for generation and purchased power, totalling $157 million for the year ended December 31, 2022 (2021 – $149 million). NSPML is accounted for as an equity investment and therefore, the corresponding earnings related to this revenue are reflected in Income from equity investments. For further details, refer to the “Business Overview and Outlook – Canadian Electric Utilities – ENL” and “Contractual Obligations” sections.

 

  •  

Natural gas transportation capacity purchases from M&NP are reported in the Consolidated Statements of Income. Purchases from M&NP reported net in Operating revenues, Non-regulated, totalled $9 million for the year ended December 31, 2022 (2021 – $19 million).

There were no significant receivables or payables between Emera and its associated companies reported on Emera’s Consolidated Balance Sheets as at December 31, 2022 and at December 31, 2021.

 

46   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

Enterprise Risk and Risk Management

Emera has an enterprise-wide risk management process, overseen by its Enterprise Risk Management Committee (“ERMC”) and monitored by the Board of Directors, to ensure an effective, consistent and coherent approach to risk management. Certain risk management activities for Emera are overseen by the ERMC to ensure such risks are appropriately identified, assessed, monitored and subject to appropriate controls.

The Board of Directors established a Risk and Sustainability Committee (“RSC”) in September 2021. The mandate of the RSC is to assist the Board in carrying out its risk and sustainability oversight responsibilities. The RSC’s mandate includes oversight of the Company’s Enterprise Risk Management framework, including the identification, assessment, monitoring and management of enterprise risks. It also includes oversight of the Company’s approach to sustainability and its performance relative to its sustainability objectives.

The Company’s financial risk management activities are focused on those areas that most significantly impact profitability, quality and consistency of income, and cash flow. Emera’s risk management focus extends to key operational risks including safety and environment, which represent core values of Emera. In this section, Emera describes the principal risks that management believes could materially affect its business, revenues, operating income, net income, net assets, liquidity or capital resources. The nature of risk is such that no list is comprehensive, and other risks may arise or risks not currently considered material may become material in the future.

REGULATORY AND POLITICAL RISK

The Company’s rate-regulated subsidiaries and certain investments subject to significant influence are subject to risk of the recovery of costs and investments. Regulatory and political risk can include changes in regulatory frameworks, shifts in government policy, legislative changes, and regulatory decisions.

As cost-of-service utilities with an obligation to serve customers, Emera’s utilities operate under formal regulatory frameworks, and must obtain regulatory approval to change or add rates and/or riders. Emera also holds investments in entities in which it has significant influence, and which are subject to regulatory and political risk including NSPML, LIL, and M&NP. As a regulated Group II pipeline, the tolls of Brunswick Pipeline are regulated by the CER on a complaint basis, as opposed to the regulatory approval process described above. In the absence of a complaint, the CER does not normally undertake a detailed examination of Brunswick Pipeline’s tolls, which are subject to a firm service agreement, expiring in 2034, with Repsol Energy North America Canada Partnership. The agreement provides for a predetermined toll increase in the fifth and fifteenth year of the contract.

Regulators administer legislation covering material aspects of the utilities’ businesses, including customer rates and/or riders, the underlying allowed ROEs, deemed capital structures, capital investment, the terms and conditions for the provision of service, performance standards, and affiliate transactions. Costs and investments can be recovered upon approval by the respective regulator as an adjustment to rates and/or riders, which normally require a public hearing process or may be mandated by other governmental bodies. During public hearing processes, consultants and customer representatives scrutinize the costs, actions and plans of these rate-regulated companies, and their respective regulators determine whether to allow recovery and to adjust rates based upon the evidence and any contrary evidence from other parties. In some circumstances, other government bodies may influence the setting of rates. Regulatory decisions, legislative changes, and prolonged delays in the recovery of costs or regulatory assets could result in decreased rate affordability for customers and could materially affect Emera and its utilities.

Emera’s utilities generally manage this risk through transparent regulatory disclosure, ongoing stakeholder and government consultation, and multi-party engagement on aspects such as utility operations, regulatory audits, rate filings and capital plans. The subsidiaries employ a collaborative regulatory approach through technical conferences and, where appropriate, negotiated settlements.

Changes in government and shifts in government policy and legislation can impact the commercial and regulatory frameworks under which Emera and its subsidiaries operate. This includes initiatives regarding deregulation or restructuring of the energy industry. Deregulation or restructuring of the energy industry may result in increased competition and unrecovered costs that could adversely affect operations, net income and cash flows. State and local policies in some United States jurisdictions have sought to prevent or limit the ability of utilities to provide customers the choice to use natural gas while in other jurisdictions policies have been adopted to prevent limitations on the use of natural gas. Changes in applicable state or local laws and regulations, including electrification legislation, could adversely impact PGS and NMGC.

 

  EMERA 2022 ANNUAL REPORT   47


Management’s Discussion & Analysis

 

Emera cannot predict future legislative, policy, or regulatory changes, whether caused by economic, political or other factors, or its ability to respond in an effective and timely manner or the resulting compliance costs. Government interference in the regulatory process can undermine regulatory stability, predictability, and independence, and could have a material adverse effect on the Company.

GLOBAL CLIMATE CHANGE RISK

The Company is subject to risks that may arise from the impacts of climate change. There is increasing public concern about climate change and growing support for reducing carbon dioxide emissions. Municipal, state, provincial and federal governments have been setting policies and enacting laws and regulations to deal with climate change impacts in a variety of ways, including decarbonization initiatives and promotion of cleaner energy and renewable energy generation of electricity. Refer to “Changes in Environmental Legislation” risk below. Insurance companies have begun to limit their exposure to coal-fired electricity generation and are evaluating the medium and long-term impacts of climate change which may result in fewer insurers, more restrictive coverage and increased premiums. Refer to the “Markets” section below and “Uninsured Risk”.

Climate change may lead to increased frequency and intensity of weather events and related impacts such as storms, ice storms, hurricanes, cyclones, heavy rainfall, extreme winds, wildfires, flooding and storm surge. The potential impacts of climate change, such as rising sea levels and larger storm surges from more intense hurricanes, can combine to produce even greater damage to coastal generation and other facilities. Climate change is also characterized by rising global temperatures. Increased air temperatures may bring increased frequency and severity of wildfires within the Company’s service territories. Refer to “Weather Risk” and “System Operating and Maintenance Risks”.

The Company has made significant investments to facilitate the use of renewable and lower-carbon energy including wind generation, the Maritime Link in Atlantic Canada, and in Florida, solar generation and modernization of the Big Bend Power Station. Tampa Electric has taken significant steps to reduce overall emissions at its facilities as a result of its capital investment plan which has and will continue to reduce carbon dioxide emissions. In 2022, NSPI achieved reductions of carbon dioxide emissions of approximately 45 per cent from 2005 levels. NSPI expects to exceed the Canadian target of 40-45 per cent reduction by 2030, as set out in the Canadian Net-Zero Emissions Accountability Act. Both the Government of Nova Scotia and the Government of Canada have enacted or introduced legislation that includes goals of net-zero GHG emissions by 2050. The Province of Nova Scotia has established targets with respect to the percentage of renewable energy in NSPI’s generation mix, reductions in GHG emissions, as well as the goal to phase out coal-fired electricity generation by 2030. Failure to meet such goals by 2030 could result in material fines, penalties, other sanctions and adverse reputational impacts. NSPI continues to work with both the provincial and federal governments on measures to seek to address their carbon reduction goals. Future compliance with provincial and federal GHG emission caps, coal phase out requirements and targets, and renewable standards has been challenged as a result of the constraints imposed by the enactment of Bill 212, “Public Utilities Act (amended)”. Within Emera’s natural gas utilities, there are ongoing efforts to reduce methane and carbon dioxide emissions through replacement of aging infrastructure, more efficient operations, operational and supply chain optimization, and support of public policy initiatives that address the effects of climate change.

The Company’s long-term capital investment plan includes significant investment across the portfolio in renewable and cleaner generation, infrastructure modernization, storm hardening, energy storage and customer-focused technologies. All these initiatives contribute toward mitigating the potential impacts of climate change. The Company continues to engage with government, regulators, industry partners and stakeholders to share information and participate in the development of climate change related policies and initiatives.

Physical Impacts

The Company is subject to physical risks that arise, or may arise, from global climate change, including damage to operating assets from more frequent and intense weather events and from wildfires due to warming air temperatures and increasing drought conditions. Substantially all of the Company’s fossil fueled generation assets are located at or near coastal sites and, as such, are exposed to the separate and combined effects of rising sea levels and increasing storm intensity, including storm surges and flooding. Refer to “Weather Risk” for further information.

 

48   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

These risks are mitigated to an extent through features such as flood walls at certain plants and through the location of plants on higher ground. Planned investments in under-grounding parts of the electricity infrastructure contribute to risk mitigation, as does insurance coverage (for assets other than electricity transmission and distribution assets). In addition, implementation of regulatory mechanisms for recovery of costs, such as storm reserves and regulatory deferral accounts, help smooth out the recovery of storm restoration costs over time.

Reputation

Failure to address issues related to climate change could affect Emera’s reputation with stakeholders, its ability to operate and grow, and the Company’s access to, and cost of, capital. Refer to “Liquidity and Capital Market Risk”. The Company seeks to mitigate this in part by moving away from higher-carbon generation in favour of lower-carbon generation and non-emitting renewable generation.

Markets

Changing carbon-related costs, policy and regulatory changes and shifts in supply and demand factors could lead to more expensive or more scarce products and services that are required by the Company in its operations. This could lead to supply shortages, delivery delays and the need to source alternate products and services. The Company seeks to mitigate these risks through close monitoring of such developments and adaptive changes to supply chain procurement strategies.

Given concerns regarding carbon-emitting generation, those assets and businesses may, over time, become difficult (or uneconomic) to insure in commercial insurance markets. In the short term, this may be mitigated through increased investment in engineered protection or alternative risk financing (such as funded self-insurance or regulatory structures, including storm reserves). Longer-term mitigation may be achieved through infrastructure siting decisions and further engineered protections. This risk may also be mitigated through the continued transition away from high-carbon generation sources to sources with low or zero carbon dioxide emissions.

Policy

Government and regulatory initiatives, including greenhouse gas emissions standards, air emissions standards and generation mix standards, are being proposed and adopted in many jurisdictions in response to concerns regarding the effects of climate change. In some jurisdictions, government policy has included timelines for mandated shutdowns of coal generating facilities, percentage of electricity generation from renewables, carbon pricing, emissions limits and cap and trade mechanisms. Over the medium and longer terms, this could potentially lead to a significant portion of hydrocarbon infrastructure assets being subject to additional regulation and limitations in respect of GHG emissions and operations. The Company is subject to climate- related and environmental legislative and regulatory requirements. Such legislative and regulatory initiatives could adversely affect Emera’s operations and financial performance. Refer to “Regulatory and Political Risk” and “Changes in Environmental Legislation” risk. The Company seeks to mitigate these risks through active engagement with governments and regulators to pursue transition strategies that meet the needs of customers, stakeholders and the Company. This has included NSPI’s participation in negotiated equivalency agreements in Nova Scotia to provide for an affordable transition to lower-carbon generation. Equivalency agreements allow NSPI to achieve compliance with federal GHG emissions regulations by meeting provincial legislative and regulatory requirements as they are deemed to be equivalent. There is no guarantee that such equivalency agreements will be renewed or remain in force in the future.

Regulatory

Depending on the regulatory response to government legislation and regulations, the Company may be exposed to the risk of reduced recovery through rates in respect of the affected assets. Valuation impairments could result from such regulatory outcomes. Mitigation efforts in respect of these risks include active engagement with policy makers and regulators to find mechanisms to avoid such impacts while being responsive to customers’ and stakeholders’ objectives.

 

  EMERA 2022 ANNUAL REPORT   49


Management’s Discussion & Analysis

 

Legal

The Company could face litigation or regulatory action related to environmental harms from carbon dioxide emissions or climate change public disclosure issues. The Company addresses these risks through compliance with all relevant laws, emissions reduction strategies, and public disclosure of climate change risks.

Water Resources

For thermal plants requiring cooling water, reduced availability of water resulting from climate change could adversely impact operations or the costs of operations. The Company seeks ways to reduce and recycle water as it does in its Polk power plant in Florida, where recovered and treated wastewater is used in operations to reduce reliance on fresh water supplies in an area where water is not as abundant as in other markets.

The Company operates hydroelectric generation in certain of its markets. Such generation depends on availability of water and the hydrological profile of water sources. Changes in precipitation patterns, water temperatures and air temperatures could adversely affect the availability of water and consequently the amount of electricity that may be produced from such facilities. The Company is reinvesting in the efficiency of certain hydroelectric generation facilities to increase generation capacity and continues to monitor changing hydrology patterns. Such issues may also affect the availability of third-party owned hydroelectricity purchased power sources.

WEATHER RISK

The Company is subject to risks that arise or may arise from weather including seasonal variations impacting energy sales, more frequent and intense weather events, changing air temperatures, wildfires and extreme weather conditions associated with climate change. Refer to “Global Climate Change Risk”.

Fluctuations in the amount of electricity or natural gas used by customers can vary significantly in response to seasonal changes in weather and could impact the operations, results of operations, financial condition, and cash flows of the Company’s utilities. For example, Tampa Electric could see lower demand in summer months if temperatures are cooler than expected. Further, extreme weather conditions such as hurricanes and other severe weather conditions which may be associated with climate change could cause these seasonal fluctuations to be more pronounced. In the absence of a regulatory recovery mechanism for unanticipated costs, such events could influence the Company’s results of operations, financial conditions or cash flows.

Extreme weather events create a risk of physical damage to the Company’s assets. High winds can impact structures and cause widespread damage to transmission and distribution infrastructure, solar generation, and wind powered generation. Increased frequency and severity of weather events increases the likelihood that the duration of power outages and fuel supply disruptions could increase. Increased frequency and intensity of flooding and storm surge could adversely affect the operations of utilities and in particular generation assets. The impact of extreme weather events would be amplified if the same events affect multiple utilities.

Each of Emera’s regulated electric utilities have programs for storm hardening of transmission and distribution facilities to minimize damage, but there can be no assurance that these measures will fully mitigate the risk. This risk to transmission and distribution facilities is typically not insured, and as such the restoration cost is generally recovered through regulatory processes, either in advance through reserves or designated self-insurance funds, or after the fact through the establishment of regulatory assets. Recovery is not assured and is subject to prudency review. The risk to generation assets is, in part, mitigated through the design, siting, construction and maintenance of such facilities, regular risk assessments, engineered mitigation, emergency storm response plans, and insurance.

The risk of wildfires is addressed primarily through asset management programs for natural gas transmission and distribution operations, and vegetation management programs for electric transmission and distribution facilities. If it is found to be responsible for such a fire, the Company could suffer costs, losses and damages, all or some of which may not be recoverable through insurance, legal, regulatory cost recovery or other processes. If not recovered through these means, they could materially affect Emera’s business and financial results including its reputation with customers, regulators, governments and financial markets. Resulting costs could include fire suppression costs, regeneration, timber value, increased insurance costs and costs arising from damages and losses incurred by third parties.

 

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Management’s Discussion & Analysis

 

CHANGES IN ENVIRONMENTAL LEGISLATION

Emera is subject to regulation by federal, provincial, state, regional and local authorities regarding environmental matters, primarily related to its utility operations. This includes laws setting GHG emissions standards and air emissions standards. Emera is also subject to laws regarding waste management, wastewater discharges and aquatic and terrestrial habitats.

Changes to GHG emissions standards and air emissions standards could adversely affect Emera’s operations and financial performance. Legislative or regulatory changes could influence decisions regarding early retirement of generation facilities and may result in stranded costs if the Company is not able to fully recover the costs and investment in the affected generation assets. Recovery is not assured and is subject to prudency review. Legislative or regulatory changes may curtail sales of natural gas to new customers, which could reduce future customer growth in Emera’s natural gas businesses. Stricter environmental laws and enforcement of such laws in the future could increase Emera’s exposure to additional liabilities and costs. These changes could also affect earnings and strategy by changing the nature and timing of capital investments.

In addition to imposing continuing compliance obligations, there are permit requirements, laws and regulations authorizing the imposition of penalties for non-compliance, including fines, injunctive relief, and other sanctions. The cost of complying with current and future environmental requirements is, and may be, material to Emera. Failure to comply with environmental requirements or to recover environmental costs in a timely manner through rates, could have a material adverse effect on Emera. In addition, Emera’s business could be materially affected by changes in government policy, utility regulation, and environmental and other legislation that could occur in response to environmental and climate change concerns.

Emera manages its environmental risk by operating in a manner that is respectful and protective of the environment and in compliance with applicable legal requirements and Company policy. Emera has implemented this policy through the development and application of environmental management systems in its operating subsidiaries. Comprehensive audit programs are in place to regularly test compliance.

CYBERSECURITY RISK

Emera is exposed to potential risks related to cyberattacks and unauthorized access. The Company increasingly relies on IT systems network, and cloud infrastructure to manage its business and safely operate its assets, including controls for interconnected systems of generation, distribution and transmission as well as financial, billing and other business systems. Emera also relies on third-party service providers to conduct business. As the Company operates critical infrastructure, it may be at greater risk of cyberattacks by third parties, which could include nation-state-controlled parties. This risk may be further elevated by geo-political risks such as the ongoing conflict between Russia and Ukraine.

Cyberattacks can reach the Company’s assets and information via their interfaces with third parties or the public internet and gain access to critical infrastructures. Cyberattacks can also occur via personnel with direct access to critical assets or trusted networks. Methods used to attack critical assets could include general purpose or energy-sector-specific malware delivered via network transfer, removable media, viruses, attachments, or links in e-mails. The methods used by attackers are continuously evolving and can be difficult to predict and detect.

Despite security measures in place, that are described below, the Company’s systems, assets and information could experience security breaches that could cause system failures, disrupt operations, or adversely affect safety. Such breaches could compromise customer, employee-related or other information systems and could result in loss of service to customers, unavailability of critical assets, safety issues, or the release, destruction, or misuse of critical, sensitive or confidential information. These breaches could also delay delivery or result in contamination or degradation of hydrocarbon products the Company transports, stores or distributes.

Cyberattacks or unauthorized accesses may cause costs, losses and damages all, or some of which, may not be recoverable (through insurance, legal, regulatory cost recovery or other processes). This could materially adversely affect Emera’s business and financial results including its reputation with customers, regulators, governments and financial markets. Resulting costs could include, amongst others, response, recovery and remediation costs, increased protection or insurance costs and costs arising from damages and losses incurred by third parties. If any such security breaches occur, there is no assurance they can be adequately addressed in a timely manner.

 

  EMERA 2022 ANNUAL REPORT   51


Management’s Discussion & Analysis

 

The Company seeks to manage these risks by aligning to a common set of cybersecurity standards and policies derived, in part, on the National Institute of Standards and Technology’s Cyber Security Framework, periodic security testing, program maturity objectives, cybersecurity incident readiness program, and employee communication and training. With respect to certain of its assets, the Company is required to comply with rules and standards relating to cybersecurity and IT including, but not limited to, those mandated by bodies such as the North American Electric Reliability Corporation, Northeast Power Coordinating Council, and the United States Department of Homeland Security. The status of key elements of the Company’s cybersecurity program is reported to the RSC.

PUBLIC HEALTH RISK

An outbreak of infectious disease, a pandemic or a similar public health threat, such as the COVID-19 pandemic, or a fear of any of the foregoing, could adversely impact the Company, including causing operating, supply chain and project development delays and disruptions, labour shortages and shutdowns (including as a result of government regulation and prevention measures), which could have a negative impact on the Company’s operations.

Any adverse changes in general economic and market conditions arising as a result of a public health threat could negatively impact demand for electricity and natural gas, revenue, operating costs, timing and extent of capital expenditures, results of financing efforts, or credit risk and counterparty risk; which could result in a material adverse effect on the Company’s business. The Company maintains pandemic and business contingency plans in each of its operations to manage and help mitigate the impact of any such public health threat.

ENERGY CONSUMPTION RISK

Emera’s rate-regulated utilities are affected by demand for energy based on changing customer patterns due to fluctuations in a number of factors including general economic conditions, weather events, customers’ focus on energy efficiency, changes in rates, and advancements in new technologies such as rooftop solar, electric vehicles and battery storage. Government policies promoting distributed generation, and new technology developments that enable those policies, have the potential to impact how electricity enters the system and how it is bought and sold. In addition, increases in distributed generation may impact demand resulting in lower load and revenues. These changes could negatively impact Emera’s operations, rate base, net earnings, and cash flows. The Company’s rate-regulated utilities are focused on understanding customer demand, energy efficiency, and government policy to ensure that the impact of these activities benefit customers, that they do not negatively impact the reliability of the energy service and that they are addressed through regulations.

FOREIGN EXCHANGE RISK

The Company is exposed to foreign currency exchange rate changes. Emera operates internationally, with an increasing amount of the Company’s net income earned outside of Canada. As such, Emera is exposed to movements in exchange rates between the CAD and, particularly, the USD, which could positively or adversely affect results.

Consistent with the Company’s risk management policies, Emera manages currency risks through matching United States denominated debt to finance its Unites States operations and may use foreign currency derivative instruments to hedge specific transactions and earnings exposure. The Company may enter FX forward and swap contracts to limit exposure on certain foreign currency transactions such as fuel purchases, revenue streams and capital expenditures, and on net income earned outside of Canada. The regulatory framework for the Company’s rate-regulated subsidiaries permits the recovery of prudently incurred costs, including FX.

The Company does not utilize derivative financial instruments for foreign currency trading or speculative purposes or to hedge the value of its investments in foreign subsidiaries. Exchange gains and losses on net investments in foreign subsidiaries do not impact net income as they are reported in Accumulated Other Comprehensive Income (Loss) (“AOCI”) (“AOCL”).

LIQUIDITY AND CAPITAL MARKET RISK

Liquidity risk relates to Emera’s ability to ensure sufficient funds are available to meet its financial obligations. Emera manages this risk by forecasting cash requirements on a continuous basis to determine whether sufficient funds are available. Liquidity and capital needs could be financed through internally generated cash flows, asset sales, short-term credit facilities, and ongoing access to capital markets. The Company reasonably expects liquidity sources to exceed capital needs.

 

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Management’s Discussion & Analysis

 

Emera’s access to capital and cost of borrowing is subject to several risk factors, including financial market conditions, market disruptions and ratings assigned by credit rating agencies. Disruptions in capital markets could prevent Emera from issuing new securities or cause the Company to issue securities with less than preferred terms and conditions. Emera’s growth plan requires significant capital investments in PP&E and the risk associated with changes in interest rates could have an adverse effect on the cost of financing. The Company’s future access to capital and cost of borrowing may be impacted by various market disruptions. The inability to access cost-effective capital could have a material impact on Emera’s ability to fund its growth plan.

Emera is subject to financial risk associated with changes in its credit ratings. There are a number of factors that rating agencies evaluate to determine credit ratings, including the Company’s business, its regulatory framework and legislative environment, political interference in the regulatory process, the ability to recover costs and earn returns, diversification, leverage, liquidity and increased exposure to climate change-related impacts, including increased frequency and severity of hurricanes and other severe weather events. A decrease in a credit rating could result in higher interest rates in future financings, increased borrowing costs under certain existing credit facilities, limit access to the commercial paper market, or limit the availability of adequate credit support for subsidiary operations. For certain derivative instruments, if the credit ratings of the Company were reduced below investment grade, the full value of the net liability of these positions could be required to be posted as collateral. Emera manages these risks by actively monitoring and managing key financial metrics with the objective of sustaining investment grade credit ratings.

The Company has exposure to its own common share price through the issuance of various forms of stock-based compensation, which affect earnings through revaluation of the outstanding units every period. The Company uses equity derivatives to reduce the earnings volatility derived from stock-based compensation.

GENERAL ECONOMIC RISK

The Company has exposure to the macro-economic conditions in North America and in other geographic regions in which Emera operates. Like most utilities, economic factors such as consumer income, employment and housing affect demand for electricity and natural gas and, in turn, the Company’s financial results. Adverse changes in general economic conditions and inflation may impact the ability of customers to afford rate increases arising from increases to fuel, operating, capital, environmental compliance, and other costs, and therefore could materially affect Emera and its utilities. This may also result in higher credit and counterparty risk, adverse shifts in government policy and legislation, and/or increased risk to full and timely recovery of costs and regulatory assets.

Interest Rate Risk

Emera utilizes a combination of fixed and floating rate debt financing for operations and capital expenditures, resulting in an exposure to interest rate risk. Emera seeks to manage interest rate risk through a portfolio approach that includes the use of fixed and floating rate debt with staggered maturities. The Company will, from time to time, issue long-term debt or enter interest rate hedging contracts to limit its exposure to fluctuations in floating interest rate debt.

For Emera’s regulated subsidiaries, the cost of debt is a component of rates and prudently incurred debt costs are recovered from customers. Regulatory ROE will generally follow the direction of interest rates, such that regulatory ROEs are likely to fall in times of reducing interest rates and rise in times of increasing interest rates, albeit not directly and generally with a lag period reflecting the regulatory process. Rising interest rates may also negatively affect the economic viability of project development and acquisition initiatives.

As with most other utilities and other similar yield-returning investments, Emera’s share price may be affected by changes in interest rates and could underperform the market in an environment of rising interest rates.

Inflation Risk

The Company may be exposed to changes in inflation that may result in increased operating and maintenance costs, capital investment, and fuel costs compared to the revenues provided by customer rates. Emera’s utilities have budgeting and forecasting processes to identify inflationary risk factors and measure operating performance, as well as collective bargaining agreements that mitigate the short-term impact of inflation on labour costs.

 

  EMERA 2022 ANNUAL REPORT   53


Management’s Discussion & Analysis

 

PROJECT DEVELOPMENT AND LAND USE RIGHTS RISK

The Company’s capital plan includes significant investment in generation, infrastructure modernization, and customer-focused technologies. Any projects planned or currently in construction, particularly significant capital projects, may be subject to risks including, but not limited to, impact on costs from schedule delays, risk of cost overruns, ensuring compliance with operating and environmental requirements and other events within or beyond the Company’s control. The Company’s projects may also require approvals and permits at the federal, provincial, state, regional and local levels. There is no assurance that Emera will be able to obtain the necessary project approvals or applicable permits or receive regulatory approval to recover the costs in rates.

Some of the Company’s assets are located on land owned by third parties, including Indigenous Peoples, and may be subject to land claims. Present or future assets may be located on lands that have been used for traditional purposes and therefore subject to specific consultations, consents, or conditions for development or operation. If the Company’s rights to locate and operate its assets on any such lands are subject to expiry or become invalid, it may incur material costs to renew rights or obtain such rights. If reasonable terms for land-use rights cannot be negotiated, the Company may incur significant costs to remove and relocate its assets and restore the land. Additional costs incurred could cause projects to be uneconomical to proceed with.

Emera manages these project development and land use rights risks by deploying robust project and risk management approaches, led by teams with extensive experience in large projects. The Company consults with Indigenous Peoples in obtaining approvals, constructing, maintaining and operating such facilities, consistent with laws and public policy frameworks. Emera maintains relationships through on-going communications with stakeholders, including Indigenous Peoples, landowners and governments.

COUNTERPARTY RISK

Emera is exposed to risk related to its reliance on certain key partners, suppliers, and customers, any of which may endure financial challenges resulting from commodity price and market volatility, economic instability or adversity, adverse political or regulatory changes and other causes which may cause or contribute to such parties’ insolvency, bankruptcy, restructuring or default on their contractual obligations to Emera. Emera is also exposed to potential losses related to amounts receivable from customers, energy marketing collateral deposits and derivative assets due to a counterparty’s non-performance under an agreement.

Emera manages this counterparty risk through due diligence and third-party risk assessment processes prior to signing contracts, contractual rights and remedies, regulatory frameworks, and by monitoring significant developments with its customers, partners and suppliers. The Company also manages credit risk with policies and procedures for counterparty analysis, exposure measurement, and exposure monitoring and mitigation. Credit assessments may be conducted on new customers and counterparties, and deposits or collateral may be requested on certain accounts. There is no assurance that management strategies will be effective, and significant counterparty defaults could have a material effect on the Company.

COUNTRY RISK

The majority of Emera’s earnings are from outside of Canada, mostly concentrated in the United States. Emera’s investments are currently in regions where political and economic risks are considered by the Company to be acceptable. For more information, refer to the “Regulatory and Political Risk” and “General Economic Risk” sections above. Emera’s operations in some countries may be subject to changes in economic growth, restrictions on the repatriation of income or capital exchange controls, inflation, the effect of global health, safety and environmental matters, including climate change, or economic conditions and market conditions, and change in financial policy and availability of credit. The Company mitigates this risk through a rigorous approval process for investment, and by forecasting cash requirements on a continuous basis to determine whether sufficient funds are available in all affiliates.

 

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Management’s Discussion & Analysis

 

COMMODITY PRICE RISK

The Company’s utility fuel supply is subject to commodity price risk. In addition, Emera Energy is subject to commodity price risk through its portfolio of commodity contracts and arrangements.

The Company manages this risk through established processes and practices to identify, monitor, report and mitigate these risks. These include the Company’s commercial arrangements, such as the combination of supply and purchase agreements, asset management agreements, pipeline transportation agreements, and financial hedging instruments. In addition, its credit policies, counterparty credit assessments, market and credit position reporting, and other risk management and reporting practices, are also used to manage and mitigate this risk.

Regulated Utilities

The Company’s utility fuel supply is exposed to broader global conditions, which may include impacts on delivery reliability and price, despite contracted terms. Supply and demand dynamics in fuel markets can be affected by a wide range of factors which are difficult to predict and may change rapidly, including but not limited to, currency fluctuations, changes in global economic conditions, natural disasters, transportation or production disruptions, and geo-political risks, such as political instability, conflicts, changes to international trade agreements, trade sanctions or embargos. The Company seeks to manage this risk using financial hedging instruments and physical contracts and through contractual protection with counterparties, where applicable.

The majority of Emera’s regulated electric and gas utilities have adopted and implemented fuel adjustment mechanisms and purchased gas adjustment mechanisms respectively, which further helps manage commodity price risk, as the regulatory framework for the Company’s rate-regulated subsidiaries permits the recovery of prudently incurred fuel and gas costs. There is no assurance that such mechanisms and regulatory frameworks will continue to exist in the future. Prolonged and substantial increases in fuel prices could result in decreased rate affordability, increased risk of recovery of costs or regulatory assets, and/or negative impacts on customer consumption patterns and sales.

Emera Energy Marketing and Trading

Emera Energy has employed further measures to manage commodity risk. The majority of Emera Energy’s portfolio of electricity and gas marketing and trading contracts and, in particular, its natural gas asset management arrangements, are contracted on a back-to-back basis, avoiding any material long or short commodity positions. However, the portfolio is subject to commodity price risk, particularly with respect to basis point differentials between relevant markets in the event of an operational issue or counterparty default. Changes in commodity prices can also result in increased collateral requirements associated with physical contracts and financial hedges, resulting in higher liquidity requirements and increased costs to the business.

To measure commodity price risk exposure, Emera Energy employs a number of controls and processes, including an estimated VaR analysis of its exposures. The VaR amount represents an estimate of the potential change in fair value that could occur from changes in Emera Energy’s portfolio or changes in market factors within a given confidence level, if an instrument or portfolio is held for a specified time period. The VaR calculation is used to quantify exposure to market risk associated with physical commodities, primarily natural gas and power positions.

FUTURE EMPLOYEE BENEFIT PLAN PERFORMANCE AND FUNDING RISK

Emera subsidiaries have both defined benefit and defined contribution employee pension plans that cover their employees and retirees. All defined benefit plans are closed to new entrants, except for the TECO Energy Group Retirement Plan. The cost of providing these benefit plans varies depending on plan provisions, interest rates, inflation, investment performance and actuarial assumptions concerning the future. Actuarial assumptions include earnings on plan assets, discount rates (interest rates used to determine funding levels, contributions to the plans and the pension and post-retirement liabilities) and expectations around future salary growth, inflation and mortality. Three of the largest drivers of cost are investment performance, interest rates and inflation, which are affected by global financial and capital markets. Depending on future interest rates and future inflation and actual versus expected investment performance, Emera could be required to make larger contributions in the future to fund these plans, which could adversely affect Emera’s cash flows, financial condition and operations.

Each of Emera’s employee defined benefit pension plans are managed according to an approved investment policy and governance framework. Emera employs a long-term approach with respect to asset allocation and each investment policy outlines the level of risk which the Company is prepared to accept with respect to the investment of the pension funds in achieving both the Company’s fiduciary and financial objectives. Studies are routinely undertaken approximately every five years with the objective that the plans’ asset allocations are appropriate for meeting Emera’s long-term pension objectives.

 

  EMERA 2022 ANNUAL REPORT   55


Management’s Discussion & Analysis

 

LABOUR RISK

Emera’s ability to deliver service to its customers and to execute its growth plan depends on attracting, developing and retaining a skilled workforce. Utilities are faced with demographic challenges related to trades, technical staff and engineers with an increasing number of employees expected to retire over the next several years. Failure to attract, develop and retain an appropriately qualified workforce could adversely affect the Company’s operations and financial results. Emera seeks to manage this risk through maintaining competitive compensation programs, a dedicated talent acquisition team, human resources programs and practices, including ethics and diversity training, employee engagement surveys, succession planning for key positions and apprenticeship programs.

Approximately 32 per cent of Emera’s labour force is represented by unions and subject to collective labour agreements. The inability to maintain or negotiate future agreements on acceptable terms could result in higher labour costs and work disruptions, which could adversely affect service to customers and have an adverse effect on the Company’s earnings, cash flow and financial position. Emera seeks to manage this risk through ongoing discussions and working to maintain positive relationships with local unions. The Company maintains contingency plans in each of its operations to manage and reduce the effect of any potential labour disruption.

IT RISK

Emera relies on various IT systems to manage operations. This subjects Emera to inherent costs and risks associated with maintaining, upgrading, replacing and changing these systems. This includes impairment of its IT, potential disruption of internal control systems, substantial capital expenditures, demands on management time and other risks of delays, difficulties in upgrading existing systems, transitioning to new systems or integrating new systems into its current systems. Emera’s digital transformation strategy, including investment in infrastructure modernization and customer focused technologies, is driving increased investment in IT solutions, resulting in increased project risks associated with the implementation of these solutions.

Emera manages these risks through IT asset lifecycle planning and management, governance, internal auditing and testing of systems, and executive oversight. Employees with extensive subject matter expertise assist in risk identification and mitigation, project management, implementation, change management and training. System resiliency, formal disaster recovery and backup processes, combined with critical incident response practices, table-top exercises, and simulations, help mitigate operational disruptions.

INCOME TAX RISK

The computation of the Company’s provision for income taxes is impacted by changes in tax legislation in Canada, the United States and the Caribbean. Any such changes could affect the Company’s future earnings, cash flows, and financial position. The value of Emera’s existing deferred tax assets and liabilities are determined by existing tax laws and could be negatively impacted by changes in laws. Emera monitors the status of existing tax laws to ensure that changes impacting the Company are appropriately reflected in the Company’s tax compliance filings and financial results.

SYSTEM OPERATING AND MAINTENANCE RISKS

The safe and reliable operation of electric generation and electric and natural gas transmission and distribution systems is critical to Emera’s operations. There are a variety of hazards and operational risks inherent in operating electric utilities and natural gas transmission and distribution pipelines. Electric generation, transmission and distribution operations can be impacted by risks such as mechanical failures, supply chain issues impacting timely access to critical equipment, activities of third parties, terrorism, cyberattacks, damage to facilities, solar panels and infrastructure caused by hurricanes, storms, falling trees, lightning strikes, floods, fires and other natural disasters. Natural gas pipeline operations can also be impacted by risks such as leaks, explosions, mechanical failures, activities of third parties, terrorism, cyberattacks, and damage to the pipeline facilities and equipment caused by hurricanes, storms, floods, fires and other natural disasters. Refer to “Global Climate Change Risk” and “Weather Risk”. Electric utility and natural gas transmission and distribution pipeline operation interruption could negatively affect revenue, earnings, and cash flows as well as customer and public confidence, and public safety.

Emera manages these risks by investing in a highly skilled workforce, operating prudently, preventative maintenance, safety and operations management systems, third-party risk program, and making effective capital investments. Insurance, warranties, or recovery through regulatory mechanisms may not cover any or all these losses, which could adversely affect the Company’s results of operations and cash flows.

 

56   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

Fuel Supply Disruptions

Emera’s electric and natural gas utilities are also exposed to the risk of fuel supply chain disruptions, both within and outside their service territories, which may be caused by severe weather or natural disasters. This may also be caused by damage to, operational issues with, terrorist or cyberattacks on, third party fuel production, storage, pipeline, and distribution facilities. The risk of fuel supply disruptions is managed through contractual protections, maintaining a diversity of fuel suppliers and transportation contracts, and contracting for access to third-party storage facilities. Significant unanticipated fuel supply disruptions, such as those which arose from Winter Storm Uri in February 2021, could result in increased exposure to commodity price risk for Emera’s regulated electric and gas utilities and Emera Energy, and these could have adverse effects on service to utility customers and on the Company’s reputation, earnings, cash flow and financial position.

UNINSURED RISK

Emera and its subsidiaries maintain insurance to cover accidental loss suffered to its facilities and to provide indemnity in the event of liability to third parties. This is consistent with Emera’s risk management policies. Certain facilities, in particular coal and other thermal generation, may, over time, become more difficult (or uneconomic) to insure as a result of the impact of global climate change. Refer to “Global Climate Change Risk – Markets”. There are certain elements of Emera’s operations which are not insured. These include a significant portion of its electric utilities’ transmission and distribution assets, as is customary in the industry. The cost of this coverage is not economically viable. In addition, Emera accepts deductibles and self-insured retentions under its various insurance policies. Insurance is subject to coverage limits as well as time sensitive claims discovery and reporting provisions and there can be no assurance that the types of liabilities or losses that may be incurred by the Company and its subsidiaries will be covered by insurance.

The occurrence of significant uninsured claims, claims in excess of the insurance coverage limits maintained by Emera and its subsidiaries, or claims that fall within a significant self-insured retention could have a material adverse effect on Emera’s results of operations, cash flows and financial position, if regulatory recovery is not available.

The Company mitigates its uninsured risk by ensuring insurance limits align with risk exposures, and for uninsured assets and operations, that appropriate risk assessments and mitigation measures are in place. The regulatory framework for the Company’s rate-regulated subsidiaries permits the recovery of prudently incurred costs, including uninsured losses.

Risk Management including Financial Instruments

Emera’s risk management policies and procedures provide a framework through which management monitors various risk exposures. The risk management policies and practices are overseen by the Board of Directors. The Company has established a number of processes and practices to identify, monitor, report on and mitigate material risks to the Company. This includes establishment of the ERMC, whose responsibilities include preparing an updated risk dashboard and heat map presented at regular meetings of the Board’s Risk and Sustainability Committee. Furthermore, a corporate team independent from operations is responsible for tracking and reporting on market and credit risks.

The Company manages its exposure to normal operating and market risks relating to commodity prices, FX, interest rates and share prices through contractual protections with counterparties where practicable, and by using financial instruments consisting mainly of FX forwards and swaps, interest rate options and swaps, equity derivatives, and coal, oil and gas futures, options, forwards and swaps. In addition, the Company has contracts for the physical purchase and sale of natural gas. These physical and financial contracts are classified as held-for-trading (“HFT”). Collectively, these contracts and financial instruments are considered derivatives.

The Company recognizes the fair value of all its derivatives on its balance sheet, except for non-financial derivatives that meet the normal purchases and normal sales (“NPNS”) exception. Physical contracts that meet the NPNS exception are not recognized on the balance sheet; these contracts are recognized in income when they settle. A physical contract generally qualifies for the NPNS exception if the transaction is reasonable in relation to the Company’s business needs, the counterparty owns or controls resources within the proximity to allow for physical delivery, the Company intends to receive physical delivery of the commodity, and the Company deems the counterparty creditworthy. The Company continually assesses contracts designated under the NPNS exception and will discontinue the treatment of these contracts under this exemption where the criteria are no longer met.

 

  EMERA 2022 ANNUAL REPORT   57


Management’s Discussion & Analysis

 

Derivatives qualify for hedge accounting if they meet stringent documentation requirements and can be proven to effectively hedge the identified risk both at the inception and over the term of the instrument. Specifically, for cash flow hedges, the change in the fair value of derivatives is deferred to AOCI and recognized in income in the same period the related hedged item is realized. Where the documentation or effectiveness requirements are not met, the derivatives are recognized at fair value with any changes in fair value recognized in net income in the reporting period, unless deferred as a result of regulatory accounting.

