Algonquin Power & Utilities Corp 6-K, filed May 13, 2022
Algonquin Power & Utilities Corp. (AQN)
6-K
2022-05-13
For: 2022-03-31
View Original
Added on
April 09, 2026
About this 6-K
Algonquin Power & Utilities Corp filed this 6-K on May 13, 2022.
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 of the
Securities Exchange Act of 1934
Date: May 12, 2022
Commission File Number: 001-37946
_______________________
| Algonquin Power & Utilities Corp. | ||
(Translation of registrant’s name into English)
_______________________
354 Davis Road
Oakville, Ontario, L6J 2X1, 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 x
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): □
Exhibits 99.1 and 99.2 to this Report on Form 6-K are hereby incorporated by reference into Algonquin Power & Utilities Corp.’s Registration Statements on Forms F-3 (File Nos. 333-220059 and 333-227246), Forms F-10 (File Nos. 333-216616, 333-227245 and 333-236975) and Forms S-8 (File Nos. 333-177418, 333-213648, 333-213650, 333-218810, 333-232012 and 333-238961).
EXHIBIT INDEX
The following exhibits are filed as part of this Form 6-K:
| Exhibit | Description | ||||
| 99.1 | Unaudited Financial Statements for the quarter ended March 31, 2022 | ||||
| 99.2 | Management's Discussion & Analysis for quarter ended March 31, 2022 | ||||
| 99.3 | Certification of Chief Executive Officer | ||||
| 99.4 | Certification of Chief Financial Officer | ||||
| 99.5 | Earnings Press Release for the quarter ended March 31, 2022 | ||||
| 99.6 | Q2 2022 Common Share & Preferred Dividend Press Release | ||||
SIGNATURE
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.
| ALGONQUIN POWER & UTILITIES CORP. | |||||
| (registrant) | |||||
| Date: May 12, 2022 | By: (signed) "Arthur Kacprzak" | ||||
| Name: Arthur Kacprzak | |||||
| Title: Chief Financial Officer | |||||
Unaudited Interim Consolidated Financial Statements of
Algonquin Power & Utilities Corp.
For the three months ended March 31, 2022 and 2021
Algonquin Power & Utilities Corp.
Unaudited Interim Consolidated Statements of Operations
| (thousands of U.S. dollars, except per share amounts) | Three months ended March 31 | ||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| Revenue | |||||||||||||||||||||||
| Regulated electricity distribution | $ | 280,694 | $ | 333,973 | |||||||||||||||||||
| Regulated gas distribution | 263,434 | 198,614 | |||||||||||||||||||||
| Regulated water reclamation and distribution | 78,631 | 54,550 | |||||||||||||||||||||
| Non-regulated energy sales | 88,220 | 30,783 | |||||||||||||||||||||
| Other revenue | 24,718 | 16,622 | |||||||||||||||||||||
| 735,697 | 634,542 | ||||||||||||||||||||||
| Expenses | |||||||||||||||||||||||
| Operating expenses | 212,002 | 180,057 | |||||||||||||||||||||
| Regulated electricity purchased | 99,183 | 169,399 | |||||||||||||||||||||
| Regulated gas purchased | 132,566 | 73,381 | |||||||||||||||||||||
| Regulated water purchased | 2,823 | 2,742 | |||||||||||||||||||||
| Non-regulated energy purchased | 14,906 | 7,928 | |||||||||||||||||||||
| Administrative expenses | 17,452 | 16,643 | |||||||||||||||||||||
| Depreciation and amortization | 119,964 | 97,439 | |||||||||||||||||||||
| Loss on foreign exchange | 262 | 862 | |||||||||||||||||||||
| 599,158 | 548,451 | ||||||||||||||||||||||
Gain on sale of renewable assets (note 13(d)) | 1,200 | — | |||||||||||||||||||||
| Operating income | 137,739 | 86,091 | |||||||||||||||||||||
| Interest expense | (57,943) | (49,580) | |||||||||||||||||||||
Loss from long-term investments (note 6) | (10,689) | (50,507) | |||||||||||||||||||||
Other net losses (note 16) | (4,730) | (8,384) | |||||||||||||||||||||
Pension and other post-employment non-service costs (note 8) | (2,578) | (3,684) | |||||||||||||||||||||
Gain on derivative financial instruments (note 21(b)(iv)) | 251 | 1,089 | |||||||||||||||||||||
| Earnings (loss) before income taxes | 62,050 | (24,975) | |||||||||||||||||||||
Income tax recovery (expense) (note 15) | |||||||||||||||||||||||
| Current | (6,304) | (3,375) | |||||||||||||||||||||
| Deferred | (3,148) | 25,013 | |||||||||||||||||||||
| (9,452) | 21,638 | ||||||||||||||||||||||
| Net earnings (loss) | 52,598 | (3,337) | |||||||||||||||||||||
Net effect of non-controlling interests (note 14) | |||||||||||||||||||||||
| Non-controlling interests | 40,942 | 19,965 | |||||||||||||||||||||
| Non-controlling interests held by related party | (2,575) | (2,681) | |||||||||||||||||||||
| $ | 38,367 | $ | 17,284 | ||||||||||||||||||||
| Net earnings attributable to shareholders of Algonquin Power & Utilities Corp. | $ | 90,965 | $ | 13,947 | |||||||||||||||||||
Preferred shares, Series A and preferred shares, Series D dividend (note 12) | 2,220 | 2,214 | |||||||||||||||||||||
| Net earnings attributable to common shareholders of Algonquin Power & Utilities Corp. | $ | 88,745 | $ | 11,733 | |||||||||||||||||||
Basic and diluted net earnings per share (note 17) | $ | 0.13 | $ | 0.02 | |||||||||||||||||||
See accompanying notes to unaudited interim consolidated financial statements
Algonquin Power & Utilities Corp.
Unaudited Interim Consolidated Statements of Comprehensive Income
| (thousands of U.S. dollars) | Three months ended March 31 | ||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| Net earnings (loss) | $ | 52,598 | $ | (3,337) | |||||||||||||||||||
| Other comprehensive income (loss) (“OCI”): | |||||||||||||||||||||||
Foreign currency translation adjustment, net of tax recovery of $3,310 and $536, respectively (notes 21(b)(iii) and 21(b)(iv)) | 7,845 | (273) | |||||||||||||||||||||
Change in fair value of cash flow hedges, net of tax recovery of $22,298 and expense of $2,685, respectively (note 21(b)(ii)) | (58,886) | 7,644 | |||||||||||||||||||||
Change in pension and other post-employment benefits, net of tax expense of $2 and $138, respectively (note 8) | 7 | 1,620 | |||||||||||||||||||||
| OCI, net of tax | (51,034) | 8,991 | |||||||||||||||||||||
| Comprehensive income | 1,564 | 5,654 | |||||||||||||||||||||
| Comprehensive loss attributable to the non-controlling interests | (37,680) | (16,899) | |||||||||||||||||||||
| Comprehensive income attributable to shareholders of Algonquin Power & Utilities Corp. | $ | 39,244 | $ | 22,553 | |||||||||||||||||||
See accompanying notes to unaudited interim consolidated financial statements
Algonquin Power & Utilities Corp.
Unaudited Interim Consolidated Balance Sheets
| (thousands of U.S. dollars) | |||||||||||
| March 31, | December 31, | ||||||||||
| 2022 | 2021 | ||||||||||
| ASSETS | |||||||||||
| Current assets: | |||||||||||
| Cash and cash equivalents | $ | 93,212 | $ | 125,157 | |||||||
Trade and other receivables, net (note 4) | 437,089 | 403,426 | |||||||||
| Fuel and natural gas in storage | 57,975 | 74,209 | |||||||||
| Supplies and consumables inventory | 111,383 | 103,552 | |||||||||
Regulatory assets (note 5) | 167,825 | 158,212 | |||||||||
| Prepaid expenses | 59,927 | 54,548 | |||||||||
Derivative instruments (note 21) | 9,119 | 3,486 | |||||||||
| Other assets | 15,079 | 16,153 | |||||||||
| 951,609 | 938,743 | ||||||||||
| Property, plant and equipment, net | 11,770,209 | 11,042,446 | |||||||||
| Intangible assets, net | 107,422 | 105,116 | |||||||||
| Goodwill | 1,302,119 | 1,201,244 | |||||||||
Regulatory assets (note 5) | 1,087,287 | 1,009,413 | |||||||||
Long-term investments (note 6) | |||||||||||
| Investments carried at fair value | 1,809,298 | 1,848,456 | |||||||||
| Other long-term investments | 492,439 | 495,826 | |||||||||
Derivative instruments (note 21) | 28,799 | 17,136 | |||||||||
| Deferred income taxes | 26,832 | 31,595 | |||||||||
| Other assets | 93,850 | 95,861 | |||||||||
| $ | 17,669,864 | $ | 16,785,836 | ||||||||
See accompanying notes to unaudited interim consolidated financial statements
Algonquin Power & Utilities Corp.
Unaudited Interim Consolidated Balance Sheets (continued)
| (thousands of U.S. dollars) | |||||||||||
| March 31, | December 31, | ||||||||||
| 2022 | 2021 | ||||||||||
| LIABILITIES AND EQUITY | |||||||||||
| Current liabilities: | |||||||||||
| Accounts payable | $ | 113,682 | $ | 185,291 | |||||||
| Accrued liabilities | 458,003 | 428,733 | |||||||||
Dividends payable (note 12) | 115,074 | 114,544 | |||||||||
Regulatory liabilities (note 5) | 75,803 | 65,809 | |||||||||
Long-term debt (note 7) | 18,285 | 356,397 | |||||||||
Other long-term liabilities (note 9) | 162,312 | 167,908 | |||||||||
Derivative instruments (note 21) | 36,325 | 38,569 | |||||||||
| Other liabilities | 9,610 | 7,461 | |||||||||
| 989,094 | 1,364,712 | ||||||||||
Long-term debt (note 7) | 7,173,090 | 5,854,978 | |||||||||
Regulatory liabilities (note 5) | 550,951 | 510,380 | |||||||||
| Deferred income taxes | 511,690 | 530,187 | |||||||||
Derivative instruments (note 21) | 112,816 | 81,676 | |||||||||
| Pension and other post-employment benefits obligation | 229,984 | 226,387 | |||||||||
Other long-term liabilities (note 9) | 509,661 | 515,911 | |||||||||
| 10,077,286 | 9,084,231 | ||||||||||
Redeemable non-controlling interests (note 14) | |||||||||||
Redeemable non-controlling interest, held by related party (note 13(b)) | 306,528 | 306,537 | |||||||||
| Redeemable non-controlling interests | 11,243 | 12,989 | |||||||||
| 317,771 | 319,526 | ||||||||||
| Equity: | |||||||||||
| Preferred shares | 184,299 | 184,299 | |||||||||
Common shares (note 10(a)) | 6,057,249 | 6,032,792 | |||||||||
| Additional paid-in capital | 1,158 | 2,007 | |||||||||
| Retained earnings (deficit) | (315,879) | (288,424) | |||||||||
Accumulated other comprehensive loss (“AOCI”) (note 11) | (123,398) | (71,677) | |||||||||
| Total equity attributable to shareholders of Algonquin Power & Utilities Corp. | 5,803,429 | 5,858,997 | |||||||||
| Non-controlling interests | |||||||||||
| Non-controlling interests | 1,397,133 | 1,441,924 | |||||||||
Non-controlling interest, held by related party (note 13(c)) | 74,245 | 81,158 | |||||||||
| 1,471,378 | 1,523,082 | ||||||||||
| Total equity | 7,274,807 | 7,382,079 | |||||||||
Commitments and contingencies (note 19) | |||||||||||
Subsequent events (notes 7(a), 10(b)) | |||||||||||
| $ | 17,669,864 | $ | 16,785,836 | ||||||||
See accompanying notes to unaudited interim consolidated financial statements
Algonquin Power & Utilities Corp.
Unaudited Interim Consolidated Statement of Equity
(thousands of U.S. dollars) For the three months ended March 31, 2022 | |||||||||||||||||||||||||||||||||||||||||||||||
| Algonquin Power & Utilities Corp. Shareholders | |||||||||||||||||||||||||||||||||||||||||||||||
| Common shares | Preferred shares | Additional paid-in capital | Retained earnings (deficit) | AOCI | Non- controlling interests | Total | |||||||||||||||||||||||||||||||||||||||||
| Balance, December 31, 2021 | $ | 6,032,792 | $ | 184,299 | $ | 2,007 | $ | (288,424) | $ | (71,677) | $ | 1,523,082 | $ | 7,382,079 | |||||||||||||||||||||||||||||||||
| Net earnings | — | — | — | 90,965 | — | (38,367) | 52,598 | ||||||||||||||||||||||||||||||||||||||||
Effect of redeemable non-controlling interests not included in equity (note 14) | — | — | — | — | — | (1,196) | (1,196) | ||||||||||||||||||||||||||||||||||||||||
| OCI | — | — | — | — | (51,721) | 687 | (51,034) | ||||||||||||||||||||||||||||||||||||||||
| Dividends declared and distributions to non-controlling interests | — | — | — | (96,254) | — | (16,558) | (112,812) | ||||||||||||||||||||||||||||||||||||||||
| Dividends and issuance of shares under dividend reinvestment plan | 21,540 | — | — | (21,540) | — | — | — | ||||||||||||||||||||||||||||||||||||||||
| Contributions received from non-controlling interests, net of cost | — | — | — | — | — | 3,730 | 3,730 | ||||||||||||||||||||||||||||||||||||||||
| Common shares issued upon conversion of convertible debentures | 6 | — | — | — | — | — | 6 | ||||||||||||||||||||||||||||||||||||||||
| Common shares issued under employee share purchase plan | 1,306 | — | — | — | — | — | 1,306 | ||||||||||||||||||||||||||||||||||||||||
| Share-based compensation | — | — | 1,622 | — | — | — | 1,622 | ||||||||||||||||||||||||||||||||||||||||
| Common shares issued pursuant to share-based awards | 1,605 | — | (2,471) | (626) | — | — | (1,492) | ||||||||||||||||||||||||||||||||||||||||
| Balance, March 31, 2022 | $ | 6,057,249 | $ | 184,299 | $ | 1,158 | $ | (315,879) | $ | (123,398) | $ | 1,471,378 | $ | 7,274,807 | |||||||||||||||||||||||||||||||||
See accompanying notes to unaudited interim consolidated financial statements
Algonquin Power & Utilities Corp.
Unaudited Interim Consolidated Statement of Equity (continued)
(thousands of U.S. dollars) For the three months ended March 31, 2021 | |||||||||||||||||||||||||||||||||||||||||||||||
| Algonquin Power & Utilities Corp. Shareholders | |||||||||||||||||||||||||||||||||||||||||||||||
| Common shares | Preferred shares | Additional paid-in capital | Deficit | AOCI | Non- controlling interests | Total | |||||||||||||||||||||||||||||||||||||||||
| Balance, December 31, 2020 | $ | 4,935,304 | $ | 184,299 | $ | 60,729 | $ | 45,753 | $ | (22,507) | $ | 458,612 | $ | 5,662,190 | |||||||||||||||||||||||||||||||||
| Net earnings (loss) | — | — | — | 13,947 | — | (17,284) | (3,337) | ||||||||||||||||||||||||||||||||||||||||
Effect of redeemable non-controlling interests not included in equity (note 14) | — | — | — | — | — | (963) | (963) | ||||||||||||||||||||||||||||||||||||||||
| OCI | — | — | — | — | 8,606 | 385 | 8,991 | ||||||||||||||||||||||||||||||||||||||||
| Dividends declared and distributions to non-controlling interests | — | — | — | (74,177) | — | (6,201) | (80,378) | ||||||||||||||||||||||||||||||||||||||||
| Dividends and issuance of shares under dividend reinvestment plan | 22,651 | — | — | (22,651) | — | — | — | ||||||||||||||||||||||||||||||||||||||||
| Contributions received from non-controlling interests, net of cost | — | — | 6,919 | — | (6,371) | 214,952 | 215,500 | ||||||||||||||||||||||||||||||||||||||||
| Common shares issued upon public offering, net of tax effected cost | 127,427 | — | — | — | — | — | 127,427 | ||||||||||||||||||||||||||||||||||||||||
| Issuance of common shares under employee share purchase plan | 1,316 | — | — | — | — | — | 1,316 | ||||||||||||||||||||||||||||||||||||||||
| Share-based compensation | — | — | 1,561 | — | — | — | 1,561 | ||||||||||||||||||||||||||||||||||||||||
| Common shares issued pursuant to share-based awards | 5,993 | — | (9,578) | (3,202) | — | — | (6,787) | ||||||||||||||||||||||||||||||||||||||||
| Non-controlling interest assumed on asset acquisition | — | — | — | — | — | 29,141 | 29,141 | ||||||||||||||||||||||||||||||||||||||||
| Balance, March 31, 2021 | $ | 5,092,691 | $ | 184,299 | $ | 59,631 | $ | (40,330) | $ | (20,272) | $ | 678,642 | $ | 5,954,661 | |||||||||||||||||||||||||||||||||
See accompanying notes to unaudited interim consolidated financial statements
Algonquin Power & Utilities Corp.
Unaudited Interim Consolidated Statements of Cash Flows
| (thousands of U.S. dollars) | Three months ended March 31 | ||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| Cash provided by (used in): | |||||||||||||||||||||||
| Operating Activities | |||||||||||||||||||||||
| Net earnings (loss) | $ | 52,598 | $ | (3,337) | |||||||||||||||||||
| Adjustments and items not affecting cash: | |||||||||||||||||||||||
| Depreciation and amortization | 119,964 | 97,439 | |||||||||||||||||||||
| Deferred taxes | 3,148 | (25,013) | |||||||||||||||||||||
| Unrealized gain on derivative financial instruments | (68) | (943) | |||||||||||||||||||||
| Share-based compensation | (365) | 1,197 | |||||||||||||||||||||
| Cost of equity funds used for construction purposes | (509) | 9 | |||||||||||||||||||||
| Change in value of investments carried at fair value | 40,507 | 71,745 | |||||||||||||||||||||
| Pension and post-employment expense lower than contributions | (5,613) | (3,658) | |||||||||||||||||||||
| Distributions received from equity investments, net of income | 2,102 | 5,537 | |||||||||||||||||||||
| Other | 2,605 | 2,018 | |||||||||||||||||||||
Net change in non-cash operating items (note 20) | (48,148) | (388,518) | |||||||||||||||||||||
| 166,221 | (243,524) | ||||||||||||||||||||||
| Financing Activities | |||||||||||||||||||||||
| Increase in long-term debt | 2,572,530 | 2,523,221 | |||||||||||||||||||||
| Repayments of long-term debt | (1,636,910) | (1,747,081) | |||||||||||||||||||||
| Issuance of common shares, net of costs | 1,306 | 128,743 | |||||||||||||||||||||
| Cash dividends on common shares | (93,381) | (70,008) | |||||||||||||||||||||
| Dividends on preferred shares | (2,220) | (2,214) | |||||||||||||||||||||
| Contributions from non-controlling interests and redeemable non-controlling interests | — | 210,673 | |||||||||||||||||||||
| Production-based cash contributions from non-controlling interest | 3,730 | 4,832 | |||||||||||||||||||||
Distributions to non-controlling interests, related party (note 13(b) and (c)) | (10,006) | (6,982) | |||||||||||||||||||||
| Distributions to non-controlling interests | (8,349) | (1,088) | |||||||||||||||||||||
| Payments upon settlement of derivatives | (26,254) | (33,782) | |||||||||||||||||||||
| Shares surrendered to fund withholding taxes on exercised share options | (626) | (809) | |||||||||||||||||||||
| Increase in other long-term liabilities | 5,199 | 38,874 | |||||||||||||||||||||
| Decrease in other long-term liabilities | (1,234) | (492) | |||||||||||||||||||||
| 803,785 | 1,043,887 | ||||||||||||||||||||||
| Investing Activities | |||||||||||||||||||||||
| Additions to property, plant and equipment and intangible assets | (327,699) | (295,389) | |||||||||||||||||||||
| Increase in long-term investments | (47,257) | (467,206) | |||||||||||||||||||||
Acquisitions of operating entities (note 3) | (632,711) | — | |||||||||||||||||||||
| Increase in other assets | (2,464) | (447) | |||||||||||||||||||||
| Receipt of principal on development loans receivable | 122 | — | |||||||||||||||||||||
| Decrease in long-term investments | 2,403 | — | |||||||||||||||||||||
| Other proceeds | — | 4,344 | |||||||||||||||||||||
| (1,007,606) | (758,698) | ||||||||||||||||||||||
| Effect of exchange rate differences on cash and restricted cash | 562 | 50 | |||||||||||||||||||||
| Increase (decrease) in cash, cash equivalents and restricted cash | (37,038) | 41,715 | |||||||||||||||||||||
| Cash, cash equivalents and restricted cash, beginning of period | 161,389 | 130,018 | |||||||||||||||||||||
| Cash, cash equivalents and restricted cash, end of period | $ | 124,351 | $ | 171,733 | |||||||||||||||||||
| Algonquin Power & Utilities Corp. Unaudited Interim Consolidated Statements of Cash Flows (continued) | |||||||||||||||||||||||
| (thousands of U.S. dollars) | Three months ended March 31 | ||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| Supplemental disclosure of cash flow information: | |||||||||||||||||||||||
| Cash paid during the period for interest expense | $ | 61,606 | $ | 56,361 | |||||||||||||||||||
| Cash paid (refund received) during the period for income taxes | $ | 1,210 | $ | (985) | |||||||||||||||||||
| Cash received during the period for distributions from equity investments | $ | 34,091 | $ | 26,785 | |||||||||||||||||||
| Non-cash financing and investing activities: | |||||||||||||||||||||||
| Property, plant and equipment acquisitions in accruals | $ | 83,319 | $ | 120,535 | |||||||||||||||||||
| Issuance of common shares under dividend reinvestment plan and share-based compensation plans | $ | 24,451 | $ | 29,960 | |||||||||||||||||||
| Property, plant and equipment, intangible assets and accrued liabilities in exchange of note receivable | $ | — | $ | 87,128 | |||||||||||||||||||
See accompanying notes to unaudited interim consolidated financial statements
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
Algonquin Power & Utilities Corp. (“AQN” or the “Company”) is an incorporated entity under the Canada Business Corporations Act. AQN's operations are organized across two primary business units consisting of the Regulated Services Group and the Renewable Energy Group. The Regulated Services Group owns and operates a portfolio of regulated electric, natural gas, water distribution and wastewater collection utility systems and transmission operations in the United States, Canada, Bermuda and Chile; the Renewable Energy Group owns and operates a diversified portfolio of non-regulated renewable and thermal electric generation assets.
1.Significant accounting policies
(a)Basis of preparation
The accompanying unaudited interim consolidated financial statements and notes have been prepared in accordance with generally accepted accounting principles in the United States (“U.S. GAAP”) and follow disclosure required under Regulation S-X provided by the U.S. Securities and Exchange Commission. In the opinion of management, the unaudited interim consolidated financial statements include all adjustments that are of a recurring nature and necessary for a fair presentation of the results of interim operations.
The significant accounting policies applied to these unaudited interim consolidated financial statements of AQN are consistent with those disclosed in the consolidated financial statements of AQN as at and for the year ended December 31, 2021.
(b)Seasonality
AQN's operating results are subject to seasonal fluctuations that could materially impact quarter-to-quarter operating results and, thus, one quarter's operating results are not necessarily indicative of a subsequent quarter's operating results. Where decoupling mechanisms exist, total volumetric revenue is prescribed by the applicable regulatory authority and is not affected by usage. AQN's electrical distribution utilities can experience higher or lower demand in the summer or winter depending on the specific regional weather and industry characteristics. During the winter period, natural gas distribution utilities generally experience higher demand than during the summer period. AQN’s water and wastewater utility assets’ revenues fluctuate depending on the demand for water, which is normally higher during drier and hotter months of the summer. AQN’s hydroelectric energy assets are primarily “run-of-river” and as such fluctuate with the natural water flows. During the winter and summer periods, flows are generally slower, while during the spring and fall periods flows are heavier. For AQN's wind energy assets, wind resources are typically stronger in spring, fall and winter, and weaker in summer. AQN's solar energy assets generally experience greater insolation in summer, weaker in winter.
(c)Foreign currency translation
AQN’s reporting currency is the U.S. dollar. Within these unaudited interim consolidated financial statements, the Company denotes any amounts denominated in Canadian dollars with “C$”, in Chilean pesos with "CLP" and in Chilean Unidad de Fomento with "CLF" immediately prior to the stated amount.
2. Recently adopted accounting pronouncements
The FASB issued ASU 2021-05, Leases (Topic 842): Lessors — Certain Leases with Variable Lease Payments to address concerns relating to day-one losses for sales-type or direct financing leases with variable payments that do not depend on a reference index or rate. The update amends the lease classification requirements for lessors to align them with past practice under Topic 840, Leases. The adoption of this update did not have an impact on the unaudited interim consolidated financial statements.
The FASB issued ASU 2020-06, Debt — Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging — Contracts in Entity's Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity's Own Equity to address the complexity associated with accounting for certain financial instruments with characteristics of liabilities and equity. The number of accounting models for convertible debt instruments and convertible preferred stock is being reduced and the guidance has been amended for the derivatives scope exception for contracts in an entity's own equity to reduce form-over-substance-based accounting conclusions. The adoption of this update did not have an impact on the unaudited interim consolidated financial statements.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
2. Recently adopted accounting pronouncements (continued)
The FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting, which provides optional expedients and exceptions to ease the potential burden in accounting for reference rate reform. The amendments apply to contracts, hedging relationships, and other transactions that reference LIBOR or another reference rate expected to be discontinued because of the reference rate reform. The FASB issued an update to Topic 848 in ASU 2021-01 to clarify that the scope of Topic 848 includes derivatives affected by the discounting transition. The adoption of this update did not have an impact on the unaudited interim consolidated financial statements.
3.Business and assets acquisitions
Acquisition of New York American Water Company, Inc.
Effective January 1, 2022, the Company completed the acquisition of New York American Water Company, Inc. (subsequently renamed Liberty Utilities (New York Water) Corp. (“Liberty NY Water”)). Liberty NY Water is a Merrick, New York based regulated water and wastewater utility company, serving customers in seven counties in southeastern New York.
A purchase price of $608,000 (before closing adjustments) was paid for this acquisition. The costs related to this acquisition have been expensed through the consolidated statement of operations. The following table summarizes the preliminary allocation of the acquisition prices of the assets acquired and liabilities assumed at the acquisition date:
| Working capital | $ | 5,020 | |||
| Property, plant and equipment | 526,785 | ||||
| Goodwill | 86,849 | ||||
| Regulatory assets | 67,319 | ||||
| Other assets | 4,507 | ||||
| Pension and other post-employment obligations | (13,402) | ||||
| Regulatory liabilities | (60,039) | ||||
| Other liabilities | (8,026) | ||||
| Total net assets acquired | 609,013 | ||||
| Cash and cash equivalents | 57 | ||||
| Net assets acquired, net of cash and cash equivalents | $ | 608,956 | |||
The determination of the fair value of assets acquired and liabilities assumed is based upon management's estimates and certain assumptions. Due to the timing of the acquisition, the Company has not finalized the fair value measurements. In particular, the valuation of regulatory assets and liabilities and deferred income taxes have not been completed. The Company will continue to review information and perform further analysis prior to finalizing the fair value of assets acquired and liabilities assumed.
Goodwill represents the excess of the purchase price over the aggregate fair value of net assets acquired. The contributing factors to the amount recorded as goodwill include future growth, potential synergies, and cost savings in the delivery of certain shared administrative and other services.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
4.Accounts receivable
Accounts receivable as at March 31, 2022 include unbilled revenue of $100,280 (December 31, 2021 - $102,693) from the Company’s regulated utilities. Accounts receivable as at March 31, 2022 are presented net of allowance for doubtful accounts of $29,238 (December 31, 2021 - $19,327).