Derivatives entered into by NSPI, NMGC and GBPC that are documented as economic hedges or for which the NPNS exception has not been taken, are subject to regulatory accounting treatment. The change in fair value of the derivatives is deferred to a regulatory asset or liability. The gain or loss is recognized in the hedged item when the hedged item is settled. Management believes any gains or losses resulting from settlement of these derivatives related to fuel for generation and purchased power will be refunded to or collected from customers in future rates. Tampa Electric has no derivatives related to hedging as a result of a FPSC approved five-year moratorium on hedging of natural gas purchases which ended on December 31, 2022. Tampa Electric’s moratorium on hedging of natural gas purchases will continue through December 31, 2024, as a result of Tampa Electric’s 2021 rate case settlement agreement.

Derivatives that do not meet any of the above criteria are designated as HFT, with changes in fair value normally recorded in net income of the period. The Company has not elected to designate any derivatives to be included in the HFT category where another accounting treatment would apply.

DERIVATIVE ASSETS AND LIABILITIES RECOGNIZED ON THE BALANCE SHEET

 

As at

millions of dollars

   December 31
2022
     December 31
2021
 

Regulatory Deferral:

     

Derivative instrument assets (1)

   $ 238      $ 237  

Derivative instrument liabilities (2)

     (25 )       (20 ) 

Regulatory assets (1)

     30        23  

Regulatory liabilities (2)

     (230 )       (241 ) 
  

 

 

    

 

 

 

Net asset (liability)

   $ 13      $ (1 ) 
  

 

 

    

 

 

 

HFT Derivatives:

     

Derivative instrument assets (1)

   $ 153      $ 53  

Derivatives instruments liabilities (2)

     (1,025 )       (662 ) 
  

 

 

    

 

 

 

Net liability

   $ (872 )     $ (609 ) 
  

 

 

    

 

 

 

Other Derivatives:

     

Derivative instrument assets (1)

   $ 5      $ 11  

Derivatives instruments liabilities (2)

     (28 )       —    
  

 

 

    

 

 

 

Net asset (liability)

   $ (23 )     $ 11  
  

 

 

    

 

 

 

 

(1)

Current and other assets.

(2)

Current and long-term liabilities.

REALIZED AND UNREALIZED GAINS (LOSSES) RECOGNIZED IN NET INCOME

 

For the

millions of dollars

   2022      Year ended
December 31
2021
 

Regulatory Deferral:

     

Regulated fuel for generation and purchased power (1)

   $ 210      $ 34  
  

 

 

    

 

 

 

HFT Derivatives:

     

Non-regulated operating revenues

   $ 64      $ (138 ) 
  

 

 

    

 

 

 

Other Derivatives:

     

OM&G

   $ (22 )     $ 26  

Other income, net

     (24 )       3  
  

 

 

    

 

 

 

Net gains (losses)

   $ (46 )     $ 29  
  

 

 

    

 

 

 

Total net gains (losses)

   $ 228      $ (75 ) 
  

 

 

    

 

 

 

 

(1)

Realized gains (losses) on derivative instruments settled and consumed in the period, hedging relationships that have been terminated or the hedged transaction is no longer probable. Realized gains (losses) recorded in inventory will be recognized in “Regulated fuel for generation and purchased power” when the hedged item is consumed.

 

58   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

As of December 31, 2022, the unrealized gain in AOCI was $16 million, net of tax (2021 – $18 million, net of tax). For the year ended December 31, 2022, unrealized gains of $2 million (2021 – $1 million), have been reclassified into interest expense.

Disclosure and Internal Controls

Management is responsible for establishing and maintaining adequate disclosure controls and procedures (“DC&P”) and internal control over financial reporting (“ICFR”), as defined in National Instrument 52-109 Certification of Disclosure in Issuers’ Annual and Interim Filings (“NI 52-109”). The Company’s internal control framework is based on the criteria published in the Internal Control – Integrated Framework (2013), a report issued by the Committee of Sponsoring Organizations (“COSO”) of the Treadway Commission. Management, including the Chief Executive Officer and Chief Financial Officer, evaluated the design and effectiveness of the Company’s DC&P and ICFR as at December 31, 2022 to provide reasonable assurance regarding the reliability of financial reporting in accordance with USGAAP.

Management recognizes the inherent limitations in internal control systems, no matter how well designed. Control systems determined to be appropriately designed can only provide reasonable assurance with respect to the reliability of financial reporting and may not prevent or detect all misstatements.

There were no changes in the Company’s ICFR, during the year ended December 31, 2022, that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

Critical Accounting Estimates

The preparation of consolidated financial statements in accordance with USGAAP requires management to make estimates and assumptions. These may affect the reported amounts of assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during the reporting periods. Significant areas requiring use of management estimates relate to rate-regulated assets and liabilities, accumulated reserve for cost of removal, pension and post-retirement benefits, unbilled revenue, useful lives for depreciable assets, goodwill and long-lived assets impairment assessments, income taxes, asset retirement obligations (“ARO”), and valuation of financial instruments. Management evaluates the Company’s estimates on an ongoing basis based upon historical experience, current and expected conditions and assumptions believed to be reasonable at the time the assumption is made, with any adjustments recognized in income in the year they arise.

RATE REGULATION

The rate-regulated accounting policies of Emera’s rate-regulated subsidiaries and regulated equity investments are subject to examination and approval by their respective regulators and may differ from the accounting policies of non-rate-regulated companies. Differences occur when regulators render their decisions on rate applications or other matters, and generally involve a difference in the timing of revenue and expense recognition. The accounting for these items is based on expectations of the future actions of the regulators. Assumptions and judgments used by regulatory authorities continue to have an impact on the recovery of costs, the rate earned on invested capital, and the timing and amount of assets to be recovered. The application of regulatory accounting guidance is a critical accounting policy as a change in these assumptions may result in a material impact on reported assets, liabilities and the results of operations.

As at December 31, 2022, the Company has recorded $3,620 million (2021 – $2,566 million) of regulatory assets and $2,273 million (2021 – $2,055 million) of regulatory liabilities.

ACCUMULATED RESERVE – COST OF REMOVAL

Tampa Electric, PGS, NMGC and NSPI recognize non-ARO costs of removal (“COR”) as regulatory liabilities. The non-ARO COR represent estimated funds received from customers through depreciation rates to cover future COR of PP&E upon retirement that are not legally required. The companies accrue for COR over the life of the related assets based on depreciation studies approved by their respective regulators. The costs are estimated based on historical experience and future expectations, including expected timing and estimated future cash outlays. As at December 31, 2022, the balance of the Accumulated reserve – COR within regulatory liabilities was $895 million (2021 – $819 million).

 

  EMERA 2022 ANNUAL REPORT   59


Management’s Discussion & Analysis

 

PENSION AND OTHER POST-RETIREMENT EMPLOYEE BENEFITS

The Company provides post-retirement benefits to employees, including defined benefit pension plans. The cost of providing these benefits is dependent upon many factors that result from actual plan experience and assumptions of future expectations.

The accounting related to employee post-retirement benefits is a critical accounting estimate. Changes in the estimated benefit obligation, affected by employee demographics, including age, compensation levels, employment periods, contribution levels and earnings, could have a material impact on reported assets, liabilities, accumulated other comprehensive income and results of operations. Changes in key actuarial assumptions, including anticipated rates of return on plan assets and discount rates used in determining the accrued benefit obligation and benefit costs, could change annual funding requirements. This could have a significant impact on the Company’s annual earnings and cash requirements.

The pension plan assets are comprised primarily of equity and fixed income investments. Fluctuations in actual equity market returns and changes in interest rates may result in changes to pension costs in future periods.

The Company’s accounting policy is to amortize the net actuarial gain or loss that exceeds 10 per cent of the greater of the projected benefit obligation / accumulated post-retirement benefit obligation (“PBO”) and the market-related value of assets, over active plan members’ average remaining service period. For the largest plans this is currently 8.3 years (8.7 years for 2022 benefit cost) for the Canadian plans and a weighted average of 11.4 years for the United States plans). The Company’s use of smoothed asset values reduces volatility related to the amortization of actuarial investment experience. As a result, the main cause of volatility in reported pension cost is the discount rate used to determine the PBO.

The discount rate used to determine benefit costs is based on the yield of high quality long-term corporate bonds in each operating entity’s country and is determined with reference to bonds which have the same duration as the PBO as at January 1 of the fiscal year. The following table shows the discount rate for benefit cost purposes and the expected return on plan assets for each plan:

 

     2022     2021  
     Discount rate
for benefit
cost purposes
    Expected
return on
plan assets
    Discount rate
for benefit
cost purposes
    Expected
return on
plan assets
 

TECO Energy Group Retirement Plan

     2.78 %      6.50 %      2.38 %      6.70 % 

TECO Energy Group Supplemental Executive Retirement Plan (1)

     2.35/5.33 %      N/A       1.84 %      N/A  

TECO Energy Group Benefit Restoration Plan (1)

     2.27/4.19/5.48 %      N/A       1.71 %      N/A  

TECO Energy Post-retirement Health and Welfare Plan

     2.84 %      N/A       2.47 %      N/A  

New Mexico Gas Company Retiree Medical Plan

     2.85 %     1.50 %      2.49 %      4.00 % 

NSPI

     3.25%, 3.48 %      5.75 %      2.59%, 2.85 %      5.25 % 

GBPC Salaried

     5.75 %      6.00 %      4.25 %      6.00 % 

GBPC Union

     5.75 %      5.35 %      5.65 %      5.65 % 

 

(1)

The discount rate and expected return on assets for benefit cost purposes is updated throughout the year as special events occur, such as settlements and curtailments.

Based on management’s estimate, the reported benefit cost for defined benefit and defined contribution plans was $64 million in 2022 (2021 – $85 million). The reported benefit cost is impacted by numerous assumptions, including the discount rate and asset return assumptions. A 0.25 per cent change in the discount rate and asset return assumptions would have had +/- impact on the 2022 benefit cost of $0.5 million and $1 million respectively (2021 – $1 million and $3 million).

UNBILLED REVENUE

Electric and gas revenues are billed on a systematic basis over a one or two-month period for NSPI and a one-month period for other Emera utilities. At the end of each month, the Company must make an estimate of energy delivered to customers since the date their meter was last read and determine related revenues earned but not yet billed. The unbilled revenue is estimated based on several factors, including current month’s generation, estimated customer usage by class, weather, line losses, inter-period changes to customer classes and applicable customer rates. Based on the extent of estimates included in the determination of unbilled revenue, actual results may differ from the estimate. At December 31, 2022, unbilled revenues totalled $424 million (2021 – $318 million) on total regulated operating revenues of $7,154 million (2021 – $5,926 million).

 

60   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

PROPERTY, PLANT AND EQUIPMENT

PP&E represents 58 per cent of total assets on the Company’s balance sheet and include the generation, transmission and distribution, and other assets of the Company.

Depreciation is determined by the straight-line method, based on the estimated remaining service lives of the depreciable assets in each category. The service lives of regulated PP&E are determined based on depreciation studies and require appropriate regulatory approval. Due to the magnitude of the Company’s PP&E, changes in estimated depreciation rates can have a material impact on depreciation expense and accumulated depreciation.

Depreciation expense was $927 million for the year ended December 31, 2022 (2021 – $877 million).

GOODWILL IMPAIRMENT ASSESSMENTS

Goodwill is calculated as the excess of the purchase price of an acquired entity over the estimated fair values of identifiable assets acquired, and liabilities assumed at the acquisition date. Goodwill is carried at initial cost less any write-down for impairment and is adjusted for the impact of foreign exchange. Under the applicable accounting guidance, goodwill is subject to assessment for impairment at the reporting unit level annually, or if an event or change in circumstances indicates that the fair value of a reporting unit may be below its carrying value. Application of the goodwill impairment test requires management judgment on significant assumptions and estimates. When assessing goodwill for impairment, the Company has the option of first performing a qualitative assessment to determine whether a quantitative assessment is necessary. In performing a qualitative assessment management considers, among other factors, macroeconomic conditions, industry and market considerations and overall financial performance.

If the Company performs the qualitative assessment and determines that it is more likely than not that its fair value is less than its carrying amount, or if the Company chooses to bypass the qualitative assessment, a quantitative test is performed. The quantitative test compares the fair value of the reporting unit to its carrying amount, including goodwill. If the carrying amount of the reporting unit exceeds its fair value, an impairment loss is recorded. Significant assumptions used in estimating the fair value include discount and growth rates, rate case assumptions including future cost of capital, valuation of the reporting units’ net operating loss (“NOL”) and projected operating and capital cash flows. Adverse changes in these assumptions could result in a future material impairment of the goodwill assigned to Emera’s reporting units.

As of December 31, 2022, $6,009 million of Emera’s goodwill represents the excess of the acquisition purchase price for TECO Energy (Tampa Electric, PGS and NMGC reporting units) over the fair values assigned to identifiable assets acquired and liabilities assumed. In Q4 2022, qualitative assessments were performed for Tampa Electric and PGS given the significant excess of fair value over carrying amounts calculated during the last quantitative test in Q4 2019. Management concluded it was more likely than not that the fair value of these reporting units exceeded their respective carrying amounts, including goodwill. As such, no quantitative testing was required. For the NMGC reporting unit, Emera elected to bypass a qualitative assessment and performed a quantitative impairment assessment using a combination of the income and market approach. This assessment estimated that the fair value of the NMGC reporting unit exceeded its carrying amount, including goodwill. As a result of this assessment, no impairment charges were recognized.

In Q4 2022, the Company elected to bypass a qualitative assessment and performed a quantitative impairment assessment for GBPC, using the income approach, as this reporting unit is sensitive to changes in assumptions due to limited excess of fair value over the carrying value, including goodwill. Although the cash flows of GBPC have not changed significantly compared to previous periods, it was determined that the carrying value, including goodwill, exceeded the fair value, due to an increase in discount rates. The discount rate for the reporting unit was negatively impacted by changes in the macro-economic environment, including the risk-free rate assumption. As a result of this assessment, a goodwill impairment charge of $73 million was recorded in 2022, reducing the GBPC goodwill balance to nil as at December 31, 2022. No impairment was recorded in 2021. For further detail, refer to note 22.

As of December 31, 2022, the Company had goodwill with a total carrying amount of $6,012 million (December 31, 2021 – $5,696 million). The change in the carrying value of goodwill from 2021 to 2022 was a result of the effect of the FX translation of Emera’s foreign affiliates, partially offset by the GBPC impairment.

 

  EMERA 2022 ANNUAL REPORT   61


Management’s Discussion & Analysis

 

LONG-LIVED ASSETS IMPAIRMENT ASSESSMENTS

In accordance with accounting guidance for long-lived assets, the Company assesses whether there has been an impairment of long-lived assets and intangibles when a triggering event occurs, such as a significant market disruption or the sale of a business. The assessment involves comparing the undiscounted expected future cash flows, to the carrying value of the asset. When the undiscounted cash flow analysis indicates a long-lived asset is not recoverable, the amount of the impairment loss is determined by measuring the excess of the carrying amount of the long-lived asset over its estimated fair value.

The Company believes accounting estimates related to asset impairments are critical estimates, as they are highly susceptible to change and the impact of an impairment on reported assets and earnings could be material. Management is required to make assumptions based on expectations regarding the results of operations for significant/indefinite future periods and the current and expected market conditions in such periods. Markets can experience significant uncertainties. Estimates based on the Company’s assumptions relating to future results of operations or other recoverable amounts are based on a combination of historical experience, fundamental economic analysis, observable market activity and independent market studies. The Company’s expectations regarding uses and holding periods of assets are based on internal long-term budgets and projections, which consider external factors and market forces, as of the end of each reporting period. Assumptions made by management are consistent with generally accepted industry approaches and assumptions used for valuation and pricing activities.

As at December 31, 2022, there were no indications of impairment of Emera’s long-lived assets. No impairment charges were recognized in either 2022 or 2021.

INCOME TAXES

Income taxes are determined based on the expected tax treatment of transactions recorded in the consolidated financial statements. In determining income taxes, tax legislation is interpreted in a variety of jurisdictions, the likelihood that deferred tax assets will be realized is assessed and assumptions about the expected timing of the reversal of deferred tax assets and liabilities are made. Uncertainty associated with application of tax statutes and regulations and the outcomes of tax audits and appeals, requires that judgments and estimates be made in the accrual process and in the calculation of effective tax rates. Only income tax benefits that meet the “more likely than not” threshold may be recognized or continue to be recognized. Unrecognized tax benefits are evaluated quarterly and changes are recorded based on new information, including issuance of relevant guidance by the courts or tax authorities and developments in examinations of the Company’s tax returns.

The Company believes the accounting estimates related to income taxes are critical estimates. The realization of deferred tax assets is dependent upon the generation of sufficient taxable income, both operating and capital, in future periods. A change in the estimated valuation allowance could have a material impact on reported assets and results of operations. Administrative actions of the tax authorities, changes in tax law or regulation, and the uncertainty associated with the application of tax statutes and regulations, could change the Company’s estimate of income taxes, including the potential for elimination or reduction of the Company’s ability to realize tax benefits and to utilize deferred tax assets.

ASSET RETIREMENT OBLIGATIONS

Measurement of the fair value of AROs requires the Company to make reasonable estimates concerning the method and timing of settlement associated with the legally obligated costs. There are uncertainties in estimating future asset-retirement costs due to potential events, such as changing legislation or regulations, and advances in remediation technologies. Emera has AROs associated with the remediation of generation, transmission, distribution and pipeline assets.

An ARO represents the fair value of the estimated cash flows necessary to discharge the future obligation using the Company’s credit-adjusted risk-free rate. The amounts are reduced by actual expenditures incurred. Estimated future cash flows are based on completed depreciation studies, remediation reports, prior experience, estimated useful lives, and governmental regulatory requirements. The present value of the liability is recorded and the carrying amount of the related long-lived asset is correspondingly increased. The amount capitalized at inception is depreciated in the same manner as the related long-lived asset. Over time, the liability is accreted to its estimated future value. Accretion expense is included as part of “Depreciation and amortization expense”. Any accretion expense not yet approved by the regulator is recorded in “PP&E” and included in the next depreciation study. Accordingly, changes to the ARO or cost recognition attributable to changes in the factors discussed above, should not impact the results of operations of the Company.

 

62   EMERA 2022 ANNUAL REPORT  


Management’s Discussion & Analysis

 

Some of the Company’s transmission and distribution assets may have conditional AROs which are not recognized in the consolidated financial statements as the fair value of these obligations could not be reasonably estimated given there is insufficient information to do so. A conditional ARO refers to a legal obligation to perform an asset retirement activity in which the timing and/or method of settlement are conditional on a future event that may or may not be within the control of the entity. Management monitors these obligations and a liability is recognized at fair value when an amount can be determined.

As at December 31, 2022, AROs recorded on the balance sheet were $174 million (2021 – $174 million). The Company estimates the undiscounted amount of cash flow required to settle the obligations is approximately $429 million (2021 – $422 million), which will be incurred between 2023 and 2061. The majority of these costs will be incurred between 2028 and 2050.

FINANCIAL INSTRUMENTS

The Company is required to determine the fair value of all derivatives except those which qualify for the normal purchase, normal sale exception. Fair value is the price that would be received for the sale of an asset or paid to transfer a liability in an orderly arms-length transaction between market participants at the measurement date. Fair value measurements are required to reflect assumptions that market participants would use in pricing an asset or liability based on the best available information, including the risks inherent in a particular valuation technique, such as a pricing model, and the risks inherent in the inputs to the model.

LEVEL DETERMINATIONS AND CLASSIFICATIONS

The Company uses Level 1, 2, and 3 classifications in the fair value hierarchy. The fair value measurement of a financial instrument is included in only one of the three levels and is based on the lowest level input significant to the derivation of the fair value. Fair values are determined, directly or indirectly, using inputs that are observable for the asset or liability. Only in limited circumstances does the Company enter into commodity transactions involving non-standard features where market observable data is not available or have contract terms that extend beyond five years.

Changes in Accounting Policies and Practices

The new USGAAP accounting policy that is applicable to, and adopted by the Company in 2022, is described as follows:

FACILITATION OF THE EFFECTS OF REFERENCE RATE REFORM ON FINANCIAL REPORTING

The Company adopted Accounting Standard Update (“ASU”) 2022-06, Reference Rate Reform (Topic 848): Deferral of the Sunset Date of Topic 848 in Q4 2022. The update extends the period of time preparers can utilize the reference rate reform relief guidance issued under ASU 2020-04, which was adopted by the Company in Q4 2020. The guidance in ASU 2022-06 was effective as of the date of issuance and entities may elect to apply the guidance prospectively through to December 31, 2024. The Company has applied the guidance permitted by ASU 2020-04 to certain debt agreements that were amended during the current period. The Company’s transition from reference rates will not have a material impact on the consolidated financial statements.

Future Accounting Pronouncements

The Company considers the applicability and impact of all ASUs issued by the Financial Accounting Standards Board (“FASB”). ASUs issued by FASB, but which are not yet effective, were assessed and determined to be either not applicable to the Company or to have an insignificant impact on the consolidated financial statements.

 

  EMERA 2022 ANNUAL REPORT   63


Management’s Discussion & Analysis

 

Summary of Quarterly Results

 

For the quarter ended

millions of dollars

(except per share amounts)

   Q4
2022
     Q3
2022
     Q2
2022
    Q1
2022
     Q4
2021
     Q3
2021
    Q2
2021
    Q1
2021
 

Operating revenues

   $ 2,358      $ 1,835      $ 1,380     $ 2,015      $ 1,868      $ 1,148     $ 1,137     $ 1,612  
  

 

 

    

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Net income (loss) attributable to common shareholders

   $ 483      $ 167      $ (67 )    $ 362      $ 324      $ (70 )    $ (17 )    $ 273  
  

 

 

    

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Adjusted net income

   $ 249      $ 203      $ 156     $ 242      $ 168      $ 175     $ 137     $ 243  
  

 

 

    

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

EPS – basic

   $ 1.80      $ 0.63      $ (0.25 )    $ 1.38      $ 1.24      $ (0.27 )    $ (0.07 )    $ 1.08  
  

 

 

    

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

EPS – diluted

   $ 1.80      $ 0.63      $ (0.25 )    $ 1.38      $ 1.20      $ (0.27 )    $ (0.07 )    $ 1.08  
  

 

 

    

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Adjusted EPS – basic

   $ 0.93      $ 0.76      $ 0.59     $ 0.92      $ 0.64      $ 0.68     $ 0.54     $ 0.96  
  

 

 

    

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Quarterly operating revenues and adjusted net income are affected by seasonality. The first quarter provides strong earnings contributions due to a significant portion of the Company’s operations being in northeastern North America, where winter is the peak electricity usage season. The third quarter provides strong earnings contributions due to summer being the heaviest electric consumption season in Florida. Seasonal and other weather patterns, as well as the number and severity of storms, can affect demand for energy and the cost of service. Quarterly results could also be affected by items outlined in the “Significant Items Affecting Earnings” section.

 

64   EMERA 2022 ANNUAL REPORT  


 

Management Report

Management’s Responsibility for Financial Reporting

The accompanying consolidated financial statements of Emera Incorporated and the information in this annual report are the responsibility of management and have been approved by the Board of Directors (“Board”).

The consolidated financial statements have been prepared by management in accordance with United States Generally Accepted Accounting Principles. When alternative accounting methods exist, management has chosen those it considers most appropriate in the circumstances. In preparation of these consolidated financial statements, estimates are sometimes necessary when transactions affecting the current accounting period cannot be finalized with certainty until future periods. Management represents that such estimates, which have been properly reflected in the accompanying consolidated financial statements, are based on careful judgments and are within reasonable limits of materiality. Management has determined such amounts on a reasonable basis in order to ensure that the consolidated financial statements are presented fairly in all material respects. Management has prepared the financial information presented elsewhere in the annual report and has ensured that it is consistent with that in the consolidated financial statements.

Emera Incorporated maintains effective systems of internal accounting and administrative controls, consistent with reasonable cost. Such systems are designed to provide reasonable assurance that the financial information is reliable and accurate, and that Emera Incorporated’s assets are appropriately accounted for and adequately safeguarded.

The Board is responsible for ensuring that management fulfils its responsibilities for financial reporting and is ultimately responsible for reviewing and approving the consolidated financial statements. The Board carries out this responsibility principally through its Audit Committee.

The Audit Committee is appointed by the Board, and its members are directors who are not officers or employees of Emera Incorporated. The Audit Committee meets periodically with management, as well as with the internal auditors and with the external auditors, to discuss internal controls over the financial reporting process, auditing matters and financial reporting issues, to satisfy itself that each party is properly discharging its responsibilities, and to review the annual report, the consolidated financial statements and the external auditors’ report. The Audit Committee reports its findings to the Board for consideration when approving the consolidated financial statements for issuance to the shareholders. The Audit Committee also considers, for review by the Board and approval by the shareholders, the appointment of the external auditors.

The consolidated financial statements have been audited by Ernst & Young LLP, the external auditors, in accordance with Canadian Generally Accepted Auditing Standards and with the standards of the Public Company Accounting Oversight Board. Ernst & Young LLP has full and free access to the Audit Committee.

February 23, 2023

 

LOGO       LOGO
“Scott Balfour”       “Gregory Blunden”
President and Chief Executive Officer       Chief Financial Officer

 

  EMERA 2022 ANNUAL REPORT   65


Independent Auditor’s Report

To the Shareholders and the Board of Directors of Emera Incorporated

Opinion

We have audited the consolidated financial statements of Emera Incorporated (the “Company”), which comprise the Consolidated Balance Sheets as at December 31, 2022 and 2021, and the Consolidated Statements of Income, Consolidated Statements of Comprehensive Income, Consolidated Statements of Changes in Equity and Consolidated Statements of Cash Flows for the years then ended, and notes to the consolidated financial statements, including a summary of significant accounting policies.

In our opinion, the accompanying consolidated financial statements present fairly, in all material respects, the consolidated financial position of the Company as at December 31, 2022 and 2021, and the consolidated results of its operations and its consolidated cash flows for the years then ended in accordance with United States generally accepted accounting principles (“USGAAP”).

Basis for opinion

We conducted our audit in accordance with Canadian generally accepted auditing standards. Our responsibilities under those standards are further described in the Auditor’s responsibilities for the audit of the consolidated financial statements section of our report. We are independent of the Company in accordance with the ethical requirements that are relevant to our audit of the consolidated financial statements in Canada, and we have fulfilled our other ethical responsibilities in accordance with these requirements. We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our opinion.

Key audit matters

Key audit matters are those matters that, in our professional judgment, were of most significance in the audit of the consolidated financial statements of the current period. These matters were addressed in the context of the audit of the consolidated financial statements as a whole, and in forming the auditor’s opinion thereon, and we do not provide a separate opinion on these matters. For each matter below, our description of how our audit addressed the matter is provided in that context.

We have fulfilled the responsibilities described in the Auditor’s responsibilities for the audit of the consolidated financial statements section of our report, including in relation to these matters. Accordingly, our audit included the performance of procedures designed to respond to our assessment of the risks of material misstatement of the consolidated financial statements. The results of our audit procedures, including the procedures performed to address the matters below, provide the basis for our audit opinion on the accompanying consolidated financial statements.

 

   Accounting for the effects of rate regulation
Key Audit Matter   

As disclosed in note 7 of the consolidated financial statements, the Company has $3.6 billion in regulatory assets and $2.3 billion in regulatory liabilities. The Company’s rate-regulated subsidiaries are subject to regulation by various federal, state and provincial regulatory authorities in the geographic regions in which they operate. The regulatory rates are designed to recover the prudently incurred costs of providing the regulated products or services and provide a reasonable return on the equity invested or assets, as applicable. In addition to regulatory assets and liabilities, rate regulation impacts multiple financial statement line items, including, but not limited to, property, plant and equipment (“PP&E”), operating revenues and expenses, income taxes, and depreciation expense.

 

Auditing the impact of rate regulation on the Company’s financial statements is complex and highly judgmental due to the significant judgments made by the Company to support its accounting and disclosure for regulatory matters when final regulatory decisions or orders have not yet been obtained or when regulatory formulas are complex. There is also subjectivity involved in assessing the potential impact of future regulatory decisions on the financial statements. Although the Company expects to recover costs from customers through rates, there is a risk that the regulator will not approve full recovery of the costs incurred. The Company’s judgments include making an assessment of the probability of recovery of and return on costs incurred, of the potential disallowance of part of the cost incurred, or of the probable refund to customers through future rates.

 

 

66   EMERA 2022 ANNUAL REPORT  


Independent Auditor’s Report

 

   Accounting for the effects of rate regulation
How Our Audit Addressed the Key Audit Matter    We performed audit procedures that included, amongst others, assessing the Company’s evaluation of the probability of future recovery for regulatory assets, PP&E, and refund of regulatory liabilities by obtaining and reviewing relevant regulatory orders, filings, testimony, hearings and correspondence, and other publicly available information. For regulatory matters for which regulatory decisions or orders have not yet been obtained, we inspected the rate-regulated subsidiaries’ filings for any evidence that might contradict the Company’s assertions, and reviewed other regulatory orders, filings and correspondence for other entities within the same or similar jurisdictions to assess the likelihood of recovery in future rates based on the regulator’s treatment of similar costs under similar circumstances. We obtained and evaluated an analysis from the Company and corroborated that analysis with letters from legal counsel, when appropriate, regarding cost recoveries or future changes in rates. We also assessed the methodology, accuracy and completeness of the Company’s calculations of regulatory asset and liability balances based on provisions and formulas outlined in rate orders and other correspondence with the regulators. We evaluated the Company’s disclosures related to the impacts of rate regulation.
   Fair value measurement and disclosure of derivative financial instruments
Key Audit Matter   

Held-for-trading (“HFT”) derivative assets of $429 million and liabilities of $1,301 million, disclosed in note 15 to the consolidated financial statements, are measured at fair value. The Company recognized $64 million in realized and unrealized gains during the year with respect to HFT derivatives.

 

Auditing the Company’s valuation of HFT derivatives is complex and highly judgmental due to the complexity of the contract terms and valuation models, and the significant estimation required in determining the fair value of the contracts. In determining the fair value of HFT derivatives, significant assumptions about future economic and market assumptions with uncertain outcomes are used, including third-party sourced forward commodity pricing curves based on illiquid markets, internally developed correlation factors and basis differentials. These assumptions have a significant impact on the fair value of the HFT derivatives.

How Our Audit Addressed the Key Audit Matter    We performed audit procedures that included, amongst others, reviewing executed contracts and agreements for the identification of inputs and assumptions impacting the valuation of derivatives. With the support of our valuation specialists, we assessed the methodology and mathematical accuracy of the Company’s valuation models and compared the commodity pricing curves used by the Company to current market and economic data. For the forward commodity pricing curves, we compared the Company’s pricing curves to independently sourced pricing curves. We also assessed the methodology and mathematical accuracy of the Company’s calculations to develop correlation factors and basis differentials. In addition, we assessed whether the fair value hierarchy disclosures in note 16 to the consolidated financial statements were consistent with the source of the significant inputs and assumptions used in determining the fair value of derivatives.

Other information

Management is responsible for the other information. The other information comprises:

 

  •  

Management’s Discussion and Analysis

 

  •  

The information, other than the consolidated financial statements and our auditor’s reports thereon, in the Annual Report

Our opinion on the consolidated financial statements does not cover the other information and we do not express any form of assurance conclusion thereon.

In connection with our audit of the consolidated financial statements, our responsibility is to read the other information, and in doing so, consider whether the other information is materially inconsistent with the consolidated financial statements or our knowledge obtained in the audit or otherwise appears to be materially misstated.

 

  EMERA 2022 ANNUAL REPORT   67


Independent Auditor’s Report

 

We obtained Management’s Discussion & Analysis prior to the date of this auditor’s report. If, based on the work we have performed, we conclude that there is a material misstatement of this other information, we are required to report that fact. We have nothing to report in this regard.

The Annual Report is expected to be made available to us after the date of the auditor’s report. If based on the work we will perform on this other information, we conclude there is a material misstatement of other information, we are required to report that fact to those charged with governance.

Responsibilities of management and those charged with governance for the consolidated financial statements

Management is responsible for the preparation and fair presentation of the consolidated financial statements in accordance with USGAAP, and for such internal control as management determines is necessary to enable the preparation of consolidated financial statements that are free from material misstatement, whether due to fraud or error.

In preparing the consolidated financial statements, management is responsible for assessing the Company’s ability to continue as a going concern, disclosing, as applicable, matters related to going concern and using the going concern basis of accounting unless management either intends to liquidate the Company or to cease operations, or has no realistic alternative but to do so.

Those charged with governance are responsible for overseeing the Company’s financial reporting process.

Auditor’s responsibilities for the audit of the consolidated financial statements

Our objectives are to obtain reasonable assurance about whether the consolidated financial statements as a whole are free from material misstatement, whether due to fraud or error, and to issue an auditor’s report that includes our opinion. Reasonable assurance is a high level of assurance, but is not a guarantee that an audit conducted in accordance with Canadian generally accepted auditing standards will always detect a material misstatement when it exists. Misstatements can arise from fraud or error and are considered material if, individually or in the aggregate, they could reasonably be expected to influence the economic decisions of users taken on the basis of these consolidated financial statements.

As part of an audit in accordance with Canadian generally accepted auditing standards, we exercise professional judgment and maintain professional skepticism throughout the audit. We also:

 

  •  

Identify and assess the risks of material misstatement of the consolidated financial statements, whether due to fraud or error, design and perform audit procedures responsive to those risks, and obtain audit evidence that is sufficient and appropriate to provide a basis for our opinion. The risk of not detecting a material misstatement resulting from fraud is higher than for one resulting from error, as fraud may involve collusion, forgery, intentional omissions, misrepresentations, or the override of internal control.

 

  •  

Obtain an understanding of internal control relevant to the audit in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control.

 

  •  

Evaluate the appropriateness of accounting policies used and the reasonableness of accounting estimates and related disclosures made by management.

 

  •  

Conclude on the appropriateness of management’s use of the going concern basis of accounting and, based on the audit evidence obtained, whether a material uncertainty exists related to events or conditions that may cast significant doubt on the Company’s ability to continue as a going concern. If we conclude that a material uncertainty exists, we are required to draw attention in our auditor’s report to the related disclosures in the consolidated financial statements or, if such disclosures are inadequate, to modify our opinion. Our conclusions are based on the audit evidence obtained up to the date of our auditor’s report. However, future events or conditions may cause the Company to cease to continue as a going concern.

 

  •  

Evaluate the overall presentation, structure and content of the consolidated financial statements, including the disclosures, and whether the consolidated financial statements represent the underlying transactions and events in a manner that achieves fair presentation.

 

  •  

Obtain sufficient appropriate audit evidence regarding the financial information of the entities or business activities within the Company to express an opinion on the consolidated financial statements. We are responsible for the direction, supervision and performance of the group audit. We remain solely responsible for our audit opinion.

 

68   EMERA 2022 ANNUAL REPORT  


Independent Auditor’s Report

 

We communicate with those charged with governance regarding, among other matters, the planned scope and timing of the audit and significant audit findings, including any significant deficiencies in internal control that we identify during our audit.

We also provide those charged with governance with a statement that we have complied with relevant ethical requirements regarding independence, and to communicate with them all relationships and other matters that may reasonably be thought to bear on our independence, and where applicable, related safeguards.

From the matters communicated with those charged with governance, we determine those matters that were of most significance in the audit of the consolidated financial statements of the current period and are therefore the key audit matters. We describe these matters in our auditor’s report unless law or regulation precludes public disclosure about the matter or when, in extremely rare circumstances, we determine that a matter should not be communicated in our report because the adverse consequences of doing so would reasonably be expected to outweigh the public interest benefits of such communication.

The engagement partner on the audit resulting in this independent auditor’s report is Tracy Brennan.

 

LOGO
Chartered Professional Accountants
Halifax, Canada
February 23, 2023

 

  EMERA 2022 ANNUAL REPORT   69


Report of Independent Registered Public Accounting Firm

To the Shareholders and the Board of Directors of Emera Incorporated

Opinion on the Consolidated Financial Statements

We have audited the accompanying Consolidated Balance Sheets of Emera Incorporated (the “Company“) as of December 31, 2022 and 2021, the related Consolidated Statements of Income, Consolidated Statements of Comprehensive Income, Consolidated Statements of Changes in Equity and Consolidated Statements of Cash Flows for the years then ended, and the related notes (collectively referred to as the “consolidated financial statements“). In our opinion, the consolidated financial statements present fairly, in all material respects, the consolidated financial position of the Company as of December 31, 2022 and 2021, and the consolidated results of its operations and its consolidated cash flows for each of the two years in the period ended December 31, 2022, in conformity with United States generally accepted accounting principles.

Basis for Opinion

These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (“PCAOB”) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.

Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.

 

70   EMERA 2022 ANNUAL REPORT  


Report of Independent Registered Public Accounting Firm

 

Critical Audit Matters

The critical audit matters communicated below are matters arising from the current period audit of the financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.

 

   Accounting for the effects of rate regulation
Description of the Matter   

As disclosed in note 7 of the consolidated financial statements, the Company has $3.6 billion in regulatory assets and $2.3 billion in regulatory liabilities. The Company’s rate-regulated subsidiaries are subject to regulation by various federal, state and provincial regulatory authorities in the geographic regions in which they operate. The regulatory rates are designed to recover the prudently incurred costs of providing the regulated products or services and provide a reasonable return on the equity invested or assets, as applicable. In addition to regulatory assets and liabilities, rate regulation impacts multiple financial statement line items, including, but not limited to, PP&E, operating revenues and expenses, income taxes, and depreciation expense.

 

Auditing the impact of rate regulation on the Company’s financial statements is complex and highly judgmental due to the significant judgments made by the Company to support its accounting and disclosure for regulatory matters when final regulatory decisions or orders have not yet been obtained or when regulatory formulas are complex. There is also subjectivity involved in assessing the potential impact of future regulatory decisions on the financial statements. Although the Company expects to recover costs from customers through rates, there is a risk that the regulator will not approve full recovery of the costs incurred. The Company’s judgments include making an assessment of the probability of recovery of and return on costs incurred, of the potential disallowance of part of the cost incurred, or of the probable refund to customers through future rates.

How We Addressed the Matter in Our Audit    We performed audit procedures that included, amongst others, assessing the Company’s evaluation of the probability of future recovery for regulatory assets, PP&E, and refund of regulatory liabilities by obtaining and reviewing relevant regulatory orders, filings, testimony, hearings and correspondence, and other publicly available information. For regulatory matters for which regulatory decisions or orders have not yet been obtained, we inspected the rate-regulated subsidiaries’ filings for any evidence that might contradict the Company’s assertions, and reviewed other regulatory orders, filings and correspondence for other entities within the same or similar jurisdictions to assess the likelihood of recovery in future rates based on the regulator’s treatment of similar costs under similar circumstances. We obtained and evaluated an analysis from the Company and corroborated that analysis with letters from legal counsel, when appropriate, regarding cost recoveries or future changes in rates. We also assessed the methodology, accuracy and completeness of the Company’s calculations of regulatory asset and liability balances based on provisions and formulas outlined in rate orders and other correspondence with the regulators. We evaluated the Company’s disclosures related to the impacts of rate regulation.

 

  EMERA 2022 ANNUAL REPORT   71


Report of Independent Registered Public Accounting Firm

 

   Fair value measurement of derivative financial instruments
Description of the Matter   

Held-for-trading (“HFT”) derivative assets of $429 million and liabilities of $1,301 million, disclosed in note 15 to the consolidated financial statements, are measured at fair value. The Company recognized $64 million in realized and unrealized gains during the year with respect to HFT derivatives.

 

Auditing the Company’s valuation of HFT derivatives is complex and highly judgmental due to the complexity of the contract terms and valuation models, and the significant estimation required in determining the fair value of the contracts. In determining the fair value of HFT derivatives, significant assumptions about future economic and market assumptions with uncertain outcomes are used, including third-party sourced forward commodity pricing curves based on illiquid markets, internally developed correlation factors and basis differentials. These assumptions have a significant impact on the fair value of the HFT derivatives.

How We Addressed the Matter in Our Audit    We performed audit procedures that included, amongst others, reviewing executed contracts and agreements for the identification of inputs and assumptions impacting the valuation of derivatives. With the support of our valuation specialists, we assessed the methodology and mathematical accuracy of the Company’s valuation models and compared the commodity pricing curves used by the Company to current market and economic data. For the forward commodity pricing curves, we compared the Company’s pricing curves to independently sourced pricing curves. We also assessed the methodology and mathematical accuracy of the Company’s calculations to develop correlation factors and basis differentials. In addition, we assessed whether the fair value hierarchy disclosures in note 16 to the consolidated financial statements were consistent with the source of the significant inputs and assumptions used in determining the fair value of derivatives.

 

LOGO
Chartered Professional Accountants
We have served as the Company’s auditor since 1998.
Halifax, Canada
February 23, 2023

 

 

72   EMERA 2022 ANNUAL REPORT  


Consolidated Financial Statements

 

Emera Incorporated

Consolidated Statements of Income

 

For the    Year ended December 31  

millions of dollars (except per share amounts)

   2022      2021  

Operating revenues

     

Regulated electric

   $ 5,473      $ 4,665  

Regulated gas

     1,681        1,261  

Non-regulated

     434        (161 ) 
  

 

 

    

 

 

 

Total operating revenues (note 6)

     7,588        5,765  
  

 

 

    

 

 

 

Operating expenses

     

Regulated fuel for generation and purchased power

     2,171        1,763  

Regulated cost of natural gas

     800        472  

Operating, maintenance and general expenses (“OM&G”)

     1,596        1,368  

Provincial, state, and municipal taxes

     367        330  

Depreciation and amortization

     952        902  

Impairment charges (note 22)

     73        —    
  

 

 

    

 

 

 

Total operating expenses

     5,959        4,835  
  

 

 

    

 

 

 

Income from operations

     1,629        930  
  

 

 

    

 

 

 

Income from equity investments (note 8)

     129        143  

Other income, net (note 9)

     145        93  

Interest expense, net

     709        611  
  

 

 

    

 

 

 

Income before provision for income taxes

     1,194        555  
  

 

 

    

 

 

 

Income tax expense (recovery) (note 10)

     185        (6 ) 
  

 

 

    

 

 

 

Net income

     1,009        561  
  

 

 

    

 

 

 

Non-controlling interest in subsidiaries

     1        1  

Preferred stock dividends

     63        50  
  

 

 

    

 

 

 

Net income attributable to common shareholders

   $ 945      $ 510  
  

 

 

    

 

 

 

Weighted average shares of common stock outstanding (in millions) (note 12)

     

Basic

     266        257  

Diluted

     266        258  
  

 

 

    

 

 

 

Earnings per common share (note 12 )

     

Basic

   $ 3.56      $ 1.98  

Diluted

   $ 3.55      $ 1.98  
  

 

 

    

 

 

 

Dividends per common share declared

   $ 2.6775      $ 2.5750  
  

 

 

    

 

 

 

The accompanying notes are an integral part of these consolidated financial statements.

 

  EMERA 2022 ANNUAL REPORT   73


Consolidated Financial Statements

 

Emera Incorporated

Consolidated Statements of Comprehensive Income

 

For the    Year ended December 31  

millions of dollars

   2022     2021  

Net income

   $ 1,009     $ 561  
  

 

 

   

 

 

 

Other comprehensive income (loss), net of tax

    

Foreign currency translation adjustment (1)

     629       (42 ) 

Unrealized (losses) gains on net investment hedges (2) (3)

     (97 )      5  

Cash flow hedges

    

Net derivative gains (4)

     —         18  

Less: reclassification adjustment for gains included in income

     (2 )      (1 ) 

Net effects of cash flow hedges

     (2 )      17  

Unrealized losses on available-for-sale investment

     (1 )      —    

Net change in unrecognized pension and post-retirement benefit obligation (5)

     24       124  

Other comprehensive income (loss) (6)

     553       104  
  

 

 

   

 

 

 

Comprehensive income

     1,562       665  
  

 

 

   

 

 

 

Comprehensive income attributable to non-controlling interest

     1       1  
  

 

 

   

 

 

 

Comprehensive Income of Emera Incorporated

   $ 1,561     $ 664  
  

 

 

   

 

 

 

The accompanying notes are an integral part of these consolidated financial statements.

 

(1)

Net of tax expense of $7 million for the year ended December 31, 2022 (2021 – $5 million expense).

(2)

The Company has designated $1.2 billion United States dollar (USD) denominated Hybrid Notes as a hedge of the foreign currency exposure of its net investment in USD denominated operations.

(3)

Net of tax recovery of $6 million for the year ended December 31, 2022 (2021 – $1 million expense).

(4)

Net of tax recovery of $1 million for the year ended December 31, 2022 (2021 – $6 million expense).

(5)

Net of tax expense of $1 million for the year ended December 31, 2022 (2021 – $2 million expense).

(6)

Net of tax expense of $1 million for the year ended December 31, 2022 (2021 – $14 million expense).

 

74   EMERA 2022 ANNUAL REPORT  


Consolidated Financial Statements

 

Emera Incorporated

Consolidated Balance Sheets

 

As at

millions of dollars

   December 31
2022
     December 31
2021
 

Assets

     

Current assets

     

Cash and cash equivalents

   $ 310      $ 394  

Restricted cash (note 32)

     22        23  

Inventory (note 14)

     769        538  

Derivative instruments (notes 15 and 16)

     296        195  

Regulatory assets (note 7)

     602        253  

Receivables and other current assets (note 18)

     2,897        1,733  
  

 

 

    

 

 

 
     4,896        3,136  
  

 

 

    

 

 

 

Property, plant and equipment (“PP&E”), net of accumulated depreciation and amortization of $9,574 and $8,739, respectively (note 20)

     22,996        20,353  
  

 

 

    

 

 

 

Other assets

     

Deferred income taxes (note 10)

     237        295  

Derivative instruments (notes 15 and 16)

     100        106  

Regulatory assets (note 7)

     3,018        2,313  

Net investment in direct finance and sales type leases (note 19)

     604        503  

Investments subject to significant influence (note 8)

     1,418        1,382  

Goodwill (note 22)

     6,012        5,696  

Other long-term assets (note 32)

     461        460  
  

 

 

    

 

 

 
     11,850        10,755  
  

 

 

    

 

 

 

Total assets

   $ 39,742      $ 34,244  
  

 

 

    

 

 

 

The accompanying notes are an integral part of these consolidated financial statements.

 

  EMERA 2022 ANNUAL REPORT   75


Consolidated Financial Statements

 

Emera Incorporated

Consolidated Balance Sheets (continued)

 

As at

millions of dollars

   December 31
2022
     December 31
2021
 

Liabilities and Equity

     

Current liabilities

     

Short-term debt (note 23)

   $ 2,726      $ 1,742  

Current portion of long-term debt (note 25)

     574        462  

Accounts payable

     2,025        1,485  

Derivative instruments (notes 15 and 16)

     888        533  

Regulatory liabilities (notes 7 and 32)

     495        290  

Other current liabilities (note 24)

     579        366  
  

 

 

    

 

 

 
     7,287        4,878  
  

 

 

    

 

 

 

Long-term liabilities

     

Long-term debt (note 25)

     15,744        14,196  

Deferred income taxes (note 10)

     2,196        1,868  

Derivative instruments (notes 15 and 16)

     190        149  

Regulatory liabilities (note 7)

     1,778        1,765  

Pension and post-retirement liabilities (note 21)

     281        370  

Other long-term liabilities (notes 8 and 26)

     825        868  
  

 

 

    

 

 

 
     21,014        19,216  
  

 

 

    

 

 

 

Equity

     

Common stock (note 11)

     7,762        7,242  

Cumulative preferred stock (note 28)

     1,422        1,422  

Contributed surplus

     81        79  

Accumulated other comprehensive income (“AOCI”) (note 13)

     578        25  

Retained earnings

     1,584        1,348  
  

 

 

    

 

 

 

Total Emera Incorporated equity

     11,427        10,116  

Non-controlling interest in subsidiaries (note 29)

     14        34  
  

 

 

    

 

 

 

Total equity

     11,441        10,150  
  

 

 

    

 

 

 

Total liabilities and equity

   $ 39,742      $ 34,244  
  

 

 

    

 

 

 

Commitments and contingencies (note 27)

The accompanying notes are an integral part of these consolidated financial statements.

Approved on behalf of the Board of Directors

 

LOGO     LOGO
“M. Jacqueline Sheppard”     “Scott Balfour”
Chair of the Board     President and Chief Executive Officer

 

76   EMERA 2022 ANNUAL REPORT  


Consolidated Financial Statements

 

Emera Incorporated

Consolidated Statements of Cash Flows

 

For the    Year ended December 31  

millions of dollars

   2022     2021  

Operating activities

    

Net income

   $ 1,009     $ 561  

Adjustments to reconcile net income to net cash provided by operating activities:

    

Depreciation and amortization

     959       915  

Income from equity investments, net of dividends

     (61 )      (69 ) 

Allowance for equity funds used during construction

     (52 )      (61 ) 

Deferred income taxes, net

     152       (37 ) 

Net change in pension and post-retirement liabilities

     (48 )      (23 ) 

Fuel adjustment mechanism (“FAM”)

     (162 )      (166 ) 

Net change in fair value of derivative instruments

     206       404  

Net change in regulatory assets and liabilities

     (471 )      (176 ) 

Net change in capitalized transportation capacity

     (445 )      (107 ) 

Impairment charge

     73       —    

Other operating activities, net

     (13 )      96  

Changes in non-cash working capital (note 30)

     (234 )      (152 ) 
  

 

 

   

 

 

 

Net cash provided by operating activities

     913       1,185  
  

 

 

   

 

 

 

Investing activities

    

Additions to PP&E

     (2,596 )      (2,359 ) 

Other investing activities

     27       27  
  

 

 

   

 

 

 

Net cash used in investing activities

     (2,569 )      (2,332 ) 
  

 

 

   

 

 

 

Financing activities

    

Change in short-term debt, net

     1,028       (155 ) 

Proceeds from short-term debt with maturities greater than 90 days

     544       640  

Repayment of short-term debt with maturities greater than 90 days

     (680 )      (377 ) 

Proceeds from long-term debt, net of issuance costs

     784       2,554  

Retirement of long-term debt

     (367 )      (1,660 ) 

Net proceeds under committed credit facilities

     511       82  

Issuance of common stock, net of issuance costs

     277       317  

Issuance of preferred stock, net of issuance costs (note 28)

     —         416  

Dividends on common stock

     (472 )      (443 ) 

Dividends on preferred stock

     (63 )      (50 ) 

Other financing activities

     (7 )      (13 ) 
  

 

 

   

 

 

 

Net cash provided by financing activities

     1,555       1,311  
  

 

 

   

 

 

 

Effect of exchange rate changes on cash, cash equivalents, and restricted cash

     16       (1 ) 
  

 

 

   

 

 

 

Net increase (decrease) in cash, cash equivalents, and restricted cash

     (85 )      163  

Cash, cash equivalents, and restricted cash, beginning of year

     417       254  
  

 

 

   

 

 

 

Cash, cash equivalents, and restricted cash, end of year

   $ 332     $ 417  
  

 

 

   

 

 

 

Cash, cash equivalents and restricted cash consists of:

    

Cash

   $ 302     $ 237  

Short-term investments

     8       157  

Restricted cash

     22       23  
  

 

 

   

 

 

 

Cash, cash equivalents and restricted cash

   $ 332     $ 417  
  

 

 

   

 

 

 

Supplementary Information to Consolidated Statements of Cash Flows (note 30)

The accompanying notes are an integral part of these consolidated financial statements.

 

  EMERA 2022 ANNUAL REPORT   77


Consolidated Financial Statements

 

Emera Incorporated

Consolidated Statements of Changes in Equity

 

     Common
Stock
     Preferred
Stock
     Contributed
Surplus
     AOCI     Retained
Earnings
    Non-
Controlling
Interest
    Total Equity  

millions of dollars

      

Balance, December 31, 2021

   $ 7,242      $ 1,422      $ 79      $ 25     $ 1,348     $ 34     $ 10,150  

Net income of Emera Inc.

     —          —          —          —         1,008       1       1,009  

Other comprehensive income, net of tax expense of $1 million

     —          —          —          553       —         —         553  

Dividends declared on preferred stock (note 28)

     —          —          —          —         (63 )      —         (63 ) 

Dividends declared on common stock ($2.6775/share)

     —          —          —          —         (709 )      —         (709 ) 

Issued under the at-the-market program (”ATM“), net of after-tax issuance costs

     248        —          —          —         —         —         248  

Issued under the Dividend Reinvestment Program (“DRIP”), net of discount

     238        —          —          —         —         —         238  

Senior management stock options exercised and Employee Share Purchase Plan

     34        —          2        —         —         —         36  

Disposal of non-controlling interest of Dominica Electricity Services Ltd (”Domlec“)

     —          —          —          —         —         (20 )      (20 ) 

Other

     —          —          —          —         —         (1 )      (1 ) 
  

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Balance, December 31, 2022

   $ 7,762      $ 1,422      $ 81      $ 578     $ 1,584     $ 14     $ 11,441  
  

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Balance, December 31, 2020

   $ 6,705      $ 1,004      $ 79      $ (79 )    $ 1,495     $ 34     $ 9,238  

Net income of Emera Inc.

     —          —          —          —         560       1       561  

Other comprehensive income, net of tax expense of $14 million

     —          —          —          104       —         —         104  

Issuance of preferred stock, net of after-tax issuance costs

     —          418        —          —         —         —         418  

Dividends declared on preferred stock (note 28)

     —          —          —          —         (50 )      —         (50 ) 

Dividends declared on common stock ($2.5750/share)

     —          —          —          —         (657 )      —         (657 ) 

Issued under the ATM, net of after- tax issuance costs

     284        —          —          —         —         —         284  

Issued under the DRIP, net of discount

     215        —          —          —         —         —         215  

Senior management stock options exercised and Employee Share Purchase Plan

     38        —          —          —         —         —         38  

Other

     —          —          —          —         —         (1 )      (1 ) 
  

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Balance, December 31, 2021

   $ 7,242      $ 1,422      $ 79      $ 25     $ 1,348     $ 34     $ 10,150  
  

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

The accompanying notes are an integral part of these consolidated financial statements.

 

78   EMERA 2022 ANNUAL REPORT  


Emera Incorporated

Notes to the Consolidated Financial Statements

As at December 31, 2022 and 2021

1. Summary of Significant Accounting Policies

NATURE OF OPERATIONS

Emera Incorporated (“Emera” or the “Company”) is an energy and services company which invests in electricity generation, transmission and distribution, and gas transmission and distribution.

At December 31, 2022, Emera’s reportable segments include the following:

 

  •  

Florida Electric Utility, which consists of Tampa Electric, a vertically integrated regulated electric utility, serving approximately 827,000 customers in West Central Florida;

 

  •  

Canadian Electric Utilities, which includes:

 

  •  

Nova Scotia Power Inc. (“NSPI”), a vertically integrated regulated electric utility and the primary electricity supplier in Nova Scotia, serving approximately 541,000 customers; and

 

  •  

Emera Newfoundland & Labrador Holdings Inc. (“ENL”), consisting of two transmission investments related to an 824 megawatt (“MW”) hydroelectric generating facility at Muskrat Falls on the Lower Churchill River in Labrador, owned and constructed by Nalcor Energy. ENL’s two investments are:

 

  •  

a 100 per cent investment in NSP Maritime Link Inc. (“NSPML”), which developed the Maritime Link Project, a $1.8 billion (including allowance for funds used during construction (“AFUDC”)) transmission project; and

 

  •  

a 31.9 per cent investment in the partnership capital of Labrador-Island Link Limited Partnership (“LIL”), a $3.7 billion electricity transmission project in Newfoundland and Labrador.

 

  •  

Gas Utilities and Infrastructure, which includes:

 

  •  

Peoples Gas System (“PGS”), a regulated gas distribution utility, serving approximately 468,000 customers across Florida;

 

  •  

New Mexico Gas Company, Inc. (“NMGC”), a regulated gas distribution utility, serving approximately 545,000 customers in New Mexico;

 

  •  

Emera Brunswick Pipeline Company Limited (“Brunswick Pipeline”), a 145-kilometre pipeline delivering re-gasified liquefied natural gas (“LNG”) from Saint John, New Brunswick to the United States border under a 25-year firm service agreement with Repsol Energy North America Canada Partnership, which expires in 2034;

 

  •  

SeaCoast Gas Transmission, LLC (“SeaCoast”), a regulated intrastate natural gas transmission company in Florida; and

 

  •  

a 12.9 per cent interest in Maritimes & Northeast Pipeline (“M&NP”), a 1,400-kilometre pipeline that transports natural gas throughout markets in Atlantic Canada and the northeastern United States.

 

  •  

Other Electric Utilities, which includes Emera (Caribbean) Incorporated (“ECI”), a holding company with regulated electric utilities that include:

 

  •  

The Barbados Light & Power Company Limited (“BLPC”), a vertically integrated regulated electric utility on the island of Barbados, serving approximately 133,000 customers;

 

  •  

Grand Bahama Power Company Limited (“GBPC”), a vertically integrated regulated electric utility on Grand Bahama Island, serving approximately 19,000 customers; and

 

  •  

a 19.5 per cent equity interest in St. Lucia Electricity Services Limited (“Lucelec”), a vertically integrated regulated electric utility on the island of St. Lucia.

 

  EMERA 2022 ANNUAL REPORT   79


Notes to the Consolidated Financial Statements

 

  •  

Emera’s other reportable segment includes investments in energy-related non-regulated companies which includes:

 

  •  

Emera Energy, which consists of:

 

  •  

Emera Energy Services (“EES”), a physical energy business that purchases and sells natural gas and electricity and provides related energy asset management services;

 

  •  

Brooklyn Power Corporation (“Brooklyn Energy”), a 30 MW biomass co-generation electricity facility in Brooklyn, Nova Scotia; and

 

  •  

a 50.0 per cent joint venture interest in Bear Swamp Power Company LLC (“Bear Swamp”), a 660 MW pumped storage hydroelectric facility in northwestern Massachusetts.

 

  •  

Emera US Finance LP (“Emera Finance”) and TECO Finance, Inc. (“TECO Finance”), financing subsidiaries of Emera;

 

  •  

Emera Technologies LLC, a wholly owned technology company focused on finding ways to deliver renewables and resilient energy to customers;

 

  •  

Emera US Holdings Inc., a wholly owned holding company for certain of Emera’s assets located in the United States; and

 

  •  

Other investments.

BASIS OF PRESENTATION

These consolidated financial statements are prepared and presented in accordance with United States Generally Accepted Accounting Principles (“USGAAP”) and in the opinion of management, include all adjustments that are of a recurring nature and necessary to fairly state the financial position of Emera.

All dollar amounts are presented in Canadian dollars (“CAD”), unless otherwise indicated.

PRINCIPLES OF CONSOLIDATION

These consolidated financial statements include the accounts of Emera Incorporated, its majority-owned subsidiaries, and a variable interest entity (“VIE”) in which Emera is the primary beneficiary. Emera uses the equity method of accounting to record investments in which the Company has the ability to exercise significant influence, and for VIEs in which Emera is not the primary beneficiary.

The Company performs ongoing analysis to assess whether it holds any VIEs or whether any reconsideration events have arisen with respect to existing VIEs. To identify potential VIEs, management reviews contractual and ownership arrangements such as leases, long-term purchase power agreements, tolling contracts, guarantees, jointly owned facilities and equity investments. VIEs of which the Company is deemed the primary beneficiary must be consolidated. The primary beneficiary of a VIE has both the power to direct the activities of the entity that most significantly impacts its economic performance and the obligation to absorb losses of the entity that could potentially be significant to the entity. In circumstances where Emera has an investment in a VIE but is not deemed the primary beneficiary, the VIE is accounted for using the equity method. For further details on VIEs, refer to note 32.

Intercompany balances and transactions have been eliminated on consolidation, except for the net profit on certain transactions between certain non-regulated and regulated entities in accordance with accounting standards for rate-regulated entities. The net profit on these transactions, which would be eliminated in the absence of the accounting standards for rate-regulated entities, is recorded in non-regulated operating revenues. An offset is recorded to PP&E, regulatory assets, regulated fuel for generation and purchased power, or OM&G, depending on the nature of the transaction.

USE OF MANAGEMENT ESTIMATES

The preparation of consolidated financial statements in accordance with USGAAP requires management to make estimates and assumptions. These may affect the reported amounts of assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during the reporting periods. Significant areas requiring use of management estimates relate to rate-regulated assets and liabilities, accumulated reserve for cost of removal, pension and post-retirement benefits, unbilled revenue, useful lives for depreciable assets, goodwill and long-lived assets impairment assessments, income taxes, asset retirement obligations (“ARO”), and valuation of financial instruments. Management evaluates the Company’s estimates on an ongoing basis based upon historical experience, current and expected conditions and assumptions believed to be reasonable at the time the assumption is made, with any adjustments recognized in income in the year they arise.

 

80   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

REGULATORY MATTERS

Regulatory accounting applies where rates are established by, or subject to approval by, an independent third-party regulator. The rates are designed to recover prudently incurred costs of providing the regulated products or services and provide an opportunity for a reasonable rate of return on invested capital, as applicable. For further detail, refer to note 7.

FOREIGN CURRENCY TRANSLATION

Monetary assets and liabilities denominated in foreign currencies are converted to CAD at the rates of exchange prevailing at the balance sheet date. The resulting differences between the translation at the original transaction date and the balance sheet date are included in income.

Assets and liabilities of foreign operations whose functional currency is not the Canadian dollar are translated using exchange rates in effect at the balance sheet date and the results of operations at the average exchange rate in effect for the period. The resulting exchange gains and losses on the assets and liabilities are deferred on the balance sheet in AOCI.

The Company designates certain USD denominated debt held in CAD functional currency companies as hedges of net investments in USD denominated foreign operations. The change in the carrying amount of these investments, measured at the exchange rates in effect at the balance sheet date is recorded in Other Comprehensive Income (“OCI”).

REVENUE RECOGNITION

Regulated Electric and Gas Revenue:

Electric and gas revenues, including energy charges, demand charges, basic facilities charges and clauses and riders, are recognized when obligations under the terms of a contract are satisfied, which is when electricity and gas are delivered to customers over time as the customer simultaneously receives and consumes the benefits. Electric and gas revenues are recognized on an accrual basis and include billed and unbilled revenues. Revenues related to the sale of electricity and gas are recognized at rates approved by the respective regulator and recorded based on metered usage, which occurs on a periodic, systematic basis, generally monthly or bi-monthly. At the end of each reporting period, the electricity and gas delivered to customers, but not billed, is estimated and the corresponding unbilled revenue is recognized. The Company’s estimate of unbilled revenue at the end of the reporting period is calculated by estimating the number of megawatt hours (“MWh”) or therms delivered to customers at the established rates expected to prevail in the upcoming billing cycle. This estimate includes assumptions as to the pattern of energy demand, weather, line losses and inter-period changes to customer classes.

Non-regulated Revenue:

Marketing and trading margins are comprised of Emera Energy’s corresponding purchases and sales of natural gas and electricity, pipeline capacity costs and energy asset management revenues. Revenues are recorded when obligations under the terms of the contract are satisfied and are presented on a net basis, reflecting the nature of the contractual relationships with customers and suppliers.

Energy sales are recognized when obligations under the terms of the contracts are satisfied, which is when electricity is delivered to customers over time.

Other non-regulated revenues are recorded when obligations under the terms of the contract are satisfied.

Other:

Sales, value add, and other taxes, except for gross receipts taxes discussed below, collected by the Company concurrent with revenue-producing activities are excluded from revenue.

LEASES

The Company determines whether a contract contains a lease at inception by evaluating if the contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration.

Emera has leases with independent power producers (“IPP”) and other utilities with annual requirements to purchase wind and hydro energy over varying contract lengths that are classified as finance leases. These finance leases are not recorded on the Company’s Consolidated Balance Sheets, as payments associated with the leases are variable in nature and there are no minimum fixed lease payments. Lease expense associated with these leases is recorded as “Regulated fuel for generation and purchased power” on the Consolidated Statements of Income.

 

  EMERA 2022 ANNUAL REPORT   81


Notes to the Consolidated Financial Statements

 

Operating lease liabilities and right-of-use assets are recognized on the Consolidated Balance Sheets based on the present value of the future minimum lease payments over the lease term at commencement date. As most of Emera’s leases do not provide an implicit rate, the incremental borrowing rate at commencement of the lease is used in determining the present value of future lease payments. Lease expense is recognized on a straight-line basis over the lease term and is recorded as “Operating, maintenance and general” on the Consolidated Statements of Income.

Where the Company is the lessor, a lease is a sales-type lease if certain criteria are met and the arrangement transfers control of the underlying asset to the lessee. For arrangements where the criteria are met due to the presence of a third-party residual value guarantee, the lease is a direct financing lease.

For direct finance leases, a net investment in the lease is recorded that consists of the sum of the minimum lease payments and residual value, net of estimated executory costs and unearned income. The difference between the gross investment and the cost of the leased item is recorded as unearned income at the inception of the lease. Unearned income is recognized in income over the life of the lease using a constant rate of interest equal to the internal rate of return on the lease.

For sales-type leases, the accounting is similar to the accounting for direct finance leases, however the difference between the fair value and the carrying value of the leased item is recorded at lease commencement rather than deferred over the term of the lease.

Emera has certain contractual agreements that include lease and non-lease components, which management has elected to account for as a single lease component.

FRANCHISE FEES AND GROSS RECEIPTS

Tampa Electric and PGS recover from customers certain costs incurred, on a dollar-for-dollar basis, through prices approved by the Florida Public Service Commission (“FPSC”). The amounts included in customers’ bills for franchise fees and gross receipt taxes are included as “Regulated electric” and “Regulated gas” revenues in the Consolidated Statements of Income. Franchise fees and gross receipt taxes payable by Tampa Electric and PGS are included as an expense on the Consolidated Statements of Income in “Provincial, state and municipal taxes”.

NMGC is an agent in the collection and payment of franchise fees and gross receipt taxes and is not required by a tariff to present the amounts on a gross basis. Therefore, NMGC’s franchise fees and gross receipt taxes are presented net with no line item impact on the Consolidated Statements of Income.

PROPERTY, PLANT AND EQUIPMENT

PP&E are recorded at original cost, including AFUDC or capitalized interest, net of contributions received in aid of construction.

The cost of additions, including betterments and replacements of units are included in “Property, plant and equipment”. When units of regulated PP&E are replaced, renewed or retired, their cost, plus removal or disposal costs, less salvage proceeds, is charged to accumulated depreciation, with no gain or loss reflected in income. Where a disposition of non-regulated PP&E occurs, gains and losses are included in income as the dispositions occur.

The cost of PP&E represents the original cost of materials, contracted services, direct labour, AFUDC for regulated property or interest for non-regulated property, ARO, and overhead attributable to the capital project. Overhead includes corporate costs such as finance, information technology and labour costs, along with other costs related to support functions, employee benefits, insurance, procurement, and fleet operating and maintenance. Expenditures for project development are capitalized if they are expected to have a future economic benefit.

Normal maintenance projects and major maintenance projects that do not increase the overall life of the related assets are expensed as incurred. When a major maintenance project increases the life or value of the underlying asset, the cost is capitalized.

Depreciation is determined by the straight-line method, based on the estimated remaining service lives of the depreciable assets in each functional class of depreciable property. For some of Emera’s rate-regulated subsidiaries, depreciation is calculated using the group remaining life method, which is applied to the average investment, adjusted for anticipated costs of removal less salvage, in functional classes of depreciable property. The service lives of regulated assets require regulatory approval.

 

82   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

Intangible assets, which are included in “Property, plant and equipment,” consist primarily of computer software and land rights. Amortization is determined by the straight-line method, based on the estimated remaining service lives of the asset in each category. For some of Emera’s rate-regulated subsidiaries, amortization is calculated using the amortizable life method which is applied to the net book value to date over the remaining life of those assets. The service lives of regulated intangible assets require regulatory approval.

GOODWILL

Goodwill is calculated as the excess of the purchase price of an acquired entity over the estimated fair values of identifiable assets acquired and liabilities assumed at the acquisition date. Goodwill is carried at initial cost less any write-down for impairment and is adjusted for the impact of foreign exchange. Under the applicable accounting guidance, goodwill is subject to assessment for impairment at the reporting unit level annually, or if an event or change in circumstances indicates that the fair value of a reporting unit may be below its carrying value. When assessing goodwill for impairment, the Company has the option of first performing a qualitative assessment to determine whether a quantitative assessment is necessary. In performing a qualitative assessment management considers, among other factors, macroeconomic conditions, industry and market considerations and overall financial performance.

If the Company performs the qualitative assessment and determines that it is more likely than not that its fair value is less than its carrying amount, or if the Company chooses to bypass the qualitative assessment, a quantitative test is performed. The quantitative test compares the fair value of the reporting unit to its carrying amount, including goodwill. If the carrying amount of the reporting unit exceeds its fair value, an impairment loss is recorded. Management estimates the fair value of the reporting unit by using the income approach, or a combination of the income and market approach. The income approach is applied using a discounted cash flow analysis which relies on management’s best estimate of the reporting units’ projected cash flows. The analysis includes an estimate of terminal values based on these expected cash flows using a methodology which derives a valuation using an assumed perpetual annuity based on the reporting unit’s residual cash flows. The discount rate used is a market participant rate based on a peer group of publicly traded comparable companies and represents the weighted average cost of capital of comparable companies. When using the market approach, management estimates fair value based on comparable companies and transactions within the utility industry. Significant assumptions used in estimating the fair value include discount and growth rates, rate case assumptions including future cost of capital, valuation of the reporting units’ net operating loss (“NOL”) and projected operating and capital cash flows. Adverse changes in these assumptions could result in a future material impairment of the goodwill assigned to Emera’s reporting units.

As of December 31, 2022, $6,009 million of Emera’s goodwill represents the excess of the acquisition purchase price for TECO Energy (Tampa Electric, PGS and NMGC reporting units) over the fair values assigned to identifiable assets acquired and liabilities assumed. In Q4 2022, qualitative assessments were performed for Tampa Electric and PGS given the significant excess of fair value over carrying amounts calculated during the last quantitative test in Q4 2019. Management concluded it was more likely than not that the fair value of these reporting units exceeded their respective carrying amounts, including goodwill. As such, no quantitative testing was required. For the NMGC reporting unit, Emera elected to bypass a qualitative assessment and performed a quantitative impairment assessment using a combination of the income and market approach. This assessment estimated that the fair value of the NMGC reporting unit exceeded its carrying amount, including goodwill. As a result of this assessment, no impairment charges were recognized.

In Q4 2022, the Company elected to bypass a qualitative assessment and performed a quantitative impairment assessment for GBPC, using the income approach, as this reporting unit is sensitive to changes in assumptions due to limited excess of fair value over the carrying value, including goodwill. Although the cash flows of GBPC have not changed significantly compared to previous periods, it was determined that the carrying amount, including goodwill, exceeded the fair value, due to an increase in discount rates. The discount rate for the reporting unit was negatively impacted by changes in the macro-economic environment, including the risk-free rate assumption. As a result of this assessment, a goodwill impairment charge of $73 million was recorded in 2022, reducing the GBPC goodwill balance to nil as at December 31, 2022. No impairment was recorded in 2021. For further detail, refer to note 22.

 

  EMERA 2022 ANNUAL REPORT   83


Notes to the Consolidated Financial Statements

 

INCOME TAXES AND INVESTMENT TAX CREDITS

Emera recognizes deferred income tax assets and liabilities for the future tax consequences of events that have been included in the financial statements or income tax returns. Deferred income tax assets and liabilities are determined based on the difference between the carrying value of assets and liabilities on the Consolidated Balance Sheets, and their respective tax bases using enacted tax rates in effect for the year in which the differences are expected to reverse. The effect of a change in income tax rates on deferred income tax assets and liabilities is recognized in earnings in the period when the change is enacted, unless required to be offset to a regulatory asset or liability by law or by order of the regulator. Emera recognizes the effect of income tax positions only when it is more likely than not that they will be realized. Management reviews all readily available current and historical information, including forward-looking information, and the likelihood that deferred tax assets will be recovered from future taxable income is assessed and assumptions about the expected timing of the reversal of deferred tax assets and liabilities are made. If management subsequently determines that it is likely that some or all of a deferred income tax asset will not be realized, then a valuation allowance is recorded to reflect the amount of deferred income tax asset expected to be realized.

Generally, investment tax credits are recorded as a reduction to income tax expense in the current or future periods to the extent that realization of such benefit is more likely than not. Investment tax credits earned by Tampa Electric, PGS and NMGC on regulated assets are deferred and amortized over the estimated service lives of the related properties, as required by regulatory practices.

Tampa Electric, PGS, NMGC and BLPC collect income taxes from customers based on current and deferred income taxes. NSPI, ENL and Brunswick Pipeline collect income taxes from customers based on income tax that is currently payable except for the deferred income taxes on certain regulatory balances specifically prescribed by the regulator. For the balance of regulated deferred income taxes, NSPI, ENL and Brunswick Pipeline recognize regulatory assets or liabilities where the deferred income taxes are expected to be recovered from or returned to customers in future years. These regulated assets or liabilities are grossed up using the respective income tax rate to reflect the income tax associated with future revenues that are required to fund these deferred income tax liabilities, and the income tax benefits associated with reduced revenues resulting from the realization of deferred income tax assets. GBPC is not subject to income taxes.

Emera classifies interest and penalties associated with unrecognized tax benefits as interest and operating expense, respectively. For further detail, refer to note 10.

DERIVATIVES AND HEDGING ACTIVITIES

The Company manages its exposure to normal operating and market risks relating to commodity prices, foreign exchange, interest rates and share prices through contractual protections with counterparties where practicable, and by using financial instruments consisting mainly of foreign exchange forwards and swaps, interest rate options and swaps, equity derivatives, and coal, oil and gas futures, options, forwards and swaps. In addition, the Company has contracts for the physical purchase and sale of natural gas. These physical and financial contracts are classified as held-for-trading (“HFT”). Collectively, these contracts and financial instruments are considered derivatives.

The Company recognizes the fair value of all its derivatives on its balance sheet, except for non-financial derivatives that meet the normal purchases and normal sales (“NPNS”) exception. Physical contracts that meet the NPNS exception are not recognized on the balance sheet; these contracts are recognized in income when they settle. A physical contract generally qualifies for the NPNS exception if the transaction is reasonable in relation to the Company’s business needs, the counterparty owns or controls resources within the proximity to allow for physical delivery, the Company intends to receive physical delivery of the commodity, and the Company deems the counterparty creditworthy. The Company continually assesses contracts designated under the NPNS exception and will discontinue the treatment of these contracts under this exemption where the criteria are no longer met.

Derivatives qualify for hedge accounting if they meet stringent documentation requirements and can be proven to effectively hedge the identified risk both at the inception and over the term of the instrument. Specifically, for cash flow hedges, the change in the fair value of derivatives is deferred to AOCI and recognized in income in the same period the related hedged item is realized. Where the documentation or effectiveness requirements are not met, the derivatives are recognized at fair value with any changes in fair value recognized in net income in the reporting period, unless deferred as a result of regulatory accounting.

 

84   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

Derivatives entered into by NSPI, NMGC and GBPC that are documented as economic hedges or for which the NPNS exception has not been taken, are subject to regulatory accounting treatment. The change in fair value of the derivatives is deferred to a regulatory asset or liability. The gain or loss is recognized in the hedged item when the hedged item is settled. Management believes any gains or losses resulting from settlement of these derivatives related to fuel for generation and purchased power will be refunded to or collected from customers in future rates. Tampa Electric has no derivatives related to hedging as a result of a FPSC approved five-year moratorium on hedging of natural gas purchases which ends on December 31, 2022. Tampa Electric’s moratorium on hedging of natural gas purchases will continue through December 31, 2024, as a result of Tampa Electric’s 2021 rate case settlement agreement.

Derivatives that do not meet any of the above criteria are designated as HFT, with changes in fair value normally recorded in net income of the period. The Company has not elected to designate any derivatives to be included in the HFT category where another accounting treatment would apply.

Emera classifies gains and losses on derivatives as a component of fuel for generation and purchased power, other expenses, inventory, OM&G and PP&E, depending on the nature of the item being economically hedged. Transportation capacity arising as a result of marketing and trading derivative transactions is recognized as an asset in “Receivables and other current assets” and amortized over the period of the transportation contract term. Cash flows from derivative activities are presented in the same category as the item being hedged within operating or investing activities on the Consolidated Statements of Cash Flows.

Non-hedged derivatives are included in operating cash flows on the Consolidated Statements of Cash Flows.

Derivatives, as reflected on the Consolidated Balance Sheets, are not offset by the fair value amounts of cash collateral with the same counterparty. Rights to reclaim cash collateral are recognized in “Receivables and other current assets” and obligations to return cash collateral are recognized in “Accounts payable”.

CASH, CASH EQUIVALENTS AND RESTRICTED CASH

Cash equivalents consist of highly liquid short-term investments with original maturities of three months or less at acquisition.

RECEIVABLES AND ALLOWANCE FOR CREDIT LOSSES

Utility customer receivables are recorded at the invoiced amount and do not bear interest. Standard payment terms for electricity and gas sales are approximately 30 days. A late payment fee may be assessed on account balances after the due date. The Company recognizes allowances for credit losses to reduce accounts receivable for amounts expected to be uncollectable. Management estimates credit losses related to accounts receivable by considering historical loss experience, customer deposits, current events, the characteristics of existing accounts and reasonable and supportable forecasts that affect the collectability of the reported amount. Provisions for credit losses on receivables are expensed to maintain the allowance at a level considered adequate to cover expected losses. Receivables are written off against the allowance when they are deemed uncollectible.

INVENTORY

Fuel and materials inventories are valued at the lower of weighted-average cost or net realizable value, unless evidence indicates that the weighted-average cost will be recovered in future customer rates.

ASSET IMPAIRMENT

Long-Lived Assets:

Emera assesses whether there has been an impairment of long-lived assets and intangibles when a triggering event occurs, such as a significant market disruption or sale of a business.

The assessment involves comparing the undiscounted expected future cash flows to the carrying value of the asset. When the undiscounted cash flow analysis indicates a long-lived asset is not recoverable, the amount of the impairment loss is determined by measuring the excess of the carrying amount of the long-lived asset over its estimated fair value. The Company’s assumptions relating to future results of operations or other recoverable amounts, are based on a combination of historical experience, fundamental economic analysis, observable market activity and independent market studies. The Company’s expectations regarding uses and holding periods of assets are based on internal long-term budgets and projections, which consider external factors and market forces, as of the end of each reporting period. The assumptions made are consistent with generally accepted industry approaches and assumptions used for valuation and pricing activities.

As at December 31, 2022, there are no indications of impairment of Emera’s long-lived assets. No impairment charges related to long-lived assets were recognized in 2022 or 2021.

 

  EMERA 2022 ANNUAL REPORT   85


Notes to the Consolidated Financial Statements

 

Equity Method Investments:

The carrying value of investments accounted for under the equity method are assessed for impairment by comparing the fair value of these investments to their carrying values, if a fair value assessment was completed, or by reviewing for the presence of impairment indicators. If an impairment exists, and it is determined to be other-than-temporary, a charge is recognized in earnings equal to the amount the carrying value exceeds the investment’s fair value. No impairment of equity method investments was required in either 2022 or 2021.

Financial Assets:

Equity investments, other than those accounted for under the equity method, are measured at fair value, with changes in fair value recognized in the Consolidated Statements of Income. Equity investments that do not have readily determinable fair values are recorded at cost minus impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions for the identical or similar investments. No impairment of financial assets was required in either 2022 or 2021.

ASSET RETIREMENT OBLIGATIONS

An ARO is recognized if a legal obligation exists in connection with the future disposal or removal costs resulting from the permanent retirement, abandonment or sale of a long-lived asset. A legal obligation may exist under an existing or enacted law or statute, written or oral contract, or by legal construction under the doctrine of promissory estoppel.

An ARO represents the fair value of the estimated cash flows necessary to discharge the future obligation, using the Company’s credit adjusted risk-free rate. The amounts are reduced by actual expenditures incurred. Estimated future cash flows are based on completed depreciation studies, remediation reports, prior experience, estimated useful lives, and governmental regulatory requirements. The present value of the liability is recorded and the carrying amount of the related long-lived asset is correspondingly increased. The amount capitalized at inception is depreciated in the same manner as the related long-lived asset. Over time, the liability is accreted to its estimated future value. AROs are included in “Other long-term liabilities” and accretion expense is included as part of “Depreciation and amortization”. Any regulated accretion expense not yet approved by the regulator is recorded in “Property, plant and equipment” and included in the next depreciation study.

Some of the Company’s transmission and distribution assets may have conditional AROs which are not recognized in the consolidated financial statements, as the fair value of these obligations could not be reasonably estimated, given there is insufficient information to do so. A conditional ARO refers to a legal obligation to perform an asset retirement activity in which the timing and/or method of settlement are conditional on a future event that may or may not be within the control of the entity. Management monitors these obligations and a liability is recognized at fair value in the period in which an amount can be determined.