5.Regulatory matters
The operating companies within the Regulated Services Group are subject to regulation by the respective authorities of the jurisdictions in which they operate. The respective public utility commissions have jurisdiction with respect to rate, service, accounting policies, issuance of securities, acquisitions and other matters. Except for ESSAL, these utilities operate under cost-of-service regulation as administered by these authorities. The Company’s regulated utility operating companies are accounted for under the principles of ASC 980, Regulated Operations. Under ASC 980, regulatory assets and liabilities that would not be recorded under U.S. GAAP for non-regulated entities are recorded to the extent that they represent probable future revenue or expenses associated with certain charges or credits that will be recovered from or refunded to customers through the rate setting process.
At any given time, the Company can have several regulatory proceedings underway. The financial effects of these proceedings are reflected in the unaudited interim consolidated financial statements based on regulatory approval obtained to the extent that there is a financial impact during the applicable reporting period.
| Utility | State, province or country | Regulatory proceeding type | Details | ||||||||
| Empire Electric System | Missouri | General rate review | On April 6, 2022, the regulator approved an annual base rate revenue increase of $35,516, as well as another $4,000 in revenues associated with the Empire Wind Facilities. Empire Electric System expects to file updated tariffs in May 2022 for new rates to become effective in the second quarter of 2022. Empire filed a petition for securitization of the costs associated with the impact of the Midwest Extreme Weather Event and the retirement of Asbury on January 19, 2022 and March 1, 2022, respectively. The commission approved the consolidation of the two petitions but reserved the right to deconsolidate at its discretion. | ||||||||
| BELCO | Bermuda | General rate review | On March 18, 2022, the regulator issued a final decision authorizing $224,056 and $226,160 in revenue for 2022 and 2023 respectively at a weighted average cost of capital or return of 7.16% in each year. The new rates are effective from April 1, 2022. On April 7, 2022, Belco filed an appeal in the Supreme Court of Bermuda challenging the decisions made through the recent Retail Tariff Review. | ||||||||
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
5.Regulatory matters (continued)
Regulatory assets and liabilities consist of the following:
| March 31, 2022 | December 31, 2021 | ||||||||||
| Regulatory assets | |||||||||||
| Fuel and commodity cost adjustments | 352,632 | 339,900 | |||||||||
| Retired generating plant | 182,573 | 185,073 | |||||||||
| Pension and post-employment benefits | 140,430 | 134,141 | |||||||||
| Rate adjustment mechanism | 120,505 | 117,309 | |||||||||
| Income taxes | 98,979 | 79,472 | |||||||||
| Environmental remediation | 79,395 | 81,802 | |||||||||
| Deferred capitalized costs | 74,773 | 62,599 | |||||||||
| Wildfire mitigation and vegetation management | 42,687 | 35,789 | |||||||||
| Debt premium | 30,198 | 34,204 | |||||||||
| Asset retirement obligation | 27,208 | 26,810 | |||||||||
| Clean energy and other customer programs | 26,268 | 26,015 | |||||||||
| Cost of removal | 10,787 | — | |||||||||
| Rate review costs | 9,341 | 9,167 | |||||||||
| Long-term maintenance contract | 7,978 | 9,134 | |||||||||
| Other | 51,358 | 26,210 | |||||||||
| Total regulatory assets | $ | 1,255,112 | $ | 1,167,625 | |||||||
| Less: current regulatory assets | (167,825) | (158,212) | |||||||||
| Non-current regulatory assets | $ | 1,087,287 | $ | 1,009,413 | |||||||
| Regulatory liabilities | |||||||||||
| Income taxes | $ | 326,919 | $ | 295,720 | |||||||
| Cost of removal | 191,605 | 191,981 | |||||||||
| Pension and post-employment benefits | 55,647 | 34,468 | |||||||||
| Clean energy and other customer programs | 15,691 | 14,829 | |||||||||
| Fuel and commodity costs adjustments | 10,144 | 18,229 | |||||||||
| Rate adjustment mechanism | 4,582 | 3,316 | |||||||||
| Rate base offset | 4,476 | 4,998 | |||||||||
| Other | 17,690 | 12,648 | |||||||||
| Total regulatory liabilities | $ | 626,754 | $ | 576,189 | |||||||
| Less: current regulatory liabilities | (75,803) | (65,809) | |||||||||
| Non-current regulatory liabilities | $ | 550,951 | $ | 510,380 | |||||||
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
6.Long-term investments
Long-term investments consist of the following:
| March 31, 2022 | December 31, 2021 | ||||||||||
| Long-term investments carried at fair value | |||||||||||
| Atlantica | $ | 1,717,130 | $ | 1,750,914 | |||||||
| Atlantica Yield Energy Solutions Canada Inc. | 90,012 | 95,246 | |||||||||
| Other | 2,156 | 2,296 | |||||||||
| $ | 1,809,298 | $ | 1,848,456 | ||||||||
| Other long-term investments | |||||||||||
| Equity-method investees (a) | $ | 401,607 | $ | 433,850 | |||||||
| Development loans receivable from equity-method investees (a) | 63,150 | 31,468 | |||||||||
| Other | 27,682 | 30,508 | |||||||||
| $ | 492,439 | $ | 495,826 | ||||||||
Income (loss) from long-term investments from the three months ended March 31 is as follows:
| Three months ended March 31 | |||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| Fair value loss on investments carried at fair value | |||||||||||||||||||||||
| Atlantica | $ | (33,784) | $ | (64,433) | |||||||||||||||||||
| Atlantica Yield Energy Solutions Canada Inc. | (6,580) | (7,312) | |||||||||||||||||||||
| Other | (143) | — | |||||||||||||||||||||
| $ | (40,507) | $ | (71,745) | ||||||||||||||||||||
| Dividend and interest income from investments carried at fair value | |||||||||||||||||||||||
| Atlantica | $ | 21,544 | $ | 20,564 | |||||||||||||||||||
| Atlantica Yield Energy Solutions Canada Inc. | 7,294 | 4,344 | |||||||||||||||||||||
| Other | (2) | — | |||||||||||||||||||||
| $ | 28,836 | $ | 24,908 | ||||||||||||||||||||
| Other long-term investments | |||||||||||||||||||||||
| Equity method loss | (4,531) | (5,554) | |||||||||||||||||||||
| Interest and other income | 5,513 | 1,884 | |||||||||||||||||||||
| $ | 982 | $ | (3,670) | ||||||||||||||||||||
| Loss from long-term investments | $ | (10,689) | $ | (50,507) | |||||||||||||||||||
(a)Equity-method investees and development loans receivable from equity investees
The Company has non-controlling interests in various corporations, partnerships and joint ventures with a total carrying value of $401,607 (December 31, 2021 - $433,850), including investments in variable interest entities ("VIEs") of $93,076 (December 31, 2021 - $86,202).
During 2021, the Company acquired a 51% interest in four operating wind facilities located in Texas (“Texas Coastal Wind Facilities”). All facilities have achieved commercial operations. The Company does not control the entities and therefore accounts for its 51% interest using the equity method. As at March 31, 2022, the Company had issued $119,750 in letters of credit and guarantees of performance obligations under energy purchase agreements and decommissioning obligations on behalf of the Texas Coastal Wind Facilities.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
6.Long-term investments (continued)
Summarized combined information for AQN's investments in significant partnerships and joint ventures is as follows:
| March 31, 2022 | December 31, 2021 | ||||||||||
| Total assets | $ | 2,277,093 | $ | 2,126,934 | |||||||
| Total liabilities | 1,181,482 | 945,971 | |||||||||
| Net assets | $ | 1,095,611 | $ | 1,180,963 | |||||||
| AQN's ownership interest in the entities | 300,320 | 327,555 | |||||||||
Difference between investment carrying amount and underlying equity in net assets(a) | 101,287 | 106,295 | |||||||||
| AQN's investment carrying amount for the entities | $ | 401,607 | $ | 433,850 | |||||||
(a) The difference between the investment carrying amount and the underlying equity in net assets relates primarily to development fees, interest capitalized while the projects are under construction, the fair value of guarantees provided by the Company in regards to the investments and transaction costs.
Except for Liberty Global Energy Solutions B.V. (“Liberty Global Energy Solutions”), the development projects are considered VIEs due to the level of equity at risk and the disproportionate voting and economic interests of the shareholders. The Company has committed loan and credit support facilities with some of its equity investees. During construction, the Company has agreed to provide cash advances and credit support for the continued development and construction of the equity investees' projects. As at March 31, 2022, the Company had issued letters of credit and guarantees of performance obligations under: a security of performance for a development opportunity; wind turbine and solar panel supply agreements; interconnection agreements; engineering, procurement and construction agreements; energy purchase agreements; and construction loan agreements. The fair value of the support provided recorded as at March 31, 2022 amounts to $6,223 (December 31, 2021 - $4,612).
Summarized combined information for AQN's VIEs is as follows:
| March 31, 2022 | December 31, 2021 | ||||||||||
| AQN's maximum exposure in regards to VIEs | |||||||||||
| Carrying amount | $ | 93,076 | $ | 86,202 | |||||||
| Development loans receivable | 63,150 | 31,468 | |||||||||
| Performance guarantees and other commitments on behalf of VIEs | 508,867 | 409,232 | |||||||||
| $ | 665,093 | $ | 526,902 | ||||||||
The commitments are presented on a gross basis assuming no recoverable value in the assets of the VIEs.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
7.Long-term debt
Long-term debt consists of the following:
| Borrowing type | Weighted average coupon | Maturity | Par value | March 31, 2022 | December 31, 2021 | |||||||||||||||||||||||||||
| Senior unsecured revolving credit facilities (a) | — | 2022-2024 | N/A | $ | 150,306 | $ | 368,806 | |||||||||||||||||||||||||
| Senior unsecured bank credit facilities (b) | — | 2022-2031 | N/A | 757,233 | 141,956 | |||||||||||||||||||||||||||
| Commercial paper | — | 2022 | N/A | — | 338,700 | |||||||||||||||||||||||||||
| U.S. dollar borrowings | ||||||||||||||||||||||||||||||||
| Senior unsecured notes (Green Equity Units) | 1.18 | % | 2026 | $ | 1,150,000 | 1,140,732 | 1,140,801 | |||||||||||||||||||||||||
| Senior unsecured notes | 3.46 | % | 2022-2047 | $ | 1,700,000 | 1,690,147 | 1,689,792 | |||||||||||||||||||||||||
| Senior unsecured utility notes | 6.34 | % | 2023-2035 | $ | 142,000 | 155,159 | 155,571 | |||||||||||||||||||||||||
| Senior secured utility bonds | 4.71 | % | 2026-2044 | $ | 556,216 | 557,346 | 558,177 | |||||||||||||||||||||||||
| Canadian dollar borrowings | ||||||||||||||||||||||||||||||||
| Senior unsecured notes (c) | 3.68 | % | 2027-2050 | C$ | 1,200,000 | 957,098 | 1,099,403 | |||||||||||||||||||||||||
| Senior secured project notes | 10.21 | % | 2027 | C$ | 22,320 | 17,861 | 18,344 | |||||||||||||||||||||||||
| Chilean Unidad de Fomento borrowings | ||||||||||||||||||||||||||||||||
| Senior unsecured utility bonds | 4.18 | % | 2028-2040 | CLF 1,753 | 85,141 | 77,963 | ||||||||||||||||||||||||||
| $ | 5,511,023 | $ | 5,589,513 | |||||||||||||||||||||||||||||
| Subordinated borrowings | ||||||||||||||||||||||||||||||||
| Subordinated unsecured notes (d) | 5.25 | % | 2082 | C$ | 400,000 | $ | 316,026 | $ | — | |||||||||||||||||||||||
| Subordinated unsecured notes (d) | 5.56 | % | 2078-2082 | $ | 1,387,500 | 1,364,326 | 621,862 | |||||||||||||||||||||||||
| $ | 1,680,352 | $ | 621,862 | |||||||||||||||||||||||||||||
| $ | 7,191,375 | $ | 6,211,375 | |||||||||||||||||||||||||||||
| Less: current portion | (18,285) | (356,397) | ||||||||||||||||||||||||||||||
| $ | 7,173,090 | $ | 5,854,978 | |||||||||||||||||||||||||||||
Short-term obligations of $960,570 that are expected to be refinanced using the long-term credit facilities are presented as long-term debt.
Long-term debt issued at a subsidiary level (project notes or utility bonds) relating to a specific operating facility is generally collateralized by the respective facility with no other recourse to the Company. Long-term debt issued at a subsidiary level whether or not collateralized generally has certain financial covenants, which must be maintained on a quarterly basis. Non-compliance with the covenants could restrict cash distributions/dividends to the Company from the specific facilities.
Recent financing activities:
(a)Senior unsecured revolving credit facilities
Subsequent to quarter-end on April 29, 2022, the Regulated Services Group entered into two new senior unsecured syndicated revolving credit facilities: a $1,000,000 senior unsecured revolving credit facility with an initial maturity date of April 29, 2027 (the “Long Term Regulated Services Credit Facility”) and a $500,000 short-term senior unsecured revolving credit facility maturing on March 31, 2023. Subject to the terms and conditions therein, the Long Term Regulated Services Credit Facility may be extended for two additional one-year periods. In conjunction with the new facilities, the Regulated Services Group’s $500,000 senior unsecured syndicated revolving credit facility was cancelled.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
7.Long-term debt (continued)
(b)Senior unsecured bank credit facilities
On December 20, 2021, the Regulated Services Group entered into a $1,100,000 senior unsecured syndicated delayed draw term facility (the “Regulated Services Delayed Draw Term Facility”), which matures on December 19, 2022. On January 3, 2022, the purchase price, plus certain adjustments and acquisition costs, for the acquisition of Liberty NY Water (note 3) of approximately $610,400 was funded through a draw on the Regulated Services Delayed Draw Term Facility.
(c)Canadian dollar senior unsecured notes
On February 15, 2022, the Company repaid a C$200,000 senior unsecured note on its maturity. Concurrent with the repayments, the Renewable Energy Group unwound and settled the related cross-currency fixed-for-fixed interest rate swap (note 21(b)(iii)).
(d)Subordinated unsecured notes
On January 18, 2022, the Company closed (i) an underwritten public offering in the United States (the “U.S. Offering”) of $750,000 aggregate principal amount of 4.75% fixed-to-fixed reset rate junior subordinated notes series 2022-B due January 18, 2082 (the “U.S. Notes”); and (ii) an underwritten public offering in Canada (the “Canadian Offering” and, together with the U.S. Offering, the “Offerings”) of C$400,000 (approximately $320,000) aggregate principal amount of 5.25% fixed-to-fixed reset rate junior subordinated notes series 2022-A due January 18, 2082 (the “Canadian Notes” and, together with the U.S. Notes, the “Notes”). Concurrent with the pricing of the Offerings, the Company entered into a cross currency interest rate swap to convert the Canadian dollar denominated proceeds from the Canadian Offering into U.S. dollars, and a forward starting swap to fix the interest rate for the second five-year term of the U.S. Notes (note 21(b)(ii)), resulting in an anticipated effective interest rate to the Company of approximately 4.95% throughout the first ten-year period of the Notes.
8.Pension and other post-employment benefits
The following table lists the components of net benefit costs for the pension plans and other post-employment benefits (“OPEB”) in the unaudited interim consolidated statements of operations for the three months ended March 31:
| Pension benefits | OPEB | ||||||||||||||||||||||
| Three months ended March 31 | Three months ended March 31 | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| Service cost | $ | 3,856 | $ | 3,828 | $ | 1,555 | $ | 1,772 | |||||||||||||||
| Non-service costs | |||||||||||||||||||||||
| Interest cost | 6,063 | 6,706 | 2,359 | 1,021 | |||||||||||||||||||
| Expected return on plan assets | (10,324) | (11,164) | (2,841) | (2,511) | |||||||||||||||||||
| Amortization of net actuarial loss | 789 | 2,272 | (86) | 437 | |||||||||||||||||||
| Amortization of prior service credits | (403) | (407) | 6 | — | |||||||||||||||||||
| Impact of regulatory accounts | 6,338 | 6,184 | 677 | 1,146 | |||||||||||||||||||
| $ | 2,463 | $ | 3,591 | $ | 115 | $ | 93 | ||||||||||||||||
| Net benefit cost | $ | 6,319 | $ | 7,419 | $ | 1,670 | $ | 1,865 | |||||||||||||||
The service cost components of pension plans and OPEB are shown as part of operating expenses within operating income in the unaudited interim consolidated statements of operations. The remaining components of net benefit cost are considered non-service costs and have been included outside of operating income in the unaudited interim consolidated statements of operations.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
9.Other long-term liabilities
Other long-term liabilities consist of the following:
| March 31, 2022 | December 31, 2021 | ||||||||||
| Contract adjustment payments | $ | 169,235 | $ | 187,580 | |||||||
| Asset retirement obligations | 142,504 | 142,147 | |||||||||
| Advances in aid of construction | 88,847 | 82,580 | |||||||||
| Environmental remediation obligation | 49,670 | 55,224 | |||||||||
| Customer deposits | 33,041 | 32,633 | |||||||||
| Unamortized investment tax credits | 17,304 | 17,439 | |||||||||
| Deferred credits and contingent consideration | 37,398 | 35,982 | |||||||||
| Preferred shares, Series C | 13,434 | 13,348 | |||||||||
| Hook-up fees | 22,685 | 21,904 | |||||||||
| Lease liabilities | 22,121 | 22,512 | |||||||||
| Contingent development support obligations | 6,223 | 4,612 | |||||||||
| Note payable to related party | 25,808 | 25,808 | |||||||||
| Other | 43,703 | 42,050 | |||||||||
| $ | 671,973 | $ | 683,819 | ||||||||
| Less: current portion | (162,312) | (167,908) | |||||||||
| $ | 509,661 | $ | 515,911 | ||||||||
10.Shareholders’ capital
(a)Common shares
Number of common shares
| Three months ended March 31 | ||||||||||||||
| 2022 | 2021 | |||||||||||||
| Common shares, beginning of period | 671,960,276 | 597,142,219 | ||||||||||||
| Public offering | — | 8,188,225 | ||||||||||||
| Dividend reinvestment plan | 1,625,414 | 1,403,635 | ||||||||||||
| Exercise of share-based awards (b) | 523,746 | 547,683 | ||||||||||||
| Conversion of convertible debentures | 754 | — | ||||||||||||
| Common shares, end of period | 674,110,190 | 607,281,762 | ||||||||||||
On May 15, 2020, AQN re-established an at-the-market equity program (“ATM program”) that allowed the Company to issue up to $500,000 of common shares from treasury to the public from time to time, at the Company's discretion, at the prevailing market price when issued on the TSX, the NYSE, or any other existing trading market for the common shares of the Company in Canada or the United States. On November 19, 2021, in connection with the filing of a new base shelf prospectus, AQN withdrew the base shelf prospectus qualifying the ATM program.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
10.Shareholders’ capital (continued)
(a)Common shares (continued)
As at May 12, 2022, the Company has issued since the inception of the ATM program in 2019 a cumulative total of 33,952,827 common shares at an average price of $15.08 per share for gross proceeds of $512,163 ($505,761 net of commissions). Other related costs, primarily related to the establishment and subsequent re-establishments of the ATM program, were $4,285.
(b)Share-based compensation
For the three months ended March 31, 2022, AQN recorded $(365) (2021 - $1,197) in total share-based compensation expense (recovery). The compensation expense (recovery) is recorded with payroll expenses in the unaudited interim consolidated statements of operations. The portion of share-based compensation costs capitalized as cost of construction is insignificant.
As at March 31, 2022, total unrecognized compensation costs related to non-vested share-based awards was $20,386 and is expected to be recognized over a period of 2.1 years.
Share option plan
During the three months ended March 31, 2022, the Board of Directors of the Company (the "Board") approved the grant of 646,090 options to executives of the Company. The options allow for the purchase of common shares at a weighted average price of C$19.11, the market price of the underlying common shares at the date of grant. One-third of the options vest on each of December 31, 2022, 2023 and 2024. The options may be exercised up to eight years following the date of grant.
The following assumptions were used in determining the fair value of share options granted:
| 2022 | ||||||||
| Risk-free interest rate | 1.9 | % | ||||||
| Expected volatility | 23 | % | ||||||
| Expected dividend yield | 4.3 | % | ||||||
| Expected life | 5.50 years | |||||||
| Weighted average grant date fair value per option | C$ | 2.44 | ||||||
Performance and restricted share units
During the three months ended March 31, 2022, a total of 411,784 performance share units ("PSUs") and restricted share units ("RSUs") were granted to employees of the Company. The awards vest based on the terms of each agreement ranging from February 2023 to January 2025. During the three months ended March 31, 2022, the Company settled 797,034 PSUs and RSUs in exchange for 409,986 common shares issued from treasury, and 387,048 PSUs and RSUs were settled at their cash value as payment for tax withholding related to the settlement of the awards.
During the three months ended March 31, 2022, the Company settled 4,108 bonus deferral RSUs in exchange for 1,908 common shares issued from treasury, and 2,200 RSUs were settled at their cash value as payment for tax withholding related to the settlement of the awards. Subsequent to the quarter, on April 15, 2022, 3,397 bonus deferral RSUs were granted to employees of the Company. The RSUs are 100% vested.
Directors' deferred share units
During the three months ended March 31, 2022, 21,149 deferred share units ("DSUs") were issued pursuant to the election by Directors of the Company to defer a percentage of their directors' fee in the form of DSUs. In addition, the Company settled 5,176 DSUs in exchange for 2,403 common shares issued from treasury, and 2,773 DSUs were settled at their cash value as payment for tax withholding related to the settlement of the awards.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
11.Accumulated other comprehensive income (loss)
AOCI consists of the following balances, net of tax:
| Foreign currency cumulative translation | Unrealized gain on cash flow hedges | Pension and post-employment actuarial changes | Total | ||||||||||||||||||||||||||
| Balance, January 1, 2021 | $ | (39,725) | $ | 50,817 | $ | (33,599) | $ | (22,507) | |||||||||||||||||||||
| OCI | (25,982) | (97,103) | 32,247 | (90,838) | |||||||||||||||||||||||||
| Amounts reclassified from AOCI to the unaudited interim consolidated statements of operations | (4,288) | 42,772 | 9,804 | 48,288 | |||||||||||||||||||||||||
| Net current period OCI | $ | (30,270) | $ | (54,331) | $ | 42,051 | $ | (42,550) | |||||||||||||||||||||
| OCI attributable to the non-controlling interests | (249) | — | — | (249) | |||||||||||||||||||||||||
| Net current period OCI attributable to shareholders of AQN | $ | (30,519) | $ | (54,331) | $ | 42,051 | $ | (42,799) | |||||||||||||||||||||
| Amounts reclassified from AOCI to non-controlling interest | (6,371) | — | — | (6,371) | |||||||||||||||||||||||||
| Balance, December 31, 2021 | $ | (76,615) | $ | (3,514) | $ | 8,452 | $ | (71,677) | |||||||||||||||||||||
| OCI | 8,539 | (61,554) | — | (53,015) | |||||||||||||||||||||||||
| Amounts reclassified from AOCI to the unaudited interim consolidated statements of operations | (694) | 2,668 | 7 | 1,981 | |||||||||||||||||||||||||
| Net current period OCI | $ | 7,845 | $ | (58,886) | $ | 7 | $ | (51,034) | |||||||||||||||||||||
| OCI attributable to the non-controlling interests | (687) | — | — | (687) | |||||||||||||||||||||||||
| Net current period OCI attributable to shareholders of AQN | $ | 7,158 | $ | (58,886) | $ | 7 | $ | (51,721) | |||||||||||||||||||||
| Balance, March 31, 2022 | $ | (69,457) | $ | (62,400) | $ | 8,459 | $ | (123,398) | |||||||||||||||||||||
Amounts reclassified from AOCI for foreign currency cumulative translation affected interest expense and derivative gain (loss); those for unrealized gain (loss) on cash flow hedges affected revenue from non-regulated energy sales, interest expense and derivative gain (loss), while those for pension and other post-employment actuarial changes affected pension and other post-employment non-service costs.
12.Dividends
All dividends of the Company are made on a discretionary basis as determined by the Board. The Company declares and pays the dividends on its common shares in U.S. dollars. Dividends declared were as follows:
| Three months ended March 31 | |||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| Dividend | Dividend per share | Dividend | Dividend per share | ||||||||||||||||||||
| Common shares | $ | 115,574 | $ | 0.1706 | $ | 94,614 | $ | 0.1551 | |||||||||||||||
| Series A preferred shares | C$ | 1,549 | C$ | 0.3226 | C$ | 1,549 | C$ | 0.3226 | |||||||||||||||
| Series D preferred shares | C$ | 1,273 | C$ | 0.3182 | C$ | 1,273 | C$ | 0.3182 | |||||||||||||||
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
13.Related party transactions
(a)Equity-method investments
The Company provides administrative and development services to its equity-method investees and is reimbursed for incurred costs. To that effect, during the three months ended March 31, 2022, the Company charged its equity-method investees $7,413 (2021 - $6,314). Additionally, one of the equity-method investees provides development services to the Company on specified projects, for which it earns a development fee upon reaching certain milestones. During the three months ended March 31, 2022, the development fees charged to the Company were $nil (2021 - $738).
In 2020, the Company issued a promissory note of $30,493 payable to Altavista Solar Subco, LLC, an equity investee of the Company at the time. The note was repaid in full during the second quarter of 2021. During the fourth quarter of 2021, the Company issued a promissory note of $25,808 payable to New Market Solar Investco, LLC, an equity investee of the Company.
(b)Redeemable non-controlling interest held by related party
Liberty Global Energy Solutions (note 6(a)), an equity investee of the Company, has a secured credit facility in the amount of $306,500 maturing on January 26, 2024. It is collateralized through a pledge of Atlantica Sustainable Infrastructure plc (“Atlantica”) ordinary shares. A collateral shortfall would occur if the net obligation as defined in the agreement would equal or exceed 50% of the market value of such Atlantica shares, in which case the lenders would have the right to sell Atlantica shares to eliminate the collateral shortfall. The Liberty Global Energy Solutions secured credit facility is repayable on demand if Atlantica ceases to be a public company. Liberty Global Energy Solutions has a preference share ownership in AY Holdings which AQN reflects as redeemable non-controlling interest held by related party. Redemption is not considered probable as at March 31, 2022. During the three months ended March 31, 2022, the Company incurred non-controlling interest attributable to Liberty Global Energy Solutions of $2,575 (2021 - $2,681) and recorded distributions of $2,584 (2021 - $2,544) (note 14).
(c)Non-controlling interest held by related party
Non-controlling interest held by related party represents an interest in a consolidated subsidiary of the Company, acquired by Atlantica Yield Energy Solutions Canada Inc.("AYES Canada") in May 2019 for $96,752 (C$130,103) and an interest in Algonquin (AY Holdco) B.V., a consolidated subsidiary of the Company, acquired by Liberty Development JV in November 2021 for $39,376. During the three months ended March 31, 2022, the Company recorded distributions of $7,422 (2021 - $4,471).
(d) Transactions with Atlantica
During 2021, the Company sold Colombian solar assets to Atlantica for consideration of $23,863, with a gain on sale of $878, and contingent consideration of $2,600, if certain milestones are met. During the three months ended March 31, 2022 a gain of $1,200 relating to the contingent consideration has been recognized.