COST OF REMOVAL

Tampa Electric, PGS, NMGC and NSPI recognize non-ARO costs of removal (“COR”) as regulatory liabilities. The non-ARO COR represent funds received from customers through depreciation rates to cover estimated future non-legally required COR of PP&E upon retirement. The companies accrue for COR over the life of the related assets based on depreciation studies approved by their respective regulators. The costs are estimated based on historical experience and future expectations, including expected timing and estimated future cash outlays.

 

86   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

STOCK-BASED COMPENSATION

The Company has several stock-based compensation plans: a common share option plan for senior management; an employee common share purchase plan; a deferred share unit (“DSU”) plan; a performance share unit (“PSU”) plan; and a restricted share unit (“RSU”) plan. The Company accounts for its plans in accordance with the fair value-based method of accounting for stock-based compensation. Stock-based compensation cost is measured at the grant date, based on the calculated fair value of the award, and is recognized as an expense over the employee’s or director’s requisite service period using the graded vesting method. Stock-based compensation plans recognized as liabilities are initially measured at fair value and re-measured at fair value at each reporting date, with the change in liability recognized in income.

EMPLOYEE BENEFITS

The costs of the Company’s pension and other post-retirement benefit programs for employees are expensed over the periods during which employees render service. The Company recognizes the funded status of its defined-benefit and other post- retirement plans on the balance sheet and recognizes changes in funded status in the year the change occurs. The Company recognizes the unamortized gains and losses and past service costs in AOCI or regulatory assets. The components of net periodic benefit cost other than the service cost component are included in “Other income, net” on the Consolidated Statements of Income. For further detail, refer to note 21.

2. Change in Accounting Policy

The new USGAAP accounting policy that is applicable to, and adopted by the Company in 2022, is described as follows:

FACILITATION OF THE EFFECTS OF REFERENCE RATE REFORM ON FINANCIAL REPORTING

The Company adopted Accounting Standard Update (“ASU”) 2022-06, Reference Rate Reform (Topic 848): Deferral of the Sunset Date of Topic 848 in Q4 2022. The update extends the period of time preparers can utilize the reference rate reform relief guidance issued under ASU 2020-04, which was adopted by the Company in Q4 2020. The guidance in ASU 2022-06 was effective as of the date of issuance and entities may elect to apply the guidance prospectively through to December 31, 2024. The Company has applied the guidance permitted by ASU 2020-04 to certain debt agreements that were amended during the current period. The Company’s transition from reference rates will not have a material impact on the consolidated financial statements.

3. Future Accounting Pronouncements

The Company considers the applicability and impact of all ASUs issued by the Financial Accounting Standards Board (“FASB”). ASUs issued by FASB, but which are not yet effective, were assessed and determined to be either not applicable to the Company or to have an insignificant impact on the consolidated financial statements.

4. Dispositions

On March 31, 2022, Emera completed the sale of its 51.9 per cent interest in Domlec for proceeds which approximated its carrying value. Domlec was included in the Company’s Other Electric reportable segment up to its date of sale. The sale did not have a material impact on earnings.

 

  EMERA 2022 ANNUAL REPORT   87


Notes to the Consolidated Financial Statements

 

5. Segment Information

Emera manages its reportable segments separately due in part to their different operating, regulatory and geographical environments. Segments are reported based on each subsidiary’s contribution of revenues, net income attributable to common shareholders and total assets, as reported to the Company’s chief operating decision maker.

 

millions of dollars

   Florida
Electric
Utility
     Canadian
Electric
Utilities
    Gas Utilities
and
Infrastructure
     Other
Electric
Utilities
    Other     Inter-
segment
Eliminations
    Total  

For the year ended December 31, 2022

                

Operating revenues from external customers (1)

   $ 3,280      $ 1,675     $ 1,697      $ 518     $ 418     $ —       $ 7,588  

Inter-segment revenues (1)

     7        —         7        —         22       (36 )      —    
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Total operating revenues

     3,287        1,675       1,704        518       440       (36 )      7,588  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Regulated fuel for generation and purchased power

     1,086        803       —          290       —         (8 )      2,171  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Regulated cost of natural gas

     —          —         800        —         —         —         800  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

OM&G

     625        338       365        123       156       (11 )      1,596  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Provincial, state and municipal taxes

     235        43       83        3       3       —         367  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Depreciation and amortization

     507        259       118        61       7       —         952  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Income from equity investments

     —          87       21        4       17       —         129  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Other income (expense), net

     68        24       13        —         23       17       145  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Interest expense, net (2)

     185        136       81        19       288       —         709  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Impairment charge

     —          —         —          73       —         —         73  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Income tax expense (recovery)

     121        (8 )      70        —         2       —         185  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Non-controlling interest in subsidiaries

     —          —         —          1       —         —         1  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Preferred stock dividends

     —          —         —          —         63       —         63  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Net income (loss) attributable to common shareholders

   $ 596      $ 215     $ 221      $ (48 )    $ (39 )    $ —       $ 945  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Capital expenditures

   $ 1,425      $ 507     $ 574      $ 63     $ 6     $ —       $ 2,575  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

As at December 31, 2022

                

Total assets

   $ 21,053      $ 8,223     $ 7,737      $ 1,337     $ 2,835     $ (1,443 )    $ 39,742  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Investments subject to significant influence

   $ —        $ 1,241     $ 128      $ 49     $ —       $ —       $ 1,418  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Goodwill

   $ 4,739      $ —       $ 1,270      $ —       $ 3     $ —       $ 6,012  
  

 

 

    

 

 

   

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

 

(1)

All significant inter-company balances and transactions have been eliminated on consolidation except for certain transactions between non-regulated and regulated entities. Management believes elimination of these transactions would understate PP&E, OM&G, or regulated fuel for generation and purchased power. Inter-company transactions that have not been eliminated are measured at the amount of consideration established and agreed to by the related parties. Eliminated transactions are included in determining reportable segments.

(2)

Segment net income is reported on a basis that includes internally allocated financing costs of $13 million for the year ended December 31, 2022, between the Gas Utilities and Infrastructure and Other segments.

 

88   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

millions of dollars

   Florida
Electric
Utility
     Canadian
Electric
Utilities
     Gas Utilities
and
Infrastructure
     Other
Electric
Utilities
     Other     Inter-
segment
Eliminations
    Total  

For the year ended December 31, 2021

                  

Operating revenues from external customers (1)

   $ 2,718      $ 1,501      $ 1,276      $ 445      $ (175 )    $ —       $ 5,765  

Inter-segment revenues (1)

     6        —          4        —          18       (28 )      —    
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Total operating revenues

     2,724        1,501        1,280        445        (157 )      (28 )      5,765  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Regulated fuel for generation and purchased power

     894        654        —          218        —         (3 )      1,763  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Regulated cost of natural gas

     —          —          472        —          —         —         472  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

OM&G

     536        291        325        140        106       (30 )      1,368  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Provincial, state and municipal taxes

     212        43        69        4        2       —         330  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Depreciation and amortization

     469        246        121        58        8       —         902  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Income from equity investments

     —          103        20        4        16       —         143  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Other income (expenses), net

     59        12        11        15        1       (5 )      93  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Interest expense, net (2)

     138        132        64        21        256       —         611  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Income tax expense (recovery)

     72        9        62        1        (150 )      —         (6 ) 
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Non-controlling interest in subsidiaries

     —          —          —          1        —         —         1  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Preferred stock dividends

     —          —          —          —          50       —         50  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Net income (loss) attributable to common shareholders

   $ 462      $ 241      $ 198      $ 21      $ (412 )    $ —       $ 510  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Capital expenditures

   $ 1,331      $ 366      $ 515      $ 111      $ 5     $ —       $ 2,328  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

As at December 31, 2021

                  

Total assets

   $ 17,903      $ 7,418      $ 6,666      $ 1,402      $ 2,034     $ (1,179 )    $ 34,244  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Investments subject to significant influence

   $ —        $ 1,215      $ 123      $ 44      $ —       $ —       $ 1,382  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Goodwill

   $ 4,436      $ —        $ 1,189      $ 68      $ 3     $ —       $ 5,696  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

 

(1)

All significant inter-company balances and transactions have been eliminated on consolidation except for certain transactions between non-regulated and regulated entities. Management believes the elimination of these transactions would understate PP&E, OM&G, or regulated fuel for generation and purchased power. Inter-company transactions that have not been eliminated are measured at the amount of consideration established and agreed to by the related parties. Eliminated transactions are included in determining reportable segments.

(2)

Segment net income is reported on a basis that includes internally allocated financing costs of $13 million for the year ended December 31, 2021, between the Gas Utilities and Infrastructure and Other segments.

GEOGRAPHICAL INFORMATION

Revenues (based on country of origin of the product or service sold)

 

For the    Year ended December 31  

millions of dollars

   2022      2021  

United States

   $ 5,346      $ 3,754  

Canada

          1,725               1,566  

Barbados

     384        292  

The Bahamas

     122        110  

Dominica

     11        43  
  

 

 

    

 

 

 
   $ 7,588      $ 5,765  
  

 

 

    

 

 

 

Property Plant and Equipment:

 

As at

millions of dollars

   December 31
2022
     December 31
2021
 

United States

   $ 17,382      $ 14,978  

Canada

     4,689        4,440  

Barbados

     583        535  

The Bahamas

     342        322  

Dominica

     —          78  
  

 

 

    

 

 

 
   $ 22,996      $ 20,353  
  

 

 

    

 

 

 

 

  EMERA 2022 ANNUAL REPORT   89


Notes to the Consolidated Financial Statements

 

6. Revenue

The following disaggregates the Company’s revenue by major source:

 

     Electric      Gas      Other        

millions of dollars

   Florida
Electric
Utility
     Canadian
Electric
Utilities
     Other
Electric
Utilities
     Gas Utilities
and
Infrastructure
     Other     Inter-
segment
Eliminations
    Total  

For the year ended December 31, 2022

                  

Regulated Revenue

                  

Residential

   $ 1,799      $ 834      $ 184      $ 800      $ —       $ —       $ 3,617  

Commercial

     869        427        282        461        —         —         2,039  

Industrial

     230        353        32        83        —         (7 )      691  

Other regulatory deferrals

     371        28        12        —          —         —         411  

Other (1)

     18        33        8        283        —         (7 )      335  

Finance income (2) (3)

     —          —          —          61        —           61  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Regulated revenue

   $ 3,287      $ 1,675      $ 518      $ 1,688      $ —       $ (14 )    $ 7,154  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Non-Regulated Revenue

                  

Marketing and trading margin (4)

     —          —          —          —          143       —         143  

Other non-regulated operating revenue

     —          —          —          16        16       (10 )      22  

Mark-to-market (3)

     —          —          —          —          281       (12 )      269  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Non-regulated revenue

   $ —        $ —        $ —        $ 16      $ 440     $ (22 )    $ 434  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Total operating revenues

   $ 3,287      $ 1,675      $ 518      $ 1,704      $ 440     $ (36 )    $ 7,588  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

For the year ended December 31, 2021

                  

Regulated Revenue

                  

Residential

   $ 1,449      $ 797      $ 165      $ 642      $ —       $ —       $ 3,053  

Commercial

     754        407        232        379        —         —         1,772  

Industrial

     215        237        26        65        —         (2 )      541  

Other regulatory deferrals

     289        27        7        —          —         —         323  

Other (1)

     17        33        15        122        —         (8 )      179  

Finance income (2) (3)

     —          —          —          58        —         —         58  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Regulated revenue

   $ 2,724      $ 1,501      $ 445      $ 1,266      $ —       $ (10 )    $ 5,926  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Non-Regulated Revenue

                  

Marketing and trading margin (4)

     —          —          —          —          102       —         102  

Other non-regulated operating revenue

     —          —          —          14        30       (21 )      23  

Mark-to-market (3)

     —          —          —          —          (289 )      3       (286 ) 
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Non-regulated revenue

   $ —        $ —        $ —        $ 14      $ (157 )    $ (18 )    $ (161 ) 
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Total operating revenues

   $ 2,724      $ 1,501      $ 445      $ 1,280      $ (157 )    $ (28 )    $ 5,765  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

 

(1)

Other includes rental revenues, which do not represent revenue from contracts with customers.

(2)

Revenue related to Brunswick Pipeline’s service agreement with Repsol Energy Canada.

(3)

Revenue which does not represent revenues from contracts with customers.

(4)

Includes gains (losses) on settlement of energy related derivatives, which do not represent revenue from contracts with customers.

Remaining Performance Obligations

Remaining performance obligations primarily represent gas transportation contracts, lighting contracts and long-term steam supply arrangements with fixed contract terms. As of December 31, 2022, the aggregate amount of the transaction price allocated to remaining performance obligations was $450 million (2021 – $437 million). This amount includes $144 million of future performance obligations related to a gas transportation contract between SeaCoast and PGS through 2040. This amount excludes contracts with an original expected length of one year or less and variable amounts for which Emera recognizes revenue at the amount to which it has the right to invoice for services performed. Emera expects to recognize revenue for the remaining performance obligations through 2042.

 

90   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

7. Regulatory Assets and Liabilities

Regulatory assets represent prudently incurred costs that have been deferred because it is probable they will be recovered through future rates or tolls collected from customers. Management believes existing regulatory assets are probable for recovery either because the Company received specific approval from the applicable regulator, or due to regulatory precedent established for similar circumstances. If management no longer considers it probable that an asset will be recovered, the deferred costs are charged to income.

Regulatory liabilities represent obligations to make refunds to customers or to reduce future revenues for previous collections. If management no longer considers it probable that a liability will be settled, the related amount is recognized in income.

For regulatory assets and liabilities that are amortized, the amortization is as approved by the respective regulator.

 

As at

millions of dollars

   December 31
2022
     December 31
2021
 

Regulatory assets

     

Deferred income tax regulatory assets

   $ 1,166      $ 1,045  

Cost recovery clauses

     707        114  

Tampa Electric capital cost recovery for early retired assets

     674        657  

Pension and post-retirement medical plan

     369        291  

FAM

     307        145  

Storm reserve

     103        —    

NMGC winter event gas cost recovery

     69        117  

Storm restoration

     35        35  

Deferrals related to derivative instruments

     30        23  

Environmental remediations

     27        27  

Stranded cost recovery

     27        26  

Other

     106        86  
  

 

 

    

 

 

 
   $ 3,620      $ 2,566  
  

 

 

    

 

 

 

Current

   $ 602      $ 253  

Long-term

     3,018        2,313  
  

 

 

    

 

 

 

Total regulatory assets

   $ 3,620      $ 2,566  
  

 

 

    

 

 

 

Regulatory liabilities

     

Accumulated reserve – cost of removal

     895        819  

Deferred income tax regulatory liabilities

     877        863  

Deferrals related to derivative instruments

     230        241  

NMGC gas hedge settlements (note 18)

     162        —    

Cost recovery clauses

     70        35  

Self-insurance fund (note 32)

     30        28  

Storm reserve

     —          58  

Other

     9        11  
  

 

 

    

 

 

 
   $ 2,273      $ 2,055  
  

 

 

    

 

 

 

Current

   $ 495      $ 290  

Long-term

     1,778        1,765  
  

 

 

    

 

 

 

Total regulatory liabilities

   $ 2,273      $ 2,055  
  

 

 

    

 

 

 

Deferred Income Tax Regulatory Assets and Liabilities

To the extent deferred income taxes are expected to be recovered from or returned to customers in future years, a regulatory asset or liability is recognized as appropriate.

Cost Recovery Clauses

These assets and liabilities are related to Tampa Electric, PGS and NMGC clauses and riders. They are recovered or refunded through cost-recovery mechanisms approved by the FPSC or New Mexico Public Regulation Commission (“NMPRC”), as applicable, on a dollar-for-dollar basis in a subsequent period.

 

  EMERA 2022 ANNUAL REPORT   91


Notes to the Consolidated Financial Statements

 

Tampa Electric Capital Cost Recovery for Early Retired Assets

This regulatory asset is related to the remaining net book value of Big Bend Power Station Units 1 through 3 and smart meter assets that were retired. The balance earns a rate of return as permitted by the FPSC and will be recovered as a separate line item on customer bills for a period of 15 years. This recovery mechanism is authorized by and survives the term of the settlement agreement approved by the FPSC in 2021. For further information, refer to “Big Bend Modernization Project” in the Tampa Electric section below.

Pension and Post-Retirement Medical Plan

This asset is primarily related to the deferred costs of pension and post-retirement benefits at Tampa Electric, PGS and NMGC. It is included in rate base and earns a rate of return as permitted by the FPSC and NMPRC as applicable. It is amortized over the remaining service life of plan participants.

FAM

This regulated asset is the difference between actual fuel costs and amounts recovered from NSPI customers through electricity rates in a given year and deferred to a FAM regulatory asset or liability and recovered from or returned to customers in subsequent periods. For the years 2020 through 2022, differences between actual fuel costs and fuel revenues recovered from customers will be recovered from customers in future periods. The Nova Scotia Utility and Review Board’s (“UARB”) decision to approve the fuel stability plan directed that any annual non-fuel revenues above NSPI’s approved range of ROE are to be applied to the FAM.

Storm Reserve

The storm reserve is for hurricanes and other named storms that cause significant damage to Tampa Electric and PGS systems. As allowed by the FPSC, if the charges to the storm reserve exceed the storm liability, the excess is to be carried as a regulatory asset. Tampa Electric and PGS can petition the FPSC to seek recovery of restoration costs over a 12-month period, or longer, as determined by the FPSC, as well as replenish the reserve. In September 2022, Tampa Electric and PGS were impacted by Hurricane Ian. For further information, refer to “Storm Reserve – Hurricane Ian” in both Tampa Electric and PGS sections below.

NMGC Winter Event Gas Cost Recovery

In February 2021, the State of New Mexico experienced an extreme cold weather event that resulted in an incremental $108 million USD for gas costs above what it would normally have paid during this period. NMGC normally recovers gas supply and related costs through a purchased gas adjustment clause (“PGAC”). On April 16, 2021, NMGC filed a Motion for Extraordinary Relief, as permitted by the NMPRC rules, to extend the terms of the repayment of the incremental gas costs and to recover a carrying charge. On June 15, 2021, the NMPRC approved the recovery of $108 million USD and related borrowing costs over a period of 30 months beginning July 1, 2021.

Storm Restoration

This asset represents storm restoration costs incurred by GBPC. GBPC maintains insurance for its generation facilities and, as with most utilities, its transmission and distribution networks are not covered by commercial insurance.

In January 2020, the Grand Bahama Port Authority (“GBPA”) approved the recovery of $15 million USD of costs related to Hurricane Dorian in 2019, over a five-year period. The recovery was implemented through rates on January 1, 2021.

Restoration costs associated with Hurricane Matthew in 2016 are being recovered through an approved fuel charge. For further information, refer to “Storm Restoration Costs – Hurricane Matthew” in the GBPC section below.

Deferrals Related to Derivative Instruments

This asset is primarily related to NSPI deferring changes in fair value of derivatives that are documented as economic hedges or that do not qualify for NPNS exemption, as a regulatory asset or liability as approved by its regulator. The realized gain or loss is recognized when the hedged item settles in regulated fuel for generation and purchased power, inventory, other income, OM&G or PP&E, depending on the nature of the item being economically hedged.

 

92   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

Environmental Remediations

This asset is primarily related to PGS costs associated with environmental remediation at Manufactured Gas Plant sites. The balance is included in rate base, partially offsetting the related liability, and earns a rate of return as permitted by the FPSC. The timing of recovery is based on a settlement agreement approved by the FPSC.

Stranded Cost Recovery

Due to the decommissioning of a GBPC steam turbine in 2012, the GBPA approved the recovery of a $21 million USD stranded cost through electricity rates; it is included in rate base and is expected to be included in rates in future years.

Accumulated Reserve – Cost of Removal (“COR”)

This regulatory liability represents the non-ARO COR reserve in Tampa Electric, PGS, NMGC and NSPI. AROs represent the fair value of estimated cash flows associated with the Company’s legal obligation to retire its PP&E. Non-ARO COR represent estimated funds received from customers through depreciation rates to cover future COR of PP&E value upon retirement that are not legally required. This reduces rate base for ratemaking purposes. This liability is reduced as COR are incurred and increased as depreciation is recorded for existing assets and as new assets are put into service.

NMGC Gas Hedge Settlements

This regulatory liability represents the regulatory deferral of gas options exercised above strike price but will settle in cash in Q1 2023. The value from the cash settlement of this options will flow through to customers via the PGAC.

REGULATORY ENVIRONMENTS AND UPDATES

Florida Electric Utility

Tampa Electric is regulated by the FPSC and is also subject to regulation by the Federal Energy Regulatory Commission (“FERC”). The FPSC sets rates at a level that allows utilities such as Tampa Electric to collect total revenues or revenue requirements equal to their cost of providing service, plus an appropriate return on invested capital. Base rates are determined in FPSC rate setting hearings which can occur at the initiative of Tampa Electric, the FPSC or other interested parties.

Tampa Electric’s approved regulated return on equity (“ROE”) range for 2022 and 2021 was 9.25 per cent to 11.25 per cent based on an allowed equity capital structure of 54 per cent. An ROE of 10.20 per cent (2021 – 10.25 per cent) is used for the calculation of the return on investments for clauses.

Fuel Recovery and Other Cost Recovery Clauses:

Tampa Electric has a fuel recovery clause approved by the FPSC, allowing the opportunity to recover fluctuating fuel expenses from customers through annual fuel rate adjustments. The FPSC annually approves cost-recovery rates for purchased power, capacity, environmental and conservation costs, including a return on capital invested. Differences between the prudently incurred fuel costs and the cost-recovery rates and amounts recovered from customers through electricity rates in a year are deferred to a regulatory asset or liability and recovered from or returned to customers in subsequent periods.

On January 23, 2023, Tampa Electric requested an adjustment to its fuel charges to recover the 2022 fuel under-recovery of $518 million USD over a period of 21 months. The request also included an adjustment to 2023 projected fuel costs to reflect the reduction in natural gas prices since September 2022 for a projected reduction of $170 million USD for the balance of 2023. The proposed changes will be decided by the FPSC in March 2023, and recovery is expected to begin in April 2023.

The mid-course fuel adjustment requested by Tampa Electric on January 19, 2022, was approved on March 1, 2022. The rate increase, effective with the first billing cycle in April 2022, covered higher fuel and capacity costs of $169 million USD, and was spread over customer bills from April 1, 2022 through December 2022.

 

  EMERA 2022 ANNUAL REPORT   93


Notes to the Consolidated Financial Statements

 

Base Rates:

On October 21, 2021, the FPSC approved a settlement agreement filed by Tampa Electric. The settlement agreement allows for an increase to rates of $191 million USD annually effective January 2022. This increase consisted of $123 million USD in base rate charges and $68 million USD to recover the costs of retiring assets including, Big Bend coal generation assets Units 1 through 3 and meter assets. The settlement agreement further includes two subsequent year adjustments of $90 million USD and $21 million USD, effective January 2023 and January 2024, respectively related to the recovery of future investments in the Big Bend Modernization project and solar generation. The allowed equity in the capital structure will continue to be 54 per cent from investor sources of capital. The settlement agreement includes an allowed regulated ROE range of 9.0 per cent to 11.0 per cent with a 9.95 per cent midpoint. It also provides for a 25 basis point increase in the allowed ROE range and mid-point, and $10 million USD of additional revenue, if United States Treasury Bond yields exceed a specific threshold set on the date the FPSC approved the agreement. Under the agreement base rates are frozen from January 1, 2022 to December 31, 2024, unless Tampa Electric’s earned ROE were to fall below the bottom of the range during that time. The settlement agreement provides for the deferral of income taxes as a result of changes in tax laws. The changes would be reflected as a regulatory asset or liability and either result in an increase or a decrease in customer rates through a subsequent regulatory process. The settlement agreement further creates a mechanism to recover the costs of retiring coal generation units and meter assets over a period of 15 years which survives the term of that agreement. The settlement agreement sets new depreciation and dismantlement rates effective January 1, 2022 and contains the provisions that Tampa Electric will not have to file another depreciation study during the term of the agreement but will file a new depreciation study no more than one year, nor less than 90 days, before the filing of its next general base rate proceeding. Tampa Electric agreed not to hedge natural gas through the period ending on December 31, 2024.

On August 16, 2022, the FPSC approved Tampa Electric’s request to increase revenue and ROE due to increases in the 30-year United States Treasury bond yield rate. Effective July 1, 2022, the new mid-point ROE is 10.20 per cent, and the range is 9.25 per cent to 11.25 per cent.

Storm Reserve – Hurricane Ian:

In September 2022, Tampa Electric was impacted by Hurricane Ian. Total restoration costs were $126 million USD, with $119 million USD of restoration costs charged against Tampa Electric’s FPSC approved storm reserve. Total restoration costs charged to the storm reserve have exceeded the reserve balance and have been deferred as a regulatory asset for future recovery. On January 23, 2023, Tampa Electric petitioned the FPSC for recovery of the storm reserve regulatory asset and the replenishment of the balance in the reserve to the previous approved reserve level of $56 million USD, for a total of approximately $131 million USD. The proposed changes will be decided by the FPSC in March 2023 and recovery is expected to begin in April 2023 through March 2024.

Solar Base Rate Adjustments Included in Base Rates:

During 2017 to 2021, Tampa Electric invested $850 million USD in 600 MW of utility-scale solar photovoltaic projects, which is recoverable through FPSC-approved solar base rate adjustments (“SoBRAs”). AFUDC was earned on these projects during construction. The FPSC has approved SoBRAs representing a total of 600 MW or $104 million USD annually in estimated revenue requirements for in-service projects.

On October 12, 2021, the FPSC approved the true-up filing for SoBRA tranche 3, included in base rates as of January 2020. A $4 million USD true-up was returned to customers during 2021. No true-up for SoBRA tranche 4 was required.

Storm Protection Cost Recovery Clause and Settlement Agreement:

On October 3, 2019, the FPSC issued a rule to implement a Storm Protection Plan (“SPP”) Cost Recovery Clause. This clause provides a process for Florida investor-owned utilities, including Tampa Electric, to recover transmission and distribution storm hardening costs for incremental activities not already included in base rates. Differences between prudently incurred clause- recoverable costs and amounts recovered from customers through electricity rates in a year are deferred and recovered from or returned to customers in a subsequent year. A settlement agreement was approved on August 10, 2020, and Tampa Electric’s cost recovery began in January 2021. The current approved plan addressed the years 2020 through 2022, and in April 2022 Tampa Electric submitted a new plan to determine cost recovery in 2023, 2024 and 2025. On October 4, 2022, the FPSC approved Tampa Electric’s SPP.

 

94   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

Big Bend Modernization Project:

Tampa Electric invested $876 million USD, including $91 million USD of AFUDC, during 2018 through 2022 to modernize the Big Bend Power Station. The modernization project repowered Big Bend Unit 1 with natural gas combined-cycle technology and eliminated coal as this unit’s fuel. As part of the modernization project, Tampa Electric retired the Unit 1 components that will not be used in the modernized plant in 2020 and Big Bend Unit 2 in 2021. Tampa Electric plans to retire Big Bend Unit 3 in 2023 as it is in the best interest of the customers from an economic, environmental risk and operational perspective.

At December 31, 2021, the balance sheet included $636 million USD in electric utility plant and $267 million USD in accumulated depreciation related to Unit 1 components and Unit 2 and Unit 3 assets. In accordance with Tampa Electric’s 2017 settlement agreement approved by the FPSC, Tampa Electric continued to account for its existing investment in Unit 1, 2 and 3 in electric utility plant and depreciated the assets using the current depreciation rates until December 31, 2021, at which point they were reclassified to a regulatory asset on the balance sheet.

Tampa Electric’s 2021 settlement agreement provides recovery for the Big Bend Modernization project in two phases. The first phase was a revenue increase to cover the costs of the assets in service during 2022, among other items. The remainder of the project costs will be recovered as part of the 2023 subsequent year adjustment. The settlement agreement also includes a new charge to recover the remaining costs of the retiring Big Bend coal generation assets, Units 1 through 3, which will be spread over 15 years and will survive the termination of the settlement agreement. The special capital recovery schedule for all three units was applied beginning January 1, 2022. This recovery mechanism is authorized by and survives the term of the settlement agreement approved by the FPSC in 2021.

Canadian Electric Utilities

NSPI

NSPI is a public utility as defined in the Public Utilities Act of Nova Scotia (“Public Utilities Act”) and is subject to regulation under the Public Utilities Act by the UARB. The Public Utilities Act gives the UARB supervisory powers over NSPI’s operations and expenditures. Electricity rates for NSPI’s customers are also subject to UARB approval. NSPI is not subject to a general annual rate review process, but rather participates in hearings held from time to time at NSPI’s or the UARB’s request.

NSPI is regulated under a cost-of-service model, with rates set to recover prudently incurred costs of providing electricity service to customers and provide a reasonable return to investors. NSPI’s approved regulated ROE range for 2022 and 2021 was 8.75 per cent to 9.25 per cent based on an actual five quarter average regulated common equity component of up to 40 per cent of approved rate base.

NSPI has a FAM, approved by the UARB, allowing NSPI to recover fluctuating fuel costs from customers through regularly scheduled fuel rate adjustments. Differences between prudently incurred fuel costs and amounts recovered from customers through electricity rates in a year are deferred to a FAM regulatory asset or liability and recovered from or returned to customers in subsequent periods.

For the period of 2020 through 2022, NSPI operated under a three-year fuel stability plan which resulted in an average annual overall rate increase of 1.5 per cent to recover fuel costs. These rates included recovery of Maritime Link costs.

General Rate Application (“GRA”):

On November 9, 2022, the Nova Scotia provincial government enacted Bill 212, “Public Utilities Act (amended)”. The legislation limits non-fuel rate increases in NSPI’s 2022 GRA to the UARB, excluding increases relating to demand side management (“DSM”) costs, to a total of 1.8 per cent between the effective date of the UARB’s decision and the end of 2024. The legislation also:

 

  •  

requires revenue generated from the non-fuel rate increase to be used only to improve the reliability of service to ratepayers,

 

  •  

limits NSPI’s return on equity to 9.25 per cent and equity ratio to 40 per cent, and

 

  •  

limits the rate used to accrue interest on regulatory deferrals to the Bank of Canada policy interest rate plus 1.75 per cent, unless otherwise directed by the UARB.

 

  EMERA 2022 ANNUAL REPORT   95


Notes to the Consolidated Financial Statements

 

On November 24, 2022, NSPI filed with the UARB a comprehensive settlement agreement between NSPI, key customer representatives and participating interest groups (“NSPI Settlement Agreement”) in relation to its GRA filed in January 2022. The NSPI Settlement Agreement was structured to be consistent with the amendments to the Public Utilities Act made under Bill 212, including the 1.8 per cent cap on non-fuel rate increases for 2023 and 2024. The NSPI Settlement Agreement also addresses the recovery of fuel costs over the settlement period and establishes a DSM rider. This will result in a combined fuel and non-fuel rate increase of 6.9 per cent each year for 2023 and 2024, and annualised incremental revenue (fuel and non-fuel) of $105 million in 2023 and $115 million in 2024. In addition, any under or over recovery of fuel costs will be addressed through the UARB’s established FAM process. NSPI’s ROE range will continue to be 8.75 per cent to 9.25 per cent, based on an actual five-quarter average regulated common equity component of up to 40 per cent. The NSPI Settlement Agreement also establishes a storm rider for each of 2023, 2024 and 2025, which gives NSPI the option to apply to the UARB for recovery of costs if major storm restoration expense exceeds approximately $10 million in a given year. On February 2, 2023, NSPI received the UARB’s decision, which substantially approved the Settlement Agreement as filed. Approved rate increases will be effective as of the date of the decision.

Maritime Link:

The Maritime Link is a $1.8 billion (including AFUDC) transmission project including two 170-kilometre sub-sea cables, connecting the island of Newfoundland and Nova Scotia. The Maritime Link entered service on January 15, 2018 and NSPI started interim assessment payments to NSPML at that time. As part of a three-year fuel stability plan, electricity rates were set to include amounts of $164 million and $162 million for 2021 and 2022, respectively. Any difference between the amounts included in the fuel stability plan and those approved by the UARB through the NSPML interim assessment application will be addressed through the FAM.

Nova Scotia Cap-and-Trade (“Cap-and-Trade”) Program:

As at December 31, 2022, the FAM includes a recovery of $172 million (December 31, 2021 – $38 million) non-cash accrual representing the estimated future cost of acquiring emissions credits for the 2019 through 2022 Cap-and-Trade compliance period. Emissions for the compliance period will not be finalized until the completion of the environmental audit which begins in March 2023. Emissions are currently based upon audited actual emissions from 2019 through 2021 and unaudited actuals for 2022. The total cost of compliance with the Cap-and-Trade program compliance period could change depending on the price paid for both credits at remaining provincial auctions and reserve credits purchased from the provincial government, and the results of the 2022 environmental emissions audit.

Lower than forecast Muskrat Falls energy received during the compliance period has resulted in the increased deployment of higher carbon-emitting generation sources. The Province of Nova Scotia has agreed to provide approximately $165 million of relief from the 2019 through 2022 compliance costs, which was equal to the total cost of compliance forecast at the time of the fuel update submitted by NSPI to the UARB in September 2022 as part of the GRA. Discussions related to the final amount of relief and how this relief will be provided are ongoing. Further, NSPI’s regulatory framework provides for the recovery of costs prudently incurred to comply with the Cap-and-Trade Program Regulations pursuant to NSPI’s FAM.

NSPML

Equity earnings from the Maritime Link are dependent on the approved ROE and operational performance of NSPML. NSPML’s approved regulated ROE range is 8.75 per cent to 9.25 per cent, based on an actual five-quarter average regulated common equity component of up to 30 per cent.

Nalcor’s Nova Scotia Block (“NS Block”) delivery obligations commenced on August 15, 2021 and delivery will continue over the next 35 years pursuant to the agreements.

In February 2022, the UARB issued its decision and Board Order approving NSPML’s requested rate base of approximately $1.8 billion less $9 million of costs ($7 million after-tax) that would not have otherwise been recoverable if incurred by NSPI. NSPML also received approval to collect up to $168 million (2021 – $172 million) from NSPI for the recovery of costs associated with the Maritime Link in 2022. This was subject to a holdback of up to $2 million a month, beginning April 2022, contingent on receiving at least 90 per cent of NS Block deliveries, including Supplemental Energy deliveries.

 

96   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

In December 2022, NSPML received UARB approval to collect up to $164 million from NSPI for the recovery of costs associated with the Maritime Link in 2023. This continues to be subject to a holdback of up to $2 million a month, as discussed above. On December 22, 2022, the UARB clarified its earlier direction regarding the holdback and NSPI can now release the holdback to NSPML when 90 per cent of NS Block deliveries, including Supplemental Energy deliveries, is achieved. This enabled NSPI to pay NSPML approximately $4 million of the 2022 holdback. As of December 31, 2022, an additional $14 million in aggregate has been held-back by NSPI. Determination of the allocation of the $14 million between NSPML and NSPI will be subject to a regulatory process that is expected to commence in early 2023 to review the holdback mechanism.

Gas Utilities and Infrastructure

PGS

PGS is regulated by the FPSC. The FPSC sets rates at a level that allows utilities such as PGS to collect total revenues or revenue requirements equal to their cost of providing service, plus an appropriate return on invested capital.

PGS’s approved ROE range for 2022 and 2021 was 8.9 per cent to 11.0 per cent with a 9.9 per cent midpoint, based on an allowed equity capital structure of 54.7 per cent.

Fuel Recovery:

PGS recovers the costs it pays for gas supply and interstate transportation for system supply through its PGAC. This clause is designed to recover actual costs incurred by PGS for purchased gas, gas storage services, interstate pipeline capacity, and other related items associated with the purchase, distribution, and sale of natural gas to its customers. These charges may be adjusted monthly based on a cap approved annually by the FPSC.

Recovery of Energy Conservation and Pipeline Replacement Programs:

The FPSC annually approves a conservation charge that is intended to permit PGS to recover prudently incurred expenditures in developing and implementing cost effective energy conservation programs which are required by Florida law and approved and monitored by the FPSC. PGS also has a Cast Iron/Bare Steel Pipe Replacement clause to recover the cost of accelerating the replacement of cast iron and bare steel distribution lines in the PGS system. In February 2017, the FPSC approved expansion of the Cast Iron/Bare Steel clause to allow recovery of accelerated replacement of certain obsolete plastic pipe. The majority of cast iron and bare steel pipe has been removed from its system, with replacement of obsolete plastic pipe continuing until 2028 under the rider.

Storm Reserve – Hurricane Ian:

In September 2022, Hurricane Ian impacted PGS’s operations in Fort Myers and Sarasota. The restoration costs were approximately $2 million USD and $1 million was charged against PGS’s FPSC-approved storm reserve.

Base Rates:

On November 19, 2020, the FPSC approved a settlement agreement filed by PGS. The settlement agreement allows for an increase to base rates by $58 million USD annually, effective January 1 2021, which is a $34 million USD increase in revenue and $24 million USD increase of revenues previously recovered through the cast iron and bare steel replacement rider. It provides PGS the ability to reverse a total of $34 million USD of accumulated depreciation through 2023. During 2022, PGS reversed $14 million USD of the $34 million USD accumulated depreciation. No amounts were reversed prior to 2022. In addition, the agreement sets new depreciation rates effective January 1, 2021. Under the agreement base rates are frozen from January 1, 2021 to December 31, 2023, unless its earned ROE were to fall below 8.9 per cent before that time with an allowed equity in the capital structure of 54.7 per cent from investor sources of capital. The settlement agreement provides for the deferral of income taxes as a result of changes in tax laws. The changes would be reflected as a regulatory asset or liability and either result in an increase or a decrease in customer rates through a subsequent regulatory process.

NMGC

NMGC is subject to regulation by the NMPRC. The NMPRC sets rates at a level that allows NMGC to collect total revenues equal to its cost of providing service, plus an appropriate return on invested capital.

NMGC’s approved ROE for 2022 and 2021 was 9.375 per cent on an allowed equity capital structure of 52 per cent.

 

  EMERA 2022 ANNUAL REPORT   97


Notes to the Consolidated Financial Statements

 

Fuel Recovery:

NMGC recovers gas supply costs through a PGAC. This clause recovers actual costs for purchased gas, gas storage services, interstate pipeline capacity, and other related items associated with the purchase, transmission, distribution, and sale of natural gas to its customers. On a monthly basis, NMGC can adjust the charges based on the next month’s expected cost of gas and any prior month under-recovery or over-recovery. The NMPRC requires that NMGC annually file a reconciliation of the PGAC period costs and recoveries. NMGC must file a PGAC Continuation Filing with the NMPRC every four years to establish that the continued use of the PGAC is reasonable and necessary. In December 2020, NMGC received approval of its PGAC Continuation Filing for the four-year period ending December 2024.

Base Rates:

On December 13, 2021, NMGC filed a rate case with the NMPRC for new rates to become effective January 2023. On May 20, 2022, NMGC filed an unopposed settlement agreement with the NMPRC for an increase of $19 million USD in annual base revenues. The rates reflect the recovery of increased operating costs and capital investments in pipelines and related infrastructure. The NMPRC approved the settlement agreement on November 30, 2022.

Weather Normalization Mechanism:

In July 2019, the NMPRC approved changes to the company’s rate design to include a five-year pilot of Weather Normalization Mechanism. This clause is designed to lower the variability of weather impacts during the October through April heating seasons. The Weather Normalization Mechanism allows customer rates and company revenue to be more predictable by partially removing the impact of warmer than usual or colder than usual weather. Weather-related revenue increases or decreases experienced from October to April are adjusted annually in October of the following heating season.

Integrity Management Programs (“IMP”) Regulatory Asset:

A portion of NMGC’s annual spending on infrastructure is for IMP, or the replacement and update of legacy systems. These programs are driven both by NMGC integrity management plans and federal and state mandates. In December 2020, NMGC received approval through its rate case to defer costs through an IMP regulatory asset for certain of its IMP capital investments occurring between January 1, 2022 and December 31, 2023 and petitioned recovery of the regulatory asset in its rate case filed on December 13, 2021. On November 30, 2022, the NMPRC issued a Final Order that included approval of recovery of the IMP regulatory asset.