The above related party transactions have been recorded at the exchange amounts agreed to by the parties to the transactions.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
14.Non-controlling interests and redeemable non-controlling interests
Net effect attributable to non-controlling interests consists of the following:
| Three months ended March 31 | |||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| HLBV and other adjustments attributable to: | |||||||||||||||||||||||
| Non-controlling interests - tax equity partnership units | $ | 40,862 | $ | 22,246 | |||||||||||||||||||
| Non-controlling interests - redeemable tax equity partnership units | 1,599 | 1,718 | |||||||||||||||||||||
| Other net earnings attributable to: | |||||||||||||||||||||||
| Non-controlling interests | (1,519) | (3,999) | |||||||||||||||||||||
| $ | 40,942 | $ | 19,965 | ||||||||||||||||||||
| Redeemable non-controlling interest, held by related party | (2,575) | (2,681) | |||||||||||||||||||||
Net effect of non-controlling interests | $ | 38,367 | $ | 17,284 | |||||||||||||||||||
The non-controlling tax equity investors (“tax equity partnership units”) in the Company's U.S. wind power and solar power generating facilities are entitled to allocations of earnings, tax attributes and cash flows in accordance with contractual agreements. The share of earnings attributable to the non-controlling interest holders in these subsidiaries is calculated using the Hypothetical Liquidation at Book Value ("HLBV") method of accounting.
15.Income taxes
For the three months ended March 31, 2022, the provision for income taxes in the unaudited interim consolidated statements of operations represents an effective tax rate different than the Canadian enacted statutory rate of 26.5% (March 31, 2021 - 26.5%). The differences are as follows:
| Three months ended March 31 | |||||||||||
| 2022 | 2021 | ||||||||||
| Expected income tax expense at Canadian statutory rate | $ | 16,443 | $ | (6,618) | |||||||
| Increase (decrease) resulting from: | |||||||||||
| Effect of differences in tax rates on transactions in and within foreign jurisdictions and change in tax rates | (12,477) | (14,937) | |||||||||
| Adjustments from investments carried at fair value | 1,013 | 4,133 | |||||||||
| Non-controlling interests share of income | 11,053 | 12,315 | |||||||||
| Acquisition related state deferred tax adjustments | 7,600 | — | |||||||||
| Tax credits | (10,151) | (11,585) | |||||||||
| Amortization and settlement of excess deferred income tax | (4,034) | (4,617) | |||||||||
| Other | 5 | (329) | |||||||||
| Income tax expense (recovery) | $ | 9,452 | $ | (21,638) | |||||||
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
16.Other net losses
Other net losses consist of the following:
| Three months ended March 31 | |||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| Acquisition and transition-related costs | $ | 2,165 | $ | 2,102 | |||||||||||||||||||
| Other | 2,565 | 6,282 | |||||||||||||||||||||
| $ | 4,730 | $ | 8,384 | ||||||||||||||||||||
17.Basic and diluted net earnings per share
Basic and diluted earnings per share have been calculated on the basis of net earnings attributable to the common shareholders of the Company and the weighted average number of common shares and bonus deferral restricted share units outstanding. Diluted net earnings per share is computed using the weighted-average number of common shares, additional shares issued subsequent to quarter-end under the dividend reinvestment plan, PSUs, RSUs and DSUs outstanding during the period and, if dilutive, potential incremental common shares related to the convertible debentures or resulting from the application of the treasury stock method to outstanding share options and Green Equity Units (note 7).
The reconciliation of the net earnings and the weighted average shares used in the computation of basic and diluted earnings per share are as follows:
| Three months ended March 31 | |||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| Net earnings attributable to shareholders of AQN | $ | 90,965 | $ | 13,947 | |||||||||||||||||||
| Series A preferred shares dividend | 1,218 | 1,215 | |||||||||||||||||||||
| Series D preferred shares dividend | 1,002 | 999 | |||||||||||||||||||||
| Net earnings attributable to common shareholders of AQN – basic and diluted | $ | 88,745 | $ | 11,733 | |||||||||||||||||||
| Weighted average number of shares | |||||||||||||||||||||||
| Basic | 673,742,425 | 599,659,587 | |||||||||||||||||||||
| Effect of dilutive securities | 4,448,713 | 5,525,965 | |||||||||||||||||||||
| Diluted | 678,191,138 | 605,185,552 | |||||||||||||||||||||
This calculation of diluted shares for the three months ended March 31, 2022 excludes the potential impact of the Green Equity Units and potential incremental shares related to 1,134,711 securities (2021 - 437,006) as they are anti-dilutive.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
18.Segmented information
The Company is managed under two primary business units consisting of the Regulated Services Group and the Renewable Energy Group. The two business units are the two segments of the Company.
The Regulated Services Group, the Company's regulated operating unit, owns and operates a portfolio of electric, natural gas, water distribution and wastewater collection utility systems and transmission operations in the United States, Canada, Bermuda and Chile; the Renewable Energy Group, the Company's non-regulated operating unit, owns and operates a diversified portfolio of renewable and thermal electric generation assets in North America and internationally.
For purposes of evaluating the performance of the business units, the Company allocates the realized portion of any gains or losses on financial instruments to the specific business units. Dividend income from Atlantica and AYES Canada is included in the operations of the Renewable Energy Group, while interest income from San Antonio Water System is included in the operations of the Regulated Services Group. Equity method income and losses are included in the operations of the Regulated Services Group or Renewable Energy Group based on the nature of the activities of the investees. The change in value of investments carried at fair value, unrealized portion of any gains or losses on derivative instruments not designated in a hedging relationship and foreign exchange gains and losses are not considered in management’s evaluation of divisional performance and are therefore, allocated and reported under corporate.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
18.Segmented information (continued)
| Three months ended March 31, 2022 | |||||||||||||||||||||||
| Regulated Services Group | Renewable Energy Group | Corporate | Total | ||||||||||||||||||||
Revenue (1)(2) | $ | 622,759 | $ | 88,220 | $ | — | $ | 710,979 | |||||||||||||||
| Other revenue | 14,988 | 9,344 | 386 | 24,718 | |||||||||||||||||||
| Fuel, power and water purchased | 234,572 | 14,906 | — | 249,478 | |||||||||||||||||||
| Net revenue | 403,175 | 82,658 | 386 | 486,219 | |||||||||||||||||||
| Operating expenses | 184,409 | 27,590 | 3 | 212,002 | |||||||||||||||||||
| Administrative expenses | 8,070 | 7,545 | 1,837 | 17,452 | |||||||||||||||||||
| Depreciation and amortization | 80,283 | 39,417 | 264 | 119,964 | |||||||||||||||||||
| Loss on foreign exchange | — | — | 262 | 262 | |||||||||||||||||||
| 130,413 | 8,106 | (1,980) | 136,539 | ||||||||||||||||||||
| Gain on sale of renewable assets | — | 1,200 | — | 1,200 | |||||||||||||||||||
| Operating income (loss) | 130,413 | 9,306 | (1,980) | 137,739 | |||||||||||||||||||
| Interest expense | (21,426) | (15,713) | (20,804) | (57,943) | |||||||||||||||||||
| Income (loss) from long-term investments | 4,509 | 27,626 | (42,824) | (10,689) | |||||||||||||||||||
| Other expenses | (4,888) | (748) | (1,421) | (7,057) | |||||||||||||||||||
| Earnings (loss) before income taxes | $ | 108,608 | $ | 20,471 | $ | (67,029) | $ | 62,050 | |||||||||||||||
| Property, plant and equipment | $ | 8,093,549 | $ | 3,645,043 | $ | 31,617 | $ | 11,770,209 | |||||||||||||||
| Investments carried at fair value | 2,156 | 1,807,142 | — | 1,809,298 | |||||||||||||||||||
| Equity-method investees | 37,855 | 342,620 | 21,132 | 401,607 | |||||||||||||||||||
| Total assets | 11,435,863 | 6,064,427 | 169,574 | 17,669,864 | |||||||||||||||||||
| Capital expenditures | $ | 255,585 | $ | 72,114 | $ | — | $ | 327,699 | |||||||||||||||
(1) Renewable Energy Group revenue includes $4,830 related to net hedging loss from energy derivative contracts and availability credits for the three-months period ended March 31, 2022 that do not represent revenue recognized from contracts with customers.
(2) Regulated Services Group revenue includes $6,278 related to alternative revenue programs for the three-months period ended March 31, 2022 that do not represent revenue recognized from contracts with customers.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
18.Segmented information (continued)
| Three months ended March 31, 2021 | |||||||||||||||||||||||
| Regulated Services Group | Renewable Energy Group | Corporate | Total | ||||||||||||||||||||
Revenue (1)(2) | $ | 587,137 | $ | 30,783 | $ | — | $ | 617,920 | |||||||||||||||
| Other revenue | 11,466 | 4,770 | 386 | 16,622 | |||||||||||||||||||
| Fuel, power and water purchased | 245,522 | 7,928 | — | 253,450 | |||||||||||||||||||
| Net revenue | 353,081 | 27,625 | 386 | 381,092 | |||||||||||||||||||
| Operating expenses | 152,182 | 27,872 | 3 | 180,057 | |||||||||||||||||||
| Administrative expenses | 7,543 | 6,183 | 2,917 | 16,643 | |||||||||||||||||||
| Depreciation and amortization | 67,567 | 29,578 | 294 | 97,439 | |||||||||||||||||||
| Loss on foreign exchange | — | — | 862 | 862 | |||||||||||||||||||
| Operating income | 125,789 | (36,008) | (3,690) | 86,091 | |||||||||||||||||||
| Interest expense | (24,301) | (16,293) | (8,986) | (49,580) | |||||||||||||||||||
| Income (loss) from long-term investments | 1,174 | 22,417 | (74,098) | (50,507) | |||||||||||||||||||
| Other expenses | (8,491) | (876) | (1,612) | (10,979) | |||||||||||||||||||
| Earnings (loss) before income taxes | $ | 94,171 | $ | (30,760) | $ | (88,386) | $ | (24,975) | |||||||||||||||
| Capital expenditures | $ | 212,519 | $ | 77,085 | $ | 5,785 | $ | 295,389 | |||||||||||||||
| December 31, 2021 | |||||||||||||||||||||||
| Property, plant and equipment | $ | 7,394,151 | $ | 3,615,915 | $ | 32,380 | $ | 11,042,446 | |||||||||||||||
| Investments carried at fair value | 2,296 | 1,846,160 | — | 1,848,456 | |||||||||||||||||||
| Equity-method investees | 37,492 | 375,460 | 20,898 | 433,850 | |||||||||||||||||||
| Total assets | $ | 10,512,799 | $ | 6,123,888 | $ | 149,149 | $ | 16,785,836 | |||||||||||||||
(1) Renewable Energy Group revenue includes $49,585 related to net hedging loss from energy derivative contracts for the three-months period ended March 31, 2021 that do not represent revenue recognized from contracts with customers.
(2) Regulated Services Group revenue includes $2,361 related to alternative revenue programs for the three-months period ended March 31, 2021 that do not represent revenue recognized from contracts with customers.
The majority of non-regulated energy sales are earned from contracts with large public utilities. The Company has sought to mitigate its credit risk by selling energy to large utilities in various North American locations. None of the utilities contribute more than 10% of total revenue.
AQN operates in the independent power and utility industries in the United States, Canada and other regions. Information on operations by geographic area is as follows:
| Three months ended March 31 | |||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| Revenue | |||||||||||||||||||||||
| United States | $ | 601,333 | $ | 511,827 | |||||||||||||||||||
| Canada | 53,835 | 47,851 | |||||||||||||||||||||
| Other regions | 80,529 | 74,864 | |||||||||||||||||||||
| $ | 735,697 | $ | 634,542 | ||||||||||||||||||||
Revenue is attributed to the regions based on the location of the underlying generating and utility facilities.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
19.Commitments and contingencies
(a)Contingencies
AQN and its subsidiaries are involved in various claims and litigation arising out of the ordinary course and conduct of its business. Although such matters cannot be predicted with certainty, management does not consider AQN’s exposure to such litigation to be material to these unaudited interim consolidated financial statements. Accruals for any contingencies related to these items are recorded in the consolidated financial statements at the time it is concluded that their occurrence is probable and the related liability is estimable.
Mountain View Fire
On November 17, 2020, a wildfire now known as the Mountain View fire occurred in the territory of Liberty Utilities (CalPeco Electric) LLC ("Liberty CalPeco"). The cause of the fire is undetermined at this time, and CAL FIRE has not yet issued a report. There are currently 10 active lawsuits that name the Company and/or certain of its subsidiaries as defendants in connection with the Mountain View fire. Five of these lawsuits are brought by groups of individual plaintiffs alleging causes of action including negligence, inverse condemnation, nuisance, trespass, and violations of Cal. Pub. Util. Code 2106 and Cal. Health and Safety Code 13007. In the sixth active lawsuit, County of Mono, Antelope Valley Fire Protection District, Toiyabe Indian Health Project, and Bridgeport Indian Colony allege similar causes of action and seek damages for fire suppression costs, law enforcement costs, property and infrastructure damage, and other costs. In three other lawsuits, insurance companies allege inverse condemnation and negligence and seek recovery of amounts paid and to be paid to their insureds. The tenth lawsuit alleges the wrongful death of an individual, along with causes of action similar to those alleged in the cases filed by groups of individual plaintiffs. The likelihood of success in these lawsuits cannot be reasonably predicted. Liberty CalPeco intends to vigorously defend them. The Company has wildfire liability insurance that is expected to apply up to applicable policy limits.
Apple Valley Condemnation Proceedings
On January 7, 2016, the Town of Apple Valley filed a lawsuit seeking to condemn the utility assets of Liberty Utilities (Apple Valley Ranchos Water) Corp. (“Liberty Apple Valley”). On May 7, 2021, the Court issued a Tentative Statement of Decision denying the Town of Apple Valley’s attempt to take the Apple Valley water system by eminent domain. The ruling confirmed that Liberty Apple Valley’s continued ownership and operation of the water system is in the best interest of the community. The Town filed its objections to the Tentative Decision on June 1, 2021. On October 14, 2021, the Court denied the Town’s objections and issued the Final Statement of Decision. The Court signed and entered an Order of Dismissal and Judgment on November 12, 2021. On January 7, 2022, the Town filed a notice of appeal of the judgment entered by the Court.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
19.Commitments and contingencies (continued)
(b)Commitments
In addition to the commitments related to the development projects disclosed in note 6, the following significant commitments exist as at March 31, 2022.
AQN has outstanding purchase commitments for power purchases, gas supply and service agreements, service agreements, capital project commitments and land easements. Detailed below are estimates of future commitments under these arrangements:
| Year 1 | Year 2 | Year 3 | Year 4 | Year 5 | Thereafter | Total | |||||||||||||||||
| Power purchase (i) | $ | 48,680 | $ | 34,053 | $ | 34,229 | $ | 26,994 | $ | 12,336 | $ | 151,997 | $ | 308,289 | |||||||||
| Gas supply and service agreements (ii) | 93,974 | 71,725 | 52,345 | 42,658 | 27,403 | 173,280 | 461,385 | ||||||||||||||||
| Service agreements | 65,179 | 59,269 | 57,695 | 55,494 | 48,167 | 336,564 | 622,368 | ||||||||||||||||
| Capital projects | 65,428 | — | — | — | — | — | 65,428 | ||||||||||||||||
| Land easements and others | 12,977 | 13,119 | 13,285 | 13,465 | 13,629 | 469,055 | 535,530 | ||||||||||||||||
| Total | $ | 286,238 | $ | 178,166 | $ | 157,554 | $ | 138,611 | $ | 101,535 | $ | 1,130,896 | $ | 1,993,000 | |||||||||
(i) Power purchase: AQN’s electric distribution facilities have commitments to purchase physical quantities of power for load serving requirements. The commitment amounts included in the table above are based on market prices as at March 31, 2022. However, the effects of purchased power unit cost adjustments are mitigated through a purchased power rate-adjustment mechanism.
(ii) Gas supply and service agreements: AQN’s gas distribution facilities and thermal generation facilities have commitments to purchase physical quantities of natural gas under contracts for purposes of load serving requirements and of generating power.
20.Non-cash operating items
The changes in non-cash operating items consist of the following:
| Three months ended March 31 | |||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| Accounts receivable | $ | (40,612) | $ | (29,746) | |||||||||||||||||||
| Fuel and natural gas in storage | 16,234 | 17,972 | |||||||||||||||||||||
| Supplies and consumables inventory | (7,769) | (3,103) | |||||||||||||||||||||
| Income taxes recoverable | 2,932 | (165) | |||||||||||||||||||||
| Prepaid expenses | (7,350) | (1,029) | |||||||||||||||||||||
| Accounts payable | (21,665) | (39,330) | |||||||||||||||||||||
| Accrued liabilities | 53,296 | (69,359) | |||||||||||||||||||||
| Current income tax liability | 2,203 | 4,852 | |||||||||||||||||||||
| Asset retirements and environmental obligations | (499) | (459) | |||||||||||||||||||||
| Net regulatory assets and liabilities | (44,918) | (268,151) | |||||||||||||||||||||
| $ | (48,148) | $ | (388,518) | ||||||||||||||||||||
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
21.Financial instruments
(a)Fair value of financial instruments
| March 31, 2022 | Carrying amount | Fair value | Level 1 | Level 2 | Level 3 | ||||||||||||||||||||||||
| Long-term investments carried at fair value | $ | 1,809,298 | $ | 1,809,298 | $ | 1,719,286 | $ | — | $ | 90,012 | |||||||||||||||||||
| Development loans and other receivables | 63,882 | 63,810 | — | 63,810 | — | ||||||||||||||||||||||||
| Derivative instruments: | |||||||||||||||||||||||||||||
| Interest rate swap designated as a hedge | 22,309 | 22,309 | — | 22,309 | — | ||||||||||||||||||||||||
| Energy contracts designated as a cash flow hedge | 2,513 | 2,513 | — | — | 2,513 | ||||||||||||||||||||||||
| Energy contracts not designated as cash flow hedge | 913 | 913 | — | — | 913 | ||||||||||||||||||||||||
| Congestion revenue rights designated as a cash flow hedge | 4,104 | 4,104 | — | — | 4,104 | ||||||||||||||||||||||||
| Congestion revenue rights not designated as a cash flow hedge | 1,451 | 1,451 | — | — | 1,451 | ||||||||||||||||||||||||
| Commodity contracts for regulated operations | 1,979 | 1,979 | — | 1,979 | — | ||||||||||||||||||||||||
| Cross-currency swap designated as a net investment hedge | 4,109 | 4,109 | — | 4,109 | — | ||||||||||||||||||||||||
| Cross-currency swap designated as a cash flow hedge | 540 | 540 | — | 540 | — | ||||||||||||||||||||||||
| Total derivative instruments | 37,918 | 37,918 | — | 28,937 | 8,981 | ||||||||||||||||||||||||
| Total financial assets | $ | 1,911,098 | $ | 1,911,026 | $ | 1,719,286 | $ | 92,747 | $ | 98,993 | |||||||||||||||||||
| Long-term debt | $ | 7,191,375 | $ | 7,156,198 | $ | 3,103,268 | $ | 4,052,930 | $ | — | |||||||||||||||||||
| Notes payable to related party | 25,808 | 25,808 | — | 25,808 | — | ||||||||||||||||||||||||
| Convertible debentures | 274 | 547 | 547 | — | — | ||||||||||||||||||||||||
| Preferred shares, Series C | 13,434 | 13,724 | — | 13,724 | — | ||||||||||||||||||||||||
| Derivative instruments: | |||||||||||||||||||||||||||||
| Energy contracts designated as a cash flow hedge | 102,571 | 102,571 | — | — | 102,571 | ||||||||||||||||||||||||
| Energy contracts not designated as a cash flow hedge | 78 | 78 | — | — | 78 | ||||||||||||||||||||||||
| Cross-currency swap designated as a net investment hedge | 36,202 | 36,202 | — | 36,202 | — | ||||||||||||||||||||||||
| Cross-currency swap designated as a cash flow hedge | 7,391 | 7,391 | — | 7,391 | — | ||||||||||||||||||||||||
| Interest rate swaps designated as a hedge | 2,899 | 2,899 | — | 2,899 | — | ||||||||||||||||||||||||
| Total derivative instruments | 149,141 | 149,141 | — | 46,492 | 102,649 | ||||||||||||||||||||||||
| Total financial liabilities | $ | 7,380,032 | $ | 7,345,418 | $ | 3,103,815 | $ | 4,138,954 | $ | 102,649 | |||||||||||||||||||
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
21.Financial instruments (continued)
(a)Fair value of financial instruments (continued)
| December 31, 2021 | Carrying amount | Fair value | Level 1 | Level 2 | Level 3 | ||||||||||||||||||||||||
| Long-term investment carried at fair value | $ | 1,848,456 | $ | 1,848,456 | $ | 1,753,210 | $ | — | $ | 95,246 | |||||||||||||||||||
| Development loans and other receivables | 32,261 | 33,286 | — | 33,286 | — | ||||||||||||||||||||||||
| Derivative instruments: | |||||||||||||||||||||||||||||
| Energy contracts designated as a cash flow hedge | 15,362 | 15,362 | — | — | 15,362 | ||||||||||||||||||||||||
| Interest rate swap designated as a hedge | 1,581 | 1,581 | — | 1,581 | — | ||||||||||||||||||||||||
| Commodity contracts for regulatory operations | 1,721 | 1,721 | — | 1,721 | — | ||||||||||||||||||||||||
| Cross-currency swap designated as a net investment hedge | 1,958 | 1,958 | — | 1,958 | — | ||||||||||||||||||||||||
| Total derivative instruments | 20,622 | 20,622 | — | 5,260 | 15,362 | ||||||||||||||||||||||||
| Total financial assets | $ | 1,901,339 | $ | 1,902,364 | $ | 1,753,210 | $ | 38,546 | $ | 110,608 | |||||||||||||||||||
| Long-term debt | $ | 6,211,375 | $ | 6,543,933 | $ | 2,418,580 | $ | 4,125,352 | — | ||||||||||||||||||||
| Notes payable to related party | 25,808 | 25,808 | — | 25,808 | — | ||||||||||||||||||||||||
| Convertible debentures | 277 | 519 | 519 | — | — | ||||||||||||||||||||||||
| Preferred shares, Series C | 13,348 | 14,580 | — | 14,580 | — | ||||||||||||||||||||||||
| Derivative instruments: | |||||||||||||||||||||||||||||
| Energy contracts designated as a cash flow hedge | 60,462 | 60,462 | — | — | 60,462 | ||||||||||||||||||||||||
| Energy contracts not designated as a cash flow hedge | 1,169 | 1,169 | — | — | 1,169 | ||||||||||||||||||||||||
| Cross-currency swap designated as a net investment hedge | 50,258 | 50,258 | — | 50,258 | — | ||||||||||||||||||||||||
| Interest rate swaps designated as a hedge | 7,008 | 7,008 | — | 7,008 | — | ||||||||||||||||||||||||
| Commodity contracts for regulated operations | 1,348 | 1,348 | — | 1,348 | — | ||||||||||||||||||||||||
| Total derivative instruments | 120,245 | 120,245 | — | 58,614 | 61,631 | ||||||||||||||||||||||||
| Total financial liabilities | $ | 6,371,053 | $ | 6,705,085 | $ | 2,419,099 | $ | 4,224,354 | $ | 61,631 | |||||||||||||||||||
The Company has determined that the carrying value of its short-term financial assets and liabilities approximates fair value as at March 31, 2022 and December 31, 2021 due to the short-term maturity of these instruments.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
21.Financial instruments (continued)
(a)Fair value of financial instruments (continued)
The fair value of development loans and other receivables (level 2) is determined using a discounted cash flow method, using estimated current market rates for similar instruments adjusted for estimated credit risk as determined by management.
The fair value of the investment in Atlantica (level 1) is measured at the closing price on the NASDAQ stock exchange.
The Company’s level 1 fair value of long-term debt is measured at the closing price on the NYSE and the over-the-counter closing price. The Company’s level 2 fair value of long-term debt at fixed interest rates and Series C preferred shares has been determined using a discounted cash flow method and current interest rates. The Company's level 2 fair value of convertible debentures has been determined as the greater of their face value and the quoted value of AQN's common shares on a converted basis.
The Company’s level 2 fair value derivative instruments primarily consist of swaps, options, rights, subscription agreements and forward physical derivatives where market data for pricing inputs are observable. Level 2 pricing inputs are obtained from various market indices and utilize discounting based on quoted interest rate curves, which are observable in the marketplace.
The Company’s level 3 instruments consist of energy contracts for electricity sales, congestion revenue rights ("CRRs") and the fair value of the Company's investment in AYES Canada. The significant unobservable inputs used in the fair value measurement of energy contracts are the internally developed forward market prices ranging from $21.14 to $126.25 with a weighted average of $38.66 as at March 31, 2022. The weighted average forward market prices are developed based on the quantity of energy expected to be sold monthly and the expected forward price during that month. The change in the fair value of the energy contracts is detailed in notes 21(b)(ii) and 21(b)(iv). The significant unobservable inputs used in the fair value measurement of CRRs are recent CRR auction prices ranging from $1.80 to $10.84 with a weighted average of $4.25 as of March 31, 2022. The significant unobservable inputs used in the fair value measurement of the Company's AYES Canada investment are the expected cash flows, the discount rates applied to these cash flows ranging from 8.45% to 8.95% with a weighted average of 8.84%, and the expected volatility of Atlantica's share price ranging from 25% to 37% as at March 31, 2022. Significant increases (decreases) in expected cash flows or increases (decreases) in discount rate in isolation would have resulted in a significantly lower (higher) fair value measurement.
(b)Derivative instruments
Derivative instruments are recognized on the unaudited interim consolidated balance sheets as either assets or liabilities and measured at fair value at each reporting period.
(i)Commodity derivatives – regulated accounting
The Company uses derivative financial instruments to reduce the cash flow variability associated with the purchase price for a portion of future natural gas purchases associated with its regulated gas and electric service territories. The Company’s strategy is to minimize fluctuations in gas sale prices to regulated customers. The following are commodity volumes, in dekatherms (“dths”), associated with the above derivative contracts:
| March 31, 2022 | |||||
| Financial contracts: Swaps | 709,839 | ||||
| Options | 113,504 | ||||
| 823,343 | |||||
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
21.Financial instruments (continued)
(b)Derivative instruments (continued)
(i)Commodity derivatives – regulated accounting (continued)
The accounting for these derivative instruments is subject to guidance for rate regulated enterprises. Most of the gains or losses on the settlement of these contracts are included in the calculation of the fuel and commodity costs adjustments (note 5). As a result, the changes in fair value of these natural gas derivative contracts and their offsetting adjustment to regulatory assets and liabilities had no earnings impact.
(ii)Cash flow hedges
The Company has sought to reduce the price risk on the expected future sale of power generation at the Sandy Ridge, Senate, Minonk, and Shady Oaks II Wind Facilities by entering into the following long-term energy derivative contracts.
| Notional quantity (MW-hrs) | Expiry | Receive average prices (per MW-hr) | Pay floating price (per MW-hr) | |||||||||||||||||
| 4,432,940 | September 2030 | $24.54 | Illinois Hub | |||||||||||||||||
| 490,238 | December 2028 | $31.29 | PJM Western HUB | |||||||||||||||||
| 2,318,930 | December 2027 | $23.26 | NI HUB | |||||||||||||||||
| 1,887,172 | December 2027 | $36.46 | ERCORT North HUB | |||||||||||||||||
The Company provides energy requirements to various customers under contracts at fixed rates. While the production from the Tinker Hydroelectric Facility is expected to provide a portion of the energy required to service these customers, AQN anticipates having to purchase a portion of its energy requirements at the ISO NE spot rates to supplement self-generated energy. The Company mitigates the risk by using short-term financial forward energy purchase contracts. These short-term derivatives are not accounted for as hedges and changes in fair value are recorded in earnings as they occur (note 21(b)(iv)). A prior contract used as a hedging instrument expired in February 2022.
The Company is party to two interest rate swap contracts as cash flow hedges to mitigate the risk that LIBOR-based interest rates will increase over the life of term loan facilities. Under the terms of the interest rate swap contracts, the Company has fixed its LIBOR interest rate expense on $87,627 and $8,875 to 3.28% and 3.02%, respectively, on its two term loan facilities. The fair value of the derivative on the designation date is amortized into earnings over the remaining life of the contract.
The Company is party to a forward-starting interest rate swap in order to reduce the interest rate risk related to the quarterly interest payments between July 1, 2024 and July 1, 2029 on the $350,000 subordinated unsecured notes and between April 18, 2027 and April 18, 2032 on the $750,000 subordinated unsecured notes. The Company designated the entire notional amount of the pay-variable and receive-fixed interest rate swaps as a hedge of the future quarterly variable-rate interest payments associated with the subordinated unsecured notes.
In January 2022, the Company entered into a cross-currency swap, coterminous with the Canadian Notes, to effectively convert the C$400,000 Canadian Offering into U.S. dollars. The change in the carrying amount of the notes due to changes in spot exchange rates is recognized each period in the unaudited interim consolidated statements of operations as loss (gain) on foreign exchange. The Company designated the entire notional amount of the cross-currency fixed-for-fixed interest rate swap as a hedge of the foreign currency exposure related to cash flows for the interest and principal repayments on the notes.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
21.Financial instruments (continued)
(b)Derivative instruments (continued)
(ii)Cash flow hedges (continued)
The following table summarizes OCI attributable to derivative financial instruments designated as a cash flow hedge:
| Three months ended March 31 | |||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| Effective portion of cash flow hedge | $ | (61,554) | $ | (30,731) | |||||||||||||||||||
| Amortization of cash flow hedge | (164) | (898) | |||||||||||||||||||||
| Amounts reclassified from AOCI | 2,832 | 39,273 | |||||||||||||||||||||
| OCI attributable to shareholders of AQN | $ | (58,886) | $ | 7,644 | |||||||||||||||||||
The Company expects $1,843, $1,555 and $302 of unrealized gains and losses currently in AOCI to be reclassified, net of taxes into non-regulated energy sales, interest expense and derivative gains, respectively, within the next 12 months, as the underlying hedged transactions settle.
(iii)Foreign exchange hedge of net investment in foreign operation
The functional currency of most of AQN's operations is the U.S. dollar. The Company designates obligations denominated in Canadian dollars as a hedge of the foreign currency exposure of its net investment in its Canadian investments and subsidiaries. The related foreign currency transaction gain or loss designated as, and effective as, a hedge of the net investment in a foreign operation is reported in the same manner as the translation adjustment (in OCI) related to the net investment. A foreign currency loss of $175 for the three months ended March 31, 2022 (2021 - loss of $268) was recorded in OCI.
On May 23, 2019, the Company entered into a cross-currency swap, coterminous with the subordinated unsecured notes, to effectively convert the $350,000 U.S.-dollar-denominated offering into Canadian dollars. The change in the carrying amount of the notes due to changes in spot exchange rates is recognized each period in the unaudited interim consolidated statements of operations as loss (gain) on foreign exchange. The Company designated the entire notional amount of the cross-currency fixed-for-fixed interest rate swap as a hedge of the foreign currency exposure related to cash flows for the interest and principal repayments on the notes. Upon the change in functional currency of AQN to the U.S. dollar on January 1, 2020, this hedge was dedesignated. The OCI related to this hedge will be amortized into earnings in the period that future interest payments affect earnings over the remaining life of the original hedge. The Company redesignated this swap as a hedge of AQN's net investment in its Canadian subsidiaries. The related foreign currency transaction gain or loss designated as a hedge of the net investment in a foreign operation is reported in the same manner as the translation adjustment (in OCI) related to the net investment. The fair value of the derivative on the redesignation date will be amortized over the remaining life of the original hedge. A foreign currency loss of $4,232 for the three months ended March 31, 2022 (2021 - $4,014) was recorded in OCI.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
21.Financial instruments (continued)
(b)Derivative instruments (continued)
(iii) Foreign exchange hedge of net investment in foreign operation (continued)
Canadian operations
The Company is exposed to currency fluctuations from its Canadian-based operations. AQN manages this risk primarily through the use of natural hedges by using Canadian long-term debt to finance its Canadian operations and a combination of foreign exchange forward contracts and spot purchases.
The Company’s Canadian operations are determined to have the Canadian dollar as their functional currency and are exposed to currency fluctuations from their U.S. dollar transactions. The Company designates obligations denominated in U.S. dollars as a hedge of the foreign currency exposure of its net investment in its U.S. investments and subsidiaries. The related foreign currency transaction gain or loss designated as, and effective as, a hedge of the net investment in a foreign operation is reported in the same manner as the translation adjustment (in OCI) related to the net investment. A foreign currency loss of $395 for the three months ended March 31, 2022 (2021 - gain of $1,921) was recorded in OCI.
The Company was party to C$500,000 cross-currency swaps to effectively convert Canadian dollar debentures into U.S. dollars. The Company designated the entire notional amount of the cross-currency fixed-for-fixed interest rate swap and related short-term U.S. dollar payables created by the monthly accruals of the swap settlement as a hedge of the foreign currency exposure of its net investment in the Renewable Energy Group's U.S. operations. The gain or loss related to the fair value changes of the swap and the related foreign currency gains and losses on the U.S. dollar accruals that are designated as, and are effective as, a hedge of the net investment in a foreign operation are reported in the same manner as the translation adjustment (in OCI) related to the net investment. A gain of $2,053 for the three months ended March 31, 2022 (2021 - $6,740) was recorded in OCI. On February 15, 2022, the Renewable Energy Group settled the related cross-currency swap related to its C$200,000 debenture that was repaid (note 7(c)).
On April 9, 2021, the Renewable Energy Group entered into a fixed-for-fixed cross-currency interest rate swap, coterminous with the senior unsecured debentures (note 7(b)), to effectively convert the C$400,000 Canadian-dollar-denominated offering into U.S. dollars. The Renewable Energy Group designated the entire notional amount of the fixed-for-fixed cross-currency interest rate swap as a hedge of the foreign currency exposure of its net investment in its U.S. operations. The gain or loss related to the fair value changes of the swap are reported in the same manner as the translation adjustment (in OCI) related to the net investment. A loss of $5,812 for the three months ended March 31, 2022 was recorded in OCI.
Chilean operations
The Company is exposed to currency fluctuations from its Chilean-based operations. The Company's Chilean operations are determined to have the Chilean peso as their functional currency. Chilean long-term debt used to finance the operations is denominated in Chilean Unidad de Fomento.
(iv)Other derivatives
Derivative financial instruments are used to manage certain exposures to fluctuations in exchange rates, interest rates and commodity prices. The Company does not enter into derivative financial agreements for speculative purposes.
For derivatives that are not designated as hedges, the changes in the fair value are immediately recognized in earnings.
| Algonquin Power & Utilities Corp. | ||
| Notes to the Unaudited Interim Consolidated Financial Statements | ||
| March 31, 2022 and 2021 | ||
| (in thousands of U.S. dollars, except as noted and per share amounts) | ||
21.Financial instruments (continued)
(b)Derivative instruments (continued)
(iv)Other derivatives (continued)
The effects on the unaudited interim consolidated statements of operations of derivative financial instruments not designated as hedges consist of the following:
| Three months ended March 31 | |||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| Change in unrealized loss on derivative financial instruments: | |||||||||||||||||||||||
| Energy derivative contracts | $ | (751) | $ | (322) | |||||||||||||||||||
| Total change in unrealized loss on derivative financial instruments | $ | (751) | $ | (322) | |||||||||||||||||||
| Realized gain on derivative financial instruments: | |||||||||||||||||||||||
| Energy derivative contracts | 306 | 163 | |||||||||||||||||||||
| Total realized gain on derivative financial instruments | $ | 306 | $ | 163 | |||||||||||||||||||
| Loss on derivative financial instruments not accounted for as hedges | (445) | (159) | |||||||||||||||||||||
| Amortization of AOCI gains frozen as a result of hedge dedesignation | 696 | 1,248 | |||||||||||||||||||||
| $ | 251 | $ | 1,089 | ||||||||||||||||||||
| Amounts recognized in the consolidated statements of operations consist of: | |||||||||||||||||||||||
| Gain on derivative financial instruments | $ | 251 | $ | 1,089 | |||||||||||||||||||
(c)Risk management
In the normal course of business, the Company is exposed to financial risks that potentially impact its operating results. The Company employs risk management strategies with a view to mitigating these risks to the extent possible on a cost-effective basis. Derivative financial instruments are used to manage certain exposures to fluctuations in exchange rates, interest rates and commodity prices. The Company does not enter into derivative financial agreements for speculative purposes.
This note provides disclosures relating to the nature and extent of the Company’s exposure to risks arising from financial instruments, including credit risk and liquidity risk, and how the Company manages those risks.
22.Comparative figures
Certain of the comparative figures have been reclassified to conform to the unaudited interim consolidated financial statement presentation adopted in the current period.
Management Discussion & Analysis Management of Algonquin Power & Utilities Corp. (“AQN” or the “Company” or the “Corporation”) has prepared the following discussion and analysis to provide information to assist its shareholders’ understanding of the financial results for the three months ended March 31, 2022. This Management Discussion & Analysis (“MD&A”) should be read in conjunction with AQN’s unaudited interim consolidated financial statements for the three months ended March 31, 2022 and 2021. This MD&A should also be read in conjunction with AQN's annual consolidated financial statements for the years ended December 31, 2021 and 2020. This material is available on SEDAR at www.sedar.com, on EDGAR at www.sec.gov/edgar, and on the AQN website at www.AlgonquinPowerandUtilities.com. Additional information about AQN, including the most recent Annual Information Form (“AIF”), can be found on SEDAR at www.sedar.com and on EDGAR at www.sec.gov/edgar.
Unless otherwise indicated, financial information provided for the three months ended March 31, 2022 and 2021 has been prepared in accordance with generally accepted accounting principles in the United States (“U.S. GAAP”). As a result, the Company's financial information may not be comparable with financial information of other Canadian companies that provide financial information on another basis.
All monetary amounts are in U.S. dollars, except where otherwise noted. We denote any amounts denominated in Canadian dollars with "C$" immediately prior to the stated amount.
Capitalized terms used herein and not otherwise defined have the meanings assigned to them in the Company's most recent AIF.
This MD&A is based on information available to management as of May 12, 2022.
Contents
| Caution Concerning Forward-Looking Statements and Forward-Looking Information | |||||
| Caution Concerning Non-GAAP Measures | |||||
| Overview and Business Strategy | |||||
| Significant Updates | |||||
| 2022 First Quarter Results From Operations | |||||
| 2022 First Quarter Net Earnings Summary | |||||
| 2022 First Quarter Adjusted EBITDA Summary | |||||
| Regulated Services Group | |||||
| Renewable Energy Group | |||||
| AQN: Corporate and Other Expenses | |||||
| Non-GAAP Financial Measures | |||||
| Corporate Development Activities | |||||
| Summary of Property, Plant and Equipment Expenditures | |||||
| Liquidity and Capital Reserves | |||||
| Share-Based Compensation Plans | |||||
| Related Party Transactions | |||||
| Enterprise Risk Management | |||||
| Quarterly Financial Information | |||||
| Disclosure Controls and Procedures | |||||
| Critical Accounting Estimates and Policies | |||||
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 1 | ||||
Caution Concerning Forward-Looking Statements and Forward-Looking Information
This document may contain statements that constitute "forward-looking information" within the meaning of applicable securities laws in each of the provinces and territories of Canada and the respective policies, regulations and rules under such laws and/or "forward-looking statements" within the meaning of the U.S. Private Securities Litigation Reform Act of 1995 (collectively, “forward-looking information”). The words “anticipates”, “believes”, “budget”, “could”, “estimates”, “expects”, “forecasts”, “intends”, “may”, “might”, “plans”, “projects”, “schedule”, “should”, “will”, “would” and similar expressions are often intended to identify forward-looking information, although not all forward-looking information contains these identifying words. Specific forward-looking information in this document includes, but is not limited to, statements relating to: expected future growth, earnings and results of operations; liquidity, capital resources and operational requirements; sources of funding, including adequacy and availability of credit facilities, debt maturation and future borrowings; expectations regarding the impact of the 2019 novel coronavirus (“COVID-19”) on the Company; expectations regarding the use of proceeds from financings; ongoing and planned acquisitions, projects and initiatives, including expectations regarding costs, results, in-service dates and completion dates; expectations regarding the anticipated closing of the Kentucky Power Transaction (as defined herein); expectations regarding the purchase price for the Kentucky Power Transaction; the anticipated benefits of the Kentucky Power Transaction, including the impact of the Kentucky Power Transaction on the Corporation’s business, operations, financial condition, and results of operations; expectations regarding the Corporation’s and Kentucky Power’s (as defined herein) rate base; expectations regarding cost recovery of amounts incurred by Empire in connection with the Midwest Extreme Weather Event (as defined herein) and retirement of the Asbury coal plant; expectations regarding the Company's corporate development activities and the results thereof, including the expected business mix between the Regulated Services Group and Renewable Energy Group; expectations regarding regulatory hearings, motions, filings, appeals and approvals, including rate reviews, and the impacts and outcomes thereof; expected future generation, capacity and production of the Company’s energy facilities; expected future capital investments, including expected timing, investment plans, sources of funds and impacts; expectations regarding future "greening the fleet" initiatives, including with respect to Kentucky Power; expectations regarding the outcome of legal claims and disputes; strategy and goals; dividends to shareholders; expectations regarding the impact of proposed tax reforms and rules; credit ratings and equity credit from rating agencies; anticipated customer benefits; the future impact on the Company of actual or proposed laws, regulations and rules; accounting estimates; interest rates and currency exchange rates. All forward-looking information is given pursuant to the “safe harbor” provisions of applicable securities legislation.
The forecasts and projections that make up the forward-looking information contained herein are based on certain factors or assumptions which include, but are not limited to: the receipt of applicable regulatory approvals and requested rate decisions; the absence of a material increase in the costs of compliance with environmental laws following the completion of the Kentucky Power Transaction; the absence of material adverse regulatory decisions being received and the expectation of regulatory stability; the absence of any material equipment breakdown or failure; availability of financing (including tax equity financing and self-monetization transactions for U.S. federal tax credits) on commercially reasonable terms and the stability of credit ratings of the Corporation and its subsidiaries; the absence of unexpected material liabilities or uninsured losses; the continued availability of commodity supplies and stability of commodity prices; the absence of sustained interest rate increases or significant currency exchange rate fluctuations; the absence of significant operational, financial or supply chain disruptions or liability; including relating to import controls and tariffs; the continued ability to maintain systems and facilities to ensure their continued performance; the absence of a severe and prolonged downturn in general economic, credit, social or market conditions; the successful and timely development and construction of new projects; the closing of pending acquisitions substantially in accordance with the expected timing for such acquisitions; the absence of capital project or financing cost overruns; sufficient liquidity and capital resources; the continuation of long term weather patterns and trends; the absence of significant counterparty defaults; the continued competitiveness of electricity pricing when compared with alternative sources of energy; the realization of the anticipated benefits of the Corporation’s acquisitions and joint ventures; the absence of a change in applicable laws, political conditions, public policies and directions by governments, materially negatively affecting the Corporation; the ability to obtain and maintain licenses and permits; maintenance of adequate insurance coverage; the absence of material fluctuations in market energy prices; the absence of material disputes with taxation authorities or changes to applicable tax laws; continued maintenance of information technology infrastructure and the absence of a material breach of cybersecurity; favourable relations with external stakeholders; favourable labour relations; the realization of the anticipated benefits of the Kentucky Power Transaction, including that it will be accretive to the Corporation’s Adjusted Net Earnings per common share; that the Corporation will be able to successfully integrate newly acquired entities, and the absence of any material adverse changes to such entities prior to closing; the successful transfer of operational control over the Mitchell Plant to Wheeling Power Company; the transfer of the Mitchell Plant being implemented in accordance with the Corporation’s expectations; the absence of undisclosed liabilities of entities being acquired; that such entities will maintain constructive regulatory relationships with state regulatory authorities; the ability of the Corporation to retain key personnel of acquired entities and the value of such employees; no adverse developments in the business and affairs of the sellers during the period when transitional services are provided to the Corporation in connection with any acquisition; the ability of the Corporation to satisfy its liabilities and meet its debt service obligations following completion of any acquisition; the
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 2 | ||||
absence of any reputational harm to the Corporation as a result of any acquisition; and the ability of the Corporation to successfully execute future “greening the fleet” initiatives. Given the continued uncertainty and evolving circumstances surrounding the COVID-19 pandemic and related response from governments, regulatory authorities, businesses, suppliers and customers, there is more uncertainty associated with the Corporation’s assumptions and expectations as compared to periods prior to the onset of COVID-19.
The forward-looking information contained herein 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 which could cause results or events to differ materially from current expectations include, but are not limited to: changes in general economic, credit, social or market conditions; changes in customer energy usage patterns and energy demand; global climate change; the incurrence of environmental liabilities; natural disasters, diseases, pandemics and other force majeure events; critical equipment breakdown or failure; supply chain disruptions; the imposition of import controls or tariffs; the failure of information technology infrastructure and cybersecurity; physical security breach; the loss of key personnel and/or labour disruptions; seasonal fluctuations and variability in weather conditions and natural resource availability; reductions in demand for electricity, gas and water due to developments in technology; reliance on transmission systems owned and operated by third parties; issues arising with respect to land use rights and access to the Corporation’s facilities; terrorist attacks; fluctuations in commodity prices; capital expenditures; reliance on subsidiaries; the incurrence of an uninsured loss; a credit rating downgrade; an increase in financing costs or limits on access to credit and capital markets; increases in interest rates; currency exchange rate fluctuations; restricted financial flexibility due to covenants in existing credit agreements; an inability to refinance maturing debt on commercially reasonable terms; disputes with taxation authorities or changes to applicable tax laws; failure to identify, acquire, develop or timely place in service projects to maximize the value of tax credits; requirement for greater than expected contributions to post-employment benefit plans; default by a counterparty; inaccurate assumptions, judgments and/or estimates with respect to asset retirement obligations; failure to maintain required regulatory authorizations; changes in, or failure to comply with, applicable laws and regulations; failure of compliance programs; failure to identify attractive acquisition or development candidates necessary to pursue the Corporation’s growth strategy; failure to dispose of assets (at all or at a competitive price) to fund the Company’s operations and growth plans; delays and cost overruns in the design and construction of projects, including as a result of COVID-19; loss of key customers; failure to complete or realize the anticipated benefits of acquisitions or joint ventures; Atlantica (as defined herein) or a third party joint venture partner acting in a manner contrary to the Corporation’s interests; a drop in the market value of Atlantica's ordinary shares; facilities being condemned or otherwise taken by governmental entities; increased external-stakeholder activism adverse to the Corporation’s interests; fluctuations in the price and liquidity of the Corporation’s common shares and the Corporation's other securities; the severity and duration of the COVID-19 pandemic and its collateral consequences, including the disruption of economic activity, volatility in capital and credit markets and legislative and regulatory responses; impact of significant demands placed on the Corporation as a result of pending acquisitions or growth strategies; potential undisclosed liabilities of any entities being acquired by the Corporation; uncertainty regarding the length of time required to complete pending acquisitions; the failure to implement the Corporation’s strategic objectives or achieve expected benefits relating to acquisitions; Kentucky Power’s failure to receive regulatory approval for the construction of new renewable generation facilities; indebtedness of any entity being acquired by the Corporation; reputational harm and increased costs of compliance with environmental laws as a result of announced or completed acquisitions; unanticipated expenses and/or cash payments as a result of change of control and/or termination for convenience provisions in agreements to which any entity being acquired is a party; and the reliance on third parties for certain transitional services following the completion of an acquisition. Although the Corporation has attempted to identify important factors that could cause actual actions, events or results to differ materially from those described in forward-looking information, there may be other factors that cause actions, events or results not to be as anticipated, estimated or intended. Some of these and other factors are discussed in more detail under the heading Enterprise Risk Management in this MD&A and under the heading Enterprise Risk Factors, in the Corporation’s MD&A for the three and twelve months ended December 31, 2021 (the “Annual MD&A”) and in the Corporation's most recent AIF.
Forward-looking information contained herein is provided for the purposes of assisting the reader in understanding the Corporation and its business, operations, risks, financial performance, financial position and cash flows as at and for the periods indicated and to present information about management’s current expectations and plans relating to the future and the reader is cautioned that such information may not be appropriate for other purposes. Forward-looking information contained herein is made as of the date of this document and based on the plans, beliefs, estimates, projections, expectations, opinions and assumptions of management on the date hereof. There can be no assurance that forward-looking information will prove to be accurate, as actual results and future events could differ materially from those anticipated in such forward-looking information. Accordingly, readers should not place undue reliance on forward-looking information. While subsequent events and developments may cause the Corporation’s views to change, the Corporation disclaims any obligation to update any forward-looking information or to explain any material difference between subsequent actual events and such forward-looking information, except to the extent required by applicable law. All forward-looking information contained herein is qualified by these cautionary statements.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | |||||
Caution Concerning Non-GAAP Measures
AQN uses a number of financial measures to assess the performance of its business lines. Some measures are calculated in accordance with U.S. GAAP, while other measures do not have a standardized meaning under U.S. GAAP. These non-GAAP measures include non-GAAP financial measures and non-GAAP ratios, each as defined in Canadian National Instrument 52-112 Non-GAAP and Other Financial Measures Disclosure. AQN’s method of calculating these measures may differ from methods used by other companies and therefore may not be comparable to similar measures presented by other companies.
The terms “Adjusted Net Earnings”, “Adjusted Earnings Before Interest, Taxes, Depreciation and Amortization” (“Adjusted EBITDA”), “Adjusted Funds from Operations”, "Net Energy Sales", "Net Utility Sales" and "Divisional Operating Profit", which are used throughout this MD&A, are non-GAAP financial measures. An explanation of each of these non-GAAP financial measures is set out below and a reconciliation to the most directly comparable U.S. GAAP measure, in each case, can be found in this MD&A. In addition, “Adjusted Net Earnings” is presented throughout this MD&A on a per share basis. Adjusted Net Earnings per common share is a non-GAAP ratio and is calculated by dividing Adjusted Net Earnings by the weighted average number of common shares outstanding during the applicable period.
Adjusted EBITDA
Adjusted EBITDA is a non-GAAP financial measure used by many investors to compare companies on the basis of ability to generate cash from operations. AQN uses these calculations to monitor the amount of cash generated by AQN. AQN uses Adjusted EBITDA to assess the operating performance of AQN without the effects of (as applicable): depreciation and amortization expense, income tax expense or recoveries, acquisition costs, certain litigation expenses, interest expense, gain or loss on derivative financial instruments, write down of intangibles and property, plant and equipment, earnings attributable to non-controlling interests, non-service pension and post-employment costs, cost related to tax equity financing, costs related to management succession and executive retirement, costs related to prior period adjustments due to changes in tax law, costs related to condemnation proceedings, financial impacts on the Company's Senate Wind Facility from the significantly elevated pricing that persisted in the Electric Reliability Council of Texas market over several days (the "Market Disruption Event") as a result of the February 2021 extreme winter storm conditions experienced in Texas and parts of the central U.S. (the “Midwest Extreme Weather Event”), gain or loss on foreign exchange, earnings or loss from discontinued operations, changes in value of investments carried at fair value, and other typically non-recurring or unusual items. AQN adjusts for these factors as they may be non-cash, unusual in nature and are not factors used by management for evaluating the operating performance of the Company. AQN believes that presentation of this measure will enhance an investor’s understanding of AQN’s operating performance. Adjusted EBITDA is not intended to be representative of cash provided by operating activities or results of operations determined in accordance with U.S. GAAP, and can be impacted positively or negatively by these items. For a reconciliation of Adjusted EBITDA to net earnings, see Non-GAAP Financial Measures starting on page 30 of this MD&A.
Adjusted Net Earnings
Adjusted Net Earnings is a non-GAAP financial measure used by many investors to compare net earnings from operations without the effects of certain volatile primarily non-cash items that generally have no current economic impact or items such as acquisition expenses or certain litigation expenses that are viewed as not directly related to a company’s operating performance. AQN uses Adjusted Net Earnings to assess its performance without the effects of (as applicable): gains or losses on foreign exchange, foreign exchange forward contracts, interest rate swaps, acquisition costs, one-time costs of arranging tax equity financing, certain litigation expenses and write down of intangibles and property, plant and equipment, earnings or loss from discontinued operations (excluding sale of assets in the course of normal operations), unrealized mark-to-market revaluation impacts (other than those realized in connection with the sales of development assets), costs related to management succession and executive retirement, costs related to prior period adjustments due to changes in tax law, costs related to condemnation proceedings, financial impacts from the Market Disruption Event on the Company's Senate Wind Facility, changes in value of investments carried at fair value, and other typically non-recurring or unusual items as these are not reflective of the performance of the underlying business of AQN. AQN believes that analysis and presentation of net earnings or loss on this basis will enhance an investor’s understanding of the operating performance of its businesses. Adjusted Net Earnings is not intended to be representative of net earnings or loss determined in accordance with U.S. GAAP, and can be impacted positively or negatively by these items. For a reconciliation of Adjusted Net Earnings to net earnings, see Non-GAAP Financial Measures starting on page 31 of this MD&A.
Adjusted Funds from Operations
Adjusted Funds from Operations is a non-GAAP financial measure used by investors to compare cash provided by operating activities without the effects of certain volatile items that generally have no current economic impact or items such as acquisition expenses that are viewed as not directly related to a company’s operating performance. AQN uses Adjusted Funds from Operations to assess its performance without the effects of (as applicable): changes in working capital balances, acquisition costs, certain litigation expenses, cash provided by or used in discontinued operations, financial impacts from the Market Disruption Event on the Company's Senate Wind Facility, and other typically non-recurring items
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 4 | ||||
affecting cash from operations as these are not reflective of the long-term performance of the underlying businesses of AQN. AQN believes that analysis and presentation of funds from operations on this basis will enhance an investor’s understanding of the operating performance of its businesses. Adjusted Funds from Operations is not intended to be representative of cash provided by operating activities as determined in accordance with U.S. GAAP, and can be impacted positively or negatively by these items. For a reconciliation of Adjusted Funds from Operations to cash provided by operating activities, see Non-GAAP Financial Measures starting on page 32 of this MD&A.
Net Energy Sales
Net Energy Sales is a non-GAAP financial measure used by investors to identify revenue after commodity costs used to generate revenue where such revenue generally increases or decreases in response to increases or decreases in the cost of the commodity used to produce that revenue. AQN uses Net Energy Sales to assess its revenues without the effects of fluctuating commodity costs as such costs are predominantly passed through either directly or indirectly in the rates that are charged to customers. AQN believes that analysis and presentation of Net Energy Sales on this basis will enhance an investor’s understanding of the revenue generation of the Renewable Energy Group. It is not intended to be representative of revenue as determined in accordance with U.S. GAAP. For a reconciliation of Net Energy Sales to revenue, see Renewable Energy Group - 2022 First Quarter Renewable Energy Group Operating Results on page 26 of this MD&A.
Net Utility Sales
Net Utility Sales is a non-GAAP financial measure used by investors to identify utility revenue after commodity costs, either natural gas or electricity, where these commodity costs are generally included as a pass through in rates to its utility customers. AQN uses Net Utility Sales to assess its utility revenues without the effects of fluctuating commodity costs as such costs are predominantly passed through and paid for by utility customers. AQN believes that analysis and presentation of Net Utility Sales on this basis will enhance an investor’s understanding of the revenue generation of the Regulated Services Group. It is not intended to be representative of revenue as determined in accordance with U.S. GAAP. For a reconciliation of Net Utility Sales to revenue, see Regulated Services Group - 2022 First Quarter Regulated Services Group Operating Results on page 18 of this MD&A.