Brunswick Pipeline

Brunswick Pipeline is a 145-kilometre pipeline delivering natural gas from the Saint John LNG import terminal near Saint John, New Brunswick to markets in the northeastern United States. Brunswick Pipeline entered into a 25-year firm service agreement commencing in July 2009 with Repsol Energy North America Canada Partnership. The agreement provides for a predetermined toll increase in the fifth and fifteenth year of the contract. The pipeline is considered a Group II pipeline regulated by the Canada Energy Regulator (“CER”). The CER Gas Transportation Tariff is filed by Brunswick Pipeline in compliance with the requirements of the CER Act and sets forth the terms and conditions of the transportation rendered by Brunswick Pipeline.

Other Electric Utilities

BLPC

BLPC is regulated by the Fair Trading Commission (“FTC”), an independent regulator, under the Utilities Regulation (Procedural) Rules 2003. BLPC is regulated under a cost-of-service model, with rates set to recover prudently incurred costs of providing electricity service to customers plus an appropriate return on capital invested. BLPC’s approved regulated return on rate base was 10 per cent for 2022 and 2021.

Licenses:

The Government of Barbados has granted BLPC a franchise to generate, transmit and distribute electricity on the island until 2028. In 2019, the Government of Barbados passed legislation amending the number of licenses required for the supply of electricity from a single integrated license which currently exists to multiple licenses for Generation, Transmission and Distribution, Storage, Dispatch and Sales. In March 2021, BLPC reached commercial agreement with the Government of Barbados for each of the license types, subject to the passage of implementing legislation. The new licenses are expected to take effect in 2023 on completion of the legislative process. The Dispatch license will have a term of 5 years with the remaining licenses having terms ranging from 25-30 years. BLPC anticipates that any increased costs associated with the implementation of the new multi-licensed structure will be recoverable through BLPC’s regulatory framework. BLPC is awaiting final enactment and will work towards implementation of the licenses once received.

 

98   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

Fuel Recovery

BLPC’s fuel costs flow through a fuel pass-through mechanism which provides opportunity to recover all prudently incurred fuel costs from customers in a timely manner. The calculation of the fuel charge is adjusted on a monthly basis and reported to the FTC for approval.

On October 4, 2021 BLPC submitted a general rate review application to the FTC. The application seeks a rate adjustment and the implementation of a cost reflective rate structure that will facilitate the changes expected in the newly reformed electricity market and the country’s transition towards 100 per cent renewable energy generation. The application seeks recovery of capital investment in plant, equipment and related infrastructure and results in an increase in annual non-fuel revenue of approximately $23 million USD upon approval. The application includes a request for allowed regulatory ROE of 12.50 per cent on an allowed equity capital structure of 65 per cent. On September 16, 2022, the FTC granted BLPC interim rate relief, allowing an increase in base rates of approximately $3 million USD for the remainder of 2022 and approximately $1 million USD per month for 2023. Interim rate relief is effective from September 16, 2022 until the implementation of final rates. The hearing concluded in October 2022. On February 15, 2023, the FTC issued a decision on the BLPC rate review application which included the following significant items: an allowed regulatory ROE of 11.75 per cent, an equity capital structure of 55 per cent, a directive to update the major components of rate base to September 16, 2022, and a directive to establish regulatory liabilities of approximately $70 million USD related to the self-insurance fund, accumulated depreciation, and taxes. The impacts to BLPC’s rate base and final rates are not yet determinable. BLPC will seek to clarify aspects of the FTC decision in its compliance filing and is also considering filing a submission to the FTC for a review of the decision. BLPC expects a decision on final rates from the FTC in 2023.

Fuel Hedging:

On October 21, 2021, the FTC approved BLPC’s application to implement a fuel hedging program which will be incorporated into the calculation of the fuel clause adjustment. On November 10, 2021, BLPC requested the FTC review the required 50/50 cost sharing arrangement between BLPC and customers in relation to the hedging administrative costs, or any gains and losses associated with the hedging program. A decision is expected from the FTC in 2023.

GBPC

GBPC is regulated by the GBPA. The GBPA has granted GBPC a licensed, regulated and exclusive franchise to produce, transmit and distribute electricity on the island until 2054. Rates are set to recover prudently incurred costs of providing electricity service to customers plus an appropriate return on rate base. GBPC’s approved regulated return on rate base was 8.23 per cent for 2022 (2021 – 8.37 per cent).

Fuel Recovery:

GBPC’s fuel costs flow through a fuel pass-through mechanism which provides the opportunity to recover all prudently incurred fuel costs from customers in a timely manner.

Effective November 1, 2022, GBPC’s fuel pass through charge was increased due to an increase in global oil prices impacting the unhedged fuel cost. In 2023, the fuel pass through charge will be adjusted monthly, in-line with actual fuel costs.

Base Rates:

There is a fuel pass-through mechanism and tariff review policy with new rates submitted every three years. On January 14, 2022, the GBPA issued its decision on GBPC’s application for rate review that was filed with the GBPA on September 23, 2021. The decision, which became effective April 1, 2022, allows for an increase in revenues of $3.5 million USD. The new rates include a regulatory ROE of 12.84 per cent.

Storm Restoration Costs – Hurricane Matthew:

In 2017, as part of the recovery of costs incurred as a result of Hurricane Matthew, the GBPA approved a fixed per kWh fuel charge and allowed the difference between this and the actual cost of fuel to be applied to the Hurricane Matthew regulatory asset. As part of its decision on GBPC’s application for rate review, issued January 14, 2022, and effective April 1, 2022, the GBPA approved the continued amortization of the remaining regulatory asset over the three year period ending December 31, 2024.

 

  EMERA 2022 ANNUAL REPORT   99


Notes to the Consolidated Financial Statements

 

8. Investments Subject to Significant Influence and Equity Income

 

    

Carrying Value

As at December 31

    

Equity Income

For the year ended

December 31

    

Percentage

of
Ownership

 

millions of dollars

   2022      2021      2022      2021      2022  

LIL (1)

   $ 740      $ 682      $ 58      $ 54        31.9  

NSPML

     501        533        29        49        100.0  

M&NP (2)

     128        123        21        20        12.9  

Lucelec (2)

     49        44        4        4        19.5  

Bear Swamp (3)

     —          —          17        16        50.0  
  

 

 

    

 

 

    

 

 

    

 

 

    
   $ 1,418      $ 1,382      $ 129      $ 143     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

(1)

Emera indirectly owns 100 per cent of the Class B units, which comprises 24.5 per cent of the total units issued. Percentage ownership in LIL is subject to change, based on the balance of capital investments required from Emera and Nalcor Energy to complete construction of the LIL. Emera’s ultimate percentage investment in LIL will be determined upon final costing of all transmission projects related to the Muskrat Falls development, including the LIL, Labrador Transmission Assets and Maritime Link Projects, such that Emera’s total investment in the Maritime Link and LIL will equal 49 per cent of the cost of all of these transmission developments.

(2)

Although Emera’s ownership percentage of these entities is relatively low, it is considered to have significant influence over the operating and financial decisions of these companies through Board representation. Therefore, Emera records its investment in these entities using the equity method.

(3)

The investment balance in Bear Swamp is in a credit position primarily as a result of a $179 million distribution received in 2015. Bear Swamp’s credit investment balance of $95 million (2021 – $104 million) is recorded in Other long-term liabilities on the Consolidated Balance Sheets.

Equity investments include a $9 million difference between the cost and the underlying fair value of the investees’ assets as at the date of acquisition. The excess is attributable to goodwill.

Emera accounts for its variable interest investment in NSPML as an equity investment (note 32). NSPML’s consolidated summarized balance sheets are illustrated as follows:

 

As at

millions of dollars

   December 31
2022
     December 31
2021
 

Balance Sheets

     

Current assets

   $ 17      $ 25  

PP&E

     1,517        1,587  

Regulatory assets

     265        247  

Non-current assets

     29        31  
  

 

 

    

 

 

 

Total assets

   $ 1,828      $ 1,890  
  

 

 

    

 

 

 

Current liabilities

   $ 48      $ 50  

Long-term debt (1)

     1,149        1,189  

Non-current liabilities

     130        118  

Equity

     501        533  
  

 

 

    

 

 

 

Total liabilities and equity

   $ 1,828      $ 1,890  
  

 

 

    

 

 

 

 

(1)

The project debt has been guaranteed by the Government of Canada.

9. Other Income, Net

 

For the    Year ended December 31  

millions of dollars

   2022      2021  

TECO Guatemala Holdings award (1)

   $ 63      $ —    

AFUDC

     52        61  

Other

     30        32  
  

 

 

    

 

 

 
   $ 145      $ 93  
  

 

 

    

 

 

 

 

(1)

Refer to note 27 for further detail related to the TECO Guatemala Holdings award.

 

100   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

10. Income Taxes

The income tax provision, for the years ended December 31, differs from that computed using the enacted combined Canadian federal and provincial statutory income tax rate for the following reasons:

 

millions of dollars

   2022     2021  

Income before provision for income taxes

   $ 1,194     $ 555  
  

 

 

   

 

 

 

Statutory income tax rate

     29.0 %      29.0 % 
  

 

 

   

 

 

 

Income taxes, at statutory income tax rate

     346       161  

Deferred income taxes on regulated income recorded as regulatory assets and regulatory liabilities

     (70 )      (62 ) 

Foreign tax rate variance

     (44 )      (42 ) 

Amortization of deferred income tax regulatory liabilities

     (33 )      (33 ) 

GBPC impairment charge

     21       —    

Tax effect of equity earnings

     (10 )      (16 ) 

Tax credits

     (18 )      (13 ) 

Other

     (7 )      (1 ) 
  

 

 

   

 

 

 

Income tax expense (recovery)

   $ 185     $ (6 ) 
  

 

 

   

 

 

 

Effective income tax rate

     15 %      (1 %) 
  

 

 

   

 

 

 

On August 16, 2022, the United States Inflation Reduction Act (“IRA”) was signed into legislation. The IRA includes numerous tax incentives for clean energy, such as the extension and modification of existing investment and production tax credits for projects placed in service through 2024 and introduces new technology-neutral clean energy related tax credits beginning in 2025. During 2022, the Company recorded a $9 million regulatory liability in recognition of its obligation to pass the incremental tax benefits realized to customers.

The following table reflects the composition of taxes on income from continuing operations presented in the Consolidated Statements of Income for the years ended December 31:

 

millions of dollars

   2022      2021  

Current income taxes

     

Canada

   $ 25      $ 20  

United States

     8        11  

Deferred income taxes

     

Canada

     120        (33 ) 

United States

     252        118  

Other

     —          2  

Investment tax credits

     

United States

     (7 )       (11 ) 

Operating loss carryforwards

     

Canada

     (92 )       (64 ) 

United States

     (121 )       (49 ) 
  

 

 

    

 

 

 

Income tax expense (recovery)

   $ 185      $ (6 ) 
  

 

 

    

 

 

 

The following table reflects the composition of income before provision for income taxes presented in the Consolidated Statements of Income for the years ended December 31:

 

millions of dollars

   2022      2021  

Canada

   $ 173      $ 244  

United States

     1,063        289  

Other

     (42 )       22  
  

 

 

    

 

 

 

Income before provision for income taxes

   $ 1,194      $ 555  
  

 

 

    

 

 

 

 

  EMERA 2022 ANNUAL REPORT   101


Notes to the Consolidated Financial Statements

 

The deferred income tax assets and liabilities presented in the Consolidated Balance Sheets as at December 31 consisted of the following:

 

millions of dollars

   2022      2021  

Deferred income tax assets:

     

Tax loss carryforwards

   $ 1,207      $ 873  

Tax credit carryforwards

     415        375  

Regulatory liabilities – cost of removal

     177        170  

Derivative instruments

     45        188  

Other

     428        434  
  

 

 

    

 

 

 

Total deferred income tax assets before valuation allowance

     2,272        2,040  

Valuation allowance

     (312 )       (256 ) 
  

 

 

    

 

 

 

Total deferred income tax assets after valuation allowance

   $ 1,960      $ 1,784  
  

 

 

    

 

 

 

Deferred income tax (liabilities):

     

PP&E

   $ (2,981 )     $ (2,622 ) 

Regulatory assets

     (219 )       (78 ) 

Derivative instruments

     (125 )       (197 ) 

Other

     (594 )       (460 ) 
  

 

 

    

 

 

 

Total deferred income tax liabilities

   $ (3,919 )     $ (3,357 ) 
  

 

 

    

 

 

 

Consolidated Balance Sheets presentation:

     

Long-term deferred income tax assets

   $ 237      $ 295  

Long-term deferred income tax liabilities

     (2,196 )       (1,868 ) 
  

 

 

    

 

 

 

Net deferred income tax liabilities

   $ (1,959 )     $ (1,573 ) 
  

 

 

    

 

 

 

Considering all evidence regarding the utilization of the Company’s deferred income tax assets, it has been determined that Emera is more likely than not to realize all recorded deferred income tax assets, except for certain loss carryforwards and unrealized capital losses on long-term debt and investments. A valuation allowance of $312 million has been recorded as at December 31, 2022 (2021 – $256 million) related to the loss carryforwards, long-term debt and investments.

The Company intends to indefinitely reinvest earnings from certain foreign operations. Accordingly, as at December 31, 2022, $3.8 billion (2021 – $2.9 billion) in cumulative temporary differences for which deferred taxes might otherwise be required, have not been recognized. It is impractical to estimate the amount of income and withholding tax that might be payable if a reversal of temporary differences occurred.

Emera’s NOL, capital loss and tax credit carryforwards and their expiration periods as at December 31, 2022 consisted of the following:

 

millions of dollars

   Tax
Carryforwards
     Subject to
Valuation
Allowance
     Net Tax
Carryforwards
     Expiration
Period
 

Canada

           

NOL

   $ 2,372      $ (977 )     $ 1,395        2026–2042  

Capital loss

     79        (79 )       —          Indefinite  

United States

           

Federal NOL

   $ 2,082      $ —        $ 2,082        2032–Indefinite  

State NOL

     1,489        —          1,489        2032–Indefinite  

Tax credit

     415        —          415        2025–2042  
  

 

 

    

 

 

    

 

 

    

 

 

 

Other

           

NOL

   $ 73      $ (33 )     $ 40        2023–2029  
  

 

 

    

 

 

    

 

 

    

 

 

 

 

102   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

The following table provides details of the change in unrecognized tax benefits for the years ended December 31 as follows:

 

millions of dollars

   2022      2021  

Balance, January 1

   $ 28      $ 30  

Increases due to tax positions related to current year

     5        4  

Increases due to tax positions related to a prior year

     2        1  

Decreases due to tax positions related to a prior year

     (2 )       (1 ) 

Decreases due to settlement with tax authorities

     —          (6 ) 
  

 

 

    

 

 

 

Balance, December 31

   $ 33      $ 28  
  

 

 

    

 

 

 

The total amount of unrecognized tax benefits as at December 31, 2022 was $33 million (2021 – $28 million), which would affect the effective tax rate if recognized. The total amount of accrued interest with respect to unrecognized tax benefits was $7 million (2021 – $6 million) with $1 million interest expense recognized in the Consolidated Statements of Income (2021 – nil). No penalties have been accrued. The balance of unrecognized tax benefits could change in the next 12 months as a result of resolving Canada Revenue Agency (“CRA”) and Internal Revenue Service audits. A reasonable estimate of any change cannot be made at this time.

During 2022, the CRA issued notices of reassessment to NSPI for the 2013 through 2016 taxation years. NSPI and the CRA are currently in a dispute with respect to the timing of certain tax deductions for its 2006 through 2010 and 2013 through 2016 taxation years. The ultimate permissibility of the tax deductions is not in dispute; rather, it is the timing of those deductions. The cumulative net amount in dispute to date is $126 million (2021 – $62 million), including interest. NSPI has prepaid $55 million (2021 – $23 million) of the amount in dispute, as required by CRA.

On November 29, 2019, NSPI filed a Notice of Appeal with the Tax Court of Canada with respect to its dispute of the 2006 through 2010 taxation years. Should NSPI be successful in defending its position, all payments including applicable interest will be refunded. If NSPI is unsuccessful in defending any portion of its position, the resulting taxes and applicable interest will be deducted from amounts previously paid, with the difference, if any, either owed to, or refunded from, the CRA. The related tax deductions will be available in subsequent years.

Should NSPI be similarly reassessed by the CRA for years not currently in dispute, further payments will be required; however, the ultimate permissibility of these deductions would be similarly not in dispute.

NSPI and its advisors believe that NSPI has reported its tax position appropriately. NSPI continues to assess its options to resolving the dispute; however, the outcome of the Notice of Appeal process is not determinable at this time.

Emera files a Canadian federal income tax return, which includes its Nova Scotia provincial income tax. Emera’s subsidiaries file Canadian, US, Barbados, and St. Lucia income tax returns. As at December 31, 2022, the Company’s tax years still open to examination by taxing authorities include 2005 and subsequent years.

 

11.

Common Stock

Authorized: Unlimited number of non-par value common shares.

 

            2022             2021  

Issued and outstanding:

   millions of
shares
     millions of
dollars
     millions of
shares
     millions of
dollars
 

Balance, December 31, 2021

     261.07      $ 7,242        251.43      $ 6,705  

Issuance of common stock under ATM program (1) (2)

     4.07        248        4.99        284  

Issued under the DRIP, net of discounts

     4.21        238        3.90        215  

Senior management stock options exercised and Employee Share Purchase Plan

     0.60        34        0.75        38  
  

 

 

    

 

 

    

 

 

    

 

 

 

Balance, December 31, 2022

     269.95      $ 7,762        261.07      $ 7,242  
  

 

 

    

 

 

    

 

 

    

 

 

 

 

(1)

As at December 31, 2021, a total of 4,987,123 common shares were issued under Emera’s ATM program at an average price of $57.63 per share for gross proceeds of $287 million ($284 million net of after-tax issuance costs).

(2)

For the year ended December 31, 2022, 4,072,469 common shares were issued under Emera’s ATM program at an average price of $61.31 per share for gross proceeds of $250 million ($248 million net of after-tax issuance costs).

 

  EMERA 2022 ANNUAL REPORT   103


Notes to the Consolidated Financial Statements

 

On August 12, 2021, Emera renewed its ATM Program that allows the Company to issue up to $600 million of common shares from treasury to the public from time to time, at the Company’s discretion, at the prevailing market price. The ATM Program was renewed pursuant to a prospectus supplement to the Company’s short form base shelf prospectus dated August 5, 2021. The ATM program is expected to remain in effect until September 5, 2023. As at December 31, 2022, an aggregate gross sales limit of $207 million remains available for issuance under the ATM program.

As at December 31, 2022, the following common shares were reserved for issuance: 6 million (2021 – 6.2 million) under the senior management stock option plan, 2.7 million (2021 – 3.1 million) under the employee common share purchase plan and 10 million (2021 – 14.2 million) under the DRIP.

The issuance of common shares under the common share compensation arrangements does not allow the plans to exceed 10 per cent of Emera’s outstanding common shares. As at December 31, 2022, Emera is in compliance with this requirement.

 

12.

Earnings Per Share

Basic earnings per share is determined by dividing net income attributable to common shareholders by the weighted average number of common shares outstanding during the period. Diluted EPS is computed by dividing net income attributable to common shareholders by the weighted average number of common shares outstanding during the period, adjusted for the exercise and/or conversion of all potentially dilutive securities. Such dilutive items include Company contributions to the senior management stock option plan, convertible debentures and shares issued under the DRIP.

The following table reconciles the computation of basic and diluted earnings per share:

 

For the    Year ended December 31  

millions of dollars (except per share amounts)

   2022      2021  

Numerator

     

Net income attributable to common shareholders

   $ 945.1      $ 510.5  
  

 

 

    

 

 

 

Diluted numerator

     945.1        510.5  
  

 

 

    

 

 

 

Denominator

     

Weighted average shares of common stock outstanding

     265.5        255.9  

Weighted average deferred share units outstanding (1)

     —          1.3  
  

 

 

    

 

 

 

Weighted average shares of common stock outstanding – basic

     265.5        257.2  
  

 

 

    

 

 

 

Stock-based compensation

     0.4        0.4  
  

 

 

    

 

 

 

Weighted average shares of common stock outstanding – diluted

     265.9        257.6  
  

 

 

    

 

 

 

Earnings per common share

     

Basic

   $ 3.56      $ 1.98  

Diluted

   $ 3.55      $ 1.98  
  

 

 

    

 

 

 

 

(1)

Effective February 10, 2022, deferred share units are no longer able to be settled in shares and are therefore no longer included in the calculation of earnings per common share.

 

104   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

13.

Accumulated Other Comprehensive Income

The components of AOCI are as follows:

 

millions of dollars

   Unrealized
gain (loss) on
translation of
self-sustaining
foreign
operations
    Net change in
net investment
hedges
    Gains on
derivatives
recognized
as cash flow
hedges
    Net change
on available-
for-sale
investments
    Net change in
unrecognized
pension
and post-
retirement
benefit costs
    Total AOCI  

For the year ended December 31, 2022

            

Balance, January 1, 2022

   $ 10     $ 35     $ 18     $ (1 )    $ (37 )    $ 25  

Other comprehensive income (loss) before reclassifications

     629       (97 )      —         (1 )      —         531  

Amounts reclassified from AOCI

     —         —         (2 )      —         24       22  
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Net current period other comprehensive income (loss)

     629       (97 )      (2 )      (1 )      24       553  
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Balance, December 31, 2022

   $ 639     $ (62 )    $ 16     $ (2 )    $ (13 )    $ 578  
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

For the year ended December 31, 2021

            

Balance, January 1, 2020

   $ 52     $ 30     $ 1     $ (1 )    $ (161 )    $ (79 ) 

Other comprehensive (loss) income before reclassifications

     (42 )      5       18       —         —         (19 ) 

Amounts reclassified from AOCI

     —         —         (1 )      —         124       123  
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Net current period other comprehensive income (loss)

     (42 )      5       17       —         124       104  
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Balance, December 31, 2021

   $ 10     $ 35     $ 18     $ (1 )    $ (37 )    $ 25  
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

The reclassifications out of accumulated other comprehensive income (loss) are as follows:

 

For the

   Year ended December 31  

millions of dollars

   2022      2021  

Affected line item in the Consolidated Financial Statements

     

Gains on derivatives recognized as cash flow hedges

     

Interest rate hedge

   Interest expense, net    $ (2 )     $ (1 ) 
     

 

 

    

 

 

 

Net change in unrecognized pension and post-retirement benefit costs

     

Actuarial losses

   Other income, net    $ 10      $ 24  

Amounts reclassified into obligations

   Pension and post-retirement benefits      15        102  
     

 

 

    

 

 

 

Total before tax

     25        126  
  

 

 

    

 

 

 

Income tax expense

     (1 )       (2 ) 
  

 

 

    

 

 

 

Total net of tax

   $ 24      $ 124  
  

 

 

    

 

 

 

Total reclassifications out of AOCI, net of tax, for the period

   $ 22      $ 123  
  

 

 

    

 

 

 

 

  EMERA 2022 ANNUAL REPORT   105


Notes to the Consolidated Financial Statements

 

14.

Inventory

 

As at

millions of dollars

   December 31
2022
     December 31
2021
 

Fuel

   $ 404      $ 255  

Materials

     365        283  
  

 

 

    

 

 

 

Total

   $ 769      $ 538  
  

 

 

    

 

 

 

 

15.

Derivative Instruments

Derivative assets and liabilities relating to the foregoing categories consisted of the following:

 

     Derivative Assets      Derivative Liabilities  

As at

millions of dollars

   December 31
2022
     December 31
2021
     December 31
2022
    December 31
2021
 

Regulatory deferral:

          

Commodity swaps and forwards

   $ 186      $ 146      $ 42     $ 16  

FX forwards

     18        7        1       8  

Physical natural gas purchases and sales

     52        88        —         —    
  

 

 

    

 

 

    

 

 

   

 

 

 
     256        241        43       24  
  

 

 

    

 

 

    

 

 

   

 

 

 

HFT derivatives:

          

Power swaps and physical contracts

     89        33        77       32  

Natural gas swaps, futures, forwards, physical contracts

     340        208        1,224       818  
  

 

 

    

 

 

    

 

 

   

 

 

 
     429        241        1,301       850  
  

 

 

    

 

 

    

 

 

   

 

 

 

Other derivatives:

          

Equity derivatives

     —          11        5       —    

FX forwards

     5        —          23       —    
  

 

 

    

 

 

    

 

 

   

 

 

 
     5        11        28       —    
  

 

 

    

 

 

    

 

 

   

 

 

 

Total gross current derivatives

     690        493        1,372       874  
  

 

 

    

 

 

    

 

 

   

 

 

 

Impact of master netting agreements:

          

Regulatory deferral

     (18 )       (4 )       (18 )      (4 ) 

HFT derivatives

     (276 )       (188 )       (276 )      (188 ) 
  

 

 

    

 

 

    

 

 

   

 

 

 

Total impact of master netting agreements

     (294 )       (192 )       (294 )      (192 ) 
  

 

 

    

 

 

    

 

 

   

 

 

 

Total derivatives

   $ 396      $ 301      $ 1,078     $ 682  
  

 

 

    

 

 

    

 

 

   

 

 

 

Current (1)

     296        195        888       533  

Long-term (1)

     100        106        190       149  
  

 

 

    

 

 

    

 

 

   

 

 

 

Total derivatives

   $ 396      $ 301      $ 1,078     $ 682  
  

 

 

    

 

 

    

 

 

   

 

 

 

 

(1)

Derivative assets and liabilities are classified as current or long-term based upon the maturities of the underlying contracts.

CASH FLOW HEDGES

On May 26, 2021, the treasury lock was settled for a gain of $19 million that is being amortized through interest expense over 10 years as the underlying hedged item settles. As of December 31, 2022, the unrealized gain in AOCI was $16 million, net of tax (2021 – $18 million, net of tax). For the year ended December 31, 2022, unrealized gains of $2 million (2021 – $1 million) have been reclassified from AOCI into interest expense. The Company expects $2 million of unrealized gains currently in AOCI to be reclassified into net income within the next twelve months.

 

106   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

REGULATORY DEFERRAL

The Company has recorded the following changes in realized and unrealized gains (losses) with respect to derivatives receiving regulatory deferral:

 

For the year ended December 31

               2022                   2021  

millions of dollars

   Physical
natural gas
purchases
    Commodity
swaps and
forwards
    FX
forwards
     Physical
natural gas
purchases
     Commodity
swaps and
forwards
    FX
forwards
 

Unrealized gain (loss) in regulatory assets

   $ —       $ (69 )    $ 1      $ —        $ (7 )    $ 9  

Unrealized gain (loss) in regulatory liabilities

     28       343       16        88        218       (3 ) 

Realized loss in regulatory assets

     —         48       —          —          —         —    

Realized gain in regulatory liabilities

     —         (41 )      —          —          (3 )      —    

Realized (gain) loss in inventory (1)

     —         (121 )      1        —          (8 )      5  

Realized (gain) loss in regulated fuel for generation and purchased power (2)

     (64 )      (146 )      —          —          (39 )      5  
  

 

 

   

 

 

   

 

 

    

 

 

    

 

 

   

 

 

 

Total change derivative instruments

   $ (36 )    $ 14     $ 18      $ 88      $ 161     $ 16  
  

 

 

   

 

 

   

 

 

    

 

 

    

 

 

   

 

 

 

 

(1)

Realized (gains) losses will be recognized in fuel for generation and purchased power when the hedged item is consumed.

(2)

Realized (gains) losses on derivative instruments settled and consumed in the period and hedging relationships that have been terminated or the hedged transaction is no longer probable.

As at December 31, 2022, the Company had the following notional volumes designated for regulatory deferral that are expected to settle as outlined below:

 

millions

   2023     2024–2026  

Physical natural gas purchases:

    

Natural gas (Mmbtu)

     6       —    
  

 

 

   

 

 

 

Commodity swaps and forwards purchases:

    

Natural gas (Mmbtu)

     18       12  

Power (MWh)

     1       1  
  

 

 

   

 

 

 

FX swaps and forwards:

    

FX contracts (millions of USD)

   $ 206     $ 123  

Weighted average rate

     1.2832       1.3064  

% of USD requirements

     50 %      28 % 
  

 

 

   

 

 

 

HFT DERIVATIVES

The Company has recognized the following realized and unrealized gains (losses) with respect to HFT derivatives:

 

For the    Year ended December 31  

millions of dollars

   2022      2021  

Power swaps and physical contracts in non-regulated operating revenues

   $ 17      $ 4  

Natural gas swaps, forwards, futures and physical contracts in non-regulated operating revenues

     47        (142 ) 
  

 

 

    

 

 

 

Total gains (losses) in net income

   $ 64      $ (138 ) 
  

 

 

    

 

 

 

As at December 31, 2022, the Company had the following notional volumes of outstanding HFT derivatives that are expected to settle as outlined below:

 

millions

   2023      2024      2025      2026      2027 and
thereafter
 

Natural gas purchases (Mmbtu)

     319        92        42        36        131  

Natural gas sales (Mmbtu)

     492        205        105        6        19  

Power purchases (MWh)

     2        —          —          —          —    

Power sales (MWh)

     2        —          —          —          —    

 

  EMERA 2022 ANNUAL REPORT   107


Notes to the Consolidated Financial Statements

 

OTHER DERIVATIVES

As at December 31, 2022, the Company had equity derivatives in place to manage the cash flow risk associated with forecasted future cash settlements of deferred compensation obligations and FX forwards in place to manage cash flow risk associated with forecasted USD cash inflows. The equity derivatives hedge the return on 2.8 million shares and extends until December 2023. The FX forwards have a combined notional amount of $448 million USD and expire throughout 2023, 2024, and 2025.

The Company has recognized the following realized and unrealized gains (losses) with respect to other derivatives:

 

For the                  Year ended December 31  

millions of dollars

          2022            2021  
     FX
Forwards
     Equity
Derivatives
     FX
Forwards
    Equity
Derivatives
 

Unrealized gain (loss) in OM&G

   $ —        $ (5 )     $ —       $ 11  

Unrealized loss in other income, net

     (18 )       —          (15 )      —    

Realized gain (loss) in OM&G

     —          (17 )       —         15  

Realized gain (loss) in other income, net

     (6 )       —          18       —    
  

 

 

    

 

 

    

 

 

   

 

 

 

Total gains (losses) in net income

   $ (24 )     $ (22 )     $ 3     $ 26  
  

 

 

    

 

 

    

 

 

   

 

 

 

CREDIT RISK

The Company is exposed to credit risk with respect to amounts receivable from customers, energy marketing collateral deposits and derivative assets. Credit risk is the potential loss from a counterparty’s non-performance under an agreement. The Company manages credit risk with policies and procedures for counterparty analysis, exposure measurement, and exposure monitoring and mitigation. Credit assessments are conducted on all new customers and counterparties, and deposits or collateral are requested on any high-risk accounts.

The Company assesses the potential for credit losses on a regular basis and, where appropriate, maintains provisions. With respect to counterparties, the Company has implemented procedures to monitor the creditworthiness and credit exposure of counterparties and to consider default probability in valuing the counterparty positions. The Company monitors counterparties’ credit standing, including those that are experiencing financial problems, have significant swings in default probability rates, have credit rating changes by external rating agencies, or have changes in ownership. Net liability positions are adjusted based on the Company’s current default probability. Net asset positions are adjusted based on the counterparty’s current default probability. The Company assesses credit risk internally for counterparties that are not rated.

As at December 31, 2022, the maximum exposure the Company had to credit risk was $1.9 billion (2021 – $1.3 billion), which includes accounts receivable net of collateral/deposits and assets related to derivatives.

It is possible that volatility in commodity prices could cause the Company to have material credit risk exposures with one or more counterparties. If such counterparties fail to perform their obligations under one or more agreements, the Company could suffer a material financial loss. The Company transacts with counterparties as part of its risk management strategy for managing commodity price, FX and interest rate risk. Counterparties that exceed established credit limits can provide a cash deposit or letter of credit to the Company for the value in excess of the credit limit where contractually required. The total cash deposits/ collateral on hand as at December 31, 2022 was $386 million (2021 – $341 million), which mitigates the Company’s maximum credit risk exposure. The Company uses the cash as payment for the amount receivable or returns the deposit/collateral to the customer/counterparty where it is no longer required by the Company.

The Company enters into commodity master arrangements with its counterparties to manage certain risks, including credit risk to these counterparties. The Company generally enters into International Swaps and Derivatives Association agreements, North American Energy Standards Board agreements and, or Edison Electric Institute agreements. The Company believes entering into such agreements offers protection by creating contractual rights relating to creditworthiness, collateral, non-performance and default.

As at December 31, 2022, the Company had $131 million (2021 – $114 million) in financial assets, considered to be past due, which have been outstanding for an average 60 days. The fair value of these financial assets is $114 million (2021 – $93 million), the difference of which is included in the allowance for credit losses. These assets primarily relate to accounts receivable from electric and gas revenue.

 

108   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

CONCENTRATION RISK

The Company’s concentrations of risk consisted of the following:

 

As at

   December 31, 2022     December 31, 2021  
     millions of
dollars
     % of total
exposure
    millions of
dollars
     % of total
exposure
 

Receivables, net

          

Regulated utilities:

          

Residential

   $ 455        19 %    $ 384        24 % 

Commercial

     192        8 %      167        10 % 

Industrial

     121        5 %      54        3 % 

Other

     122        5 %      91        6 % 
  

 

 

    

 

 

   

 

 

    

 

 

 
     890        37 %      696        43 % 
  

 

 

    

 

 

   

 

 

    

 

 

 

Trading group:

          

Credit rating of A- or above

     125        5 %      66        4 % 

Credit rating of BBB- to BBB+

     75        3 %      107        7 % 

Not rated

     307        13 %      132        8 % 
  

 

 

    

 

 

   

 

 

    

 

 

 
     507        21 %      305        19 % 
  

 

 

    

 

 

   

 

 

    

 

 

 

Other accounts receivable

     585        25 %      329        20 % 
  

 

 

    

 

 

   

 

 

    

 

 

 
     1,982        83 %      1,330        82 % 
  

 

 

    

 

 

   

 

 

    

 

 

 

Derivative Instruments (current and long-term)

          

Credit rating of A- or above

     202        9 %      155        9 % 

Credit rating of BBB- to BBB+

     8        0 %      22        1 % 

Not rated

     186        8 %      124        8 % 
  

 

 

    

 

 

   

 

 

    

 

 

 
     396        17 %      301        18 % 
  

 

 

    

 

 

   

 

 

    

 

 

 
   $ 2,378        100 %    $ 1,631        100 % 
  

 

 

    

 

 

   

 

 

    

 

 

 

CASH COLLATERAL

The Company’s cash collateral positions consisted of the following:

 

As at

millions of dollars

   December 31
2022
     December 31
2021
 

Cash collateral provided to others

   $ 224      $ 212  
  

 

 

    

 

 

 

Cash collateral received from others

   $ 112      $ 100  
  

 

 

    

 

 

 

Collateral is posted in the normal course of business based on the Company’s creditworthiness, including its senior unsecured credit rating as determined by certain major credit rating agencies. Certain derivatives contain financial assurance provisions that require collateral to be posted if a material adverse credit-related event occurs. If a material adverse event resulted in the senior unsecured debt falling below investment grade, the counterparties to such derivatives could request ongoing full collateralization.

As at December 31, 2022, the total fair value of derivatives in a liability position was $1,078 million (December 31, 2021 – $682 million). If the credit ratings of the Company were reduced below investment grade, the full value of the net liability position could be required to be posted as collateral for these derivatives.

 

16.

Fair Value Measurements

The Company is required to determine the fair value of all derivatives except those which qualify for the NPNS exemption (see note 1) and uses a market approach to do so. The three levels of the fair value hierarchy are defined as follows:

Level 1 – Where possible, the Company bases the fair valuation of its financial assets and liabilities on quoted prices in active markets (“quoted prices”) for identical assets and liabilities.

Level 2 – Where quoted prices for identical assets and liabilities are not available, the valuation of certain contracts must be based on quoted prices for similar assets and liabilities with an adjustment related to location differences. Also, certain derivatives are valued using quotes from over-the-counter clearing houses.

 

  EMERA 2022 ANNUAL REPORT   109


Notes to the Consolidated Financial Statements

 

Level 3 – Where the information required for a Level 1 or Level 2 valuation is not available, derivatives must be valued using unobservable or internally-developed inputs. The primary reasons for a Level 3 classification are as follows:

 

  •  

While valuations were based on quoted prices, significant assumptions were necessary to reflect seasonal or monthly shaping and locational basis differentials.

 

  •  

The term of certain transactions extends beyond the period when quoted prices are available and, accordingly, assumptions were made to extrapolate prices from the last quoted period through the end of the transaction term.

 

  •  

The valuations of certain transactions were based on internal models, although quoted prices were utilized in the valuations.

Derivative assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement.

The following tables set out the classification of the methodology used by the Company to fair value its derivatives:

 

As at                  December 31, 2022  

millions of dollars

   Level 1      Level 2      Level 3     Total  

Assets

          

Regulatory deferral:

          

Commodity swaps and forwards

   $ 120      $ 48      $ —       $ 168  

FX forwards

     —          18        —         18  

Physical natural gas purchases

     —          —          52       52  
  

 

 

    

 

 

    

 

 

   

 

 

 
     120        66        52       238  
  

 

 

    

 

 

    

 

 

   

 

 

 

HFT derivatives:

          

Power swaps and physical contracts

     9        31        4       44  

Natural gas swaps, futures, forwards, physical contracts and related transportation

     3        72        34       109  
  

 

 

    

 

 

    

 

 

   

 

 

 
     12        103        38       153  
  

 

 

    

 

 

    

 

 

   

 

 

 

Other derivatives:

          

FX forwards

     —          5        —         5  
  

 

 

    

 

 

    

 

 

   

 

 

 

Total assets

     132        174        90       396  
  

 

 

    

 

 

    

 

 

   

 

 

 

Liabilities

          

Regulatory deferral:

          

Commodity swaps and forwards

     15        9        —         24  

FX forwards

     —          1        —         1  
  

 

 

    

 

 

    

 

 

   

 

 

 
     15        10        —         25  
  

 

 

    

 

 

    

 

 

   

 

 

 

HFT derivatives:

          

Power swaps and physical contracts

     2        28        1       31  

Natural gas swaps, futures, forwards and physical contracts

     51        118        825       994  
  

 

 

    

 

 

    

 

 

   

 

 

 
     53        146        826       1,025  
  

 

 

    

 

 

    

 

 

   

 

 

 

Other derivatives:

          

FX forwards

     —          23        —         23  

Equity derivatives

     5        —          —         5  
  

 

 

    

 

 

    

 

 

   

 

 

 
     5        23        —         28  
  

 

 

    

 

 

    

 

 

   

 

 

 

Total liabilities

     73        179        826       1,078  
  

 

 

    

 

 

    

 

 

   

 

 

 

Net assets (liabilities)

   $ 59      $ (5 )     $ (736 )    $ (682 ) 
  

 

 

    

 

 

    

 

 

   

 

 

 

 

110   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

As at                  December 31, 2021  

millions of dollars

   Level 1      Level 2      Level 3     Total  

Assets

          

Regulatory deferral:

          

Commodity swaps and forwards

   $ 101      $ 41      $ —       $ 142  

FX forwards

     —          7        —         7  

Physical natural gas purchases and sales

     —          —          88       88  
  

 

 

    

 

 

    

 

 

   

 

 

 
     101        48        88       237  
  

 

 

    

 

 

    

 

 

   

 

 

 

HFT derivatives:

          

Power swaps and physical contracts

     4        5        4       13  

Natural gas swaps, futures, forwards, physical contracts and related transportation

     (1 )       29        12       40  
  

 

 

    

 

 

    

 

 

   

 

 

 
     3        34        16       53  
  

 

 

    

 

 

    

 

 

   

 

 

 

Other derivatives:

          

Equity derivatives

     11        —          —         11  
  

 

 

    

 

 

    

 

 

   

 

 

 

Total assets

     115        82        104       301  
  

 

 

    

 

 

    

 

 

   

 

 

 

Liabilities

          

Regulatory deferral:

          

Commodity swaps and forwards

     7        5        —         12  

FX forwards

     —          8        —         8  
  

 

 

    

 

 

    

 

 

   

 

 

 
     7        13        —         20  
  

 

 

    

 

 

    

 

 

   

 

 

 

HFT derivatives:

          

Power swaps and physical contracts

     4        5        3       12  

Natural gas swaps, futures, forwards and physical contracts

     13        122        515       650  
  

 

 

    

 

 

    

 

 

   

 

 

 
     17        127        518       662  
  

 

 

    

 

 

    

 

 

   

 

 

 

Total liabilities

     24        140        518       682  
  

 

 

    

 

 

    

 

 

   

 

 

 

Net assets (liabilities)

   $ 91      $ (58 )     $ (414 )    $ (381 ) 
  

 

 

    

 

 

    

 

 

   

 

 

 

The change in the fair value of the Level 3 financial assets for the year ended December 31, 2022 was as follows:

 

     Regulatory
Deferral
     HFT Derivatives  

millions of dollars

   Physical
natural gas
purchases
     Power      Natural gas      Total  

Balance, January 1, 2022

   $ 88      $ 4      $ 12      $ 104  

Realized gains included in fuel for generation and purchased power

     (64 )       —          —          (64 ) 

Unrealized gains included in regulatory liabilities

     28        —          —          28  

Total realized and unrealized gains included in non-regulated operating revenues

     —          —          22        22  
  

 

 

    

 

 

    

 

 

    

 

 

 

Balance, December 31, 2022

   $ 52      $ 4      $ 34      $ 90  
  

 

 

    

 

 

    

 

 

    

 

 

 

The change in the fair value of the Level 3 financial liabilities for the year ended December 31, 2022 was as follows:

 

     HFT Derivatives  

millions of dollars

   Power      Natural gas      Total  

Balance, January 1, 2022

   $ 3      $ 515      $ 518  

Total realized and unrealized gains (losses) included in non-regulated operating revenues

     (2 )       310        308  
  

 

 

    

 

 

    

 

 

 

Balance, December 31, 2022

   $ 1      $ 825      $ 826  
  

 

 

    

 

 

    

 

 

 

 

  EMERA 2022 ANNUAL REPORT   111


Notes to the Consolidated Financial Statements

 

Significant unobservable inputs used in the fair value measurement of Emera’s natural gas and power derivatives include third-party sourced pricing for instruments based on illiquid markets. Significant increases (decreases) in any of these inputs in isolation would result in a significantly lower (higher) fair value measurement. Other unobservable inputs used include internally developed correlation factors and basis differentials; own credit risk; and discount rates. Internally developed correlations and basis differentials are reviewed on a quarterly basis based on statistical analysis of the spot markets in the various illiquid term markets. Discount rates may include a risk premium for those long-term forward contracts with illiquid future price points to incorporate the inherent uncertainty of these points. Any risk premiums for long-term contracts are evaluated by observing similar industry practices and in discussion with industry peers.