Divisional Operating Profit
Divisional Operating Profit is a non-GAAP financial measure. AQN uses Divisional Operating Profit to assess the operating performance of its business groups without the effects of (as applicable): depreciation and amortization expense, corporate administrative expenses, income tax expense or recoveries, acquisition costs, certain litigation expenses, interest expense, gain or loss on derivative financial instruments, write down of intangibles and property, plant and equipment, gain or loss on foreign exchange, earnings or loss from discontinued operations (excluding the sale of assets in the course of normal operations), non-service pension and post-employment costs, financial impacts from the Market Disruption Event on the Company's Senate Wind Facility, and other typically non-recurring or unusual items. AQN adjusts for these factors as they may be non-cash, unusual in nature and are not factors used by management for evaluating the operating performance of the divisional units. Divisional Operating Profit is calculated inclusive of interest, dividend and equity income earned from indirect investments, and Hypothetical Liquidation at Book Value (“HLBV”) income, which represents the value of net tax attributes earned in the period from electricity generated by certain of its U.S. wind power and U.S. solar generation facilities. AQN believes that presentation of this measure will enhance an investor’s understanding of AQN’s divisional operating performance. Divisional Operating Profit is not intended to be representative of cash provided by operating activities or results of operations determined in accordance with U.S. GAAP, and can be impacted positively or negatively by these items. For a reconciliation of Divisional Operating Profit to revenue for AQN's main business units, see Regulated Services Group - 2022 First Quarter Regulated Services Group Operating Results on page 18 and Renewable Energy Group - 2022 First Quarter Renewable Energy Group Operating Results on page 26 of this MD&A.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | |||||
Overview and Business Strategy
AQN is incorporated under the Canada Business Corporations Act. AQN owns and operates a diversified portfolio of regulated and non-regulated generation, distribution, and transmission utility assets which are expected to deliver predictable earnings and cash flows. AQN seeks to maximize total shareholder value through real per share growth in earnings and cash flows to support a growing dividend and share price appreciation. AQN strives to achieve these results while also seeking to maintain a business risk profile consistent with its BBB flat investment grade credit ratings and a strong focus on Environmental, Social and Governance factors.
AQN’s current quarterly dividend to shareholders is $0.1808 per common share or $0.7233 per common share per annum. Based on the Bank of Canada exchange rate on May 11, 2022, the quarterly dividend is equivalent to C$0.2345 per common share or C$0.9380 per common share per annum. AQN believes its annual dividend payout allows for both an immediate return on investment for shareholders and retention of sufficient cash within AQN to fund growth opportunities. Changes in the level of dividends paid by AQN are at the discretion of AQN’s Board of Directors (the “Board”), with dividend levels being reviewed periodically by the Board in the context of AQN’s financial performance and growth prospects.
AQN’s operations are organized across two primary business units consisting of: the Regulated Services Group, which primarily owns and operates a portfolio of regulated assets in the United States, Canada, Bermuda and Chile, and the Renewable Energy Group, which primarily operates a diversified portfolio of owned renewable generation assets.
AQN pursues investment opportunities with an objective of maintaining the current business mix between its Regulated Services Group and Renewable Energy Group and with leverage consistent with its current credit ratings1. The business mix target may from time to time require AQN to grow its Regulated Services Group or implement other strategies in order to pursue investment opportunities within its Renewable Energy Group.
The Company also undertakes development activities for both business units, working with a global reach to identify, develop, acquire, or invest in renewable power generating facilities, regulated utilities and other complementary infrastructure projects. See additional discussion in Corporate Development Activities.
Summary Structure of the Business
The following chart depicts, in summary form, AQN’s key businesses. A more detailed description of AQN’s organizational structure can be found in the most recent AIF.
1 See Treasury Risk Management -Downgrade in the Company's Credit Rating Risk in the Annual MD&A.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 6 | ||||
Regulated Services Group
The Regulated Services Group operates a diversified portfolio of regulated utility systems throughout the United States, Canada, Bermuda and Chile serving approximately 1,232,000 customer connections as at March 31, 2022 (using an average of 2.5 customers per connection, this translates into approximately 3,080,000 customers). The Regulated Services Group seeks to provide safe, high quality, and reliable services to its customers and to deliver stable and predictable earnings to AQN. In addition to encouraging and supporting organic growth within its service territories, the Regulated Services Group seeks to deliver growth through accretive acquisitions of additional utility systems.
The Regulated Services Group's regulated electrical distribution utility systems and related generation assets are located in the U.S. States of California, New Hampshire, Missouri, Kansas, Oklahoma, and Arkansas, as well as in Bermuda, which together served approximately 307,000 electric customer connections as at March 31, 2022. The group also owns and operates generating assets with a gross capacity of approximately 2.0 GW and has investments in generating assets with approximately 0.3 GW of net generation capacity.
The Regulated Services Group's regulated natural gas distribution utility systems are located in the U.S. States of Georgia, Illinois, Iowa, Massachusetts, New Hampshire, Missouri, and New York, and in the Canadian Province of New Brunswick, which together served approximately 374,000 natural gas customer connections as at March 31, 2022.
The Regulated Services Group's regulated water distribution and wastewater collection utility systems are located in the U.S. States of Arizona, Arkansas, California, Illinois, Missouri, New York, and Texas as well as in Chile which together served approximately 551,000 customer connections as at March 31, 2022, including the approximately 127,000 customer connections in the state of New York that were added effective January 1, 2022 with the acquisition of New York American Water Company, Inc. (subsequently renamed Liberty Utilities (New York Water) Corp. (“Liberty NY Water”)).
Below is a breakdown of the Regulated Services Group’s Revenue by geographic area for the three months ended March 31, 2022.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | |||||
Renewable Energy Group
The Renewable Energy Group generates and sells electrical energy produced by its diverse portfolio of renewable power generation and clean power generation facilities primarily located across the United States and Canada. The Renewable Energy Group seeks to deliver growth through the development of new power generation projects and accretive acquisitions of additional power generation facilities, as well as the acquisition and development of other complementary projects, such as renewable natural gas and energy storage.
The Renewable Energy Group directly owns and operates hydroelectric, wind, solar, and thermal facilities with a combined gross generating capacity of approximately 2.5 GW. Approximately 82% of the electrical output is sold pursuant to long term contractual arrangements which as of March 31, 2022 had a production-weighted average remaining contract life of approximately 12 years.
In addition to directly owned and operated assets, the Renewable Energy Group has investments in generating assets with approximately 1.4 GW of net generating capacity which includes the Company’s approximately 43% interest in Atlantica Sustainable Infrastructure plc (“Atlantica”). Atlantica owns and operates a portfolio of international clean energy and water infrastructure assets under long term contracts with a Cash Available for Distribution (CAFD) weighted average remaining contract life of approximately 15 years as of March 31, 2022.
Below is a breakdown of the Renewable Energy Group’s generating capacity by geographic area as of March 31, 2022, which was comprised of gross generating capacity of facilities owned and operated and net generating capacity of investments including the Company’s approximately 43% interest in Atlantica.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | |||||
Significant Updates
Operating Results
AQN operating results relative to the same period last year are as follows:
| (all dollar amounts in $ millions except per share information) | Three months ended March 31 | ||||||||||||||||||||||||||||||||||||||||||||||||||||
| 2022 | 2021 | Change | |||||||||||||||||||||||||||||||||||||||||||||||||||
| Net earnings attributable to shareholders | $91.0 | $13.9 | 555% | ||||||||||||||||||||||||||||||||||||||||||||||||||
Adjusted Net Earnings1 | $141.3 | $124.5 | 13% | ||||||||||||||||||||||||||||||||||||||||||||||||||
Adjusted EBITDA1 | $330.6 | $282.9 | 17% | ||||||||||||||||||||||||||||||||||||||||||||||||||
| Net earnings per common share | $0.13 | $0.02 | 550% | ||||||||||||||||||||||||||||||||||||||||||||||||||
Adjusted Net Earnings per common share1 | $0.21 | $0.20 | 5% | ||||||||||||||||||||||||||||||||||||||||||||||||||
| 1 | See Caution Concerning Non-GAAP Measures. | ||||
Annual Dividend increased from $0.6824 to $0.7233 per Common Share and declaration of 2022 Second Quarter Dividend of $0.1808 (C$0.2345) per Common Share
AQN currently targets annual growth in dividends payable to shareholders underpinned by increases in earnings and cash flow. In setting the appropriate dividend level, the Board considers the Company’s current and expected growth in earnings per share as well as a dividend payout ratio as a percentage of earnings per share and cash flow per share.
On May 12, 2022, AQN announced that the Board approved an increase in the common share dividend to $0.1808 per quarter and $0.7233 annually and declared a second quarter 2022 dividend of $0.1808 per common share payable on July 14, 2022 to shareholders of record on June 30, 2022.
Based on the Bank of Canada exchange rate on May 11, 2022, the Canadian dollar equivalent for the second quarter 2022 dividend is C$0.2345 per common share.
The previous four quarter U.S and Canadian dollar equivalent dividends per common share have been as follows:
| Q3 2021 | Q4 2021 | Q1 2022 | Q2 2022 | Total | |||||||||||||
| U.S. dollar dividend | $ | 0.1706 | $ | 0.1706 | $ | 0.1706 | $ | 0.1808 | $0.6926 | ||||||||
| Canadian dollar equivalent | $ | 0.2134 | $ | 0.2124 | $ | 0.2161 | $ | 0.2345 | $0.8764 | ||||||||
Pending Acquisition of Kentucky Power Company and AEP Kentucky Transmission Company, Inc.
On October 26, 2021, Liberty Utilities Co. (“Liberty Utilities”), an indirect subsidiary of AQN, entered into an agreement with American Electric Power Company, Inc. and AEP Transmission Company, LLC to acquire Kentucky Power Company (“Kentucky Power”) and AEP Kentucky Transmission Company, Inc. (“Kentucky TransCo”) for a total purchase price of approximately $2.846 billion, including the assumption of approximately $1.221 billion in debt (the “Kentucky Power Transaction”).
Kentucky Power is a state rate-regulated electricity generation, distribution and transmission utility serving approximately 228,000 active customer connections in 20 eastern Kentucky counties and operating under a cost of service framework. Kentucky TransCo is an electricity transmission business operating in the Kentucky portion of the transmission infrastructure that is part of the Pennsylvania – New Jersey – Maryland regional transmission organization, PJM Interconnection, L.L.C.. Kentucky Power and Kentucky TransCo are both regulated by the U.S. Federal Energy Regulatory Commission (“FERC”).
Closing of the Kentucky Power Transaction is subject to receipt of certain regulatory and governmental approvals. During the first quarter of 2022, the applicable waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976 expired and the Committee on Foreign Investment in the United States cleared the Kentucky Power Transaction. On May 4, 2022 the Kentucky Public Service Commission (“KPSC”) issued an order approving the Kentucky Power Transaction, subject to certain conditions set forth in the order, including those agreed to by Liberty Utilities in the course of the docket.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 9 | ||||
The Kentucky Power Transaction is expected to close in mid-2022 subject to the satisfaction of certain conditions precedent, which include the approval of FERC for the Kentucky Power Transaction and certain approvals from FERC, the KPSC and the Public Service Commission of West Virginia with respect to the termination and replacement of the existing operating agreement for the Mitchell coal generating facility (in which Kentucky Power owns a 50% interest, representing 780 MW) (the “Mitchell Plant”).
The Kentucky Power Transaction is expected to add over $2.0 billion of regulated rate base assets in a favourable regulatory jurisdiction. AQN expects the Kentucky Power Transaction to be accretive to Adjusted Net Earnings per common share in the first full year of ownership, generate mid-single digit percentage Adjusted Net Earnings per common share accretion thereafter, and support growth in AQN’s Adjusted Net Earnings per common share over the long term (see Caution Concerning Non-GAAP Measures).
Acquisition of Liberty NY Water (formerly New York American Water Company, Inc.)
Effective January 1, 2022, Liberty Utilities (Eastern Water Holdings) Corp., a wholly-owned subsidiary of Liberty Utilities, closed the previously-announced acquisition of Liberty NY Water from American Water Works Company, Inc. ("American Water") for a purchase price of approximately $609 million.
Headquartered in Merrick, NY, Liberty NY Water is a regulated water and wastewater utility serving over 127,000 customer connections across seven counties in southeastern New York. Liberty NY Water’s operations include approximately 1,270 miles of water mains and distribution lines, with 98% of customers located in Nassau County on Long Island.
Integration of Liberty NY Water is proceeding well. The Company has incorporated the operations into its East Region. Transitioning employees remain engaged and continue to deliver safe and reliable water service to the Liberty NY Water's customers in New York. The Company also has a transition services agreement with American Water to facilitate an effective migration of operating technology.
Issuance of approximately $1.1 Billion of Subordinated Notes
On January 18, 2022, the Company closed (i) an underwritten public offering in the United States (the “U.S. Note Offering”) of $750 million aggregate principal amount of 4.75% fixed-to-fixed reset rate junior subordinated notes series 2022-B due January 18, 2082 (the “U.S. Notes”); and (ii) an underwritten public offering in Canada (the “Canadian Note Offering” and, together with the U.S. Note Offering, the “Note Offerings”) of C$400 million aggregate principal amount of 5.25% fixed-to-fixed reset rate junior subordinated notes series 2022-A due January 18, 2082 (the “Canadian Notes” and, together with the U.S. Notes, the “Notes”). The Company intends to use the net proceeds of the Note Offerings to partially finance the Kentucky Power Transaction provided that in the short-term, prior to closing of the Kentucky Power Transaction, the Company has used such net proceeds to repay certain indebtedness of the Corporation and its subsidiaries. Concurrent with the pricing of the Note Offerings, the Company entered into a cross currency interest rate swap, to convert the Canadian dollar denominated proceeds from the Canadian Note Offering into U.S. dollars and a forward starting swap to fix the interest rate for the second five year term of the U.S. Notes, resulting in an anticipated effective interest rate to the Company of approximately 4.95% throughout the first ten year period of the Notes.
Empire Missouri Rate Case
On May 28, 2021, The Empire District Electric Company ("Empire") filed a rate review based on a 12 month historical test year ending September 30, 2020, with an update period through June 30, 2021, requesting an increase in rates of $79.9 million which included $29.9 million related to recovery of fuel and power pass-through costs related to last year's Midwest Extreme Weather Event. Empire subsequently amended the rate request to $50.0 million after deferring the recovery of the extraordinary fuel pass-through costs as well as certain costs related to the retirement of the Asbury coal plant to a subsequent docket requesting securitization. On April 6, 2022, the Missouri Public Service Commission (“MPSC”) issued its final Report and Order resulting in an annual base rate revenue increase of $39.5 million.
Completion of the Blue Hill Wind Project
On April 14, 2022, the Renewable Energy Group achieved full commercial operations (“COD”) at its 175 MW Blue Hill Wind Facility, located in southwest Saskatchewan. The Blue Hill Facility is the Renewable Energy Group's 15th wind powered electric generating facility and is expected to generate approximately 683 GW-hrs of energy per year with the output being sold through a long-term power purchase agreement (“PPA”) with an investment grade rated entity.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | |||||
2022 First Quarter Results From Operations
Key Financial Information | Three months ended March 31 | ||||||||||
| (all dollar amounts in $ millions except per share information) | 2022 | 2021 | |||||||||
| Revenue | $ | 735.7 | $ | 634.5 | |||||||
| Net earnings attributable to shareholders | 91.0 | 13.9 | |||||||||
| Cash provided by operating activities | 166.2 | (243.5) | |||||||||
Adjusted Net Earnings1 | 141.3 | 124.5 | |||||||||
Adjusted EBITDA1 | 330.6 | 282.9 | |||||||||
Adjusted Funds from Operations1 | 220.2 | 205.3 | |||||||||
| Dividends declared to common shareholders | 115.6 | 94.6 | |||||||||
| Weighted average number of common shares outstanding | 673,742,425 | 599,659,587 | |||||||||
| Per share | |||||||||||
| Basic net earnings | $ | 0.13 | $ | 0.02 | |||||||
| Diluted net earnings | $ | 0.13 | $ | 0.02 | |||||||
Adjusted Net Earnings1 | $ | 0.21 | $ | 0.20 | |||||||
| Dividends declared to common shareholders | $ | 0.17 | $ | 0.16 | |||||||
| 1 | See Caution Concerning Non-GAAP Measures. | ||||
For the three months ended March 31, 2022, AQN experienced an average exchange rate of Canadian to U.S. dollars of approximately 0.7897 as compared to 0.7895 in the same period in 2021, and an average exchange rate of Chilean pesos to U.S. dollars of approximately 0.0012 for the three months ended March 31, 2022 as compared to 0.0014 for the same period in 2021. As such, any quarter over quarter variance in revenue or expenses, in local currency, at any of AQN’s Canadian and Chilean entities is affected by a change in the average exchange rate upon conversion to AQN’s reporting currency.
For the three months ended March 31, 2022, AQN reported total revenue of $735.7 million as compared to $634.5 million during the same period in 2021, an increase of $101.2 million or 15.9%. The major factors impacting AQN’s revenue in the three months ended March 31, 2022 as compared to the same period in 2021 are set out as follows:
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 11 | ||||
| (all dollar amounts in $ millions) | Three months ended March 31 | ||||
| Comparative Prior Period Revenue | $ | 634.5 | |||
| REGULATED SERVICES GROUP | |||||
| Existing Facilities | |||||
| Electricity: Decrease is primarily due to the absence of consumption and pass through commodity costs at the Empire Electric System that resulted from the Midwest Extreme Weather Event in the first quarter of 2021. This was partially offset by higher pass through costs at the Granite State and Bermuda Electric Systems. | (59.6) | ||||
Gas: Increase is primarily due to higher pass through commodity costs. | 61.8 | ||||
| Water: Increase is primarily due to the addition of the Beardsley Water System and organic growth at the Litchfield Park Water System. | 1.1 | ||||
| Other: Decrease is primarily due to a reduction in projects at Ft. Benning. | (0.2) | ||||
| 3.1 | |||||
| New Facilities | |||||
Electricity: Acquisition of the Empire Wind Facilities (2021). | 8.6 | ||||
Water: Acquisition of Liberty NY Water (January 2022). | 22.5 | ||||
| 31.1 | |||||
| Rate Reviews | |||||
| Electricity: Increase is primarily due to implementation of new rates at the Granite State and Bermuda Electric Systems. | 1.6 | ||||
| Gas: Increase is primarily due to implementation of new rates at the EnergyNorth and Peach State Gas Systems. | 3.2 | ||||
| Water: Increase is due to implementation of new rates at the ESSAL, Park Water and Apple Valley Water Systems. | 2.7 | ||||
| 7.5 | |||||
| Foreign Exchange | (2.6) | ||||
| RENEWABLE ENERGY GROUP | |||||
| Existing Facilities | |||||
| Hydro: Decrease is primarily due to lower production primarily in the Ontario Region. | (0.1) | ||||
| Wind Canada: Increase is primarily due to higher production at the St. Leon, Morse and Amherst Wind Facilities. | 3.0 | ||||
| Wind U.S.: Increase is primarily due to the non-recurring impacts of the Market Disruption Event at the Senate Wind Facility in 2021, higher production across the Company's U.S. wind portfolio as well as higher renewable energy certificate ("REC") revenue from Minonk Wind Facility, driven by higher pricing. This increase is partially offset by unfavourable pricing at Senate Wind Facility. | 54.5 | ||||
| Solar: Increase is primarily due to higher REC revenue for the Great Bay I & II Solar Facilities driven by the sales of RECs in inventory. | 2.1 | ||||
| Thermal: Increase is primarily due to higher production at the Sanger Thermal Facility as well as favourable pricing and higher production at the Windsor Locks Thermal Facility. | 3.9 | ||||
| Other: Decrease is primarily due to non-recurring Operational Management Agreement fees received in the first quarter of 2021 prior to the Company's acquisition of the remaining 50% interest in the Maverick Creek Wind Facility. | (0.5) | ||||
| 62.9 | |||||
| New Facilities | |||||
| Wind U.S.: Decrease is driven by unfavourable pricing, partially offset by higher production at the Maverick Creek Wind Facility. This facility achieved partial completion on November 6, 2020 and COD on April 21, 2021. | (4.2) | ||||
| Solar: Altavista Solar Facility (full COD in June 2021) and Croton Solar Facility (full COD in December 2021). | 1.5 | ||||
| Other: Increase is due to Congestion Revenue Rights ("CRRs") revenue at the Texas Coastal Wind Facilities. | 2.0 | ||||
| (0.7) | |||||
| Foreign Exchange | (0.1) | ||||
| Current Period Revenue | $ | 735.7 | |||
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | |||||
2022 First Quarter Net Earnings Summary
Net earnings attributable to shareholders for the three months ended March 31, 2022 totaled $91.0 million as compared to $13.9 million during the same period in 2021, an increase of $77.1 million or 554.7%. A summary of changes is shown below.
| Change in Net Earnings | Three months ended | ||||||||||||||||
| March 31 | |||||||||||||||||
| (all dollar amounts in $ millions) | 2022 | ||||||||||||||||
| Prior Period Balance | $ | 13.9 | |||||||||||||||
Adjusted EBITDA1 | 47.7 | ||||||||||||||||
| Net earnings attributable to the non-controlling interest, exclusive of HLBV | 2.3 | ||||||||||||||||
| Income tax expense (recovery) | (31.1) | ||||||||||||||||
| Interest expense | (8.3) | ||||||||||||||||
| Other net losses | 3.7 | ||||||||||||||||
| Pension and post-employment non-service costs | 1.1 | ||||||||||||||||
| Change in value of investments carried at fair value | 31.2 | ||||||||||||||||
| Impacts from the Market Disruption Event on the Senate Wind Facility | 53.4 | ||||||||||||||||
| Loss (gain) on derivative financial instruments | (0.8) | ||||||||||||||||
| Realized loss on energy derivative contracts | (0.1) | ||||||||||||||||
| Loss (gain) on foreign exchange | 0.6 | ||||||||||||||||
| Depreciation and amortization | (22.6) | ||||||||||||||||
| Current Period Balance | $ | 91.0 | |||||||||||||||
| Change in Net Earnings ($) | $ | 77.1 | |||||||||||||||
| Change in Net Earnings (%) | 554.7 | % | |||||||||||||||
| 1 | See Caution Concerning Non-GAAP Measures. | ||||
During the three months ended March 31, 2022, cash provided by (used in) operating activities totaled $166.2 million as compared to $(243.5) million during the same period in 2021, an increase of $409.7 million. During the three months ended March 31, 2022, Adjusted Funds from Operations totaled $220.2 million as compared to Adjusted Funds from Operations of $205.3 million during the same period in 2021, an increase of $14.9 million (see Caution Concerning Non-GAAP Measures).
During the three months ended March 31, 2022, Adjusted EBITDA totaled $330.6 million as compared to $282.9 million during the same period in 2021, an increase of $47.7 million or 16.9% (see Caution Concerning Non-GAAP Measures). A more detailed analysis of these factors is presented within the reconciliation of Adjusted EBITDA to net earnings set out below.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 13 | ||||
2022 First Quarter Adjusted EBITDA Summary
Adjusted EBITDA (see Caution Concerning Non-GAAP Financial Measures) for the three months ended March 31, 2022 totaled $330.6 million as compared to $282.9 million during the same period in 2021, an increase of $47.7 million or 16.9%. The breakdown of Adjusted EBITDA by the Company's main operating segments and a summary of changes are shown below.
| Adjusted EBITDA by segment | Three months ended March 31 | ||||||||||||||||||||||
| (all dollar amounts in $ millions) | 2022 | 2021 | |||||||||||||||||||||
Divisional Operating Profit for Regulated Services Group1 | $ | 231.2 | $ | 206.4 | |||||||||||||||||||
Divisional Operating Profit for Renewable Energy Group1 | 118.6 | 95.0 | |||||||||||||||||||||
| Administration Expenses | (17.5) | (16.6) | |||||||||||||||||||||
| Other Income & Expenses | $ | (1.7) | $ | (1.9) | |||||||||||||||||||
| Total AQN Adjusted EBITDA | $ | 330.6 | $ | 282.9 | |||||||||||||||||||
| Change in Adjusted EBITDA ($) | $ | 47.7 | |||||||||||||||||||||
| Change in Adjusted EBITDA (%) | 16.9 | % | |||||||||||||||||||||
| 1 | See Caution Concerning Non-GAAP Measures. | ||||
| Change in Adjusted EBITDA Breakdown | Three months ended March 31, 2022 | ||||||||||||||||
| (all dollar amounts in $ millions) | Regulated Services | Renewable Energy | Corporate | Total | |||||||||||||
| Prior period balances | $ | 206.4 | $ | 95.0 | $ | (18.5) | $ | 282.9 | |||||||||
| Existing Facilities and Investments | 11.2 | 15.3 | 0.2 | 26.7 | |||||||||||||
| New Facilities and Investments | 7.2 | 8.5 | — | 15.7 | |||||||||||||
| Rate Reviews | 7.5 | — | — | 7.5 | |||||||||||||
| Foreign Exchange Impact | (1.1) | (0.2) | — | (1.3) | |||||||||||||
| Administration Expenses | — | — | (0.9) | (0.9) | |||||||||||||
| Total change during the period | $ | 24.8 | $ | 23.6 | $ | (0.7) | $ | 47.7 | |||||||||
| Current Period Balances | $ | 231.2 | $ | 118.6 | $ | (19.2) | $ | 330.6 | |||||||||
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 14 | ||||
REGULATED SERVICES GROUP
The Regulated Services Group operates rate-regulated utilities that as of March 31, 2022 provided distribution services to approximately 1,232,000 customer connections in the electric, natural gas, and water and wastewater sectors which is an increase of approximately 143,000 customer connections as compared to the prior year, including the approximately 127,000 customers in the state of New York that were added effective January 1, 2022 with the acquisition of Liberty NY Water.
The Regulated Services Group's strategy is to grow its business organically and through business development activities while using prudent acquisition criteria. The Regulated Services Group believes that its business results are maximized by building constructive regulatory and customer relationships, and enhancing customer connections in the communities in which it operates.
| Utility System Type | As at March 31 | ||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| (all dollar amounts in $ millions) | Assets | Net Utility Sales1 | Total Customer Connections2 | Assets | Net Utility Sales1 | Total Customer Connections2 | |||||||||||||||||
| Electricity | 4,774.6 | 181.5 | 307,000 | 3,633.1 | 164.6 | 306,000 | |||||||||||||||||
| Natural Gas | 1,590.4 | 130.9 | 374,000 | 1,477.4 | 125.2 | 372,000 | |||||||||||||||||
| Water and Wastewater | 1,405.7 | 75.8 | 551,000 | 836.3 | 51.8 | 411,000 | |||||||||||||||||
| Other | 322.8 | 15.0 | 220.1 | 11.5 | |||||||||||||||||||
| Total | $ | 8,093.5 | $ | 403.2 | 1,232,000 | $ | 6,166.9 | $ | 353.1 | 1,089,000 | |||||||||||||
| Accumulated Deferred Income Taxes Liability | $ | 627.5 | $ | 543.9 | |||||||||||||||||||
| 1 | Net Utility Sales for the three months ended March 31, 2022 and 2021. See Caution Concerning Non-GAAP Measures. | ||||
| 2 | Total Customer Connections represents the sum of all active and vacant customer connections. | ||||
The Regulated Services Group aggregates the performance of its utility operations by utility system type – electricity, natural gas, and water and wastewater systems.
The electric distribution systems are comprised of regulated electrical distribution utility systems and served approximately 307,000 customer connections in the U.S. States of California, New Hampshire, Missouri, Kansas, Oklahoma and Arkansas and in Bermuda as at March 31, 2022.
The natural gas distribution systems are comprised of regulated natural gas distribution utility systems and served approximately 374,000 customer connections located in the U.S. States of New Hampshire, Illinois, Iowa, Missouri, Georgia, Massachusetts and New York and in the Canadian Province of New Brunswick as at March 31, 2022 .
The water and wastewater distribution systems are comprised of regulated water distribution and wastewater collection utility systems and served approximately 551,000 customer connections located in the U.S. States of Arkansas, Arizona, California, Illinois, Missouri, New York, and Texas, and in Chile as at March 31, 2022.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 15 | ||||
2022 First Quarter Usage Results
| Electric Distribution Systems | Three months ended March 31 | ||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| Average Active Electric Customer Connections For The Period | |||||||||||||||||||||||
| Residential | 261,500 | 261,100 | |||||||||||||||||||||
| Commercial and industrial | 42,300 | 41,800 | |||||||||||||||||||||
| Total Average Active Electric Customer Connections For The Period | 303,800 | 302,900 | |||||||||||||||||||||
| Customer Usage (GW-hrs) | |||||||||||||||||||||||
| Residential | 844.9 | 843.9 | |||||||||||||||||||||
| Commercial and industrial | 915.9 | 901.0 | |||||||||||||||||||||
| Total Customer Usage (GW-hrs) | 1,760.8 | 1,744.9 | |||||||||||||||||||||
For the three months ended March 31, 2022, the electric distribution systems' usage totaled 1,760.8 GW-hrs as compared to 1,744.9 GW-hrs for the same period in 2021, an increase of 15.9 GW-hrs or 0.9%. The increase in electricity consumption is primarily due to more favourable weather.
| Natural Gas Distribution Systems | Three months ended March 31 | ||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| Average Active Natural Gas Customer Connections For The Period | |||||||||||||||||||||||
| Residential | 322,300 | 321,000 | |||||||||||||||||||||
| Commercial and industrial | 39,100 | 38,300 | |||||||||||||||||||||
| Total Average Active Natural Gas Customer Connections For The Period | 361,400 | 359,300 | |||||||||||||||||||||
| Customer Usage (MMBTU) | |||||||||||||||||||||||
| Residential | 11,143,000 | 10,787,000 | |||||||||||||||||||||
| Commercial and industrial | 8,879,000 | 8,227,000 | |||||||||||||||||||||
| Total Customer Usage (MMBTU) | 20,022,000 | 19,014,000 | |||||||||||||||||||||
For the three months ended March 31, 2022, usage at the natural gas distribution systems totaled 20,022,000 MMBTU as compared to 19,014,000 MMBTU during the same period in 2021, an increase of 1,008,000 MMBTU, or 5%. The increase in customer usage was primarily due to colder weather at the Mid-States, New York, and New Brunswick Gas Systems.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 16 | ||||
| Water and Wastewater Distribution Systems | Three months ended March 31 | ||||||||||||||||||||||
| 2022 | 2021 | ||||||||||||||||||||||
| Average Active Customer Connections For The Period | |||||||||||||||||||||||
| Wastewater customer connections | 47,900 | 46,900 | |||||||||||||||||||||
| Water distribution customer connections | 492,400 | 357,400 | |||||||||||||||||||||
| Total Average Active Customer Connections For The Period | 540,300 | 404,300 | |||||||||||||||||||||
| Gallons Provided (millions of gallons) | |||||||||||||||||||||||
| Wastewater treated | 779 | 663 | |||||||||||||||||||||
| Water provided | 8,705 | 6,139 | |||||||||||||||||||||
| Total Gallons Provided (millions of gallons) | 9,484 | 6,802 | |||||||||||||||||||||
For the three months ended March 31, 2022, the water and wastewater distribution systems provided approximately 8,705 million gallons of water to customers and treated approximately 779 million gallons of wastewater. This is compared to 6,139 million gallons of water provided and 663 million gallons of wastewater treated during the same period in 2021, an increase in total gallons provided of 2,681 million or 39%. This is primarily due to the acquisition of Liberty NY Water.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | |||||
2022 First Quarter Regulated Services Group Operating Results
| Three months ended March 31 | |||||||||||||||||||||||
| (all dollar amounts in $ millions) | 2022 | 2021 | |||||||||||||||||||||
| Revenue | |||||||||||||||||||||||
| Regulated electricity distribution | $ | 280.7 | $ | 334.0 | |||||||||||||||||||
| Less: Regulated electricity purchased | (99.2) | (169.4) | |||||||||||||||||||||
Net Utility Sales - electricity1 | 181.5 | 164.6 | |||||||||||||||||||||
| Regulated gas distribution | 263.4 | 198.6 | |||||||||||||||||||||
| Less: Regulated gas purchased | (132.5) | (73.4) | |||||||||||||||||||||
Net Utility Sales - natural gas1 | 130.9 | 125.2 | |||||||||||||||||||||
| Regulated water reclamation and distribution | 78.6 | 54.5 | |||||||||||||||||||||
| Less: Regulated water purchased | (2.8) | (2.7) | |||||||||||||||||||||
Net Utility Sales - water reclamation and distribution1 | 75.8 | 51.8 | |||||||||||||||||||||
Other revenue2 | 15.0 | 11.5 | |||||||||||||||||||||
Net Utility Sales1,3 | 403.2 | 353.1 | |||||||||||||||||||||
| Operating expenses | (184.4) | (152.2) | |||||||||||||||||||||
| Other income | 4.5 | 1.2 | |||||||||||||||||||||
HLBV4 | 7.9 | 4.3 | |||||||||||||||||||||
Divisional Operating Profit1,5,6 | $ | 231.2 | $ | 206.4 | |||||||||||||||||||
| 1 | See Caution Concerning Non-GAAP Measures. | ||||
| 2 | See Note 18 in the unaudited interim consolidated financial statements. | ||||
| 3 | This table contains a reconciliation of Net Utility Sales to revenue. The relevant sections of the table are derived from and should be read in conjunction with the consolidated statement of operations and Note 18 in the unaudited interim consolidated financial statements, “Segmented Information”. This supplementary disclosure is intended to more fully explain disclosures related to Net Utility Sales and provides additional information related to the operating performance of the Regulated Services Group. Investors are cautioned that Net Utility Sales should not be construed as an alternative to revenue. | ||||
| 4 | HLBV income represents the value of net tax attributes monetized by the Regulated Services Group in the period at the Luning and Turquoise Solar Facilities and the Empire Wind Facilities (Neosho Ridge, Kings Point and North Fork Ridge). | ||||
| 5 | This table contains a reconciliation of Divisional Operating Profit to revenue. The relevant sections of the table are derived from and should be read in conjunction with the consolidated statement of operations and Note 18 in the unaudited interim consolidated financial statements, “Segmented Information”. This supplementary disclosure is intended to more fully explain disclosures related to Divisional Operating Profit and provides additional information related to the operating performance of the Regulated Services Group. Investors are cautioned that Divisional Operating Profit should not be construed as an alternative to revenue. | ||||
| 6 | Certain prior year items have been reclassified to conform with current year presentation. | ||||
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 18 | ||||
2022 First Quarter Operating Results
For the three months ended March 31, 2022, the Regulated Services Group reported revenue of $622.8 million (i.e., $280.7 million of regulated electricity distribution, $263.4 million of regulated gas distribution and $78.6 million of regulated water reclamation and distribution) as compared to revenue of $587.1 million in the comparable period in the prior year (i.e., $334.0 million of regulated electricity distribution, $198.6 million of regulated gas distribution and $54.5 million of regulated water reclamation and distribution).
For the three months ended March 31, 2022, the Regulated Services Group reported a Divisional Operating Profit (excluding corporate administration expenses) of $231.2 million as compared to $206.4 million for the comparable period in the prior year (see Caution Concerning Non-GAAP Measures).
Highlights of the changes are summarized in the following table:
| (all dollar amounts in $ millions) | Three months ended March 31 | ||||
Prior Period Divisional Operating Profit1 | $ | 206.4 | |||
| Existing Facilities | |||||
| Electricity: Increase is primarily due to the absence of significant non-pass through fuel cost increases incurred during the Midwest Extreme Weather Event in the first quarter of 2021. | 9.1 | ||||
| Gas: Increase is primarily due to higher Gas System Enhancement Plan mechanism and environmental cost recovery mechanism revenues at the New England Gas System. | 0.7 | ||||
| Water: Decrease is primarily due to higher operating expenses at the ESSAL Water System, partially offset by the tuck-in addition of the Beardsley Water System. | (1.7) | ||||
| Other: Increase is due to recoverable carrying costs related to the Midwest Extreme Weather Event. | 3.1 | ||||
| 11.2 | |||||
| New Facilities | |||||
| Electricity: Increase is primarily due to the acquisition of the Empire Wind Facilities (2021). | 9.5 | ||||
| Water: Acquisition of Liberty NY Water (January 2022). Decrease is primarily due to seasonality impacts with earnings mainly occurring in the warmer months as well as one time transition costs. | (2.3) | ||||
| 7.2 | |||||
| Rate Reviews | |||||
Electricity: Increase is primarily due to implementation of new rates at the Granite State and Bermuda Electric Systems. | 1.6 | ||||
| Gas: Increase is primarily due to implementation of new rates at the EnergyNorth and Peach State Gas Systems. | 3.2 | ||||
| Water: Increase is due to the implementation of new rates at the ESSAL, Park Water and Apple Valley Water Systems. | 2.7 | ||||
| 7.5 | |||||
| Foreign Exchange | (1.1) | ||||
Current Period Divisional Operating Profit1 | $ | 231.2 | |||
| 1 | See Caution Concerning Non-GAAP Measures. | ||||
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 19 | ||||
Regulatory Proceedings
The following table summarizes the major regulatory proceedings currently underway or completed in 2022 within the Regulated Services Group1.
| Utility | Jurisdiction | Regulatory Proceeding Type | Rate Request (millions) | Current Status | ||||||||||
| Completed Rate Reviews | ||||||||||||||
| Empire | Missouri | General Rate Case ("GRC") | $79.9 | On May 28, 2021, Empire filed a rate review based on a 12 month historical test year ending September 30, 2020, with an update period through June 30, 2021, seeking to recover an annual revenue deficiency of $50.0 million, or a 7.61% increase in total base rate operating revenue, based on a rate base of $2.6 billion, which includes the recently completed Empire Wind Facilities and the retirement of the Asbury generating plant, and $29.9 million in costs associated with the impact of the Midwest Extreme Weather Event. On March 9, 2022 the MPSC approved four stipulation agreements resolving all issues, except rate design, and resulting in an annual base rate revenue increase of $35.5 million, as well as another $4 million in revenues associated with the Empire Wind Facilities. On April 6, 2022 the MPSC issued its Report and Order resolving all issues. Empire filed updated tariffs in May 2022 for new rates to become effective in June 2022. On January 19, 2022, Empire filed a petition for securitization of the costs associated with the impact of the Midwest Extreme Weather Event. An order on the securitization is expected in July/August 2022. On March 21, 2022, Empire filed a petition for securitization of the costs associated with the retirement of the Asbury generating plant. | ||||||||||
| BELCO | Bermuda | GRC | $34.8 | On September 30, 2021, filed its revenue allowance application in which it requested a $34.8 million increase for 2022 and a $6.1 million increase for 2023. On March 18, 2022, the Regulatory Authority (“RA”) approved an annual increase of $22.8 million, for a revenue allowance of $224.1 million for 2022 and $226.2 million for 2023. The RA authorized a 7.16% rate of return, comprised of a 62% equity and an 8.92% return on equity (“ROE”). In April 2022, BELCO filed an appeal in the Supreme Court of Bermuda challenging the decisions made by the RA through the recent Retail Tariff Review. | ||||||||||
| Pending Rate Reviews | ||||||||||||||
| Empire | Kansas | GRC | $4.5 | On May 27, 2021, submitted an abbreviated rate review seeking to recover costs associated with the addition of the Empire Wind Facilities, the retirement of Asbury and non-growth related plant investments since the 2019 rate review. In March 2022, all parties reached a settlement on the rate treatment of the Asbury retirement and the non-wind investments. Recovery for the investment in the Empire Wind Facilities was not settled. An evidentiary hearing was held in March 2022. If the parties do not settle the remaining issues, the Commission is expected to issue a decision prior to the end of May 2022. | ||||||||||
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 20 | ||||
| Utility | Jurisdiction | Regulatory Proceeding Type | Rate Request (millions) | Current Status | ||||||||||
| CalPeco Electric System | California | GRC | $35.7 | On May 28, 2021, filed an application requesting a revenue increase of $35.7 million for 2022 based on an ROE of 10.5% and on a 54% equity capital structure. CPUC Public Advocates Office issued its report on February 23, 2022 and CalPeco filed its rebuttal testimony in March 2022. A hearing is scheduled for May 31 – June 8, 2022. | ||||||||||
| Apple Valley Ranchos Water System | California | GRC | $2.9 | On July 2, 2021, filed an application requesting revenue increases of $2.9 million for 2022, $2.1 million for 2023, and $2.3 million for 2024 based on an ROE of 9.4% and on a 57% equity capital structure. CPUC Public Advocates Office issued its report in January 2022. Rebuttal testimony was filed in February 2022. A hearing was held in March 2022 and a decision is expected in the second quarter of 2022. | ||||||||||
| Park Water System | California | GRC | $5.5 | On July 2, 2021, filed an application requesting revenue increases of $5.5 million for 2022, $1.8 million for 2023, and $1.8 million for 2024 based on an ROE of 9.4% and on a 57% equity capital structure. CPUC Public Advocates Office issued its report in January 2022. Rebuttal testimony was filed in February 2022. A hearing was held in March 2022 and a decision is expected the second quarter of 2022. | ||||||||||
| Empire District Gas Company | Missouri | GRC | $1.4 | On August 23, 2021, filed an application requesting a revenue increase of $1.4 million based on an ROE of 10% and on a 52% equity capital structure. In January 2022, MPSC Staff filed its testimony, recommending a $1.0 million revenue increase based on an ROE of 9.5%. On April 12, 2022 the Company, MPSC Staff, consumer advocate group and industrial customer group filed a stipulation and agreement resolving most of the issues in the case. An evidentiary hearing was held April 25, 2022 and a decision is expected in July 2022. If approved by the Commission, the stipulation and agreement will result in an annual increase of $1.0 million in base rate revenues. | ||||||||||
| Empire | Oklahoma | GRC | $4.1 | On February 28, 2022, filed an application seeking an increase of $4.1 million based on an ROE of 10% and a 52.79% equity capital structure. | ||||||||||
| New Brunswick Gas | Canada | GRC | -$3.9 | On November 22, 2021, filed its 2022 general rate application for a revenue decrease based on the Energy & Utilities Board's recent decision authorizing a capital structure of 45% equity and an ROE of 8.5%. New Brunswick Gas is appealing the Energy & Utilities Board's cost of capital decision and a decision is expected in the second quarter of 2022. A hearing on the rate case was held in March 2022 and a decision is expected prior to the end of May 2022 for new rates to become effective in the second quarter of 2022. | ||||||||||
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | |||||
| Utility | Jurisdiction | Regulatory Proceeding Type | Rate Request (millions) | Current Status | ||||||||||
St. Lawrence Gas | New York | GRC | $4.1 | On November 24, 2021, filed an application requesting a revenue increase of $3.4 million based on an ROE of 10.5% and a capital structure of 50% equity. On January 31, 2022, filed a supplemental filing to update the requested revenue increase to $4.1 million. | ||||||||||
| Various | Various | Various | $0.1 | Other pending rate review requests across two wastewater utilities. | ||||||||||
| 1 | All rate requests do not include step-up adjustments | ||||
Regulatory Proceedings related to the Midwest Extreme Weather Event (EO-2022-0040)
The Midwest Extreme Weather Event resulted in an increase in demand for natural gas used by Empire for the generation of electricity. Empire’s Missouri retail jurisdiction incurred approximately $205 million in extraordinary fuel and purchased power costs, carrying charges, and legal costs, including Southwest Power Pool ("SPP") market charges, related to the event. The amount of purchased power costs incurred by Empire is subject to resettlement activity and further review by SPP. This review and any subsequent resettlement activity could result in increases or decreases to the final amount of purchased power costs incurred by Empire, and these changes could be material. Empire has deferred substantially all of the fuel and purchased power costs related to the Midwest Extreme Weather Event to a regulatory asset. 95% of extraordinary fuel and purchased power costs are deferred pursuant to a fuel adjustment clause proceeding. The remaining 5% of the extraordinary fuel and purchased power costs, plus carrying charges and legal fees, are being deferred pursuant to an Accounting Authority Order ("AAO") request. While Empire currently expects to recover substantially all of the increased fuel and purchased power costs related to the Midwest Extreme Weather Event from customers, the timing of the cost recovery is expected to be delayed or spread over a longer than typical recovery timeframe to help moderate monthly customer bill impacts given the extraordinary nature of the Midwest Extreme Weather Event.
When Empire filed its most recent Missouri rate case (“ER-2021-0312”) in May 2021, costs related to the Midwest Extreme Weather Event were included. In July 2021, Missouri House Bill 734 was signed into law, creating an option for utilities to finance the recovery of extraordinary weather event costs. When it filed its surrebuttal testimony in ER-2021-0312 in January 2022, Empire removed all costs related to the Midwest Extreme Weather Event from its rate request. Pursuant to House Bill 734, Empire filed a Petition for Financing Order for authorization of the issuance of securitized utility tariff bonds regarding 100% of the extraordinary costs incurred during the Midwest Extreme Winter Weather Event. A decision by the MPSC regarding Empire’s securitization request is required by August 22, 2022.
Regulatory Proceedings related to the retirement of Asbury (EO-2022-0193)
In the course of completing its 2017 and 2019 Integrated Resource Plans (“IRPs”), Empire analyzed the effects of retiring Asbury, a coal-fired generation unit that was constructed in 1970. In the course of the 2019 IRP, Empire determined that retiring the plant would generate $93.0 million in customer savings in the 20 years following the unit’s decommissioning. Asbury was retired on March 1, 2020. On July 23, 2020, the MPSC issued an AAO that directed Empire to establish regulatory asset and liability accounts, beginning January 1, 2020, to reflect the impact of the closure of Asbury on operating and capital expenses in Missouri.
When Empire filed ER-2021-0312 in May 2021, its Asbury related revenues and expenses, along with the balance of the AAO, were included in the application. In July 2021, Missouri House Bill 734 created an option for utilities to finance the recovery of costs related to the retirement of obsolescent generation infrastructure, including recovery of undepreciated rate base balances and financing costs, through securitized utility tariff bonds.
When it filed its surrebuttal testimony in ER-2021-0312 in January 2022, Empire removed all the balances associated with Asbury from its rate request, including the undepreciated balance on the asset and other Asbury-related balances, resulting in total amounts to be securitized of approximately $90.0 million. On March 21, 2022, Empire filed a Petition for Financing Order for authorization of issuance of securitized utility tariff bonds regarding the Asbury generating plant.
On April 18, 2022, Empire filed a motion seeking to consolidate the case regarding the securitization of Asbury retirement costs (EO-2022-0193) with the case regarding the securitization of extraordinary costs related to the Midwest Extreme Weather Event (EO-2022-0040). On April 27, 2022 the MPSC issued an order consolidating the two securitization cases for purposes of hearing, utilizing the procedural schedule previously established for EO-2022-0040 which requires a decision by the MPSC by August 22, 2022.
As described above, Empire has also filed rate cases that include requests for recovery of costs related to Asbury in Kansas and Oklahoma. Both cases are pending.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | |||||
Regulatory Proceedings related to Acquisitions:
Kentucky Power
On October 26, 2021, Liberty Utilities entered into an agreement with American Electric Power Company, Inc. and AEP Transmission Company, LLC to acquire Kentucky Power and Kentucky TransCo.
On January 4, 2022, Liberty Utilities and Kentucky Power jointly filed for the approval of the Kentucky Power Transaction at the KPSC. By statute, the KPSC must issue an order on the application within 120 days. A hearing was held on March 28-29, 2022. On May 4, 2022 the KPSC issued an order approving the Kentucky Power Transaction, subject to certain conditions set forth in the order, including those agreed to by Liberty Utilities in the course of the docket. In addition to the approval of the KPSC, closing of the Kentucky Power Transaction is subject to receipt of certain other regulatory approvals, including the approval of FERC and the approval of KPSC, FERC and the Public Service Commission of West Virginia with respect to the termination and replacement of the existing operating agreement for the Mitchell Plant.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | |||||
RENEWABLE ENERGY GROUP
2022 First Quarter Electricity Generation Performance | |||||||||||||||||||||||||||||||||||
| Long Term Average Resource | Three months ended March 31 | ||||||||||||||||||||||||||||||||||
| (Performance in GW-hrs sold) | 2022 | 2021 | |||||||||||||||||||||||||||||||||
| Hydro Facilities: | |||||||||||||||||||||||||||||||||||
| Maritime Region | 27.5 | 25.6 | 24.9 | ||||||||||||||||||||||||||||||||
| Quebec Region | 56.0 | 56.9 | 61.2 | ||||||||||||||||||||||||||||||||
| Ontario Region | 38.3 | 25.2 | 31.3 | ||||||||||||||||||||||||||||||||
| Western Region | 9.6 | 9.0 | 6.0 | ||||||||||||||||||||||||||||||||
| 131.4 | 116.7 | 123.4 | |||||||||||||||||||||||||||||||||
| Canadian Wind Facilities: | |||||||||||||||||||||||||||||||||||
| St. Damase | 20.9 | 23.0 | 21.9 | ||||||||||||||||||||||||||||||||
| St. Leon | 121.4 | 118.6 | 108.1 | ||||||||||||||||||||||||||||||||
Red Lily1 | 23.2 | 26.7 | 24.3 | ||||||||||||||||||||||||||||||||
| Morse | 30.5 | 32.1 | 29.2 | ||||||||||||||||||||||||||||||||
| Amherst | 65.3 | 68.5 | 57.6 | ||||||||||||||||||||||||||||||||
Blue Hill2 | 63.3 | 62.5 | — | ||||||||||||||||||||||||||||||||
EBR3 | 19.8 | 18.9 | — | ||||||||||||||||||||||||||||||||
| 344.4 | 350.3 | 241.1 | |||||||||||||||||||||||||||||||||
| U.S. Wind Facilities: | |||||||||||||||||||||||||||||||||||
| Sandy Ridge | 47.1 | 42.7 | 37.2 | ||||||||||||||||||||||||||||||||
| Minonk | 187.4 | 215.8 | 184.9 | ||||||||||||||||||||||||||||||||
| Senate | 151.3 | 136.4 | 136.5 | ||||||||||||||||||||||||||||||||
| Shady Oaks | 108.2 | 110.5 | 106.2 | ||||||||||||||||||||||||||||||||
| Odell | 230.5 | 249.8 | 193.8 | ||||||||||||||||||||||||||||||||
| Deerfield | 160.4 | 169.0 | 165.2 | ||||||||||||||||||||||||||||||||
Sugar Creek4 | 202.6 | 208.9 | 84.4 | ||||||||||||||||||||||||||||||||
Maverick Creek5 | 503.3 | 446.4 | 291.5 | ||||||||||||||||||||||||||||||||
| 1,590.8 | 1,579.5 | 1,199.7 | |||||||||||||||||||||||||||||||||
| Solar Facilities: | |||||||||||||||||||||||||||||||||||
| Cornwall | 2.6 | 2.2 | 2.3 | ||||||||||||||||||||||||||||||||
| Bakersfield | 12.9 | 12.3 | 14.2 | ||||||||||||||||||||||||||||||||
| Great Bay | 46.7 | 40.3 | 43.7 | ||||||||||||||||||||||||||||||||
Altavista6 | 36.8 | 34.3 | 4.4 | ||||||||||||||||||||||||||||||||
Croton7 | 1.1 | 1.0 | — | ||||||||||||||||||||||||||||||||
| 100.1 | 90.1 | 64.6 | |||||||||||||||||||||||||||||||||
| Renewable Energy Performance | 2,166.7 | 2,136.6 | 1,628.8 | ||||||||||||||||||||||||||||||||
| Thermal Facilities: | |||||||||||||||||||||||||||||||||||
| Windsor Locks | N/A8 | 35.4 | 33.0 | ||||||||||||||||||||||||||||||||
| Sanger | N/A8 | 33.3 | 11.4 | ||||||||||||||||||||||||||||||||
| 68.7 | 44.4 | ||||||||||||||||||||||||||||||||||
| Total Performance | 2,205.3 | 1,673.2 | |||||||||||||||||||||||||||||||||
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 24 | ||||
| 1 | AQN owns a 75% equity interest but accounts for the facility using the equity method. Figures show full energy produced by the facility. | ||||
| 2 | The Blue Hill Wind Facility achieved COD on April 14, 2022. AQN owns a 50% equity interest but accounts for the facility using the equity method. Figures show expected long-term average resources ("LTAR") and actual energy produced by the facility during the quarter. | ||||
| 3 | The EBR Wind Facility achieved COD on December 31, 2021. AQN owns a 50% equity interest but accounts for the facility using the equity method. Figures show full energy produced by the facility. | ||||
| 4 | The Sugar Creek Wind Facility achieved COD on November 9, 2020. Prior to January 29, 2021, AQN owned a 50% equity interest in the facility. On January 29, 2021, AQN acquired the remaining 50% equity interest that it did not previously own. Figures show full energy produced by the facility. As a result of a blade manufacturing error 26 of 40 turbines were initially shut down. All impacted turbines were back in service as of September 29, 2021. | ||||
| 5 | The Maverick Creek Wind Facility achieved partial completion on November 6, 2020 and COD on April 21, 2021. Prior to January 19, 2021, AQN owned a 50% equity interest in the facility. On January 19, 2021, AQN acquired the remaining 50% equity interest that it did not previously own. Figures show full energy produced by the facility. As a result of a blade manufacturing error 26 of 73 turbines were initially shut down. All impacted turbines were back in service as of June 7, 2021. | ||||
| 6 | The Altavista Solar Facility achieved partial completion on March 8, 2021 and COD on June 1, 2021. Prior to April 9, 2021, AQN owned a 50% equity interest in the facility. On April 9, 2021, AQN acquired the remaining 50% equity interest that it did not previously own. Figures show full energy produced by the facility. | ||||
| 7 | The Croton Solar Facility achieved COD on December 8, 2021. | ||||
| 8 | Natural gas fired co-generation facility. | ||||
2022 First Quarter Renewable Energy Group Performance
For the three months ended March 31, 2022, the Renewable Energy Group generated 2,205.3 GW-hrs of electricity as compared to 1,673.2 GW-hrs during the same period in 2021.
For the three months ended March 31, 2022, the hydro facilities generated 116.7 GW-hrs of electricity as compared to 123.4 GW-hrs produced in the same period in 2021, a decrease of 5.4%. Electricity generated represented 88.8% of LTAR as compared to 93.9% during the same period in 2021. During the quarter, all regions except the Quebec Region were below their respective LTAR.
For the three months ended March 31, 2022, the wind facilities produced 1,929.8 GW-hrs of electricity as compared to 1,440.8 GW-hrs produced in the same period in 2021, an increase of 33.9%. The increase in production is primarily due to the addition of the Maverick Creek Wind Facility which achieved COD on April 21, 2021, the EBR Wind Facility which achieved COD on December 31, 2021, and the Blue Hill Wind Facility which achieved COD on April 14, 2022. In addition, the Sugar Creek Wind Facility and the Maverick Creek Wind Facility experienced lower production in 2021 due to the shutdown of turbines resulting from a blade manufacturing error. Excluding the Maverick Creek, Sugar Creek, EBR, and Blue Hill Wind Facilities, production was 12.0% above the same period last year. The wind facilities, including new facilities, generated electricity equal to 99.7% of LTAR as compared to 88.5% during the same period in 2021.
For the three months ended March 31, 2022, the solar facilities generated 90.1 GW-hrs of electricity as compared to 64.6 GW-hrs of electricity in the same period in 2021, an increase of 39.5%. The increase in production is primarily due to the Altavista Solar Facility which achieved partial completion on March 8, 2021 and COD on June 1, 2021. In addition, the Croton Solar Facility achieved COD on December 8, 2021. Excluding the new facilities, production was 9.0% below the same period last year. The solar facilities, including new facilities, generated electricity equal to 90.0% of LTAR as compared to 87.1% in the same period in 2021.