The Company uses a modelled pricing valuation technique for determining the fair value of Level 3 derivative instruments. The following table outlines quantitative information about the significant unobservable inputs used in the fair value measurements categorized within Level 3 of the fair value hierarchy:

 

As at                                December 31, 2022  

millions of dollars

          Fair Value      Significant
Unobservable Input
     Low      High      Weighted
Average (1)
 
     Assets      Liabilities                              

Regulatory deferral – Physical natural gas purchases and sales

   $ 52      $ —          Third-party pricing      $ 5.79      $ 31.85      $ 12.27  
  

 

 

    

 

 

       

 

 

    

 

 

    

 

 

 

HFT derivatives – Power swaps and physical contracts

     4        1        Third-party pricing      $ 43.24      $ 269.10      $ 138.79  
  

 

 

    

 

 

       

 

 

    

 

 

    

 

 

 

HFT derivatives – Natural gas swaps, futures, forwards and physical contracts

     34        825        Third-party pricing      $ 2.45      $ 33.88      $ 12.01  

Total

   $ 90      $ 826              
  

 

 

    

 

 

             

Net liability

      $ 736              
     

 

 

             

 

(1)

Unobservable inputs were weighted by the relative fair value of the instruments.

 

As at                                December 31, 2021  

millions of dollars

          Fair Value      Significant
Unobservable Input
     Low      High      Weighted
Average (1)
 
     Assets      Liabilities                              

Regulatory deferral – Physical natural gas purchases and sales

   $ 88      $ —          Third-party pricing      $ 4.51      $ 26.09      $ 9.74  
  

 

 

    

 

 

       

 

 

    

 

 

    

 

 

 

HFT derivatives – Power swaps and physical contracts

     4        3        Third-party pricing      $ 37.05      $ 213.00      $ 99.34  
  

 

 

    

 

 

       

 

 

    

 

 

    

 

 

 

HFT derivatives – Natural gas swaps, futures, forwards and physical contracts

     12        515        Third-party pricing      $ 1.90      $ 21.53      $ 8.80  

Total

   $ 104      $ 518              
  

 

 

    

 

 

             

Net liability

      $ 414              
     

 

 

             

 

(1)

Unobservable inputs were weighted by the relative fair value of the instruments.

Long-term debt is a financial liability not measured at fair value on the Consolidated Balance Sheets. The balance consisted of the following:

 

As at

millions of dollars

   Carrying
Amount
     Fair Value      Level 1      Level 2      Level 3      Total  

December 31, 2022

   $  16,318      $  14,670      $ —        $  14,284      $ 386      $  14,670  

December 31, 2021

   $ 14,658      $ 16,775      $ —        $ 16,308      $ 467      $ 16,775  

 

112   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

The Company has designated $1.2 billion USD denominated Hybrid Notes as a hedge of the foreign currency exposure of its net investment in USD denominated operations. The Company’s Hybrid Notes are contingently convertible into preferred shares in the event of bankruptcy or other related events. A redemption option on or after June 15, 2026 is available and at the control of the Company. The Hybrid Notes are classified as Level 2 financial assets. As at December 31, 2022, the fair value of the Hybrid Notes was $1.1 billion (2021 – $1.7 billion). An after-tax foreign currency loss of $97 million was recorded in AOCI for the year ended December 31, 2022 (2021 – $5 million after-tax gain).

 

17.

Related Party Transactions

In the ordinary course of business, Emera provides energy and other services and enters into transactions with its subsidiaries, associates and other related companies on terms similar to those offered to non-related parties. Intercompany balances and intercompany transactions have been eliminated on consolidation, except for the net profit on certain transactions between non- regulated and regulated entities in accordance with accounting standards for rate-regulated entities. All material amounts are under normal interest and credit terms.

Significant transactions between Emera and its associated companies are as follows:

 

  •  

Transactions between NSPI and NSPML related to the Maritime Link assessment are reported in the Consolidated Statements of Income. NSPI’s expense is reported in Regulated fuel for generation and purchased power, totalling $157 million for the year ended December 31, 2022 (2021 – $149 million). NSPML is accounted for as an equity investment and therefore, the corresponding earnings related to this revenue are reflected in Income from equity investments.

 

  •  

Natural gas transportation capacity purchases from M&NP are reported in the Consolidated Statements of Income. Purchases from M&NP reported net in Operating revenues, Non-regulated, totalled $9 million for the year ended December 31, 2022 (2021 – $19 million).

There were no significant receivables or payables between Emera and its associated companies reported on Emera’s Consolidated Balance Sheets as at December 31, 2022 and at December 31, 2021.

 

18.

Receivables and Other Current Assets

 

As at

millions of dollars

   December 31
2022
     December 31
2021
 

Customer accounts receivable – billed

   $ 1,096      $ 767  

Customer accounts receivable – unbilled

     424        318  

Allowance for credit losses

     (17 )       (21 ) 

Capitalized transportation capacity (1)

     781        316  

NMGC gas hedge settlement receivable (2)

     162        —    

Income tax receivable

     9        8  

Prepaid expenses

     82        65  

Other

     360        280  
  

 

 

    

 

 

 

Total receivables and other current assets

   $ 2,897      $ 1,733  
  

 

 

    

 

 

 

 

(1)

Capitalized transportation capacity represents the value of transportation/storage received by EES on asset management agreements at the inception of the contracts. The asset is amortized over the term of each contract.

(2)

Related amount is included in regulatory liabilities for NMGC as gas hedges are part of the PGAC. Refer to note 7.

 

  EMERA 2022 ANNUAL REPORT   113


Notes to the Consolidated Financial Statements

 

19.

Leases

LESSEE

The Company has operating leases for buildings, land, telecommunication services, and rail cars. Emera’s leases have remaining lease terms of 1 year to 63 years, some of which include options to extend the leases for up to 65 years. These options are included as part of the lease term when it is considered reasonably certain that they will be exercised.

 

As at

millions of dollars

  

Classification

   December 31
2022
     December 31
2021
 

Right-of-use asset

   Other long-term assets    $ 58      $ 58  
     

 

 

    

 

 

 

Lease liabilities

        

Current

   Other current liabilities      3        3  

Long-term

   Other long-term liabilities      59        58  
     

 

 

    

 

 

 

Total lease liabilities

      $ 62      $ 61  
     

 

 

    

 

 

 

The Company has recorded lease expense of $138 million for the year ended December 31, 2022 (2021 – $150 million), of which $131 million (2021 – $142 million) relates to variable costs for power generation facility finance leases, recorded in “Regulated fuel for generation and purchased power” in the Consolidated Statements of Income.

Future minimum lease payments under non-cancellable operating leases for each of the next five years and in aggregate thereafter are as follows:

 

millions of dollars

   2023      2024      2025      2026      2027      Thereafter      Total  

Minimum lease payments

   $ 6      $ 6      $ 5      $ 3      $ 3      $ 116      $ 139  

Less imputed interest

                       (77 ) 
                    

 

 

 

Total

                     $ 62  
                    

 

 

 

Additional information related to Emera’s leases is as follows:

 

     Year ended December 31  

For the

   2022     2021  

Cash paid for amounts included in the measurement of lease liabilities:

    

Operating cash flows for operating leases (millions of dollars)

   $ 8     $ 7  
  

 

 

   

 

 

 

Right-of-use assets obtained in exchange for lease obligations:

    

Operating leases (millions of dollars)

   $ 1     $ —    
  

 

 

   

 

 

 

Weighted average remaining lease term (years)

     44       44  
  

 

 

   

 

 

 

Weighted average discount rate – operating leases

     3.98 %      3.98 % 
  

 

 

   

 

 

 

LESSOR

The Company’s net investment in direct finance and sales-type leases primarily relates to Brunswick Pipeline, Seacoast, compressed natural gas (“CNG”) stations and heat pumps.

The Company manages its risk associated with the residual value of the Brunswick Pipeline lease through proper routine maintenance of the asset.

Customers have the option to purchase CNG station assets by paying a make-whole payment at the date of the purchase based on a targeted internal rate of return or may take possession of the CNG station asset at the end of the lease term for no cost. Customers have the option to purchase heat pumps at the end of the lease term for a nominal fee.

Commencing in January 2022, the Company leased a Seacoast pipeline, a 21-mile, 30-inch lateral that is classified as a sales-type lease. The term of the pipeline lateral lease is 34 years with a net investment of $100 million USD. The lessee of the new pipeline lateral has renewal options for an additional 16 years. These renewal options have not been included as part of the pipeline lateral lease term as it is not reasonably certain that they will be exercised.

Direct finance and sales-type lease unearned income is recognized in income over the life of the lease using a constant rate of interest equal to the internal rate of return on the lease and is recorded as “Operating revenues – regulated gas” and “Other income, net” on the Consolidated Statements of Income.

 

114   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

The total net investment in direct finance and sales-type leases consist of the following:

 

As at

millions of dollars

   December 31
2022
     December 31
2021
 

Total minimum lease payment to be received

   $ 1,393      $ 947  

Less: amounts representing estimated executory costs

     (205 )       (165 ) 
  

 

 

    

 

 

 

Minimum lease payments receivable

   $ 1,188      $ 782  

Estimated residual value of leased property (unguaranteed)

     183        183  

Less: unearned finance lease income

     (733 )       (443 ) 
  

 

 

    

 

 

 

Net investment in direct finance and sales-type leases

   $ 638      $ 522  
  

 

 

    

 

 

 

Principal due within one year (included in “Receivables and other current assets”)

     34        19  
  

 

 

    

 

 

 

Net Investment in direct finance and sales type leases – long-term

   $ 604      $ 503  
  

 

 

    

 

 

 

As at December 31, 2022, future minimum lease payments to be received for each of the next five years and in aggregate thereafter are as follows:

 

millions of dollars

   2023      2024      2025      2026      2027      Thereafter      Total  

Minimum lease payments to be received

   $ 90      $ 92      $ 95      $ 94      $ 92      $ 930      $ 1,393  

Less: executory costs

                       (205 ) 
                    

 

 

 

Total

                     $ 1,188  
                    

 

 

 

 

20.

Property, Plant and Equipment

PP&E consisted of the following regulated and non-regulated assets:

 

As at

millions of dollars

   Estimated useful life      December 31
2022
     December 31
2021
 

Generation

     2 to 131      $ 13,083      $ 11,173  

Transmission

     10 to 80        2,731        2,532  

Distribution

     10 to 65        6,978        6,305  

Gas transmission and distribution

     13 to 83        5,061        4,385  

General plant and other (1)

     2 to 71        2,723        2,473  
     

 

 

    

 

 

 

Total cost

        30,576        26,868  

Less: Accumulated depreciation (1)

        (9,574 )       (8,739 ) 
     

 

 

    

 

 

 
        21,002        18,129  

Construction work in progress (1)

        1,994        2,224  
     

 

 

    

 

 

 

Net book value

      $ 22,996      $ 20,353  
     

 

 

    

 

 

 

 

(1)

SeaCoast owns a 50% undivided ownership interest in a jointly owned 26-mile pipeline lateral located in Florida, which went into service in 2020. At December 31, 2022, SeaCoast’s share of plant in service was $27 million USD (2021 – $27 million USD), and accumulated depreciation of $1 million USD (2021 – $1 million USD). SeaCoast’s undivided ownership interest is financed with its funds and all operations are accounted for as if such participating interest were a wholly owned facility. SeaCoast’s share of direct expenses of the jointly owned pipeline is included in OM&G in the Consolidated Statements of Income.

 

  EMERA 2022 ANNUAL REPORT   115


Notes to the Consolidated Financial Statements

 

21.

Employee Benefit Plans

Emera maintains a number of contributory defined-benefit and defined-contribution pension plans, which cover substantially all of its employees. In addition, the Company provides non-pension benefits for its retirees. These plans cover employees in Nova Scotia, New Brunswick, Newfoundland and Labrador, Florida, New Mexico, Barbados, and Grand Bahama Island.

Emera’s net periodic benefit cost included the following:

BENEFIT OBLIGATION AND PLAN ASSETS

The changes in benefit obligation and plan assets, and the funded status for all plans were as follows:

 

For the

millions of dollars

                 Year ended December 31  
          2022            2021  

Change in Projected Benefit Obligation (“PBO”) and

Accumulated Post-retirement Benefit Obligation (“APBO”)

   Defined benefit
pension plans
     Non-pension
benefit plans
     Defined benefit
pension plans
    Non-pension
benefit plans
 

Balance, January 1

   $ 2,624      $ 318      $ 2,759     $ 339  

Service cost

     41        4        43       5  

Plan participant contributions

     6        6        6       4  

Interest cost

     80        9        67       8  

Benefits paid

     (174 )       (31 )       (160 )      (27 ) 

Actuarial gains

     (480 )       (79 )       (89 )      (10 ) 

Settlements and curtailments

     (6 )       —          —         —    

Foreign currency translation adjustment

     67        16        (2 )      (1 ) 
  

 

 

    

 

 

    

 

 

   

 

 

 

Balance, December 31

     2,158        243        2,624       318  
  

 

 

    

 

 

    

 

 

   

 

 

 

Change in plan assets

          

Balance, January 1

     2,702        51        2,605       52  

Employer contributions

     45        24        42       21  

Plan participant contributions

     6        6        6       4  

Benefits paid

     (174 )       (31 )       (160 )      (27 ) 

Actual return on assets, net of expenses

     (489 )       (7 )       214       2  

Settlements and curtailments

     (6 )       —          —         —    

Foreign currency translation adjustment

     79        3        (5 )      (1 ) 
  

 

 

    

 

 

    

 

 

   

 

 

 

Balance, December 31

     2,163        46        2,702       51  
  

 

 

    

 

 

    

 

 

   

 

 

 

Funded status, end of year

   $ 5      $ (197 )     $ 78     $ (267 ) 
  

 

 

    

 

 

    

 

 

   

 

 

 

The actuarial gains recognized in the period are primarily due to changes in the discount rate and compensation-related assumption changes. This was partially offset by losses associated with member experience and indexation.

PLANS WITH PBO/APBO IN EXCESS OF PLAN ASSETS

The aggregate financial position for all pension plans where the PBO or APBO (for post-retirement benefit plans) exceeds the plan assets for the years ended December 31 is as follows:

 

millions of dollars

          2022            2021  
     Defined benefit
pension plans
     Non-pension
benefit plans
     Defined benefit
pension plans
    Non-pension
benefit plans
 

PBO/APBO

   $ 1,006      $ 221      $ 140     $ 290  

Fair value of plan assets

     914        —          35       —    
  

 

 

    

 

 

    

 

 

   

 

 

 

Funded status

   $ (92 )     $ (221 )     $ (105 )    $ (290 ) 
  

 

 

    

 

 

    

 

 

   

 

 

 

 

116   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

PLANS WITH ACCUMULATED BENEFIT OBLIGATION (“ABO”) IN EXCESS OF PLAN ASSETS

The ABO for the defined benefit pension plans was $2,080 million as at December 31, 2022 (2021 – $2,507 million). The aggregate financial position for those plans with an ABO in excess of the plan assets for the years ended December 31 is as follows:

 

millions of dollars

   2022      2021  
     Defined benefit
pension plans
     Defined benefit
pension plans
 

ABO

   $ 111      $ 133  

Fair value of plan assets

     33        35  
  

 

 

    

 

 

 

Funded status

   $ (78 )     $ (98 ) 
  

 

 

    

 

 

 

BALANCE SHEET

The amounts recognized in the Consolidated Balance Sheets consisted of the following:

 

As at

millions of dollars

          December 31
2022
           December 31
2021
 
     Defined benefit
pension plans
     Non-pension
benefit plans
     Defined benefit
pension plans
    Non-pension
benefit plans
 

Other current liabilities

   $ (13 )     $ (20 )     $ (7 )    $ (20 ) 

Long-term liabilities

     (80 )       (201 )       (100 )      (270 ) 

Other long-term assets

     98        24        185       23  

AOCI, net of tax and regulatory assets

     358        22        230       90  

Less: Deferred income tax (expense) recovery in AOCI

     (7 )       (1 )       (8 )      1  
  

 

 

    

 

 

    

 

 

   

 

 

 

Net amount recognized

   $ 356      $ (176 )     $ 300     $ (176 ) 
  

 

 

    

 

 

    

 

 

   

 

 

 

AMOUNTS RECOGNIZED IN AOCI AND REGULATORY ASSETS

Unamortized gains and losses and past service costs arising on post-retirement benefits are recorded in AOCI or regulatory assets. The following table summarizes the change in AOCI and regulatory assets:

 

millions of dollars

   Regulatory
assets
     Actuarial
(gains) losses
 

Defined Benefit Pension Plans

     

Balance, January 1, 2022

   $ 192      $ 30  

Amortized in current period

     (21 )       (10 ) 

Current year addition to AOCI or regulatory assets

     147        (5 ) 

Change in FX rate

     18        —    
  

 

 

    

 

 

 

Balance, December 31, 2022

   $ 336      $ 15  
  

 

 

    

 

 

 

Non-pension benefits plans

     

Balance, January 1, 2022

   $ 91      $ —    

Amortized in current period

     (2 )       —    

Current year addition to AOCI or regulatory assets

     (62 )       (10 ) 

Change in FX rate

     4        —    
  

 

 

    

 

 

 

Balance, December 31, 2022

   $ 31      $ (10 ) 
  

 

 

    

 

 

 

 

  EMERA 2022 ANNUAL REPORT   117


Notes to the Consolidated Financial Statements

 

As at

millions of dollars

          December
2022
            December
2021
 
     Defined benefit
pension plans
     Non-pension
benefit plans
     Defined benefit
pension plans
     Non-pension
benefit plans
 

Actuarial losses (gains)

   $ 15      $ (10 )     $ 30      $ —    

Deferred income tax expense (recovery)

     7        1        8        (1 ) 
  

 

 

    

 

 

    

 

 

    

 

 

 

AOCI, net of tax

     22        (9 )       38        (1 ) 

Regulatory assets

     336        31        192        91  
  

 

 

    

 

 

    

 

 

    

 

 

 

AOCI, net of tax and regulatory assets

   $ 358      $ 22      $ 230      $ 90  
  

 

 

    

 

 

    

 

 

    

 

 

 

BENEFIT COST COMPONENTS

Emera’s net periodic benefit cost included the following:

 

As at

millions of dollars

                 Year ended December 31  
          2022            2021  
     Defined benefit
pension plans
     Non-pension
benefit plans
     Defined benefit
pension plans
    Non-pension
benefit plans
 

Service cost

   $ 41      $ 4      $ 43     $ 5  

Interest cost

     80        9        67       8  

Expected return on plan assets

     (144 )       —          (132 )      (1 ) 

Current year amortization of:

          

Actuarial losses

     8        —          21       3  

Regulatory assets (liability)

     21        2        24       2  

Settlement, curtailments

     2        —          —         —    
  

 

 

    

 

 

    

 

 

   

 

 

 

Total

   $ 8      $ 15      $ 23     $ 17  
  

 

 

    

 

 

    

 

 

   

 

 

 

The expected return on plan assets is determined based on the market-related value of plan assets of $2,482 million as at January 1, 2022 (2021 – $2,151 million), adjusted for interest on certain cash flows during the year. The market-related value of assets is based on a five-year smoothed asset value. Any investment gains (or losses) in excess of (or less than) the expected return on plan assets are recognized on a straight-line basis into the market-related value of assets over a five-year period.

PENSION PLAN ASSET ALLOCATIONS

Emera’s investment policy includes discussion regarding the investment philosophy, the level of risk which the Company is prepared to accept with respect to the investment of the Pension Funds, and the basis for measuring the performance of the assets. Central to the policy is the target asset allocation by major asset categories. The objective of the target asset allocation is to diversify risk and to achieve asset returns that meet or exceed the plan’s actuarial assumptions. The diversification of assets reduces the inherent risk in financial markets by requiring that assets be spread out amongst various asset classes. Within each asset class, a further diversification is undertaken through the investment in a broad range of investment and non-investment grade securities. Emera’s target asset allocation is as follows:

Canadian Pension Plans

 

Asset class

   Target Range at Market  

Short-term securities

     0% to 5 % 

Fixed income

     35% to 50 % 

Equities:

  

Canadian

     7% to 17 % 

Non-Canadian

     36% to 60 % 

 

118   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

Non-Canadian Pension Plans

 

Asset class

   Target Range at Market
Weighted Average
 

Fixed income

     30% to 50 % 

Equities

     50% to 70 % 

Pension Plan assets are overseen by the respective Management Pension Committees in the sponsoring companies. All pension investments are in accordance with policies approved by the respective Board of Directors of each sponsoring company.

The following tables set out the classification of the methodology used by the Company to fair value its investments:

 

millions of dollars

   NAV      Level 1     Level 2     Total     Percentage  

As at

                      December 31, 2022  

Cash and cash equivalents

   $ —        $ 70     $ —       $ 70       3 % 

Net in-transits

     —          (70 )      —         (70 )      (3 )% 

Equity securities:

           

Canadian equity

     —          87       —         87       4 % 

United States equity

     —          233       —         233       11 % 

Other equity

     —          186       —         186       8 % 

Fixed income securities:

           

Government

     —          —         104       104       5 % 

Corporate

     —          —         83       83       4 % 

Other

     —          3       11       14       1 % 

Mutual funds

     —          68       —         68       3 % 

Other

     —          —         (3 )      (3 )      —   % 

Open-ended investments measured at NAV (1)

     790        —         —         790       36 % 

Common collective trusts measured at NAV (2)

     601        —         —         601       28 % 
  

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Total

   $ 1,391      $ 577     $ 195     $ 2,163       100 % 
  

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

 

millions of dollars

   NAV      Level 1     Level 2     Total     Percentage  

As at

                      December 31, 2021  

Cash and cash equivalents

   $ —        $ 60     $ —       $ 60       2 % 

Net in-transits

     —          (84 )      —         (84 )      (3 )% 

Equity securities:

           

Canadian equity

     —          97       —         97       4 % 

United States equity

     —          366       —         366       14 % 

Other equity

     —          215       —         215       8 % 

Fixed income securities:

           

Government

     —          —         132       132       5 % 

Corporate

     —          —         117       117       4 % 

Other

     —          8       3       11       —   % 

Mutual funds

     —          86       —         86       3 % 

Other

     —          1       (1 )      —         —   % 

Open-ended investments measured at NAV (1)

     952        —         —         952       35 % 

Common collective trusts measured at NAV (2)

     750        —         —         750       28 % 
  

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Total

   $ 1,702      $ 749     $ 251     $ 2,702       100 % 
  

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

 

(1)

NAV investments are open-ended registered and non-registered mutual funds, collective investment trusts, or pooled funds. NAV’s are calculated at least monthly and the funds honor subscription and redemption activity regularly.

(2)

The common collective trusts are private funds valued at NAV. The NAVs are calculated based on bid prices of the underlying securities. Since the prices are not published to external sources, NAV is used as a practical expedient. Certain funds invest primarily in equity securities of domestic and foreign issuers while others invest in long duration U.S. investment grade fixed income assets and seeks to increase return through active management of interest rate and credit risks. The funds honor subscription and redemption activity regularly.

Refer to note 16 for more information on the fair value hierarchy and inputs used to measure fair value.

 

  EMERA 2022 ANNUAL REPORT   119


Notes to the Consolidated Financial Statements

 

POST-RETIREMENT BENEFIT PLANS

There are no assets set aside to pay for most of the Company’s post-retirement benefit plans. As is common practice, post- retirement health benefits are paid from general accounts as required. The primary exceptions to this is the NMGC Retiree Medical Plan, which is fully funded.

INVESTMENTS IN EMERA

As at December 31, 2022 and 2021, the assets related to the pension funds and post-retirement benefit plans did not hold any material investments in Emera or its subsidiaries securities. However, as a significant portion of assets for the benefit plan are held in pooled assets, there may be indirect investments in these securities.

CASH FLOWS

The following table shows the expected cash flows for defined benefit pension and other post-retirement benefit plans:

 

millions of dollars

   Defined benefit
pension plans
     Non-pension
benefit plans
 

Expected employer contributions

     

2023

   $ 44      $ 20  
  

 

 

    

 

 

 

Expected benefit payments

     

2023

     164        22  

2024

     161        23  

2025

     168        23  

2026

     172        22  

2027

     178        22  

2028–2032

     919        105  
  

 

 

    

 

 

 

ASSUMPTIONS

The following table shows the assumptions that have been used in accounting for defined benefit pension and other post- retirement benefit plans:

 

           2022           2021  

(weighted average assumptions)

   Defined benefit
pension plans
    Non-pension
benefit plans
    Defined benefit
pension plans
    Non-pension
benefit plans
 

Benefit obligation – December 31:

        

Discount rate – past service

     5.33 %      5.31 %      3.05 %      2.81 % 

Discount rate – future service

     5.34 %      5.32 %      3.18 %      2.92 % 

Rate of compensation increase

     3.62 %      3.61 %      3.31 %      3.29 % 

Health care trend – initial (next year)

     —         5.40 %      —         5.09 % 

– ultimate

     —         3.77 %      —         3.77 % 

– year ultimate reached

       2043         2042  
    

 

 

     

 

 

 

Benefit cost for year ended December 31:

        

Discount rate – past service

     3.05 %      2.81 %      2.49 %      2.48 % 

Discount rate – future service

     3.18 %      2.92 %      2.64 %      2.51 % 

Expected long-term return on plan assets

     6.07 %      1.32 %      5.86 %      —   % 

Rate of compensation increase

     3.31 %      3.29 %      2.89 %      3.04 % 

Health care trend – initial (current year)

     —         5.09 %      —         5.64 % 

– ultimate

     —         3.77 %      —         4.35 % 

– year ultimate reached

       2042         2038  
    

 

 

     

 

 

 

Actual assumptions used differ by plan.

The expected long-term rate of return on plan assets is based on historical and projected real rates of return for the plan’s current asset allocation, and assumed inflation. A real rate of return is determined for each asset class. Based on the asset allocation, an overall expected real rate of return for all assets is determined. The asset return assumption is equal to the overall real rate of return assumption added to the inflation assumption, adjusted for assumed expenses to be paid from the plan.

 

120   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

The discount rate is based on high-quality long-term corporate bonds, with maturities matching the estimated cash flows from the pension plan.

DEFINED CONTRIBUTION PLAN

Emera also provides a defined contribution pension plan for certain employees. The Company’s contribution for the year ended December 31, 2022 was $41 million (2021 – $45 million).

 

22.

Goodwill

The change in goodwill for the year ended December 31 is due to the following:

 

millions of dollars

   2022      2021  

Balance, January 1

   $ 5,696      $ 5,720  

GBPC impairment charge (1)

     (73 )       —    

Change in FX rate

     389        (24 ) 
  

 

 

    

 

 

 

Balance, December 31

   $ 6,012      $ 5,696  
  

 

 

    

 

 

 

 

(1)

At the beginning of the period, Emera’s accumulated impairment charges related to GBPC were $30 million.

Goodwill is subject to an annual assessment for impairment at the reporting unit level. The goodwill on Emera’s Consolidated Balance Sheets at December 31, 2022, primarily relates to TECO Energy. Emera’s reporting units with goodwill are Tampa Electric, PGS, NMGC, and GBPC.

In 2022, Emera performed a qualitative impairment assessment for Tampa Electric and PGS, concluding that the fair value of the reporting units exceeded their respective carrying amounts, and as such, no quantitative assessments were performed and no impairment charges were recognized. For the NMGC reporting unit, Emera elected to bypass a qualitative assessment and performed a quantitative impairment assessment using a combination of the income approach and market approach. This assessment estimated that the fair value of the NMGC reporting unit exceeded its carrying amount, including goodwill. As a result of this assessment, no impairment charges were recognized.

In 2022, the Company elected to bypass a qualitative assessment and performed a quantitative impairment assessment for GBPC, using the income approach, as this reporting unit is sensitive to changes in assumptions due to limited excess of fair value over carrying amount, including goodwill. Although the cash flows of GBPC have not changed significantly compared to previous periods, it was determined that the fair value did not exceed its carrying amount, including goodwill, primarily due to an increase in discount rates. The discount rate for the reporting unit was negatively impacted by changes in the macro-economic environment, including the risk-free rate assumption. As a result of this assessment, a goodwill impairment charge of $73 million was recorded in 2022, reducing the GBPC goodwill balance to nil as at December 31, 2022. This non-cash charge is included in “Impairment charge” on the Consolidated Statements of Income.

 

  EMERA 2022 ANNUAL REPORT   121


Notes to the Consolidated Financial Statements

 

23.

Short-Term Debt

Emera’s short-term borrowings consist of commercial paper issuances, advances on revolving and non-revolving credit facilities and short-term notes. Short-term debt and the related weighted-average interest rates as at December 31 consisted of the following:

 

millions of dollars

   2022      Weighted
average

interest rate
    2021      Weighted
average
interest rate
 

Tampa Electric Company (“TEC”)

          

Advances on term, revolving and accounts receivable facilities

   $ 1,380        5.00 %    $ 945        0.58 % 
  

 

 

    

 

 

   

 

 

    

 

 

 

Emera

          

Non-revolving term facility

     796        5.19 %      400        0.96 % 

Bank indebtedness

     —          —   %      6        —   % 
  

 

 

    

 

 

   

 

 

    

 

 

 

TECO Finance

          

Advances on revolving credit and term facilities

     481        5.47 %      355        1.20 % 
  

 

 

    

 

 

   

 

 

    

 

 

 

NMGC

          

Advances on revolving credit facilities

     59        5.15 %      25        1.20 % 
  

 

 

    

 

 

   

 

 

    

 

 

 

GBPC

          

Advances on revolving credit facilities

     10        5.25 %      10        5.25 % 
  

 

 

    

 

 

   

 

 

    

 

 

 

NSPI

          

Bank indebtedness

     —          —   %      1        —   % 
  

 

 

    

 

 

   

 

 

    

 

 

 

Short-term debt

   $ 2,726        $ 1,742     
  

 

 

      

 

 

    

The Company’s total short-term revolving and non-revolving credit facilities, outstanding borrowings and available capacity as at December 31 were as follows:

 

millions of dollars

   Maturity      2022      2021  

TEC – Unsecured committed revolving credit facility

     2026      $ 1,084      $ 1,014  

TECO Energy/TECO Finance – revolving credit facility

     2026        542        507  

Emera – non-revolving term facility

     2023        400        400  

Emera – non-revolving term facility

     2023        400        —    

TEC – Unsecured non-revolving facility

     2023        542        634  

NMGC – revolving credit facility

     2026        169        158  

GBPC – revolving credit facility

     on demand        18        16  
     

 

 

    

 

 

 

Total

      $ 3,155      $ 2,729  
     

 

 

    

 

 

 

Less:

        

Advances under revolving credit and term facilities

        2,731        1,735  

Letters of credit issued within the credit facilities

        4        4  
     

 

 

    

 

 

 

Total advances under available facilities

        2,735        1,739  
     

 

 

    

 

 

 

Available capacity under existing agreements

      $ 420      $ 990  
     

 

 

    

 

 

 

The weighted average interest rate on outstanding short-term debt at December 31, 2022 was 5.01 per cent (2021 – 0.83 per cent).

 

122   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

RECENT SIGNIFICANT FINANCING ACTIVITY BY SEGMENT

Florida Electric Utilities

On December 13, 2022, TEC amended its 364-day non-revolving term credit facility to extend the maturity date from December 16, 2022 to December 13, 2023 and reduced the facility amount from $500 million USD to $400 million USD. There were no other significant changes in commercial terms from the prior agreement.

Other

On December 16, 2022, Emera amended its $400 million non-revolving term credit facility to extend the maturity from December 16, 2022 to December 16, 2023. There were no other significant changes in commercial terms from the prior agreement.

On August 2, 2022, Emera entered into a $400 million non-revolving term facility which matures on August 2, 2023. The credit agreement contains customary representation and warranties, events of default and financial and other covenants and bears interest at Bankers’ Acceptances or prime rate advances, plus a margin.

 

24.

Other Current Liabilities

 

As at

millions of dollars

   December 31
2022
     December 31
2021
 

Accrued charges

   $ 174      $ 157  

Nova Scotia Cap-and-Trade Program provision (note 7)

     172        —    

Accrued interest on long-term debt

     97        75  

Pension and post-retirement liabilities (note 21)

     33        27  

Sales and other taxes payable

     14        6  

Income tax payable

     9        6  

Other

     80        95  
  

 

 

    

 

 

 
   $ 579      $ 366  
  

 

 

    

 

 

 

 

  EMERA 2022 ANNUAL REPORT   123


Notes to the Consolidated Financial Statements

 

25.

Long-Term Debt

Bonds, notes and debentures are at fixed interest rates and are unsecured unless noted below. Included are certain bankers’ acceptances and commercial paper where the Company has the intention and the unencumbered ability to refinance the obligations for a period greater than one year.

Long-term debt as at December 31 consisted of the following:

 

    

Weighted average

interest rate (1)

                    

millions of dollars

   2022     2021     Maturity      2022     2021  

Emera

           

Bankers acceptances, LIBOR loans

     Variable       Variable       2027      $ 403     $ 378  

Unsecured fixed rate notes

     2.90 %      2.90 %      2023        500       500  

Fixed to floating subordinated notes (USD) (2)

     6.75 %      6.75 %      2076        1,625       1,521  
         

 

 

   

 

 

 
          $ 2,528     $ 2,399  
         

 

 

   

 

 

 

Emera Finance

           

Unsecured senior notes (USD)

     3.65 %      3.65 %      2024–2046      $ 3,725     $ 3,487  
         

 

 

   

 

 

 

Tampa Electric (3)

           

Fixed rate notes and bonds (USD)

     4.15 %      4.15 %      2024–2052      $ 4,341     $ 3,683  
         

 

 

   

 

 

 

PGS

           

Fixed rate notes and bonds (USD)

     3.78 %      3.78 %      2024–2052      $ 772     $ 660  
         

 

 

   

 

 

 

NMGC

           

Fixed rate notes and bonds (USD)

     3.11 %      3.11 %      2026–2051      $ 521     $ 488  

Non-revolving term facility, floating rate

     Variable       Variable       2024        108       101  
         

 

 

   

 

 

 
          $ 629     $ 589  
         

 

 

   

 

 

 

NMGI

           

Fixed rate notes and bonds (USD)

     3.64 %      3.64 %      2024      $ 203     $ 190  
         

 

 

   

 

 

 

NSPI

           

Discount notes

     Variable       Variable       2024–2027      $ 881     $ 376  

Medium term fixed rate notes

     5.14 %      5.14 %      2025–2097        2,665       2,665  
         

 

 

   

 

 

 
          $ 3,546     $ 3,041  
         

 

 

   

 

 

 

EBP

           

Senior secured credit facility

     Variable       Variable       2026      $ 249     $ 249  
         

 

 

   

 

 

 

ECI

           

Secured senior notes (USD)

     Variable       Variable       2026      $ 86     $ 84  

Amortizing fixed rate notes (USD)

     3.97 %      3.97 %      2024–2026        100       104  

Non-revolving term facility, floating rate

     Variable       Variable       2027        30       28  

Non-revolving term facility, fixed rate

     2.05 %      2.36 %      2025–2026        91       101  

Secured fixed rate senior notes (4)

     3.06 %      4.43 %      2023–2029        142       161  
         

 

 

   

 

 

 
          $ 449     $ 478  
         

 

 

   

 

 

 

Adjustments

           

Fair market value adjustment – TECO Energy acquisition (5)

          $ 2     $ 3  

Debt issuance costs

            (126 )      (121 ) 

Amount due within one year

            (574 )      (462 ) 
         

 

 

   

 

 

 
          $ (698 )    $ (580 ) 
         

 

 

   

 

 

 

Long-Term Debt

          $ 15,744     $ 14,196  
         

 

 

   

 

 

 

 

(1)

Weighted average interest rate of fixed rate long-term debt.

(2)

In 2022, the Company recognized $110 million in interest expense (2021 – $102 million) related to its fixed to floating subordinated notes.

(3)

A substantial part of Tampa Electric’s tangible assets are pledged as collateral to secure its first mortgage bonds. There are currently no bonds outstanding under Tampa Electric’s first mortgage bond indenture.

(4)

Notes are issued and payable in either USD or BBD.

(5)

On acquisition of TECO Energy, Emera recorded a fair market value adjustment on the unregulated long-term debt acquired. The fair market value adjustment is amortized over the remaining term of the debt.

 

124   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

The Company’s total long-term revolving credit facilities, outstanding borrowings and available capacity as at December 31 were as follows:

 

millions of dollars

   Maturity      2022      2021  

Emera – revolving credit facility (1)

     June 2027      $ 900      $ 900  

NSPI – revolving credit facility (1)

     December 2027        800        600  

NSPI – non-revolving credit facility

     July 2024        400        —    

NMGC – non-revolving credit facility

     March 2024        108        —    

ECI – revolving credit facilities

     2023–2032        11        27  
     

 

 

    

 

 

 

Total

      $ 2,219      $ 1,527  
     

 

 

    

 

 

 

Less:

        

Borrowings under credit facilities

        1,396        770  

Letters of credit issued inside credit facilities

        12        124  
     

 

 

    

 

 

 

Use of available facilities

      $ 1,408      $ 894  
     

 

 

    

 

 

 

Available capacity under existing agreements

      $ 811      $ 633  
     

 

 

    

 

 

 

 

(1)

Advances on the revolving credit facility can be made by way of overdraft on accounts up to $50 million.

DEBT COVENANTS

Emera and its subsidiaries have debt covenants associated with their credit facilities. Covenants are tested regularly and the Company is in compliance with covenant requirements. Emera’s significant covenants are listed below:

 

    

Financial Covenant

  

Requirement

   As at
December 31, 2022
 

Emera

        

Syndicated credit facilities

   Debt to capital ratio    Less than or equal to 0.70 to 1      0.57 : 1  

RECENT SIGNIFICANT FINANCING ACTIVITY BY SEGMENT

Florida Electric Utility

On September 15, 2022, TEC repaid a $250 million USD note upon maturity. The note was repaid using existing credit facilities.

On July 12, 2022, TEC completed an issuance of $600 million USD senior notes. The issuance included $300 million USD senior notes that bear an interest rate of 3.875 per cent with a maturity date of July 12, 2024, and $300 million USD senior notes that bear an interest rate of 5 per cent with a maturity date of July 15, 2052.

Canadian Electric Utilities

On December 16, 2022, NSPI amended its revolving operating credit facility to extend the maturity date from December 16, 2026 to December 16, 2027 and increase the amount of the facility from $600 million to $800 million. There were no other significant changes in commercial terms from the prior agreement.