For the three months ended March 31, 2022, the thermal facilities generated 68.7 GW-hrs of electricity as compared to 44.4 GW-hrs of electricity during the same period in 2021. During the same period, the Windsor Locks Thermal Facility generated 168.7 billion lbs of steam as compared to 176.7 billion lbs of steam during the same period in 2021.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 25 | ||||
2022 First Quarter Renewable Energy Group Operating Results | |||||||||||||||||||||||
| Three months ended March 31 | |||||||||||||||||||||||
| (all dollar amounts in $ millions) | 2022 | 2021 | |||||||||||||||||||||
Revenue1 | |||||||||||||||||||||||
| Hydro | $ | 12.6 | $ | 10.7 | |||||||||||||||||||
| Wind | 58.1 | 7.6 | |||||||||||||||||||||
| Solar | 5.4 | 3.9 | |||||||||||||||||||||
| Thermal | 12.1 | 8.6 | |||||||||||||||||||||
| Total Non-Regulated Energy Sales | $ | 88.2 | $ | 30.8 | |||||||||||||||||||
| Less: | |||||||||||||||||||||||
Cost of Sales - Energy2 | (5.5) | (3.3) | |||||||||||||||||||||
| Cost of Sales - Thermal | (9.4) | (4.6) | |||||||||||||||||||||
Realized gain (loss) on hedges3 | 0.3 | 0.2 | |||||||||||||||||||||
Net Energy Sales 4, 5 | $ | 73.6 | $ | 23.1 | |||||||||||||||||||
Renewable Energy Credits6 | 9.2 | 4.1 | |||||||||||||||||||||
| Other Revenue | 0.1 | 0.7 | |||||||||||||||||||||
| Total Net Revenue | $ | 82.9 | $ | 27.9 | |||||||||||||||||||
| Expenses & Other Income | |||||||||||||||||||||||
| Operating expenses | (27.6) | (27.9) | |||||||||||||||||||||
| Gain on sale of renewable assets | 1.2 | — | |||||||||||||||||||||
Dividend, interest, equity and other income7 | 27.6 | 22.4 | |||||||||||||||||||||
| Impacts from the Market Disruption Event on the Senate Wind Facility | — | 53.4 | |||||||||||||||||||||
HLBV income8 | 34.5 | 19.2 | |||||||||||||||||||||
Divisional Operating Profit4,9,10 | $ | 118.6 | $ | 95.0 | |||||||||||||||||||
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 26 | ||||
| 1 | Many of the Renewable Energy Group’s PPAs include annual rate increases. However, a change to the weighted average production levels resulting from higher average production from facilities that earn lower energy rates can result in a lower weighted average energy rate earned by the division as compared to the same period in the prior year. Includes the impacts from the Market Disruption Event on the Senate Wind Facility. | ||||
| 2 | Cost of Sales - Energy consists of energy purchases in the Maritime Region to manage the energy sales from the Tinker Hydro Facility which is sold to retail and industrial customers under multi-year contracts. | ||||
| 3 | See Note 21(b)(iv) in the unaudited interim consolidated financial statements. | ||||
| 4 | See Caution Concerning Non-GAAP Measures. | ||||
| 5 | This table contains a reconciliation of Net Energy Sales to revenue. The relevant sections of the table are derived from and should be read in conjunction with the consolidated statement of operations and Note 18 in the unaudited interim consolidated financial statements, “Segmented information”. This supplementary disclosure is intended to more fully explain disclosures related to Net Energy Sales and provides additional information related to the operating performance of AQN. Investors are cautioned that Net Energy Sales should not be construed as an alternative to revenue. | ||||
| 6 | Qualifying renewable energy projects receive RECs for the generation and delivery of renewable energy to the power grid. The RECs represent proof that 1 MW-hr of electricity was generated from an eligible energy source. | ||||
| 7 | Includes dividends received from Atlantica and related parties (see Note 6 and 13 in the unaudited interim consolidated financial statements) as well as the equity investment in the Texas Coastal Wind Facilities (Stella, Cranell, East Raymond and West Raymond). | ||||
| 8 | HLBV income represents the value of net tax attributes earned by the Renewable Energy Group in the period primarily from electricity generated by certain of its U.S. wind and U.S. solar generation facilities. Production tax credits ("PTCs") are earned as wind energy is generated based on a dollar per kW-hr rate prescribed in applicable federal and state statutes. For the three months ended March 31, 2022, the Renewable Energy Group's eligible facilities generated 1,469.0 GW-hrs representing approximately $36.7 million in PTCs earned as compared to 717.6 GW-hrs representing $17.9 million in PTCs earned during the same period in 2021. The majority of the PTCs have been allocated to tax equity investors to monetize the value to AQN of the PTCs and other tax attributes which are the primary drivers of HLBV income offset by the return earned by the investor. Some PTCs have been utilized directly by the Company to lower its overall effective tax rate. | ||||
| 9 | Certain prior year items have been reclassified to conform to current year presentation. | ||||
| 10 | This table contains a reconciliation of Divisional Operating Profit to revenue. The relevant sections of the table are derived from and should be read in conjunction with the consolidated statement of operations and Note 18 in the unaudited interim consolidated financial statements, “Segmented Information”. This supplementary disclosure is intended to more fully explain disclosures related to Divisional Operating Profit and provides additional information related to the operating performance of the Renewable Energy Group. Investors are cautioned that Divisional Operating Profit should not be construed as an alternative to revenue. | ||||
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | |||||
2022 First Quarter Operating Results
For the three months ended March 31, 2022, the Renewable Energy Group’s facilities generated operating revenue of $88.2 million (i.e., non-regulated energy sales) as compared to $30.8 million in the comparable period in the prior year.
For the three months ended March 31, 2022, the Renewable Energy Group's facilities generated $118.6 million of Divisional Operating Profit (excluding corporate administration expenses) as compared to $95.0 million during the same period in 2021, which represents an increase of $23.6 million or 24.8%. (see Caution Concerning Non-GAAP Measures).
Highlights of the changes are summarized in the following table:
| (all dollar amounts in $ millions) | Three months ended March 31 | ||||
Prior Period Divisional Operating Profit1 | $ | 95.0 | |||
| Existing Facilities and Investments | |||||
| Hydro: Decrease is primarily due to lower production and higher operating expenses primarily in the Ontario Region. | (0.2) | ||||
| Wind Canada: Increase is primarily due to higher production at the St. Leon, Morse and Amherst Wind Facilities. | 2.9 | ||||
| Wind U.S.: Increase is primarily due to the higher production across the Company's U.S. wind portfolio along with higher HLBV income, partially offset by unfavourable pricing at the Senate Wind Facility. | 8.7 | ||||
| Solar: Increase is primarily due to higher REC revenue for the Great Bay I & II Solar Facilities driven by the sales of RECs in inventory, partially offset by lower HLBV income for the Great Bay I and Bakersfield II Solar Facilities. | 0.8 | ||||
| Thermal: Decrease is primarily due to higher fuel costs, partially offset by higher production at the Sanger Thermal Facility as well as favourable pricing and higher production at the Windsor Locks Thermal Facility. | (1.0) | ||||
Investments: Increase is primarily due to higher dividends from AQN's investments in Atlantica.2 | 4.0 | ||||
| Other: | 0.1 | ||||
| 15.3 | |||||
| New Facilities and Investments | |||||
| Wind U.S.: Increase is primarily due to lower operating expenses, higher HLBV income and higher production, partially offset by unfavourable pricing at the Maverick Creek Wind Facility. This facility achieved partial completion on November 6, 2020 and COD on April 21, 2021. | 5.6 | ||||
| Solar: Increase is primarily due to the acquisition of the Altavista Solar Facility (full COD in June 2021) and Croton Solar Facility (full COD in December 2021). | 1.1 | ||||
| Other: Increase is primarily due to higher equity income in 2022 from the investment in the Texas Coastal Wind Facilities. | 1.8 | ||||
| 8.5 | |||||
| Foreign Exchange | (0.2) | ||||
Current Period Divisional Operating Profit1 | $ | 118.6 | |||
| 1 | See Caution Concerning Non-GAAP Measures. | ||||
| 2 | See Note 6 and 13 in the unaudited interim consolidated financial statements. | ||||
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 28 | ||||
AQN: CORPORATE AND OTHER EXPENSES
| Three months ended March 31 | |||||||||||||||||||||||
| (all dollar amounts in $ millions) | 2022 | 2021 | |||||||||||||||||||||
| Corporate and other expenses: | |||||||||||||||||||||||
| Administrative expenses | $ | 17.5 | $ | 16.6 | |||||||||||||||||||
| Loss (gain) on foreign exchange | 0.3 | 0.9 | |||||||||||||||||||||
| Interest expense | 57.9 | 49.6 | |||||||||||||||||||||
| Depreciation and amortization | 120.0 | 97.4 | |||||||||||||||||||||
| Change in value of investments carried at fair value | 40.5 | 71.7 | |||||||||||||||||||||
Interest, dividend, equity, and other loss (income)1 | 2.3 | 2.4 | |||||||||||||||||||||
| Pension and other post-employment non-service costs | 2.6 | 3.7 | |||||||||||||||||||||
| Other net losses | 4.7 | 8.4 | |||||||||||||||||||||
| Loss (gain) on derivative financial instruments | (0.3) | (1.1) | |||||||||||||||||||||
| Income tax expense (recovery) | 9.5 | (21.6) | |||||||||||||||||||||
| 1 | Excludes income directly pertaining to the Regulated Services and Renewable Energy Groups (disclosed in the relevant sections). | ||||
2022 First Quarter Corporate and Other Expenses
For the three months ended March 31, 2022, administrative expenses totaled $17.5 million as compared to $16.6 million in the same period in 2021. The increase was primarily due to higher staffing expenses partially offset by higher capitalization.
For the three months ended March 31, 2022, interest expense totaled $57.9 million as compared to $49.6 million in the same period in 2021 due to the funding of capital deployed in 2022 primarily related to the acquisition of Liberty NY Water and development of renewable energy projects.
For the three months ended March 31, 2022, depreciation expense totaled $120.0 million as compared to $97.4 million in the same period in 2021. The increase was primarily due to higher overall property, plant and equipment, and the acquisition of Liberty NY Water.
For the three months ended March 31, 2022, change in investments carried at fair value totaled a loss of $40.5 million as compared to a loss of $71.7 million in the same period in 2021. The Company records certain of its investments, including Atlantica, using the fair value method and accordingly any change in the fair value of the investment is recorded in the Statement of Operations (see Note 6 in the unaudited interim consolidated financial statements).
For the three months ended March 31, 2022, pension and post-employment non-service costs totaled $2.6 million as compared to $3.7 million in the same period in 2021. The decrease was primarily due to lower amortization of actuarial losses.
For the three months ended March 31, 2022, other net losses were $4.7 million as compared to $8.4 million in the same period in 2021. The net losses in the first quarter of 2022 were primarily due to acquisition and transition-related costs. The net losses in the first quarter of 2021 were primarily due to an adjustment to a regulatory liability pertaining to the true-up of prior period tracking accounts, costs pertaining to the Apple Valley condemnation proceeding, and other miscellaneous asset write-downs. See Note 16 in the unaudited interim consolidated financial statements.
For the three months ended March 31, 2022, the gain on derivative financial instruments totaled $0.3 million as compared to a gain of $1.1 million in the same period in 2021. AQN uses derivative instruments to manage exposure to changes in commodity prices, foreign exchange rates, and interest rates. Both the gains in the first quarter of 2022 and 2021 respectively were primarily related to mark-to-markets on energy derivatives.
For the three months ended March 31, 2022, an income tax expense of $9.5 million was recorded as compared to an income tax recovery of $21.6 million during the same period in 2021. The increase in income tax expense was primarily due to the tax benefits associated with the impact of the Midwest Extreme Weather Event in 2021, state deferred tax adjustments related to the acquisition of Liberty NY Water, and the tax impact associated with the change in fair value of the investment in Atlantica. For the three months ended March 31, 2022, the Company accrued $10.1 million of investment tax credits ("ITCs") and PTCs associated with renewable energy projects that have either been placed in service or are expected to be placed in service by the end of 2022 as compared to $11.6 million recorded in the same period in 2021.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 29 | ||||
NON-GAAP FINANCIAL MEASURES
Reconciliation of Adjusted EBITDA to Net Earnings
The following table is derived from and should be read in conjunction with the consolidated statement of operations. This supplementary disclosure is intended to more fully explain disclosures related to Adjusted EBITDA and provides additional information related to the operating performance of AQN. Investors are cautioned that this measure should not be construed as an alternative to U.S. GAAP consolidated net earnings.
| Three months ended March 31 | |||||||||||||||||||||||
| (all dollar amounts in $ millions) | 2022 | 2021 | |||||||||||||||||||||
| Net earnings attributable to shareholders | $ | 91.0 | $ | 13.9 | |||||||||||||||||||
| Add (deduct): | |||||||||||||||||||||||
Net earnings attributable to the non-controlling interest, exclusive of HLBV1 | 4.1 | 6.4 | |||||||||||||||||||||
| Income tax expense (recovery) | 9.5 | (21.6) | |||||||||||||||||||||
| Interest expense | 57.9 | 49.6 | |||||||||||||||||||||
Other net losses3 | 4.7 | 8.4 | |||||||||||||||||||||
| Pension and post-employment non-service costs | 2.6 | 3.7 | |||||||||||||||||||||
Change in value of investments carried at fair value2 | 40.5 | 71.7 | |||||||||||||||||||||
| Impacts from the Market Disruption Event on the Senate Wind Facility | — | 53.4 | |||||||||||||||||||||
| Loss (gain) on derivative financial instruments | (0.3) | (1.1) | |||||||||||||||||||||
| Realized loss on energy derivative contracts | 0.3 | 0.2 | |||||||||||||||||||||
| Loss (gain) on foreign exchange | 0.3 | 0.9 | |||||||||||||||||||||
| Depreciation and amortization | 120.0 | 97.4 | |||||||||||||||||||||
| Adjusted EBITDA | $ | 330.6 | $ | 282.9 | |||||||||||||||||||
| 1 | HLBV represents the value of net tax attributes earned during the period primarily from electricity generated by certain U.S. wind power and U.S. solar generation facilities. HLBV earned in the three months ended March 31, 2022 amounted to $42.5 million, as compared to $23.9 million during the same period in 2021. | ||||
| 2 | See Note 6 in the unaudited interim consolidated financial statements. | ||||
| 3 | See Note 16 in the unaudited interim consolidated financial statements. | ||||
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 30 | ||||
Reconciliation of Adjusted Net Earnings to Net Earnings
The following table is derived from and should be read in conjunction with the consolidated statement of operations. This supplementary disclosure is intended to more fully explain disclosures related to Adjusted Net Earnings and provides additional information related to the operating performance of AQN. Investors are cautioned that this measure should not be construed as an alternative to consolidated net earnings in accordance with U.S. GAAP.
The following table shows the reconciliation of net earnings to Adjusted Net Earnings exclusive of these items:
| Three months ended March 31 | |||||||||||||||||||||||
| (all dollar amounts in $ millions except per share information) | 2022 | 2021 | |||||||||||||||||||||
| Net earnings attributable to shareholders | $ | 91.0 | $ | 13.9 | |||||||||||||||||||
| Add (deduct): | |||||||||||||||||||||||
| Loss (gain) on derivative financial instruments | (0.3) | (1.1) | |||||||||||||||||||||
| Realized loss on energy derivative contracts | 0.3 | 0.2 | |||||||||||||||||||||
Other net losses2 | 4.7 | 8.4 | |||||||||||||||||||||
| Loss (gain) on foreign exchange | 0.3 | 0.9 | |||||||||||||||||||||
Change in value of investments carried at fair value1 | 40.5 | 71.7 | |||||||||||||||||||||
| Impacts from the Market Disruption Event on the Senate Wind Facility | — | 53.4 | |||||||||||||||||||||
| Adjustment for taxes related to above | 4.8 | (22.9) | |||||||||||||||||||||
| Adjusted Net Earnings | $ | 141.3 | $ | 124.5 | |||||||||||||||||||
| Adjusted Net Earnings per common share | $ | 0.21 | $ | 0.20 | |||||||||||||||||||
| 1 | See Note 6 in the unaudited interim consolidated financial statements. | ||||
| 2 | See Note 16 in the unaudited interim consolidated financial statements. | ||||
For the three months ended March 31, 2022, Adjusted Net Earnings totaled $141.3 million as compared to Adjusted Net Earnings of $124.5 million for the same period in 2021, an increase of $16.8 million.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 31 | ||||
Reconciliation of Adjusted Funds from Operations to Cash Provided by Operating Activities
The following table is derived from and should be read in conjunction with the consolidated statement of operations and consolidated statement of cash flows. This supplementary disclosure is intended to more fully explain disclosures related to Adjusted Funds from Operations and provides additional information related to the operating performance of AQN. Investors are cautioned that this measure should not be construed as an alternative to cash provided by operating activities in accordance with U.S GAAP.
The following table shows the reconciliation of cash provided by operating activities to Adjusted Funds from Operations exclusive of these items:
| Three months ended March 31 | |||||||||||||||||||||||
| (all dollar amounts in $ millions) | 2022 | 2021 | |||||||||||||||||||||
| Cash provided by operating activities | $ | 166.2 | $ | (243.5) | |||||||||||||||||||
| Add (deduct): | |||||||||||||||||||||||
| Changes in non-cash operating items | 48.1 | 388.5 | |||||||||||||||||||||
| Production based cash contributions from non-controlling interests | 3.7 | 4.8 | |||||||||||||||||||||
| Impacts from the Market Disruption Event on the Senate Wind Facility | — | 53.4 | |||||||||||||||||||||
| Acquisition-related costs | 2.2 | 2.1 | |||||||||||||||||||||
| Adjusted Funds from Operations | $ | 220.2 | $ | 205.3 | |||||||||||||||||||
For the three months ended March 31, 2022, Adjusted Funds from Operations totaled $220.2 million as compared to Adjusted Funds from Operations of $205.3 million for the same period in 2021, an increase of $14.9 million.
CORPORATE DEVELOPMENT ACTIVITIES
The Company undertakes development activities working with a global reach to identify, develop, and construct both regulated and non-regulated renewable energy facilities, power transmission lines, water infrastructure assets, and other complementary infrastructure projects as well as to invest in local utility electric, natural gas and water distribution systems.
The Company has announced a capital investment plan of approximately $12.4 billion consisting of approximately $8.8 billion of anticipated investments by its Regulated Services Group and approximately $3.6 billion of anticipated investments by its Renewable Energy Group for the period from 2022 through the end of 2026.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 32 | ||||
SUMMARY OF PROPERTY, PLANT, AND EQUIPMENT EXPENDITURES
| Three months ended March 31 | |||||||||||||||||||||||
| (all dollar amounts in $ millions) | 2022 | 2021 | |||||||||||||||||||||
| Regulated Services Group | |||||||||||||||||||||||
| Rate Base Maintenance | $ | 80.1 | $ | 67.3 | |||||||||||||||||||
| Rate Base Growth | 145.5 | 171.0 | |||||||||||||||||||||
Property, Plant & Equipment Acquired1 | 609.0 | 248.1 | |||||||||||||||||||||
| $ | 834.6 | $ | 486.4 | ||||||||||||||||||||
| Renewable Energy Group | |||||||||||||||||||||||
| Maintenance | $ | 7.3 | $ | 6.8 | |||||||||||||||||||
Investment in Capital Projects1 | 19.9 | 1,436.6 | |||||||||||||||||||||
| $ | 27.2 | $ | 1,443.4 | ||||||||||||||||||||
| Total Capital Expenditures | $ | 861.8 | $ | 1,929.8 | |||||||||||||||||||
| 1 | Includes expenditures on Property Plant & Equipment, equity-method investees, and acquisitions of operating entities that may have been jointly developed by the Company with another third party developer. Excludes temporary advances to joint venture partners in connection with capital projects under development or construction. | |||||||
2022 First Quarter Property Plant and Equipment Expenditures
During the three months ended March 31, 2022, the Regulated Services Group invested $834.6 million in capital expenditures as compared to $486.4 million during the same period in 2021. The Regulated Services Group's investment was primarily related to the acquisition of Liberty NY Water in January 2022. In addition, the Regulated Services Group continued investments in the construction of transmission and distribution main replacements, work on new and existing substation assets, and initiatives relating to the safety and reliability of the electric and gas systems.
During the three months ended March 31, 2022, the Renewable Energy Group incurred capital expenditures of $27.2 million as compared to $1,443.4 million during the same period in 2021. The Renewable Energy Group's investments, during the first quarter of 2022, were primarily related to the development and/or construction of ongoing maintenance capital at existing operating sites.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 33 | ||||
2022 Capital Investments
The following discussion should be read in conjunction with the Caution Concerning Forward-Looking Statements and Forward-Looking Information section of this MD&A.
Over the course of the 2022 financial year, the Company expects to spend between approximately $4.35 billion and $4.68 billion on capital investment opportunities. Actual expenditures in 2022 may vary due to, among other things, the impacts of COVID-19 and related response measures, the timing of various project investments and acquisitions, the availability of financing on acceptable terms, and realized foreign exchange rates.
Ranges of expected capital investment in the 2022 financial year are as follows:
| (all dollar amounts in $ millions) | |||||||||||
| Regulated Services Group: | |||||||||||
Rate Base Maintenance | $ | 400.0 | - | $ | 440.0 | ||||||
Rate Base Growth | 450.0 | - | 540.0 | ||||||||
| Rate Base Acquisitions | 3,400.0 | - | 3,550.0 | ||||||||
| Total Regulated Services Group: | $ | 4,250.0 | - | $ | 4,530.0 | ||||||
| Renewable Energy Group: | |||||||||||
Maintenance | $ | 35.0 | - | $ | 50.0 | ||||||
Investment in Capital Projects | 65.0 | - | 100.0 | ||||||||
Total Renewable Energy Group: | $ | 100.0 | - | $ | 150.0 | ||||||
| Total 2022 Capital Investments | $ | 4,350.0 | - | $ | 4,680.0 | ||||||
The Regulated Services Group expects to spend between $4,250.0 million and $4,530.0 million over the course of 2022 primarily attributable to rate base acquisitions between $3,510.0 million and $3,720.0 million. In January 2022, the Regulated Services Group closed the acquisition of Liberty NY Water for a purchase price of approximately $609.0 million excluding transaction costs. Furthermore, in October 2021, an agreement was reached to acquire Kentucky Power and Kentucky TransCo for a total purchase price of approximately $2,846.0 million excluding transaction costs. The Kentucky Power Transaction is expected to close in mid-2022. The remaining Regulated Services Group spend is expected to contribute to continued efforts to expand operations, improve the reliability of the utility systems and broaden the technologies used to better serve its service areas. Project spending includes capital for structural improvements, specifically in relation to refurbishing substations, replacing poles and wires, drilling and equipping aquifers, main replacements, and reservoir pumping stations.
The Renewable Energy Group expects to spend between $100.0 million and $150.0 million over the course of 2022 to develop or further invest in development and construction (as applicable) of the Renewable Energy Group's wind and solar projects. Furthermore, the Renewable Energy Group plans to spend between $35.0 million and $50.0 million on various operational solar, thermal, and wind assets to maintain safety, regulatory, and operational efficiencies.
The Company expects to fund its 2022 capital plan through a combination of retained cash, tax equity funding, senior notes, subordinated notes, bank revolving and term credit facilities, and common equity or equity linked instruments.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 34 | ||||
LIQUIDITY AND CAPITAL RESERVES
AQN has revolving credit and letter of credit facilities as well as separate credit facilities for the Regulated Services Group and the Renewable Energy Group to manage the liquidity and working capital requirements of each division (collectively the “Bank Credit Facilities”).
Bank Credit Facilities
The following table sets out the Bank Credit Facilities available to AQN and its operating groups as at March 31, 2022:
| As at March 31, 2022 | As at Dec 31, 2021 | ||||||||||||||||||||||||||||
| (all dollar amounts in $ millions) | Corporate | Regulated Services Group | Renewable Energy Group | Total | Total | ||||||||||||||||||||||||
| Revolving and term credit facilities | $ | 550.0 | 1 | $ | 1,675.0 | $ | 850.0 | 2 | $ | 3,075.0 | $ | 3,075.0 | |||||||||||||||||
| Funds drawn on facilities/ commercial paper issued | — | (684.7) | (76.0) | (760.7) | (707.6) | ||||||||||||||||||||||||
| Letters of credit issued | (24.7) | (67.2) | (299.7) | (391.6) | (317.2) | ||||||||||||||||||||||||
| Liquidity available under the facilities | 525.3 | 923.1 | 474.3 | 1,922.7 | 2,050.2 | ||||||||||||||||||||||||
| Undrawn portion of uncommitted letter of credit facilities | (29.1) | — | (186.7) | (215.8) | (224.0) | ||||||||||||||||||||||||
| Cash on hand | 93.2 | 125.2 | |||||||||||||||||||||||||||
| Total Liquidity and Capital Reserves | $ | 496.2 | $ | 923.1 | $ | 287.6 | $ | 1,800.1 | $ | 1,951.4 | |||||||||||||||||||
1 Includes a $50 million uncommitted standalone letter of credit facility. | |||||||||||||||||||||||||||||
2 Includes a $350 million uncommitted standalone letter of credit facility. | |||||||||||||||||||||||||||||
Corporate
As at March 31, 2022, the Company's $500.0 million senior unsecured syndicated revolving credit facility (the "Corporate Credit Facility") had no amounts drawn and had $3.8 million of outstanding letters of credit. The Corporate Credit Facility matures on July 12, 2024.
As at March 31, 2022, the Company had also issued $20.9 million of letters of credit from its $50 million uncommitted bi-lateral letter of credit facility.
In conjunction with the Kentucky Power Transaction, AQN obtained a $2,725.0 million syndicated acquisition financing commitment ("Acquisition Bridge"). The Acquisition Bridge was subject to customary terms and conditions, including certain commitment reductions upon closing of permanent financing. As discussed below, the Acquisition Bridge has been terminated.
Regulated Services Group
As at March 31, 2022, the Regulated Services Group's $500.0 million senior unsecured syndicated revolving credit facility (the "Regulated Services Credit Facility") had no amounts drawn and had $67.2 million of outstanding letters of credit. The Regulated Services Credit Facility matures on February 23, 2023. As at March 31, 2022, there was no commercial paper issued and outstanding. Subsequent to quarter-end on April 29, 2022, the Regulated Services Group entered into two new senior unsecured syndicated revolving credit facilities: a $1.0 billion senior unsecured revolving credit facility with an initial maturity date of April 29, 2027 (the "Long Term Regulated Services Credit Facility") and a $500.0 million short-term senior unsecured revolving credit facility maturing on March 31, 2023. Subject to the terms and conditions therein, the Long Term Regulated Services Credit Facility may be extended for two additional one-year periods. In conjunction with the new facilities, the Regulated Services Credit Facility and the Acquisition Bridge were terminated.
As at March 31, 2022, the Regulated Services Group's $75.0 million senior unsecured revolving credit facility (the "BELCO Credit Facility") had $74.3 million drawn. The BELCO Credit Facility was amended to extend the maturity to June 30, 2022. The Company expects to refinance the BELCO Credit Facility before maturity.
On December 20, 2021, the Regulated Services Group entered into a $1.1 billion senior unsecured syndicated delayed draw term facility ("the "Regulated Services Delayed Draw Term Facility") which matures on December 19, 2022. As at March 31, 2022, the Regulated Services Delayed Draw Term Facility had $610.4 million drawn in connection with the acquisition of Liberty NY Water.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 35 | ||||
Renewable Energy Group
As at March 31, 2022, the Renewable Energy Group's bank lines consisted of a $500.0 million senior unsecured syndicated revolving credit facility (the "Renewable Energy Credit Facility") maturing on October 6, 2023 and a $350.0 million letter of credit facility ("Renewable Energy LC Facility") that was amended to extend the maturity to June 30, 2023. As at March 31, 2022, the Renewable Energy Credit Facility had $76.0 million drawn and had $136.3 million in outstanding letters of credit. As at March 31, 2022, the Renewable Energy LC Facility had $163.3 million in outstanding letters of credit.