On July 15, 2022, NSPI entered into a $400 million non-revolving term credit facility which matures on July 15, 2024. The credit facility contains customary representation and warranties, events of default and financial and other covenants, and bears interest at Bankers’ Acceptances or prime rate advances, plus a margin.

Gas Utilities and Infrastructure

On September 23, 2022, NMGC amended its $80 million USD, unsecured, non-revolving term credit facility to extend the maturity from September 23, 2022, to March 22, 2024. There were no other changes in commercial terms from the prior agreement.

On June 30, 2022, Brunswick Pipeline amended its non-revolving credit agreement to extend the maturity from June 30, 2025 to June 30, 2026. There were no other changes in commercial terms from the prior agreement.

Other Electric Utilities

On March 25, 2022, ECI amended its amortizing floating rate notes to extend the maturity from March 25, 2022 to March 25, 2027. There were no other changes in commercial terms from the prior agreement.

 

  EMERA 2022 ANNUAL REPORT   125


Notes to the Consolidated Financial Statements

 

Other

On December 16, 2022, Emera amended its $900 million revolving operating credit facility to extend the maturity date from June 30, 2026 to June 30, 2027. There were no other significant changes in commercial terms from the prior agreement.

LONG-TERM DEBT MATURITIES

As at December 31, long-term debt maturities, including capital lease obligations, for each of the next five years and in aggregate thereafter are as follows:

 

millions of dollars

   2023      2024      2025      2026      2027      Thereafter      Total  

Emera

   $ 500      $ —        $ —        $ 1,625      $ 403      $ —        $ 2,528  

Emera US Finance LP

     —          407        —          1,016        —          2,302        3,725  

Tampa Electric

     —          356        —          —          —          3,985        4,341  

PGS

     —          51        —          —          —          721        772  

NMGC

     —          108        —          95        —          426        629  

NMGI

     —          203        —          —          —          —          203  

NSPI

     —          398        125        40        483        2,500        3,546  

EBP

     —          —          —          249        —          —          249  

ECI

     74        90        137        85        60        3        449  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total

   $ 574      $ 1,613      $ 262      $ 3,110      $ 946      $ 9,937      $  16,442  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

 

26.

Asset Retirement Obligations

AROs mostly relate to reclamation of land at the thermal, hydro and combustion turbine sites; and the disposal of polychlorinated biphenyls in transmission and distribution equipment and a pipeline site. Certain hydro, transmission and distribution assets may have additional AROs that cannot be measured as these assets are expected to be used for an indefinite period and, as a result, a reasonable estimate of the fair value of any related ARO cannot be made.

The change in ARO for the years ended December 31 is as follows:

 

millions of dollars

   2022      2021  

Balance, January 1

   $ 174      $ 178  

Accretion included in depreciation expense

     9        10  

Change in FX rate

     3        (1 ) 

Additions

     1        1  

Accretion deferred to regulatory asset (included in PP&E)

     1        (2 ) 

Liabilities settled (1)

     (1 )       (13 ) 

Revisions in estimated cash flows

     (13 )       —    

Other

     —          1  
  

 

 

    

 

 

 

Balance, December 31

   $ 174      $ 174  
  

 

 

    

 

 

 

 

(1)

Tampa Electric produced ash and other by-products, collectively known as CCR’s, at its Big Bend and Polk power stations. The decrease in ARO in 2021 was due to the closure of CCR management facilities.

 

126   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

27.

Commitments and Contingencies

A. COMMITMENTS

As at December 31, 2022, contractual commitments (excluding pensions and other post-retirement obligations, long-term debt and asset retirement obligations) for each of the next five years and in aggregate thereafter consisted of the following:

 

millions of dollars

   2023      2024      2025      2026      2027      Thereafter      Total  

Transportation (1)

   $ 693      $ 516      $ 423      $ 383      $ 367      $ 2,817      $ 5,199  

Purchased power (2)

     269        243        237        228        243        2,145        3,365  

Fuel, gas supply and storage

     1,161        282        138        40        5        1        1,627  

Capital projects

     264        89        4        1        —          —          358  

Equity investment commitments (3)

     240        —          —          —          —          —          240  

Other

     149        142        132        49        42        189        703  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 
   $ 2,776      $ 1,272      $ 934      $ 701      $ 657      $ 5,152      $  11,492
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

 

(1)

Purchasing commitments for transportation of fuel and transportation capacity on various pipelines. Includes a commitment of $144 million related to a gas transportation contract between PGS and SeaCoast through 2040.

(2)

Annual requirement to purchase electricity production from IPPs or other utilities over varying contract lengths.

(3)

Emera has a commitment to make a final equity contribution to the LIL upon its commissioning. Once commissioned, the commercial agreements between Emera and Nalcor require true ups to finalize the respective investment obligations of the parties in relation to the Maritime Link and LIL.

NSPI has a contractual obligation to pay NSPML for use of the Maritime Link over approximately 38 years from its January 15, 2018 in-service date. In February 2022, the UARB issued its decision and Board Order approving NSPML’s requested rate base of approximately $1.8 billion. In December 2022, the UARB approved the collection of $164 million from NSPI for the recovery of Maritime Link costs in 2023. The timing and amounts payable to NSPML for the remainder of the 38-year commitment period are subject to UARB approval.

Emera has committed to obtain certain transmission rights for Nalcor, if requested, to enable it to transmit energy which is not otherwise used in Newfoundland and Labrador or Nova Scotia. Nalcor has the right to transmit this energy from Nova Scotia to New England energy markets effective August 15, 2021, the date the NS Block delivery obligation commenced, and continuing for 50 years. As transmission rights are contracted, the obligations are included within “Other” in the above table.

B. LEGAL PROCEEDINGS

TECO Guatemala Holdings (“TGH”)

Prior to Emera’s acquisition of TECO Energy in 2016, TGH, a wholly owned subsidiary of TECO Energy, divested of its indirect investment in the Guatemala electricity sector, but retained certain claims against the Republic of Guatemala (“Guatemala”). In 2013, TGH asserted an arbitration claim against Guatemala with the International Centre for the Settlement of Investment Disputes (“ICSID”) under the Dominican Republic Central America – United States Free Trade Agreement. The arbitration concerned TGH’s allegation that Guatemala unfairly set the distribution tariff for a local distribution company which harmed TGH’s investment in that company. A tribunal established by the ICSID ruled in favour of TGH (the “First Award”) and, in November 2020, Guatemala made a payment of approximately $38 million USD in full and final satisfaction of the First Award.

On September 23, 2016, TGH had filed a request for resubmission to arbitration seeking damages in addition to those awarded in the First Award. On May 13, 2020, an ICSID tribunal awarded TGH additional damages and costs against Guatemala of more than $35 million USD plus interest (the “Second Award”). TGH subsequently requested a reconsideration of the interest quantum awarded in connection with the Second Award. On October 16, 2020, the tribunal granted TGH’s request for additional interest. The additional amount was approximately $2 million USD. On February 12, 2021, Guatemala filed an application with ICSID for annulment of the Second Award. On March 31, 2021, ICSID constituted an ad hoc Committee to oversee the annulment proceeding. A three-day hearing was held before the ad hoc Committee beginning on July 27, 2022.

On November 28, 2022, TGH and Guatemala entered into a settlement agreement with respect to the Second Award. Pursuant to the settlement agreement, on December 15, 2022, Guatemala paid TGH $46 million USD and the parties agreed to settle all outstanding disputes, concluding this matter. This amount was recognized in “Other Income, net” on the Consolidated Statements of Income.

 

  EMERA 2022 ANNUAL REPORT   127


Notes to the Consolidated Financial Statements

 

Superfund and Former Manufactured Gas Plant Sites

TEC, through its Tampa Electric and PGS divisions, is a potentially responsible party (“PRP”) for certain superfund sites and, through its PGS division, for certain former manufactured gas plant sites. While the joint and several liability associated with these sites presents the potential for significant response costs, as at December 31, 2022, TEC estimated its financial liability to be $17 million ($13 million USD), primarily at PGS. This estimate assumes that other involved PRPs are credit-worthy entities. This amount has been accrued and is primarily reflected in the long-term liability section under “Other long-term liabilities” on the Consolidated Balance Sheets. The environmental remediation costs associated with these sites are expected to be paid over many years.

The estimated amounts represent only the portion of the cleanup costs attributable to TEC. The estimates to perform the work are based on TEC’s experience with similar work, adjusted for site-specific conditions and agreements with the respective governmental agencies. The estimates are made in current dollars, are not discounted and do not assume any insurance recoveries.

In instances where other PRPs are involved, most of those PRPs are believed to be currently credit-worthy and are likely to continue to be credit-worthy for the duration of the remediation work. However, in those instances that they are not, TEC could be liable for more than TEC’s actual percentage of the remediation costs. Other factors that could impact these estimates include additional testing and investigation which could expand the scope of the cleanup activities, additional liability that might arise from the cleanup activities themselves or changes in laws or regulations that could require additional remediation. Under current regulations, these costs are recoverable through customer rates established in base rate proceedings.

Other Legal Proceedings

Emera and its subsidiaries may, from time to time, be involved in other legal proceedings, claims and litigation that arise in the ordinary course of business which the Company believes would not reasonably be expected to have a material adverse effect on the financial condition of the Company.

C. PRINCIPAL FINANCIAL RISKS AND UNCERTAINTIES

Emera believes the following principal financial risks could materially affect the Company in the normal course of business. Risks associated with derivative instruments and fair value measurements are discussed in note 15 and note 16.

Sound risk management is an essential discipline for running the business efficiently and pursuing the Company’s strategy successfully. Emera has an enterprise-wide risk management process, overseen by its Enterprise Risk Management Committee (“ERMC”) and monitored by the Board of Directors, to ensure an effective, consistent and coherent approach to risk management. The Board of Directors established a Risk and Sustainability Committee (’RSC”) in September 2021. The RSC’s mandate includes oversight of the Company’s Enterprise Risk Management framework, including the identification, assessment, monitoring and management of enterprise risks. It also includes oversight of the Company’s approach to sustainability and its performance relative to its sustainability objectives.

Regulatory and Political Risk

The Company’s rate-regulated subsidiaries and certain investments subject to significant influence are subject to risk of the recovery of costs and investments. Regulatory and political risk can include changes in regulatory frameworks, shifts in government policy, legislative changes, and regulatory decisions.

As cost-of-service utilities with an obligation to serve customers, Emera’s utilities operate under formal regulatory frameworks, and must obtain regulatory approval to change or add rates and/or riders. Emera also holds investments in entities in which it has significant influence, and which are subject to regulatory and political risk including NSPML, LIL, and M&NP. As a regulated Group II pipeline, the tolls of Brunswick Pipeline are regulated by the CER on a complaint basis, as opposed to the regulatory approval process described above. In the absence of a complaint, the CER does not normally undertake a detailed examination of Brunswick Pipeline’s tolls, which are subject to a firm service agreement expiring in 2034, with Repsol Energy North America Canada Partnership. The agreement provides for a predetermined toll increase in the fifth and fifteenth year of the contract.

 

128   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

Regulators administer legislation covering material aspects of the utilities’ businesses, including customer rates and/or riders, the underlying allowed ROEs, deemed capital structures, capital investment, the terms and conditions for the provision of service, performance standards, and affiliate transactions. Costs and investments can be recovered upon approval by the respective regulator as an adjustment to rates and/or riders, which normally requires a public hearing process or may be mandated by other governmental bodies. During public hearing processes, consultants and customer representatives scrutinize the costs, actions and plans of these rate-regulated companies, and their respective regulators determine whether to allow recovery and to adjust rates based upon the evidence and any contrary evidence from other parties. In some circumstances, other government bodies may influence the setting of rates. Regulatory decisions, legislative changes, and prolonged delays in the recovery of costs or regulatory assets could result in decreased rate affordability for customers and could materially affect Emera and its utilities.

Emera’s utilities generally manage this risk through transparent regulatory disclosure, ongoing stakeholder and government consultation and multi-party engagement on aspects such as utility operations, regulatory audits, rate filings and capital plans. The subsidiaries employ a collaborative regulatory approach through technical conferences and, where appropriate, negotiated settlements.

Changes in government and shifts in government policy and legislation can impact the commercial and regulatory frameworks under which Emera and its subsidiaries operate. This includes initiatives regarding deregulation or restructuring of the energy industry. Deregulation or restructuring of the energy industry may result in increased competition and unrecovered costs that could adversely affect operations, net income and cash flows. State and local policies in some United States jurisdictions have sought to prevent or limit the ability of utilities to provide customers the choice to use natural gas while in other jurisdictions policies have been adopted to prevent limitations on the use of natural gas. Changes in applicable state or local laws and regulations, including electrification legislation, could adversely impact PGS and NMGC.

Emera cannot predict future legislative, policy, or regulatory changes, whether caused by economic, political or other factors, or its ability to respond in an effective and timely manner or the resulting compliance costs. Government interference in the regulatory process can undermine regulatory stability, predictability, and independence, and could have a material adverse effect on the Company.

Foreign Exchange Risk

The Company is exposed to foreign currency exchange rate changes. Emera operates internationally, with an increasing amount of the Company’s net income earned outside of Canada. As such, Emera is exposed to movements in exchange rates between the CAD and, particularly, the USD, which could positively or adversely affect results.

Consistent with the Company’s risk management policies, Emera manages currency risks through matching United States denominated debt to finance its United States operations and may use foreign currency derivative instruments to hedge specific transactions and earnings exposure. The Company may enter FX forward and swap contracts to limit exposure on certain foreign currency transactions such as fuel purchases, revenue streams and capital expenditures, and on net income earned outside of Canada. The regulatory framework for the Company’s rate-regulated subsidiaries permits the recovery of prudently incurred costs, including FX.

The Company does not utilize derivative financial instruments for foreign currency trading or speculative purposes or to hedge the value of its investments in foreign subsidiaries. Exchange gains and losses on net investments in foreign subsidiaries do not impact net income as they are reported in AOCI.

Liquidity and Capital Market Risk

Liquidity risk relates to Emera’s ability to ensure sufficient funds are available to meet its financial obligations. Emera manages this risk by forecasting cash requirements on a continuous basis to determine whether sufficient funds are available. Liquidity and capital needs could be financed through internally generated cash flows, asset sales, short-term credit facilities, and ongoing access to capital markets.

Emera’s access to capital and cost of borrowing is subject to several risk factors, including financial market conditions, market disruptions, and ratings assigned by credit rating agencies. Disruptions in capital markets could prevent Emera from issuing new securities or cause the Company to issue securities with less than preferred terms and conditions. Emera’s growth plan requires significant capital investments in PP&E and the risk associated with changes in interest rates could have an adverse effect on the cost of financing. The Company’s future access to capital and cost of borrowing may be impacted by various market disruptions. The inability to access cost-effective capital could have a material impact on Emera’s ability to fund its growth plan.

 

  EMERA 2022 ANNUAL REPORT   129


Notes to the Consolidated Financial Statements

 

Emera is subject to financial risk associated with changes in its credit ratings. There are a number of factors that rating agencies evaluate to determine credit ratings, including the Company’s business, its regulatory framework and the legislative environment, political interference in the regulatory process, the ability to recover costs and earn returns, diversification, leverage, liquidity and increased exposure to climate change-related impacts, including increased frequency and severity of hurricanes and other severe weather events. A decrease in a credit rating could result in higher interest rates in future financings, increased borrowing costs under certain existing credit facilities, limit access to the commercial paper market or limit the availability of adequate credit support for subsidiary operations. For certain derivative instruments, if the credit ratings of the Company were reduced below investment grade, the full value of the net liability of these positions could be required to be posted as collateral. Emera manages these risks by actively monitoring and managing key financial metrics with the objective of sustaining investment grade credit ratings.

The Company has exposure to its own common share price through the issuance of various forms of stock-based compensation, which affect earnings through revaluation of the outstanding units every period. The Company uses equity derivatives to reduce the earnings volatility derived from stock-based compensation.

General Economic Risk

The Company has exposure to the macro-economic conditions in North America and in other geographic regions in which Emera operates. Like most utilities, economic factors such as consumer income, employment and housing affect demand for electricity and natural gas, and in turn the Company’s financial results. Adverse changes in general economic conditions and inflation may impact the ability of customers to afford rate increases arising from increases to fuel, operating, capital, environmental compliance, and other costs, and therefore could materially affect Emera and its utilities. This may also result in higher credit and counterparty risk, adverse shifts in government policy and legislation, and/or increased risk to full and timely recovery of costs and regulatory assets.

Interest Rate Risk

Emera utilizes a combination of fixed and floating rate debt financing for operations and capital expenditures, resulting in an exposure to interest rate risk. Emera seeks to manage interest rate risk through a portfolio approach that includes the use of fixed and floating rate debt with staggered maturities. The Company will, from time to time, issue long-term debt or enter interest rate hedging contracts to limit its exposure to fluctuations in floating interest rate debt.

For Emera’s regulated subsidiaries, the cost of debt is a component of rates and prudently incurred debt costs are recovered from customers. Regulatory ROE will generally follow the direction of interest rates, such that regulatory ROE’s are likely to fall in times of reducing interest rates and rise in times of increasing interest rates, albeit not directly and generally with a lag period reflecting the regulatory process. Rising interest rates may also negatively affect the economic viability of project development and acquisition initiatives.

As with most other utilities and other similar yield-returning investments, Emera’s share price may be affected by changes in interest rates and could underperform the market in an environment of rising interest rates.

Inflation Risk

The Company may be exposed to changes in inflation that may result in increased operating and maintenance costs, capital investment, and fuel costs compared to the revenues provided by customer rates. Emera’s utilities have budgeting and forecasting processes to identify inflationary risk factors and measure operating performance, as well as collective bargaining agreements that mitigate the short-term impact of inflation on labour costs.

Commodity Price Risk

The Company’s utility fuel supply is subject to commodity price risk. In addition, Emera Energy is subject to commodity price risk through its portfolio of commodity contracts and arrangements.

The Company manages this risk through established processes and practices to identify, monitor, report and mitigate these risks. These include the Company’s commercial arrangements, such as the combination of supply and purchase agreements, asset management agreements, pipeline transportation agreements and financial hedging instruments. In addition, its credit policies, counterparty credit assessments, market and credit position reporting, and other risk management and reporting practices, are also used to manage and mitigate this risk.

 

130   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

Regulated Utilities

The Company’s utility fuel supply is exposed to broader global conditions, which may include impacts on delivery reliability and price, despite contracted terms. Supply and demand dynamics in fuel markets can be affected by a wide range of factors which are difficult to predict and may change rapidly, including but not limited to currency fluctuations, changes in global economic conditions, natural disasters, transportation or production disruptions, and geo-political risks such as political instability, conflicts, changes to international trade agreements, trade sanctions or embargos. The Company seeks to manage this risk using financial hedging instruments and physical contracts and through contractual protection with counterparties, where applicable.

The majority of Emera’s regulated electric and gas utilities have adopted and implemented fuel adjustment mechanisms and purchased gas adjustment mechanisms respectively, which has further helped manage commodity price risk, as the regulatory framework for the Company’s rate-regulated subsidiaries permits the recovery of prudently incurred fuel and gas costs. There is no assurance that such mechanisms and regulatory frameworks will continue to exist in the future. Prolonged and substantial increases in fuel prices could result in decreased rate affordability, increased risk of recovery of costs or regulatory assets, and/or negative impacts on customer consumption patterns and sales.

Emera Energy Marketing and Trading

Emera Energy has employed further measures to manage commodity risk. The majority of Emera Energy’s portfolio of electricity and gas marketing and trading contracts and, in particular, its natural gas asset management arrangements, are contracted on a back-to-back basis, avoiding any material long or short commodity positions. However, the portfolio is subject to commodity price risk, particularly with respect to basis point differentials between relevant markets in the event of an operational issue or counterparty default. Changes in commodity prices can also result in increased collateral requirements associated with physical contracts and financial hedges, resulting in higher liquidity requirements and increased costs to the business.

To measure commodity price risk exposure, Emera Energy employs a number of controls and processes, including an estimated VaR analysis of its exposures. The VaR amount represents an estimate of the potential change in fair value that could occur from changes in Emera Energy’s portfolio or changes in market factors within a given confidence level, if an instrument or portfolio is held for a specified time period. The VaR calculation is used to quantify exposure to market risk associated with physical commodities, primarily natural gas and power positions.

Income Tax Risk

The computation of the Company’s provision for income taxes is impacted by changes in tax legislation in Canada, the United States and the Caribbean. Any such changes could affect the Company’s future earnings, cash flows, and financial position. The value of Emera’s existing deferred tax assets and liabilities are determined by existing tax laws and could be negatively impacted by changes in laws. Emera monitors the status of existing tax laws to ensure that changes impacting the Company are appropriately reflected in the Company’s tax compliance filings and financial results.

D. GUARANTEES AND LETTERS OF CREDIT

Emera has guarantees and letters of credit on behalf of third parties outstanding. The following significant guarantees and letters of credit are not included within the Consolidated Balance Sheets as at December 31, 2022:

TECO Energy has issued a guarantee in connection with SeaCoast’s performance of obligations under a gas transportation precedent agreement. The guarantee is for a maximum potential amount of $45 million USD if SeaCoast fails to pay or perform under the contract. The guarantee expires five years after the gas transportation precedent agreement termination date, which was terminated on January 1, 2022. In the event that TECO Energy’s and Emera’s long-term senior unsecured credit ratings are downgraded below investment grade by Moody’s Investor Services (“Moody’s”) or S&P Global Ratings (“S&P”). TECO Energy would be required to provide its counterparty a letter of credit or cash deposit of $27 million USD.

TECO Energy issued a guarantee in connection with SeaCoast’s performance obligations under a firm service agreement, which expires on December 31, 2055, subject to two extension terms at the option of the counterparty with a final expiration date of December 31, 2071. The guarantee is for a maximum potential amount of $13 million USD if SeaCoast fails to pay or perform under the firm service agreement. In the event that TECO Energy’s long-term senior unsecured credit ratings are downgraded below investment grade by Moody’s or S&P, TECO Energy would need to provide either a substitute guarantee from an affiliate with an investment grade credit rating or a letter of credit or cash deposit of $13 million USD.

Emera Inc. has issued a guarantee of up to $35 million USD relating to outstanding notes of GBPC. The guarantee for the notes will expire in May 2023.

 

  EMERA 2022 ANNUAL REPORT   131


Notes to the Consolidated Financial Statements

 

Emera Inc. has issued a guarantee of $66 million USD relating to outstanding notes of ECI. This guarantee will automatically terminate on the date upon which the obligations have been repaid in full.

NSPI has issued guarantees on behalf of its subsidiary, NS Power Energy Marketing Incorporated (“NSPEMI”), in the amount of $119 million USD (2021 – $118 million USD) with terms of varying lengths.

The Company has standby letters of credit and surety bonds in the amount of $145 million USD (December 31, 2020 – $148 million USD) to third parties that have extended credit to Emera and its subsidiaries. These letters of credit and surety bonds typically have a one-year term and are renewed annually as required.

Emera Inc., on behalf of NSPI, has a standby letter of credit to secure obligations under a supplementary retirement plan. The expiry date of this letter of credit was extended to June 2023. The amount committed as at December 31, 2022 was $63 million (December 31, 2021 – $64 million).

Collaborative Arrangements

For the years ended December 31, 2022 and 2021, the Company has identified the following material collaborative arrangements:

Through NSPI, the Company is a participant in three wind energy projects in Nova Scotia. The percentage ownership of the wind project assets is based on the relative value of each party’s project assets by the total project assets. NSPI has power purchase arrangements to purchase the entire net output of the projects and, therefore, NSPI’s portion of the revenues are recorded net within regulated fuel for generation and purchased power. NSPI’s portion of operating expenses is recorded in OM&G. In 2022, NSPI recognized $12 million net expense (2021 – $18 million) in “Regulated fuel for generation and purchased power” and $3 million (2021 – $3 million) in OM&G.

 

28.

Cumulative Preferred Stock

Authorized:

Unlimited number of First Preferred shares, issuable in series.

Unlimited number of Second Preferred shares, issuable in series.

 

                   December 31, 2022      December 31, 2021  
     Annual Dividend
per Share
     Redemption
Price per Share
     Issued and
Outstanding
     Net
Proceeds
     Issued and
Outstanding
     Net
Proceeds
 

Series A

   $ 0.5456      $ 25.00        4,866,814      $ 119        4,866,814      $ 119  

Series B

     Floating      $ 25.00        1,133,186      $ 28        1,133,186      $ 28  

Series C

   $ 1.1802      $ 25.00        10,000,000      $ 245        10,000,000      $ 245  

Series E

   $ 1.1250      $ 25.00        5,000,000      $ 122        5,000,000      $ 122  

Series F

   $ 1.0505      $ 25.00        8,000,000      $ 195        8,000,000      $ 195  

Series H

   $ 1.2250      $ 25.00        12,000,000      $ 295        12,000,000      $ 295  

Series J

   $ 1.0625      $ 25.00        8,000,000      $ 196        8,000,000      $ 196  

Series L

   $ 1.1500      $ 26.00        9,000,000      $ 222        9,000,000      $ 222  
        

 

 

    

 

 

    

 

 

    

 

 

 

Total

           58,000,000      $ 1,422        58,000,000      $ 1,422  
        

 

 

    

 

 

    

 

 

    

 

 

 

 

132   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

Characteristics of the First Preferred Shares:

 

First Preferred Shares (1) (2)

   Initial
Yield
(%)
     Current
Annual
Dividend
($)
     Minimum
Reset
Dividend Yield
(%)
     Earliest Redemption
and/or Conversion
Option Date
     Redemption
Value
($)
     Right to
Convert on
a One for
One Basis
 

Fixed rate reset (3) (4)

                 

Series A

     4.400        0.5456        1.84        August 15, 2025        25.00        Series B  

Series C

     4.100        1.1802        2.65        August 15, 2023        25.00        Series D  

Series F

     4.202        1.0505        2.63        February 15, 2025        25.00        Series G  

Minimum rate reset (3) (4)

                 

Series B

     2.393        Floating        1.84        August 15, 2025        25.00        Series A  

Series H

     4.900        1.2250        4.90        August 15, 2023        25.00        Series I  

Series J

     4.250        1.0625        4.25        May 15, 2026        25.00        Series K  

Perpetual fixed rate

                 

Series E (5)

     4.500        1.1250              25.00     

Series L (6)

     4.600        1.1500           November 15, 2026        26.00     

 

(1)

Holders are entitled to receive fixed or floating cumulative cash dividends when declared by the Board of Directors of the Corporation.

(2)

On or after the specified redemption dates, the Corporation has the option to redeem for cash the outstanding First Preferred Shares, in whole or in part, at the specified per share redemption value plus all accrued and unpaid dividends up to but excluding the dates fixed for redemption.

(3)

On the redemption and/or conversion option date the reset annual dividend per share will be determined by multiplying $25.00 per share by the annual fixed or floating dividend rate, which for Series A, C, F and H is the sum of the five-year Government of Canada Bond Yield on the applicable reset date, plus the applicable reset dividend yield (Series H annual reset rate must be a minimum of 4.90 per cent) and for Series B equals the Government of Treasury Bill Rate on the applicable reset date, plus 1.84 per cent.

(4)

On each conversion option date, the holders have the option, subject to certain conditions, to convert any or all of their Shares into an equal number of Cumulative Redeemable First Preferred Shares of a specified series. The Company has the right to redeem the outstanding Preferred Shares, Series D, Series G and Series I shares without the consent of the holder every five years thereafter for cash, in whole or in part at a price of $25.00 per share plus all accrued and unpaid dividends up to but excluding the date fixed for redemption and $25.50 per share plus all accrued and unpaid dividends up to but excluding the date fixed for redemption in the case of redemptions on any other date after August 15, 2023, February 15, 2025 and August 15, 2023, respectively. The reset dividend yield for Series I equals the Government of Treasury Bill Rate on the applicable reset date, plus 2.54 per cent.

(5)

First Preferred Shares, Series E are redeemable at $25.00 per share.

(6)

First Preferred Shares, Series L are redeemable at $26.00 on or after November 15, 2026 to November 15, 2027, decreasing $0.25 each year until November 15, 2030 and $25.00 per share thereafter.

First Preferred Shares are neither redeemable at the option of the shareholder nor have a mandatory redemption date. They are classified as equity and the associated dividends are deducted on the Consolidated Statements of Income before arriving at “Net income attributable to common shareholders” and shown on the Consolidated Statement of Equity as a deduction from retained earnings.

The First Preferred Shares of each series rank on a parity with the First Preferred Shares of every other series and are entitled to a preference over the Second Preferred Shares, the Common Shares, and any other shares ranking junior to the First Preferred Shares with respect to the payment of dividends and the distribution of the remaining property and assets or return of capital of the Company in the liquidation, dissolution or wind-up, whether voluntary or involuntary.

In the event the Company fails to pay, in aggregate, eight quarterly dividends on any series of the First Preferred Shares, the holders of the First Preferred Shares, for only so long as the dividends remain in arrears, will be entitled to attend any meeting of shareholders of the Company at which directors are to be elected and to vote for the election of two directors out of the total number of directors elected at any such meeting.

 

29.

Non-Controlling Interest in Subsidiaries

 

As at

millions of dollars

   December 31
2022
     December 31
2021
 

Preferred shares of GBPC

   $ 14      $ 14  

Domlec (1)

     —          20  
  

 

 

    

 

 

 
   $ 14      $ 34  
  

 

 

    

 

 

 

 

(1)

On March 31, 2022, Emera disposed its interest in Domlec. For further details, refer to note 4.

 

  EMERA 2022 ANNUAL REPORT   133


Notes to the Consolidated Financial Statements

 

PREFERRED SHARES OF GBPC:

Authorized:

10,000 non-voting cumulative redeemable variable perpetual preferred shares.

 

            2022             2021  

Issued and outstanding:

   number of
shares
     millions of
dollars
     number of
shares
     millions of
dollars
 

Outstanding as at December 31

     10,000      $ 14        10,000      $ 14  

GBPC NON–VOTING CUMULATIVE VARIABLE PERPETUAL PREFERRED STOCK:

The preferred shares are redeemable by GBPC after June 17, 2021, at $1,000 Bahamian per share plus accrued and unpaid dividends and are entitled to a 6.0 per cent per annum fixed cumulative preferential dividend to be paid semi-annually.

The Preferred Shares rank behind GBPC’s current and future secured and unsecured debt and ahead of all of GBPC’s current and future common stock.

 

30.

Supplementary Information to Consolidated Statements of Cash Flows

 

For the    Year ended December 31  

millions of dollars

   2022      2021  

Changes in non-cash working capital:

     

Inventory

   $ (214 )     $ (84 ) 

Receivables and other current assets (1)

     (636 )       (364 ) 

Accounts payable

     423        289  

Other current liabilities (2)

     193        7  
  

 

 

    

 

 

 

Total non-cash working capital

   $ (234 )     $ (152 ) 
  

 

 

    

 

 

 

 

(1)

Includes $(162) million related to the January 2023 settlement of NMGC gas hedges. Offsetting regulatory liability is included in operating cash flow before working capital resulting in no impact to net cash provided by operating activities.

(2)

Includes $172 million related to the Nova Scotia Cap-and-Trade program. For further detail, refer to note 7. Offsetting regulatory asset (FAM) balance is included in operating cash flow before working capital resulting in no impact to net cash provided by operating activities.

 

Supplemental disclosure of cash paid (received):

     

Interest

   $ 699      $ 603  
  

 

 

    

 

 

 

Income taxes

   $ 67      $ 24  
  

 

 

    

 

 

 

Supplemental disclosure of non-cash activities:

     

Common share dividends reinvested

   $ 237      $ 214  
  

 

 

    

 

 

 

Reclassification of long-term debt to short-term debt

   $ 500      $ —    
  

 

 

    

 

 

 

Decrease in accrued capital expenditures

   $ (13 )     $ (45 ) 
  

 

 

    

 

 

 

Supplemental disclosure of operating activities:

     

Net change in short-term regulatory assets and liabilities

   $ (157 )     $ (108 ) 
  

 

 

    

 

 

 

 

31.

Stock-Based Compensation

EMPLOYEE COMMON SHARE PURCHASE PLAN AND COMMON SHAREHOLDERS DIVIDEND REINVESTMENT AND SHARE PURCHASE PLAN

Eligible employees may participate in Emera’s Employee Common Share Purchase Plan. As of December 31, 2022, the plan allows employees to make cash contributions of a minimum of $25 to a maximum of $20,000 CAD or $15,000 USD per year for the purpose of purchasing common shares of Emera. The Company also contributes 20 per cent of the employees’ contributions to the plan.

The plan allows the reinvestment of dividends for all participants except for where it is prohibited by law. The maximum aggregate number of Emera common shares reserved for issuance under this plan is 7 million common shares. As at December 31, 2022, Emera is in compliance with this requirement.

 

134   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

Compensation cost for shares issued under the Employee Common Share Purchase Plan for the year ended December 31, 2022 was $3 million (2021 – $3 million) and is included in OM&G on the Consolidated Statements of Income.

The Company also has a Common Shareholders Dividend Reinvestment and Share Purchase Plan (“Dividend Reinvestment Plan”), which provides an opportunity for shareholders to reinvest dividends and purchase common shares. This plan provides for a discount of up to 5 per cent from the average market price of Emera’s common shares for common shares purchased in connection with the reinvestment of cash dividends. The discount was 2 per cent in 2022.

STOCK-BASED COMPENSATION PLANS

Stock Option Plan

The Company has a stock option plan that grants options to senior management of the Company for a maximum term of 10 years. The option price of the stock options is the closing price of the Company’s common shares on the Toronto Stock Exchange on the last business day on which such shares were traded before the date on which the option is granted. The maximum aggregate number of shares issuable under this plan is 14.7 million shares. As at December 31, 2022, Emera is in compliance with this requirement.

Stock options granted in 2021 and prior vest in 25 per cent increments on the first, second, third and fourth anniversaries of the date of the grant. Stock options granted in 2022 vest in 20 per cent increments on the first, second, third, fourth and fifth anniversaries of the date of the grant. If an option is not exercised within 10 years, it expires and the optionee loses all rights thereunder. The holder of the option has no rights as a shareholder until the option is exercised and shares have been issued. The total number of stocks to be optioned to any optionee shall not exceed five per cent of the issued and outstanding common stocks on the date the option is granted.

For stock options granted in 2021 and prior, unless a stock option has expired, vested options may be exercised within the 27 months following the option holders date of retirement, six months following a termination without just cause or death, and within sixty days following the date of termination for just cause or resignation. Commencing with the 2022 stock option grant, vested options may be exercised during the full term of the option following the option holders date of retirement, six months following a termination without just cause or death, and within sixty days following the date of termination for just cause or resignation. If stock options are not exercised within such time, they expire.

The Company uses the Black-Scholes valuation model to estimate the compensation expense related to its stock-based compensation and recognizes the expense over the vesting period on a straight-line basis.

The following table shows the weighted average fair values per stock option along with the assumptions incorporated into the valuation models for options granted, for the year-ended December 31:

 

     2022     2021  

Weighted average fair value per option

   $ 5.35     $ 3.63  

Expected term (1)

     5 years     5 years  

Risk-free interest rate (2)

     1.79 %      0.60 % 

Expected dividend yield (3)

     4.55 %      5.00 % 

Expected volatility (4)

     18.87 %      19.14 % 

 

(1)

The expected term of the option awards is calculated based on historical exercise behaviour and represents the period of time that the options are expected to be outstanding.

(2)

Based on the Bank of Canada five-year government bond yields.

(3)

Incorporates current dividend rates and historical dividend increase patterns.

(4)

Estimated using the five-year historical volatility.

 

  EMERA 2022 ANNUAL REPORT   135


Notes to the Consolidated Financial Statements

 

The following table summarizes stock option information for 2022:

 

     Total Options      Non-Vested Options (1)  
     Number of
Options
     Weighted
Average
Exercise Price
per Share
     Number of
Options
    Weighted
Average Grant
Date Fair Value
 

Outstanding as at December 31, 2021

     2,590,304      $ 48.48        1,452,475     $ 3.18  

Granted

     467,100        58.26        467,100       5.35  

Exercised

     (203,525 )       43.87        N/A       N/A  

Vested

     N/A        N/A        (571,175 )      2.83  
  

 

 

    

 

 

    

 

 

   

 

 

 

Options outstanding December 31, 2022

     2,853,879      $ 50.41        1,348,400     $ 4.08  
  

 

 

    

 

 

    

 

 

   

 

 

 

Options exercisable December 31, 2022 (2) (3)

     1,505,479      $ 46.59       
  

 

 

    

 

 

      

 

(1)

As at December 31, 2022, there was $4 million of unrecognized compensation related to stock options not yet vested which is expected to be recognized over a weighted average period of approximately 3 years (2021 – $3 million, 3 years).

(2)

As at December 31, 2022, the weighted average remaining term of vested options was 5 years with an aggregate intrinsic value of $10 million (2021 – 6 years, $21 million).

(3)

As at December 31, 2022, the fair value of options that vested in the year was $2 million (2021 – $1 million).

Compensation cost recognized for stock options for the year ended December 31, 2022 was $2 million (2021 – $2 million), which is included in OM&G on the Consolidated Statements of Income.

As at December 31, 2022, cash received from option exercises was $9 million (2021 – $14 million). The total intrinsic value of options exercised for the year ended December 31, 2022 was $4 million (2021 – $6 million). The range of exercise prices for the options outstanding as at December 31, 2022 was $32.35 to $60.03 (2021 – $32.35 to $60.03).

SHARE UNIT PLANS

The Company has DSU, PSU and RSU plans. The plans and the liabilities are marked-to-market at the end of each period based on an average common share price at the end of the period.

Deferred Share Unit Plans

Under the Directors’ DSU plan, Directors of the Company may elect to receive all or any portion of their compensation in DSUs in lieu of cash compensation, subject to requirements to receive a minimum portion of their annual retainer in DSUs. Directors’ fees are paid on a quarterly basis and, at the time of each payment of fees, the applicable amount is converted to DSUs. A DSU has a value equal to one Emera common share. When a dividend is paid on Emera’s common shares, the Director’s DSU account is credited with additional DSUs. DSUs cannot be redeemed for cash until the Director retires, resigns or otherwise leaves the Board. The cash redemption value of a DSU equals the market value of a common share at the time of redemption, pursuant to the plan. Following retirement or resignation from the Board, the value of the DSUs credited to the participant’s account is calculated by multiplying the number of DSUs in the participant’s account by Emera’s closing common share price on the date DSUs are redeemed.

Under the executive and senior management DSU plan, each participant may elect to defer all or a percentage of their annual incentive award in the form of DSUs with the understanding, for participants who are subject to executive share ownership guidelines, a minimum of 50 per cent of the value of their actual annual incentive award (25 per cent in the first year of the program) will be payable in DSUs until the applicable guidelines are met.

When short-term incentive awards are determined, the amount elected is converted to DSUs, which have a value equal to the market price of an Emera common share. When a dividend is paid on Emera’s common shares, each participant’s DSU account is allocated additional DSUs equal in value to the dividends paid on an equivalent number of Emera common shares. Following termination of employment or retirement, and by December 15 of the calendar year after termination or retirement, the value of the DSUs credited to the participant’s account is calculated by multiplying the number of DSUs in the participant’s account by the average of Emera’s stock closing price for the fifty trading days prior to a given calculation date. Payments are made in cash.

In addition, special DSU awards may be made from time to time by the Management Resources and Compensation Committee (“MRCC”), to selected executives and senior management to recognize singular achievements or by achieving certain corporate objectives.

 

136   EMERA 2022 ANNUAL REPORT  


Notes to the Consolidated Financial Statements

 

A summary of the activity related to employee and director DSUs for the year ended December 31, 2022 is presented in the following table:

 

     Employee
DSU
     Weighted
Average Grant
Date Fair Value
     Director
DSU
    Weighted
Average Grant
Date Fair Value
 

Outstanding as at December 31, 2021

     610,601      $ 39.22        614,365     $ 43.80  

Granted including DRIP

     76,252        52.42        104,465       57.89  

Exercised

     (59,630 )       31.57        (54,572 )      46.04  
  

 

 

    

 

 

    

 

 

   

 

 

 

Outstanding and exercisable as at December 31, 2022

     627,223      $ 41.55        664,258     $ 45.83  
  

 

 

    

 

 

    

 

 

   

 

 

 

Compensation cost recovery recognized for employee and director DSU’s for the year ended December 31, 2022 was $6 million (2021 – $9 million expense). Tax expense related to this compensation cost recovery for share units realized for the year ended December 31, 2022 was $2 million (2021 – $3 million tax recovery). The aggregate intrinsic value of the outstanding shares for the year ended December 31, 2022 for employees was $33 million (2021 – $39 million). The aggregate intrinsic value of the outstanding shares for the year ended December 31, 2022 for directors was $34 million (2021 – $39 million). Cash payments made during the year ended December 31, 2021 associated with the DSU plan was $8 million (2021 – $11 million).

Performance Share Unit Plan

Under the PSU plan, certain executive and senior employees are eligible for long-term incentives payable through the PSU plan. PSUs are granted annually for three-year overlapping performance cycles, resulting in a cash payment. PSUs are granted based on the average of Emera’s stock closing price for the fifty trading days prior to the effective grant date. Dividend equivalents are awarded and paid in the form of additional PSUs. The PSU value varies according to the Emera common share market price and corporate performance.

PSUs vest at the end of the three-year cycle and the payouts will be calculated and approved by the MRCC early in the following year. The value of the payout considers actual service over the performance cycle and may be pro-rated in certain departure scenarios.

A summary of the activity related to employee PSUs for the year ended December 31, 2022 is presented in the following table:

 

     Employee
PSU
     Weighted
Average Grant
Date Fair Value
     Aggregate
Intrinsic Value
 

Outstanding as at December 31, 2021

     951,935      $ 48.60      $ 66  

Granted including DRIP

     242,462        59.30     

Exercised

     (357,960 )       42.85     

Forfeited

     (145,991 )       44.28     
  

 

 

    

 

 

    

 

 

 

Outstanding as at December 31, 2022

     690,446      $ 56.24      $ 40  
  

 

 

    

 

 

    

 

 

 

Compensation cost recognized for the PSU plan for the year ended December 31, 2022 was $18 million (2021 – $12 million). Tax benefits related to this compensation cost for share units realized for the year ended December 31, 2022 were $5 million (2021 – $3 million). Cash payments made during the year ended December 31, 2021 associated with the PSU plan was $24 million (2021 – $29 million).

Restricted Share Unit Plan

Under the RSU plan, certain executive and senior employees are eligible for long-term incentives payable through the RSU plan. RSUs are granted annually for three-year overlapping performance cycles, resulting in a cash payment. RSUs are granted based on the average of Emera’s stock closing price for the fifty trading days prior to the effective grant date. Dividend equivalents are awarded and paid in the form of additional RSUs. The RSU value varies according to the Emera common share market price.

RSUs vest at the end of the three-year cycle and the payouts will be calculated and approved by the MRCC early in the following year. The value of the payout considers actual service over the performance cycle and may be pro-rated in certain departure scenarios.

 

  EMERA 2022 ANNUAL REPORT   137


Notes to the Consolidated Financial Statements

 

A summary of the activity related to employee RSUs for the year ended December 31, 2022 is presented in the following table:

 

     Employee
RSU
     Weighted
Average Grant
Date Fair Value
     Aggregate
Intrinsic Value
 

Outstanding as at December 31, 2021

     343,952      $ 54.64      $ 24  

Granted including DRIP

     180,426        59.30     

Exercised

     (134 )       54.63     

Forfeited

     (15,776 )       56.08     
  

 

 

    

 

 

    

 

 

 

Outstanding as at December 31, 2022

     508,468      $ 56.25      $ 30  
  

 

 

    

 

 

    

 

 

 

Compensation cost recognized for the RSU plan for the year ended December 31, 2022 was $9 million (2021 – $8 million). Tax benefits related to this compensation cost for share units realized for the year ended December 31, 2022 were $2 million (2021 – $2 million). Cash payments made during the year ended December 31, 2022 associated with the RSU plan was nil (2021 – nil).

 

32.

Variable Interest Entities

Emera holds a variable interest in NSPML, a VIE for which it was determined that Emera is not the primary beneficiary since it does not have the controlling financial interest of NSPML. When the critical milestones were achieved, Nalcor Energy was deemed the primary beneficiary of the asset for financial reporting purposes as it has authority over the majority of the direct activities that are expected to most significantly impact the economic performance of the Maritime Link. Thus, Emera began recording the Maritime Link as an equity investment.

BLPC has established a Self-Insurance Fund (“SIF”), primarily for the purpose of building a fund to cover risk against damage and consequential loss to certain generating, transmission and distribution systems. ECI holds a variable interest in the SIF for which it was determined that ECI was the primary beneficiary and, accordingly, the SIF must be consolidated by ECI. In its determination that ECI controls the SIF, management considered that, in substance, the activities of the SIF are being conducted on behalf of ECI’s subsidiary BLPC and BLPC, alone, obtains the benefits from the SIF’s operations. Additionally, because ECI, through BLPC, has rights to all the benefits of the SIF, it is also exposed to the risks related to the activities of the SIF. Any withdrawal of SIF fund assets by the Company would be subject to existing regulations. Emera’s consolidated VIE in the SIF is recorded as “Other long- term assets”, “Restricted cash” and “Regulatory liabilities” on the Consolidated Balance Sheets. Amounts included in restricted cash represent the cash portion of funds required to be set aside for the BLPC SIF.

The Company has identified certain long-term purchase power agreements that meet the definition of variable interests as the Company has to purchase all or a majority of the electricity generation at a fixed price. However, it was determined that the Company was not the primary beneficiary since it lacked the power to direct the activities of the entity, including the ability to operate the generating facilities and make management decisions.

The following table provides information about Emera’s portion of material unconsolidated VIEs:

 

As at

   December 31, 2022      December 31, 2021  

millions of dollars

   Total
Assets
     Maximum
Exposure to
Loss
     Total Assets      Maximum
Exposure to
Loss
 

Unconsolidated VIEs in which Emera has variable interests

           

NSPML (equity accounted)

   $ 501      $ 6      $ 533      $ 11  

 

33.

Comparative Information

These financial statements contain certain reclassifications of prior period amounts to be consistent with the current period presentation, with no effect on net income.

 

34.

Subsequent Events

These financial statements and notes reflect the Company’s evaluation of events occurring subsequent to the balance sheet date through February 23, 2023, the date the financial statements were issued.

 

138   EMERA 2022 ANNUAL REPORT  


Emera Leadership and Board

As of March 31, 2023

 

Emera Leadership

Scott Balfour

President and

Chief Executive Officer, Emera Inc.

Mike Barrett

Executive Vice President, Legal and General Counsel, Emera Inc.

Greg Blunden

Chief Financial Officer, Emera Inc.

Archie Collins

President and Chief Executive Officer, Tampa Electric

Peter Gregg

President and Chief Executive Officer, Nova Scotia Power

Karen Hutt

Executive Vice President, Business Development and Strategy,

Emera Inc.

Bruce Marchand

Chief Risk and Sustainability Officer,

Emera Inc.

Dan Muldoon

Executive Vice President, Project Development and Operations Support, Emera Inc.

Michael Roberts

Chief Human Resources Officer,

Emera Inc.

Ryan Shell

President,

New Mexico Gas Company

Judy Steele

President and

Chief Operating Officer, Emera Energy

Helen Wesley

President, Peoples Gas

Board of Directors

Jackie Sheppard

Chair, Emera Board of Directors

Calgary, Alberta

Scott Balfour

President and

Chief Executive Officer Halifax, Nova Scotia

James Bertram

Calgary, Alberta

Henry Demone

Lunenburg, Nova Scotia

Paula Gold-Williams

San Antonio, Texas

Kent Harvey

New York, New York

Lynn Loewen

Westmount, Quebec

Ian Robertson

Oakville, Ontario

Andrea Rosen

Toronto, Ontario

Richard Sergel

Boston, Massachusetts

Karen Sheriff

Picton, Ontario

Jochen Tilk

Toronto, Ontario

 

 

  EMERA 2022 ANNUAL REPORT   139


Shareholder Information

 

For general inquiries, please contact our corporate office:

Emera Inc.

P.O. Box 910

Halifax, Nova Scotia B3J 2W5

T: 902.450.0507 or 1.888.450.0507

Information regarding Company news and initiatives, including our 2022 Annual Report, is available on our website: www.emera.com

Transfer Agent

TSX Trust Company

P.O. Box 2082, Station C

Halifax, NS B3J 3B7

T: 1.877.982.8762

F: 1.888.249.6189

www.tsxtrust.com

Investor Services

T: 902.428.6060 or 1.800.358.1995

F: 902.428.6181

E: investors@emera.com

Financial Analysts, Portfolio Managers and Institutional Investors

Dave Bezanson

Vice President, Investor Relations and Pensions

T: 902.474.2126

E: dave.bezanson@emera.com

Arianne Amirkhalkhali

Manager, Investor Relations

T: 902.425.8130

E: arianne.amirkhalkhali@emera.com

This Annual Report contains forward- looking information. Actual future results may differ materially. Additional financial and operational information is filed electronically with various securities commissions in Canada through the System for Electronic Document Analysis and Retrieval (SEDAR).

Share Listings

Toronto Stock Exchange (TSX) Common shares: EMA Preferred shares: EMA.PR.A, EMA.PR.B, EMA.PR.C, EMA.PR.E, EMA.PR.F, EMA.PR.H, EMA.PR.J and EMA.PR.L Barbados Stock Exchange (BSE) Depositary receipts: EMABDR Bahamas International Securities Exchange (BISX) Depositary receipts: EMAB

Shares Outstanding

Common shares: 269,944,308 (as of December 31, 2022)

Dividends Paid in 2022

Emera Inc. paid common share dividends of $0.6625 per quarter in Q1, Q2 and Q3 (annualized rate of $2.65 per common share) and $0.69 in Q4 (annualized rate of $2.76 per common share), for an effective annual common share dividend rate of $2.6775 per common share.

Dividend Payments in 2023

Subject to approval by the Board of Directors, dividends for Emera Inc. are payable on or about the 15th of February, May, August and November. A first quarter common share dividend of $0.69, a Series A First Preferred Share dividend of $0.1364, a Series B First Preferred Share dividend of $0.3570, a Series C First Preferred Share dividend of $0.29506, a Series E First Preferred Share dividend of $0.28125, a Series F First Preferred Share dividend of $0.26263, a Series H First Preferred Share dividend of $0.30625, a Series J First Preferred Share dividend of $0.265625 and a Series L First Preferred Share dividend of $0.2875 were declared and paid on February 15, 2023.

Dividend Reinvestment and Share Purchase Plan

Emera’s Dividend Reinvestment and Share Purchase Plan is available to shareholders who reside in Canada. The plan provides a convenient and economical means of acquiring additional common shares through the reinvestment of dividends with a discount of up to five per cent. In 2022, the discount was two per cent. Plan participants may also contribute cash payments of up to $5,000 per quarter. Plan participants pay no commissions, service charges or brokerage fees for shares purchased under the plan. Please contact Investor Services if you have questions or wish to receive an enrollment form.

Direct Deposit Service

Registered shareholders may have dividends deposited directly to any bank account in Canada. To arrange this service, please contact TSX Trust Company. Beneficial shareholders should contact their financial intermediary.

Quarterly Earnings

Quarterly earnings are expected to be announced in May, August and November 2023. Year-end results for 2022 were released in February 2023.

 

 

 

LOGO

Emera is represented in the TSX Composite, TSX Capped Utilities, TSX60 and select MSCI and FTSE World indexes.

Shareholder Information

 

 

140   EMERA 2022 ANNUAL REPORT  


Our Operating Companies
As of March 31, 2023     

TAMPA ELECTRIC

 

Vertically integrated electric utility serving about 830,000 customers in west central Florida.

 

NOVA SCOTIA POWER

 

Vertically integrated electric utility serving approximately 540,000 customers in Nova Scotia.

 

PEOPLES GAS

 

Natural gas utility serving 470,000 customers in Florida.

 

NEW MEXICO GAS

 

Natural gas utility serving 540,000 customers in New Mexico.

 

EMERA CARIBBEAN

 

Vertically integrated electric utilities serving more than 150,000 customers on the islands of Barbados and Grand Bahama.

             

EMERA NEWFOUNDLAND & LABRADOR

 

Owns and operates the Maritime Link and manages Emera’s investment in an associated project.

 

EMERA ENERGY

 

Energy marketing and trading, asset management and optimization in Canada and the US.

 

EMERA NEW BRUNSWICK

 

Owns and operates the Brunswick pipeline, a 145-kilometre natural gas pipeline in New Brunswick.

 

EMERA TECHNOLOGIES

 

A technology company focused on finding new, innovative ways to deliver renewable and resilient energy to customers.

www.emera.com


LOGO

Exhibit 99.3

 

LOGO    LOGO

Form of Proxy - Emera Incorporated

Annual Shareholders Meeting of May 24, 2023

Appointment of Proxyholder

I/We, being holder(s) of Emera Incorporated (the “Company”) common shares, hereby appoint: M. Jacqueline Sheppard, or failing her, Scott C. Balfour, or failing him, Stephen D. Aftanas, OR

 

                                                                                                                                                                                                

[Print the name of the person you are appointing if this person is someone other than the individuals listed above.]

as proxy of the undersigned, to participate, act and vote on behalf of the undersigned in accordance with the below direction (or if no directions have been given, as the proxy sees fit) on all of the following matters and any other matter that may properly come before the Annual Meeting of Shareholders of the Company to be held at 5:00 p.m. Atlantic time on Wednesday, May 24, 2023, virtually at: https://web.lumiagm.com/458327786, using password: emera2023 (case sensitive) (the “Meeting”), and at any and all adjournments or postponements thereof in the same manner, to the same extent and with the same powers as if the undersigned were personally present, with full power of substitution.

Management recommends voting FOR Resolutions 1, 2, 3, 4 and 5. Please use a dark black pencil or pen.

 

 

1.  Election of Directors

   FOR    WITHHOLD       FOR    WITHHOLD   
 

01.  Scott C. Balfour

   ☐    ☐   

07.  Ian E. Robertson

   ☐    ☐   
 

02.  James V. Bertram

   ☐    ☐   

08.  Andrea S. Rosen

   ☐    ☐   
      

03.  Henry E. Demone

   ☐    ☐   

09.  M. Jacqueline Sheppard

   ☐    ☐   
 

04.  Paula Y. Gold-Williams

   ☐    ☐   

10.  Karen H. Sheriff

   ☐    ☐   
 

05.  Kent M. Harvey

   ☐    ☐   

11.  Jochen E. Tilk

   ☐    ☐   
 

06.  B. Lynn Loewen

   ☐    ☐            
 

2.  Appointment of Auditors

   FOR    WITHHOLD   
 

Appointment of Ernst & Young LLP as auditors

   ☐    ☐   
 

3.  Authorize Remuneration of Auditors

   FOR    AGAINST   
 

Authorize the directors to fix the remuneration of the Auditors pursuant to the Nova Scotia Companies Act

   ☐    ☐   
 

4.  Advisory Vote on Executive Compensation

   FOR    AGAINST   
 

Consider and approve, on an advisory basis, a resolution on Emera’s approach to executive compensation as disclosed in the Management Information Circular

   ☐    ☐   
 

5.  Senior Management Stock Option Plan (“Plan”) Amendment

   FOR    AGAINST   
 

Authorize Directors to amend the Plan text to add a provision for options expiring during a trading blackout period, to extend the expiration of those options to ten (10) business days after a trading blackout period is lifted by the Company

   ☐    ☐   

I/We authorize you to act in accordance with my/our instructions set out above. I/We hereby revoke any proxy previously given with respect to the Meeting.

If no voting instructions are indicated above, this proxy will be voted FOR a matter by Management’s appointees or, if you appoint another proxyholder, as that other proxyholder sees fit. On any amendments or variations proposed or any new business properly submitted before the Meeting, I/We authorize you to vote as you see fit.

 

                                                                                                                                                                                    
Signature(s)    Date

Please sign exactly as your name(s) appears on this proxy. Please see reverse for instructions. All proxies must be received by 12:00 noon Atlantic time, Tuesday, May 23, 2023 or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date.

Under Canadian Securities Law, you are entitled to receive certain investor documents. Electronic financial statements and MD&A are available at www.emera.com and at www.SEDAR.com. If you wish copies, please tick the box below or go to the website https://services.tsxtrust.com/financialstatements and input code 1705a.

 

☐

I would like to receive interim financial statements and MD&A.

☐

I would like to receive annual financial statements and MD&A.


LOGO    LOGO

 

Form of Proxy - Emera Incorporated

Annual Shareholders Meeting of May 24, 2023

 

 

 

1.

Every shareholder has the right to appoint some other person or company of the shareholder’s choice, who need not be a shareholder of Emera Incorporated, as that shareholder’s proxyholder to participate, act and vote on the shareholder’s behalf at the meeting or any adjournment or postponement thereof. If you wish to appoint a person or company other than the persons whose names are printed herein, please insert the name of your chosen proxyholder in the space provided on the reverse and return your proxy by mail, fax or email. In addition, to enable your chosen proxyholder to participate and vote virtually at the Meeting, YOU MUST contact TSX Trust Company “TSX” either by calling 1-866-751-6315 (toll-free in North America) or 1-647-252-9650 (outside North America) or by logging onto the TSX website at: https://www.tsxtrust.com/control-number-request, by 12:00 noon Atlantic time on May 23, 2023 or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date, to request a new Control Number for the meeting. This new Control Number will allow your proxyholder to log in to and vote at the meeting. Without a new Control Number your proxyholder will only be able to log in to the meeting as a guest and will not be able to vote.

 

2.

This proxy confers discretionary authority on the appointee to vote as the appointee sees fit in respect of amendments or variations to matters identified in the notice of meeting or other matters as may properly come before the Meeting or any adjournment or postponement thereof, in each instance to the extent permitted by law, whether or not the amendment or other matter that comes before the meeting is routine and whether or not the amendment or other matter that comes before the meeting is contested.

 

3.

This proxy must be signed by a holder or his or her attorney duly authorized in writing. If you are an individual, please sign exactly as your name appears on this proxy. If the holder is a corporation, a duly authorized officer or attorney of the corporation must sign this proxy.

 

4.

If the securities are registered in the name of an executor, administrator or trustee, please sign exactly as your name appears on this proxy. If the securities are registered in the name of a deceased or other holder, the proxy must be signed by the legal representative with his or her name printed below his or her signature, and evidence of authority to sign on behalf of the deceased or other holder must be attached to this proxy.

 

5.

Some holders may own securities as both a registered and a beneficial holder and will need to vote separately as a registered holder and as a beneficial holder. Beneficial holders may be forwarded either a form of proxy already signed by the intermediary or a voting instruction form to allow them to direct the voting of securities they beneficially own. Beneficial holders should follow instructions for voting conveyed to them by their intermediaries.

 

6.

If a security is held by two or more individuals, any one of them present or represented by proxy at the Meeting may, in the absence of the other or others, vote at the Meeting. However, if one or more of them are present or represented by proxy, they must vote together the number of securities indicated on the proxy.

 

7.

If this proxy is not dated, it will be deemed to bear the date on which it was mailed on behalf of management of the Company to you.

All holders should refer to the Management Information Circular for further information regarding completion and use of this proxy and other information pertaining to the Meeting.

This proxy is solicited by and on behalf of Management of the Company.

Emera offers a number of ways to cast your vote prior to the meeting. By using one of these ways provided for you, you will be considered to have signed and returned this proxy.

 

LOGO INTERNET    LOGO TELEPHONE    LOGO SMARTPHONE
     

•   Go to www.meeting-vote.com

 

•   Follow the instructions on the screen

 

•   You will be required to enter the 13-digit control number located on the reverse

 

•   No need to return this proxy

  

•   Use any touch-tone telephone, call toll free in Canada and United States 1-888-489-5760 (English only) or 1-888-489-7352 (Bilingual)

 

•   Follow the voice instructions

 

•   When prompted, enter the 13-digit control number located on the reverse

 

•   No need to return this proxy

  

To vote using your smartphone, please scan this QR Code. No need to return this proxy.

 

LOGO

LOGO  MAIL    LOGO FAX    LOGO  EMAIL
     

 

•   Complete the reverse of this form

 

•   Return your signed proxy in the envelope provided or send to:

TSX Trust Company

P.O. Box 721

Agincourt, ON M1S 0A1

  

 

•   Complete the reverse of this form and fax your signed proxy to 416-595-9593.

  

•   Complete the reverse of this form

 

•   Scan your signed proxy and email it to proxyvote@tmx.com.

All proxies must be received by 12:00 noon Atlantic time, Tuesday, May 23, 2023 or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date.

Exhibit 99.4

 

LOGO    LOGO

Voting Instruction Form (“VIF”) - Emera Incorporated

Annual Shareholders Meeting of May 24, 2023

Appointee

I/We, being holder(s) of Emera Incorporated (the “Company”) common shares, hereby appoint: M. Jacqueline Sheppard, or failing her, Scott C. Balfour, or failing him, Stephen D. Aftanas, OR

 

                                                                                                                                                                                                              

[To participate in the meeting and vote or to appoint someone to participate and vote on your behalf, print the name of the attendee here.]

as proxy of the undersigned, to participate, act and vote on behalf of the undersigned in accordance with the below direction (or if no directions have been given, as the proxy sees fit) on all of the following matters and any other matter that may properly come before the Annual Meeting of Shareholders of the Company to be held at 5:00 p.m. Atlantic time on Wednesday, May 24, 2023, virtually via webcast at: https://web.lumiagm.com/458327786, using password: emera2023 (case sensitive) (the “Meeting”), and at any and all adjournments or postponements thereof in the same manner, to the same extent and with the same powers as if the undersigned were personally present, with full power of substitution.

Management recommends voting FOR Resolutions 1, 2, 3, 4 and 5. Please use a dark black pencil or pen.

 

 

1.  Election of Directors

   FOR    WITHHOLD       FOR    WITHHOLD   
      

01.  Scott C. Balfour

   ☐    ☐   

07.  Ian E. Robertson

   ☐    ☐   
 

02.  James V. Bertram

   ☐    ☐   

08.  Andrea S. Rosen

   ☐    ☐   
 

03.  Henry E. Demone

   ☐    ☐   

09.  M. Jacqueline Sheppard

   ☐    ☐   
 

04.  Paula Y. Gold-Williams

   ☐    ☐   

10.  Karen H. Sheriff

   ☐    ☐   
 

05.  Kent M. Harvey

   ☐    ☐   

11.  Jochen E. Tilk

   ☐    ☐   
 

06.  B. Lynn Loewen

   ☐    ☐            
 

2.  Appointment of Auditors

   FOR    WITHHOLD   
 

Appointment of Ernst & Young LLP as auditors

   ☐    ☐   
 

3.  Authorized Remuneration of Auditors

   FOR    AGAINST   
 

Authorize Directors to fix the remuneration of the Auditors pursuant to the Nova Scotia Companies Act

   ☐    ☐   
 

4.  Advisory Vote on Executive Compensation

   FOR    AGAINST   
 

Consider and approve, on an advisory basis, a resolution on Emera’s approach to executive compensation as disclosed in the Management Information Circular

   ☐    ☐   
 

5.  Senior Management Stock Option Plan (“Plan”) Amendment

   FOR    AGAINST   
 

Authorize Directors to amend the Plan text to add a provision for options expiring during a trading blackout period, to extend the expiration of those options to ten (10) business days after a trading blackout period is lifted by the Company

   ☐    ☐   

I/We authorize you to act in accordance with my/our instructions set out above. I/We hereby revoke any proxy previously given with respect to the Meeting.

If no voting instructions are indicated above, this VIF will be voted FOR a matter by Management’s appointees or, if you appoint another person, as such other person sees fit. On any amendments or variations proposed or any new business properly submitted before the Meeting, I/We authorize you to vote as you see fit.

 

 

Signature(s)

                     

 

Date

                   

Please sign exactly as your name(s) appears on this VIF. Please see reverse for instructions. All VIFs must be received by 12:00 noon Atlantic time, Tuesday, May 23, 2023 or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date.

Under Canadian Securities Law, you are entitled to receive certain investor documents. Electronic financial statements and MD&A are available at www.emera.com and at www.SEDAR.com. If you wish copies, please tick the box below or go to the website https://services.tsxtrust.com/financialstatements and input code 1705a.

 

☐

I would like to receive interim financial statements and MD&A

☐

I would like to receive annual financial statements and MD&A


LOGO                 LOGO

Voting Instruction Form (“VIF”) - Emera Incorporated

Annual Shareholders Meeting of May 24, 2023

 

 

 

1.

We are sending to you the enclosed proxy-related materials that relate to a meeting of holders of Emera Incorporated’s common shares. Unless you, as an appointee, or an alternate appointee participate(s) in the Meeting and vote(s) in person or virtually, your securities can be voted only by management, as appointee of the registered holder, in accordance with your instructions.

 

2.

Every shareholder has the right to appoint some other person or company of the shareholder’s choice, who need not be a shareholder of Emera Incorporated, to participate and act on the shareholder’s behalf at the meeting or any adjournment or postponement thereof. If you wish to appoint a person or company other than the persons whose names are printed herein, please insert the name of your chosen proxyholder in the space provided on the reverse and return your proxy by mail, fax or email. In addition, to enable your chosen proxyholder to participate and vote virtually at the Meeting YOU MUST contact TSX Trust Company “TSX” either by calling 1-866-751-6315 (toll-free in North America) or 1-647-252-9650 (outside North America) or logging onto the TSX website at: https://www.tsxtrust.com/control-number-request, by 12:00 noon. Atlantic time on May 23, 2023 or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date, to request a new Control Number for the meeting. This new Control Number will allow your proxyholder to log in to and vote at the meeting. Without a new Control Number your proxyholder will only be able to log in to the meeting as a guest and will not be able to vote. Unless prohibited by law, the person whose name is written in the space provided will have full authority to present matters to the Meeting and vote on all matters that are presented at the Meeting, even if those matters are not set out in this form or the Management Information Circular. Consult a legal advisor if you wish to modify the authority of that person in any way. If you require help, please contact the Registered Representative who services your account.

 

3.

This VIF confers discretionary authority on the appointee to vote as the appointee sees fit in respect of amendments or variations to matters identified in the notice of meeting or other matters as may properly come before the Meeting or any adjournment or postponement thereof, in each instance to the extent permitted by law, whether or not the amendment or other matter that comes before the meeting is routine and whether or not the amendment or other matter that comes before the meeting is contested.

 

4.

We are prohibited from voting these securities on any of the matters to be acted upon at the Meeting without your specific voting instructions. In order for these securities to be voted at the Meeting, it will be necessary for us to have your specific voting instructions. Please complete and return the information requested in this VIF to provide your voting instructions to us promptly.

 

5.

This VIF should be signed by you in the exact manner as your name appears on the VIF. If these voting instructions are given on behalf of a body corporate, set out the full legal name of the body corporate, the name and position of the person giving voting instructions on behalf of the body corporate, and the address for service of the body corporate.

 

6.

If this VIF is not dated it will be deemed to bear the date on which it is mailed by management to you.

 

7.

When properly signed and delivered, securities represented by this VIF will be voted as directed by you, however, if such a direction is not made in respect of any matter, the VIF will direct the voting of the securities to be made as recommended in the documentation provided by Management for the Meeting.

 

8.

Your voting instructions will be recorded on receipt of the VIF.

 

9.

By providing voting instructions as requested, you are acknowledging that you are the beneficial owner of, and are entitled to instruct us with respect to the voting of, these securities.

 

10.

If you have any questions regarding the enclosed documents, please contact the Registered Representative who services your account.

 

11.

This VIF should be read in conjunction with the Management Information Circular and other proxy materials provided by Management.

All holders should refer to the Management Information Circular for further information regarding completion and use of this VIF and other information pertaining to the Meeting.

Emera offers a number of ways to cast your vote prior to the meeting.

 

LOGO INTERNET    LOGO TELEPHONE    LOGO  SMARTPHONE

 

•   Go to www.meeting-vote.com

 

•   Follow the instructions on the screen

 

•   You will be required to enter the 13-digit control number located on the reverse

 

•   No need to return this VIF

  

 

•   Use any touch-tone telephone, call toll free in Canada and United States 1-888-489-5760 (English only) or 1-888-489-7352 (Bilingual)

 

•   Follow the voice instructions

 

•   When prompted, enter the 13-digit control number located on the reverse

 

•   No need to return this VIF

  

 

To vote using your smartphone, please scan this QR Code. There is no need to return this VIF.

 

LOGO

     
LOGO  MAIL    LOGO FAX    LOGO  EMAIL

 

•   Complete the reverse of this form

 

•   Return your signed VIF in the envelope provided or send to:

TSX Trust Company

P.O. Box 721

Agincourt, ON M1S 0A1

  

 

•   Complete the reverse of this form Fax your signed VIF to 416-595-9593

  

 

•   Complete the reverse of this form

 

•   Scan your signed VIF and email it to proxyvote@tmx.com.

All VIFs must be received by 12:00 noon Atlantic time, Tuesday, May 23, 2023 or if the meeting is adjourned or postponed,

by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date.

Exhibit 99.5

 

LOGO

ANNUAL SHAREHOLDERS MEETING OF

EMERA INCORPORATED

NOTICE TO REGISTERED SHAREHOLDERS

REGARDING ACCESS TO EMERA’S MANAGEMENT INFORMATION CIRCULAR

and ANNUAL REPORT

 

MEETING DATE and LOCATION

 

Date:  Wednesday, May 24, 2023

 

Time:   5:00 p.m. Atlantic time

 

Place:   Virtual-only meeting via live webcast online at: https://web.lumiagm.com/458327786 Meeting password: emera2023 (case sensitive)

 

Q

WHY AM I RECEIVING THIS NOTICE?

 

A

As permitted by Canadian securities regulators, Emera Incorporated (“Company”) is providing you with access to our management information circular (“Information Circular”) for the annual shareholders meeting (“Meeting”) as well as the 2022 Annual Report (together, the “Meeting Materials”), electronically, instead of mailing paper copies. This notice provides you with information on how to view the Meeting Materials online and / or request paper copies. Accompanying this notice is the proxy form that you will need to vote.

 

Q

WHERE CAN I ACCESS THE MEETING MATERIALS ON-LINE?

 

A

The Meeting Materials can be viewed online at www.meetingdocuments.com/TSXT/ema as of Monday, April 10, 2023 for a period of one year following the Meeting, or at www.SEDAR.com.

 

Q

HOW CAN I OBTAIN A PAPER COPY OF THE MEETING MATERIALS?

 

A

At any time prior to the date of the Meeting, you can request a paper copy of the Meeting Materials free of charge by calling the phone number, sending an email or accessing the website below:

 

  •  

Phone number: Toll free 1-888-433-6443 (or 1-416-682-3801 for shareholders outside of Canada and the United States)

 

  •  

Email address: tsxt-fulfilment@tmx.com

 

  •  

Website: www.meetingdocuments.com/TSXT/ema

Paper copies requested before the date of the Meeting will be sent to you within three business days of receiving your request. Therefore, to receive the Meeting Materials prior to the proxy deadline for the Meeting described below, you should make your request before 11:00 a.m. Atlantic time on Tuesday, May 9, 2023. To receive the Meeting Materials prior to the Meeting you should make your request before 11:00 a.m. Atlantic time on Thursday, May 11, 2023.

Paper copies of the Meeting Materials requested on or after the date of the Meeting will be sent to you within 10 calendar days after receiving the request. Requests for paper copies of the Meeting Materials can be made until one year following the Meeting.


LOGO

 

Q

WHAT MATTERS ARE BEING RECEIVED OR VOTED ON AT THE MEETING?

 

A

Shareholders are being asked to vote on the following items of business:

 

MEETING BUSINESS ITEM

  

INFORMATION CIRCULAR REFERENCE

1.  Election of the Board of Directors – elect Directors of the Company for the ensuing year.

   See the section entitled “Items To Be Discussed at the Meeting – Election of the Board of Directors” in the Information Circular for more information.

2.  Appointment of Auditors – appoint Ernst & Young LLP as auditors for the ensuing year.

   See the section entitled “Items To Be Discussed at the Meeting – Appointment of Auditors” in the Information Circular for more information.

3.  Authorize Remuneration of Auditors – authorize the Directors to fix the remuneration of the Auditors.

   See the section entitled “Items To Be Discussed at the Meeting – Auditors’ Fee” in the Information Circular for more information.

4.  Advisory Vote on Executive Compensation - Consider and approve, on an advisory basis, a resolution on Emera’s approach to executive compensation.

   See the section entitled “Items To Be Discussed at the Meeting – Advisory Vote on Executive Compensation” in the Information Circular for more information.

5.  Senior Management Stock Option Plan Amendment - providing that if an option expires during a trading blackout period, then the option shall expire ten (10) business days after a trading blackout period is lifted by the Company.

   See the section entitled “Items To Be Discussed at the Meeting - Senior Management Stock Option Plan Amendment” in the Information Circular for more information.

All Shareholders are reminded to review the Information Circular before voting.

 

Q

HOW DO I VOTE MY SHARES?

 

A

You may vote by Internet, telephone, posted mail, delivered mail, e-mail, fax or via live webcast. Details of the methods of voting can be found on your accompanying proxy form. You will need your control number contained in the proxy form in order to vote by telephone, by Internet or via the live webcast.

To be valid, proxy forms or voting instructions must be received by Emera’s Corporate Secretary, c/o TSX Trust Company at P.O. Box 721, Agincourt, ON M1S 0A1 by no later than 12:00 noon Atlantic time on Tuesday, May 23, 2023 or, if the Meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days before the reconvened meeting date. Emera reserves the right to accept late proxies or voting instructions and to waive the proxy deadline, with or without notice, but is under no obligation to accept or reject any particular late proxy or voting instructions.

If you wish to appoint someone else to participate and vote virtually on your behalf, you MUST appoint your chosen proxyholder using your proxy form. IN ADDITION, in order for your chosen proxyholder to participate and vote virtually at the Meeting, you must contact TSX Trust by 12:00 noon Atlantic time on Tuesday, May 23, 2023 to request a new Control Number for the Meeting. In order to request a new Control Number, please visit TSX Trust’s website at: https://www.tsxtrust.com/control-number-request and complete an electronic form. This form once completed and submitted online will generate a message to TSX Trust to send the new Control Number to the designated proxyholder. This new Control Number will allow your chosen proxyholder to log in to and vote at the Meeting. Without a new Control Number your proxyholder will only be able to log in to the Meeting as a guest and will not be able to vote.

 

Q

WHO CAN I CONTACT IF I HAVE QUESTIONS ABOUT NOTICE & ACCESS?

 

A

Shareholders with questions about notice and access can call toll free at 1-888-433-6443 or shareholders outside of Canada and the United States can call 1-416-682-3801, or email tsxt-fulfilment@tmx.com.

 

2

Exhibit 99.6

 

LOGO

ANNUAL SHAREHOLDERS MEETING OF

EMERA INCORPORATED

NOTICE TO NON-REGISTERED SHAREHOLDERS

REGARDING ACCESS TO EMERA’S MANAGEMENT INFORMATION CIRCULAR

and ANNUAL REPORT

MEETING DATE and LOCATION

 

Date:

Wednesday, May 24, 2023

 

Time:

5:00 p.m. Atlantic Time

 

Place:

Virtual-only meeting via live webcast online at: https://web.lumiagm.com/458327786 Meeting password: emera2023 (case sensitive)

 

Q

WHY AM I RECEIVING THIS NOTICE?

 

A

As permitted by Canadian securities regulators, Emera Incorporated (“Company”) is providing you with access to our management information circular (“Information Circular”) for the annual shareholders meeting (“Meeting”) as well as the 2022 Annual Report (together, the “Meeting Materials”), electronically, instead of mailing paper copies. This notice provides you with information on how to view the Meeting Materials online and / or request paper copies. Accompanying this notice is the voting instruction form that you will need to vote.

 

Q

WHERE CAN I ACCESS THE MEETING MATERIALS ON-LINE?

 

A

The Meeting Materials can be viewed online www.meetingdocuments.com/TSXT/ema as of Monday, April 10, 2023 for a period of one year following the Meeting, or at www.SEDAR.com.

 

Q

HOW CAN I OBTAIN A PAPER COPY OF THE MEETING MATERIALS?

 

A

At any time prior to the date of the Meeting, you can request a paper copy of the Meeting Materials free of charge by calling the phone number, sending an email or accessing the website below:

 

  •  

Phone number: Toll free 1-888-433-6443 (or 1-416-682-3801 for shareholders outside of Canada and the United States)

 

  •  

Email address: tsxt-fulfilment@tmx.com

 

  •  

Website: www.meetingdocuments.com/TSXT/ema

Paper copies requested before the date of the Meeting will be sent to you within three business days of receiving your request. Therefore, to receive the Meeting Materials prior to the proxy deadline for the Meeting described below, you should make your request before 11:00 a.m. Atlantic time on Tuesday, May 9, 2023.

To receive the Meeting Materials prior to the Meeting you should make your request before 11:00 a.m. Atlantic time on Thursday, May 11, 2023. Paper copies of the Meeting Materials requested on or after the date of the Meeting will be sent to you within 10 calendar days after receiving the request. Requests for paper copies of the Meeting Materials can be made until one year following the Meeting.


LOGO

 

Q

WHAT MATTERS ARE BEING RECEIVED OR VOTED ON AT THE MEETING?

 

A

Shareholders are being asked to vote on the following items of business:

 

MEETING BUSINESS ITEM

  

INFORMATION CIRCULAR REFERENCE

1.  Election of the Board of Directors – elect Directors of the Company for the ensuing year.

   See the section entitled “Items To Be Discussed at the Meeting – Election of the Board of Directors” in the Information Circular for more information.

2.  Appointment of Auditors – appoint Ernst & Young LLP as auditors for the ensuing year.

   See the section entitled “ Items To Be Discussed at the Meeting – Appointment of Auditors” in the Information Circular for more information.

3.  Authorize Remuneration of Auditors – authorize the Directors to fix the remuneration of the Auditors.

   See the section entitled “ Items To Be Discussed at the Meeting – Auditors’ Fee” in the Information Circular for more information.

4.  Advisory Vote on Executive Compensation - Consider and approve, on an advisory basis, a resolution on Emera’s approach to executive compensation.

   See the section entitled “ Items To Be Discussed at the Meeting - Advisory Vote on Executive Compensation” in the Information Circular for more information.

5.  Senior Management Stock Option Plan Amendment - providing that if an option expires during a trading blackout period, then the option shall expire ten (10) business days after a trading blackout period is lifted by the Company.

   See the section entitled “ Items To Be Discussed at the Meeting - Senior Management Stock Option Plan Amendment” in the Information Circular for more information.

All Shareholders are reminded to review the Information Circular before voting.

 

Q

HOW DO I VOTE MY SHARES?

 

A

Details of the methods of voting can be found on your accompanying voting instruction form (“VIF”). To the extent specified on your VIF, you may vote by Internet, telephone, posted mail, delivered mail, e-mail, fax or via live webcast. You will need your control number contained in the VIF in order to vote by telephone, by Internet or via the live webcast.

To be valid, voting instructions must be received by Emera’s Corporate Secretary, c/o TSX Trust Company at P.O. Box 721, Agincourt, ON M1S 0A1 by no later than 12:00 noon Atlantic time on Tuesday, May 23, 2023 or, if the Meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days before the reconvened meeting date. However, it is important to note that your voting instructions must be submitted to your broker or other intermediary by the deadline specified in the VIF and, in any case, at least one business day in advance of the proxy deadline to provide sufficient time for your broker or other intermediary to act on those instructions prior to the proxy deadline. Emera reserves the right to accept late voting instructions and to waive the proxy deadline, with or without notice, but is under no obligation to accept or reject any particular late voting instructions.

To participate and vote at the Meeting virtually, or if you wish to appoint someone else to participate and vote virtually on your behalf, you MUST appoint yourself or your chosen proxyholder using your VIF. IN ADDITION, in order for your chosen proxyholder to participate and vote virtually at the Meeting, you must contact TSX Trust by 12:00 noon Atlantic time on Tuesday, May 23, 2023 to request a new Control Number for the Meeting. In order to request a new Control Number, please visit TSX Trust’s website at: https://www.tsxtrust.com/control-number-request and complete an electronic form. This form once completed and submitted online will generate a message to TSX Trust to send the new Control Number to the designated proxyholder. This new Control Number will allow you or your chosen proxyholder to log in to and vote at the Meeting. Without a new Control Number you or your proxyholder will only be able to log in to the Meeting as a guest and will not be able to vote.

 

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WHO CAN I CONTACT IF I HAVE QUESTIONS ABOUT NOTICE & ACCESS?

 

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Shareholders with questions about notice and access can call toll free at 1-888-433-6443 or shareholders outside of Canada and the United States can call 1-416-682-3801, or email tsxt-fulfilment@tmx.com.

 

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