Long Term Debt
On February 15, 2022, the Company repaid a C$200.0 million senior unsecured note on its maturity.
Subsequent to quarter-end on April 30, 2022, the Company repaid a $80.0 million senior unsecured note on its maturity.
Issuance of approximately $1.1 Billion of Subordinated Notes
On January 18, 2022, the Company closed (i) an underwritten public offering in the United States of $750 million aggregate principal amount of the U.S. Notes; and (ii) an underwritten public offering in Canada of C$400 million aggregate principal amount of the Canadian Notes. Concurrent with the pricing of the Note Offerings, the Company entered into a cross currency interest rate swap to convert the Canadian dollar denominated proceeds from the Canadian Note Offering into U.S. dollars and a forward starting swap to fix the interest rate for the second five year term of the U.S. Notes, resulting in an anticipated effective interest rate to the Company of approximately 4.95% throughout the first ten year period of the Notes. The Note Offerings were assigned a BB+ rating from S&P and Fitch.
The Company intends to use the net proceeds of the Note Offerings to partially finance the Kentucky Power Transaction, provided that, in the short-term, prior to the closing of the Kentucky Power Transaction, the Company has used such net proceeds to repay certain indebtedness of the Corporation and its subsidiaries.
Credit Ratings
AQN has a long term consolidated corporate credit rating of BBB from S&P, a BBB rating from DBRS and a BBB issuer rating from Fitch. Liberty Utilities has a corporate credit rating of BBB from S&P and a BBB issuer rating from Fitch. Debt issued by Liberty Utilities Finance GP1 (“Liberty GP”) has a rating of BBB (high) from DBRS, BBB+ from Fitch and BBB from S&P. Empire has an issuer rating of BBB from S&P and a Baa1 rating from Moody's Investors Service, Inc. Liberty Utilities (Canada) LP, the parent company for the Canadian regulated utilities under the Regulated Services Group, has an issuer rating of BBB from DBRS. APCo has a BBB issuer rating from S&P, a BBB issuer rating from DBRS and a BBB issuer rating from Fitch.
On October 28, 2021, following the announcement of the Kentucky Power Transaction, each of DBRS, Fitch and S&P made announcements regarding the credit ratings of the Corporation and its subsidiaries.
Fitch affirmed (i) the existing issuer ratings of both the Corporation and Liberty Utilities (‘BBB’ Long-Term Issuer Default Rating (“IDR”) and ‘F2’ Short-Term IDR, respectively), and (ii) all the security ratings of the Corporation, Liberty Utilities and Liberty GP. Fitch also noted that the rating outlooks for the Corporation and Liberty Utilities are stable and that the credit ratings of APCo are unaffected by the Kentucky Power Transaction. Fitch noted that it views the Kentucky Power Transaction to be neutral to the credit quality of the Corporation and Liberty Utilities, given the underlying credit quality of Kentucky Power, and what Fitch expects to be a relatively credit-supportive financing plan for the Kentucky Power Transaction.
DBRS placed the Corporation’s ‘BBB’ Issuer Rating and ‘Pfd-3’ Preferred Shares ratings ‘Under Review with Developing Implications’. DBRS indicated that it views the Kentucky Power Transaction as a positive development from a business risk perspective due to the expected increase in the Corporation’s regulated assets and rate base and expected improvements in jurisdictional diversification and capital expenditure planning. Notwithstanding these potentially positive impacts, the ‘Under Review with Developing Implications’ rating action reflects DBRS’s view that the Corporation’s financing plan for the Kentucky Power Transaction, which may include the issuance of hybrid debt, could increase the Corporation’s nonconsolidated leverage. DBRS noted that if the Corporation’s nonconsolidated debt-to-capital ratio, as calculated by DBRS, rises significantly above 20% following the issuance of any hybrid debt, a negative rating action could be taken.
S&P revised its outlook on the Corporation, Liberty Utilities, APCo, Liberty GP and Empire from stable to negative, noting a lack of certainty regarding the Corporation’s financing plan for the Kentucky Power Transaction, beyond the Common Equity Offering, which could expose the Corporation to execution risks related to the procurement of credit supportive funding. S&P also noted that the negative outlook incorporates the possibility of any material adverse regulatory requirements which may be necessary to close the Kentucky Power Transaction. S&P also affirmed its ‘BBB’ issuer credit rating for each of the Corporation, Liberty Utilities, APCo, Liberty GP and Empire. Finally, S&P placed its rating on Liberty GP’s senior unsecured debt on CreditWatch with negative implications to reflect its view of the potential for such debt to be structurally subordinated following the closing of the Kentucky Power Transaction.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 36 | ||||
During the first quarter of 2022 or subsequent to quarter-end, S&P, Fitch, Moody's and DBRS affirmed their existing ratings. In addition, S&P removed the "CreditWatch with negative implications" from Liberty GP's senior unsecured debt.
Contractual Obligations
Information concerning contractual obligations as of March 31, 2022 is shown below:
| (all dollar amounts in $ millions) | Total | Due in less than 1 year | Due in 1 to 3 years | Due in 4 to 5 years | Due after 5 years | ||||||||||||||||||||||||
Principal repayments on debt obligations1,2 | $ | 7,213.2 | $ | 978.8 | $ | 544.8 | $ | 1,218.4 | $ | 4,471.2 | |||||||||||||||||||
| Advances in aid of construction | 88.9 | 1.8 | — | — | 87.1 | ||||||||||||||||||||||||
Interest on long-term debt obligations2 | 5,177.8 | 237.6 | 444.2 | 408.1 | 4,087.9 | ||||||||||||||||||||||||
| Purchase obligations | 571.7 | 571.7 | — | — | — | ||||||||||||||||||||||||
| Environmental obligations | 44.8 | 6.8 | 17.6 | 1.0 | 19.4 | ||||||||||||||||||||||||
| Derivative financial instruments: | |||||||||||||||||||||||||||||
| Cross currency interest rate swaps | 49.2 | 2.0 | 28.6 | 1.1 | 17.5 | ||||||||||||||||||||||||
| Interest rate swaps | 2.9 | 1.6 | 0.2 | 0.7 | 0.4 | ||||||||||||||||||||||||
| Energy derivative and commodity contracts | 103.3 | 32.7 | 32.3 | 19.1 | 19.2 | ||||||||||||||||||||||||
| Purchased power | 308.3 | 48.7 | 68.3 | 39.3 | 152.0 | ||||||||||||||||||||||||
| Gas delivery, service and supply agreements | 461.4 | 94.0 | 124.1 | 70.0 | 173.3 | ||||||||||||||||||||||||
| Service agreements | 622.4 | 65.2 | 117.0 | 103.7 | 336.5 | ||||||||||||||||||||||||
| Capital projects | 65.4 | 65.4 | — | — | — | ||||||||||||||||||||||||
| Land easements | 535.5 | 13.0 | 26.4 | 27.1 | 469.0 | ||||||||||||||||||||||||
| Contract adjustment payments on equity units | 169.3 | 75.6 | 93.7 | — | — | ||||||||||||||||||||||||
| Other obligations | 328.2 | 67.2 | 5.4 | 5.3 | 250.3 | ||||||||||||||||||||||||
| Total Obligations | $ | 15,742.3 | $ | 2,262.1 | $ | 1,502.6 | $ | 1,893.8 | $ | 10,083.8 | |||||||||||||||||||
| 1 | Exclusive of deferred financing costs, bond premium/discount, fair value adjustments at the time of issuance or acquisition. | ||||
| 2 | The Company's subordinated unsecured notes have a maturity in 2078, 2079, and 2082 respectively. However, the Company currently anticipates repaying in 2023, 2029, and 2032 upon exercising its redemption right. | ||||
Equity
The common shares of AQN are publicly traded on the Toronto Stock Exchange ("TSX") and the New York Stock Exchange ("NYSE") under the trading symbol "AQN". As at May 11, 2022, AQN had 675,544,895 issued and outstanding common shares.
AQN may issue an unlimited number of common shares. The holders of common shares are entitled to dividends, if and when declared; to one vote for each share at meetings of the holders of common shares; and to receive a pro rata share of any remaining property and assets of AQN upon liquidation, dissolution or winding up of AQN. All shares are of the same class and with equal rights and privileges and are not subject to future calls or assessments.
AQN is also authorized to issue an unlimited number of preferred shares, issuable in one or more series, containing terms and conditions as approved by the Board. As at March 31, 2022, AQN had outstanding:
•4,800,000 cumulative rate reset Series A preferred shares, yielding 5.162% annually for the five-year period ending on December 31, 2023;
•100 Series C preferred shares that were issued in exchange for 100 Class B limited partnership units by St. Leon Wind Energy LP; and
•4,000,000 cumulative rate reset Series D preferred shares, yielding 5.091% annually for the five year period ending on March 31, 2024.
In addition, AQN’s outstanding equity units (the "Green Equity Units") (that are in the form of "corporate units") are listed on the NYSE under the ticker symbol "AQNU". As at May 11, 2022, there were 23,000,000 Green Equity Units outstanding. Pursuant to the purchase contract forming part of each outstanding Green Equity Unit, holders are required to purchase AQN common shares on June 15, 2024. The minimum settlement rate under each purchase contract is 2.7778 common shares and the maximum settlement rate is 3.3333 common shares, resulting in a minimum of 63,889,400 common shares and a maximum of 76,665,900 common shares issuable on settlement of the purchase contracts.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | |||||
At-The-Market Equity Program
On May 15, 2020, AQN re-established an at-the-market equity program ("ATM program") that allowed the Company to issue up to $500 million of common shares from treasury to the public from time to time, at the Company's discretion, at the prevailing market price when issued on the TSX, the NYSE, or any other existing trading market for the common shares of the Company in Canada or the United States. On November 19, 2021, in connection with the filing of a new base shelf prospectus, AQN withdrew the base shelf prospectus qualifying the ATM program.
As at May 12, 2022, the Company has issued since the inception of the ATM program in 2019 a cumulative total of 33,952,827 common shares under the ATM program at an average price of $15.08 per share for gross proceeds of approximately $512.2 million ($505.7 million net of commissions). Other related costs, primarily related to the establishment and subsequent re-establishments of the ATM program, were $4.3 million.
Dividend Reinvestment Plan
AQN has a shareholder dividend reinvestment plan (the “Reinvestment Plan”) for registered holders of common shares of AQN. As at March 31, 2022, 124,494,375 common shares representing approximately 18% of total common shares outstanding had been registered with the Reinvestment Plan. During the three months ended March 31, 2022, 1,625,414 common shares were issued under the Reinvestment Plan, and subsequent to quarter-end, on April 14, 2022, an additional 1,388,850 common shares were issued under the Reinvestment Plan.
SHARE-BASED COMPENSATION PLANS
For the three months ended March 31, 2022, AQN recorded $(0.4) million in total share-based compensation expense (recovery) as compared to $1.2 million for the same period in 2021. The compensation expense (recovery) is recorded as part of administrative expenses in the consolidated statement of operations. The portion of share-based compensation costs capitalized as cost of construction is insignificant.
As at March 31, 2022, total unrecognized compensation costs related to non-vested share-based awards was $20.4 million and is expected to be recognized over a period of 2.1 years.
Stock Option Plan
AQN has a stock option plan that permits the grant of share options to officers, directors, employees and selected service providers. Except in certain circumstances, the term of an option shall not exceed ten (10) years from the date of the grant of the option.
AQN determines the fair value of options granted using the Black-Scholes option-pricing model. The estimated fair value of options, including the effect of estimated forfeitures, is recognized as an expense on a straight-line basis over the options’ vesting periods while ensuring that the cumulative amount of compensation cost recognized at least equals the value of the vested portion of the award at that date. During the three months ended March 31, 2022, the Company granted 646,090 options to executives of the Company. The options allow for the purchase of common shares at a weighted average price of C$19.11, the market price of the underlying common share at the date of grant. During the three months ended March 31, 2022, there were no stock options exercised.
As at March 31, 2022, a total of 2,686,618 options were issued and outstanding under the stock option plan.
Performance and Restricted Share Units
AQN issues performance share units (“PSUs”) and restricted share units ("RSUs") to certain employees as part of AQN’s long-term incentive program. During the three months ended March 31, 2022, the Company granted (including dividends and performance adjustments) a combined total of 411,784 PSUs and RSUs to employees of the Company. During the three months ended March 31, 2022, the Company settled 797,034 PSUs, of which 409,986 PSUs were exchanged for common shares issued from treasury and 387,048 PSUs were settled at their cash value as payment for tax withholdings related to the settlement of the PSUs.
As at March 31, 2022, a combined total of 2,058,422 PSUs and RSUs were granted and outstanding under the performance and restricted share unit plan.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 38 | ||||
Directors' Deferred Share Units
AQN has a Directors' Deferred Share Unit Plan. Under the plan, non-employee directors of AQN receive all or any portion of their annual compensation in deferred share units (“DSUs”) and may elect to receive any portion of their remaining compensation in DSUs. The DSUs provide for settlement in cash or common shares at the election of AQN. As AQN does not expect to settle the DSUs in cash, these DSUs are accounted for as equity awards. During the three months ended March 31, 2022, the Company issued 21,149 DSUs (including DSUs in lieu of dividends) to the non-employee directors of the Company. During the three months ended March 31, 2022, the Company settled 5,176 DSUs, of which 2,403 DSUs were exchanged for common shares issued from treasury and 2,773 DSUs were settled at their cash value as payment for tax withholdings related to the settlement of DSUs.
As at March 31, 2022, a total of 546,350 DSUs were outstanding under the Directors’ Deferred Share Unit Plan.
Bonus Deferral Restricted Share Units
The Company has a bonus deferral RSU program that is available to certain employees. The eligible employees have the option to receive a portion or all of their annual bonus payment in RSUs in lieu of cash. The RSUs provide for settlement in common shares, and therefore these RSUs are accounted for as equity awards. During the three months ended March 31, 2022, the Company settled 4,108 bonus RSUs, of which 1,908 were exchanged for common shares issued from treasury and 2,200 RSUs were settled at their cash value as payment for tax withholdings related to the settlement of the RSUs. Subsequent to the quarter, on April 15, 2022, 3,397 bonus deferral RSUs were granted (including RSUs in lieu of dividends) to employees of the Company pursuant to the bonus deferral RSU program. The RSUs are 100% vested.
Employee Share Purchase Plan
AQN has an Employee Share Purchase Plan (the “ESPP”) which allows eligible employees to use a portion of their earnings to purchase common shares of AQN. The aggregate number of common shares reserved for issuance from treasury by AQN under this plan shall not exceed 4,000,000 shares. During the three months ended March 31, 2022, the Company issued 109,449 common shares to employees under the ESPP.
As at March 31, 2022, a total of 2,053,061 shares had been issued under the ESPP.
RELATED PARTY TRANSACTIONS
Equity-method investments
The Company entered into a number of transactions with equity-method investees in 2022 and 2021 (see Note 6 in the unaudited interim consolidated financial statements).
The Company provides administrative and development services to its equity-method investees and is reimbursed for incurred costs. To that effect, the Company charged its equity-method investees $7.4 million in the first quarter of 2022, as compared to $6.3 million during the same period in 2021. Additionally, one of the equity-method investees provides development services to the Company on specified projects, for which it earns a development fee upon reaching certain milestones. During the first quarter of 2022, the development fees charged to the Company were $nil as compared to $0.7 million during the same period in 2021. See Note 13 in the unaudited interim consolidated financial statements.
In 2021, a subsidiary of the Company made a tax equity investment into New Market Solar Investco, LLC, an equity investee of the Company and indirect owner of the New Market Solar Project. Following the closing of the construction financing facility for the New Market Solar Project, certain excess funds were distributed to the Company and in return the Company issued a promissory note of $25.8 million payable to New Market Solar Investco, LLC.
In 2021, the Sandy Ridge II Wind Project, the Shady Oaks II Wind Project and the New Market Solar Project were contributed into joint venture entities in exchange for 50% equity interests in the joint ventures and loans receivable in the net amount of $10.8 million and a contract asset of $17.0 million recognized for the portion of consideration payable upon mechanical completion but in no event later than December 31, 2022. The transfer of the New Market Solar Project resulted in a gain of $26.2 million.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 39 | ||||
During the third quarter of 2021, the Company paid $1.5 million to Abengoa S.A. to purchase all of Abengoa S.A.'s interests in the AAGES, AAGES Development Canada Inc., and AAGES Development Spain, S.A. joint ventures. The assets acquired for AAGES Development Spain S.A included project development assets for $2.7 million and working capital of $1.5 million. The existing loan between the Company and the partnership of $3.1 million was treated as additional consideration incurred to acquire the partnership. Pursuant to an agreement between AQN and funds managed by the Infrastructure and Power strategy of Ares Management, LLC (“Ares”), in November 2021, Ares became AQN’s new partner in its non-regulated development platform for renewable energy, water and other sectors through an investment in the AAGES and AAGES Development Canada Inc. joint ventures (collectively, the "Liberty JV").
Redeemable non-controlling interest held by related party
Redeemable non-controlling interest held by related party represents a preference share in a consolidated subsidiary of the Company acquired by Liberty Global Energy Solutions (see Note 13 in the unaudited interim consolidated financial statements). Redemption is not considered probable as at March 31, 2022. The preference share was used to finance a portion of the Company's investment in Atlantica. The Company incurred non-controlling interest attributable to Liberty Global Energy Solutions of $2.6 million in 2022 as compared to $2.7 million during the same period in 2021 and recorded distributions of $2.6 million in 2022 as compared to $2.5 million during the same period in 2021 (see Note 13 in the unaudited interim consolidated financial statements).
Non-controlling interest held by related party
Non-controlling interest held by related party represents interest in a consolidated subsidiary of the Company acquired by a subsidiary of Atlantica in May 2019 for $96.8 million. The interest was used to finance a portion of the Company's investment in the Amherst Island Wind Facility. During 2022 the Company recorded distributions of $7.4 million as compared to $4.5 million during the same period in 2021.
The above related party transactions have been recorded at the exchange amounts agreed to by the parties to the transactions.
Transactions with Atlantica
During 2021, the Company sold Colombian solar assets to Atlantica for consideration of approximately $23.9 million, with a gain on sale of $0.9 million, and contingent consideration of approximately $2.6 million, if certain milestones are met. For the three months ended March 31, 2022, a gain of $1.2 million relating to the contingent consideration has been recognized.
ENTERPRISE RISK MANAGEMENT
The Corporation is subject to a number of risks and uncertainties, certain of which are described below. A risk is the possibility that an event might happen in the future that could have a negative effect on the financial condition, financial performance or business of the Corporation. The actual effect of any event on the Corporation’s business could be materially different from what is anticipated or described below. The description of risks below does not include all possible risks.
Led by the Chief Compliance and Risk Officer, the Corporation has an established enterprise risk management ("ERM") framework. The Corporation’s ERM framework follows the guidance of ISO 31000 and the Committee of Sponsoring Organizations of the Treadway Commission ("COSO") Enterprise Risk Management - Integrated Framework. The Corporation’s ERM Policy details the Corporation’s risk management processes and risk governance structure.
As part of the risk management process, risk registers have been developed across the organization through ongoing risk identification and risk assessment exercises facilitated by the Corporation’s internal ERM team. Key risks and associated mitigation strategies are reviewed by the executive-level Enterprise Risk Management Council and are presented to the Board’s Risk Committee periodically.
Identified risks are evaluated using a standardized risk scoring matrix to assess impact and likelihood. Financial, safety, security, reputational, reliability, and planned execution implications are among those considered when determining the impact of a potential risk. Risk treatment priorities are established based upon these risk assessments and incorporated into the development of the Corporation’s strategic and business plans. However, there can be no assurance that the Corporation's risk management activities will be successful in identifying, assessing, or mitigating the risks to which the Corporation is subject.
The risks discussed below are not intended as a complete list of all risks that AQN, its subsidiaries and affiliates are encountering or may encounter. Please see the Company's most recent AIF and Annual MD&A available on SEDAR and EDGAR for a further discussion of risk factors to which the Company is subject. To the extent of any inconsistency, the risks discussed below are intended to provide an update on those that were previously disclosed.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 40 | ||||
Risks Related to COVID-19
The COVID-19 situation remains fluid and its full impact on the Company’s business, financial condition, cash flows and results of operations is not fully known at this time. In addition to the risks and impacts described elsewhere in this MD&A, the COVID-19 pandemic and efforts to contain the virus could result in:
•operating, supply chain and project development and construction delays, disruptions and cost overruns;
•delayed collection of accounts receivable and increased levels of bad debt expense;
•delayed placed-in-service dates for the Company's renewable energy projects, which may give rise to, among other things, lower than anticipated revenue, delay-related liabilities to contractual counterparties and increased amounts of interest payable to construction lenders;
•reduced availability of funding under construction loans and tax equity financing, which may require the Company to initially increase its funding and, if possible, directly realize the tax benefits;
•lower revenue from the Company’s utility operations, including as a result of decreased demand and consumption by customers not covered by rate decoupling;
•negative impacts to the Company's existing and planned rate reviews, including non-recovery of certain costs incurred directly or indirectly as a result of the COVID-19 pandemic and delays in filing, processing and settlement of the reviews;
•introduction of new legislation, policies, rules or regulations that adversely impact the Company;
•labour shortages and shutdowns (including as a result of government regulation and prevention measures), reduced employee and/or contractor productivity, and loss of key personnel;
•inability to implement the Company’s growth strategy, including sourcing new acquisitions and completing previously-announced acquisitions;
•inability to carry out the Company’s capital expenditure plans on previously anticipated timelines;
•lower earnings from unhedged power generation as a result of lower wholesale commodity prices in energy markets;
•losses or liabilities resulting from default, delays or non-performance by either the Company or its counterparties under the Company’s contracts, including joint venture agreements, supply agreements, construction agreements, services agreements and power purchase and other offtake agreements;
•lower revenue from the Company's power generation facilities as a result of system load reduction and related system directed curtailments;
•delay in the permitting process of certain development projects, affecting the timing of final investment decisions and start of construction dates;
•reduced ability of the Company and its employees to effectively respond to, or mitigate the effects of, another force majeure or other significant event;
•increased operating costs for emergency supplies, personal protective equipment, cleaning services, enabling technology and other specific needs in response to COVID-19, some of which may not be recovered through future rates;
•increased market volatility and lower pension plan returns which could adversely impact the valuation of pension plan assets and future funding requirements for the Company's pension plans;
•deterioration in financial metrics and other factors that impact the Company’s credit ratings;
•inability to meet the requirements of the covenants in existing credit facilities;
•inability to access credit and capital markets on acceptable terms or at all, including to refinance maturing indebtedness;
•IT and operational technology system interruptions, loss of critical data and increased cybersecurity and privacy breaches due to “work from home” arrangements implemented by the Company;
•business disruptions and costs as "work from home" arrangements are reduced and a greater number of employees return to the office;
•losses to the Company caused by fluctuations and volatility in the trading price of Atlantica’s ordinary shares or reduction of the dividend paid to holders of Atlantica’s ordinary shares; and
•fluctuations and volatility in the trading price of the Company’s common shares and other securities, which could result in losses for the Company’s security holders.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 41 | ||||
The COVID-19 pandemic may also have the effect of heightening the other risks described herein, under the heading Enterprise Risk Management in the Company’s Annual MD&A and under the heading Enterprise Risk Factors in the Company's most recent AIF. The adverse impacts of COVID-19 on the Company can be expected to increase the longer the pandemic and the related response measures persist.
Treasury Risk Management
Interest Rate Risk
The Company is exposed to interest rate risk from certain outstanding variable interest indebtedness and any new credit facilities and debt issuances. Fluctuations in interest rates may also impact the costs to obtain other forms of capital.
In addition, for the Regulated Services Group, costs resulting from interest rate increases may not be recoverable in whole or in part, and “regulatory lag” may cause a time delay in the payment to the Regulated Services Group of any such costs that are recoverable. Rising interest rates may also negatively impact the economics of development projects and energy facilities, especially where project financing is being renewed or arranged.
As a result, fluctuations in interest rates could materially increase the Corporation’s financing costs, limit the Corporation’s options for financing, and adversely affect its results of operations, cash flows, key credit metrics, borrowing capacity and ability to implement its business strategy.
As at March 31, 2022, approximately 88% of debt outstanding in AQN and its subsidiaries was subject to a fixed rate of interest and as such is not subject to significant interest rate risk in the short to medium term time horizon.
Borrowings subject to variable interest rates can vary significantly from month to month, quarter to quarter and year to year. AQN does not actively manage interest rate risk on its variable interest rate borrowings due to the primarily short term and revolving nature of the amounts drawn.
Based on amounts outstanding as at March 31, 2022, the impact to interest expense from changes in interest rates are as follows:
•the Corporate Credit Facility is subject to a variable interest rate and had no amounts outstanding as at March 31, 2022. As a result, a 100 basis point change in the variable rate charged would not impact interest expense;
•the Regulated Services Credit Facility is subject to a variable interest rate and had no amounts outstanding as at March 31, 2022. As a result, a 100 basis point change in the variable rate charged would not impact interest expense;
•the Regulated Services Delayed Draw Term Facility is subject to a variable interest rate and had $610.4 million outstanding as at March 31, 2022. As a result, a 100 basis point change in the variable rate charged would impact interest expense by $6.1 million annually;
•the BELCO Credit Facility is subject to a variable interest rate and had $74.3 million outstanding as at March 31, 2022. As a result, a 100 basis point change in the variable rate charged would impact interest expense by $0.7 million annually;
•the Regulated Services Group's commercial paper program is subject to a variable interest rate and had no amounts outstanding as at March 31, 2022. As a result, a 100 basis point change in the variable rate charged would not impact interest expense;
•the Renewable Energy Credit Facility is subject to a variable interest rate and had $76.0 million outstanding as at March 31, 2022. As a result, a 100 basis point change in the variable rate charged would impact interest expense by $0.8 million annually; and
•term facilities at BELCO and ESSAL that are subject to variable interest rates had $66.4 million outstanding as at March 31, 2022. As a result, a 100 basis point change in the variable rate charged would impact interest expense by $0.7 million annually.
On January 13, 2022, the Company entered into a forward starting swap to fix the interest rate for the second five-year term of the U.S. Notes.
Tax Risk and Uncertainty
The Corporation is subject to income and other taxes primarily in the United States and Canada; however, it is also subject to income and other taxes in international jurisdictions, such as Chile and Bermuda. Changes in tax laws or interpretations thereof in the jurisdictions in which the Corporation does business could adversely affect the Company's results from
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | |||||
operations, returns to shareholders, and cash flows. One or more taxing jurisdictions could seek to impose incremental or new taxes on the Company pursuant to one of the following or otherwise:
•Tax legislative proposals have been drafted in the U.S. that include a minimum tax, increase in tax rates, additional interest limitations, and extension of clean energy tax credits. It is unknown when legislation incorporating these proposals could be enacted.
•On April 19, 2021, the Canadian federal government delivered its 2021 budget which contained proposed measures related to limitations on interest deductibility and changes in relation to international taxation. Draft legislative proposals pertaining to interest deductibility and other matters were released for public comment on February 4, 2022 and are expected to be effective beginning in 2023. The Corporation is currently reviewing the legislative proposals to determine the impact to the Corporation. The proposed rules and their application are complex and could have a material adverse impact on the Corporation's effective tax rate and financial results in future years if enacted as drafted.
•As a consequence of the Organization for Economic Cooperation and Development’s (“OECD”) project on “Base Erosion and Profit Shifting”, there could be a focus by taxing authorities to pursue common international principles for the entitlement to taxation of global corporate profits and minimum global tax rates. In December 2021, the OECD released model legislation outlining how a global minimum tax would apply. Each local jurisdiction will need to draft their own legislation to enact these minimum tax rules with application expected no earlier than January 1, 2023.
The Corporation cannot provide assurance that the Canada Revenue Agency, the Internal Revenue Service or any other applicable taxation authority will agree with the tax positions taken by the Corporation, including with respect to claimed expenses and the cost amount of the Corporation’s depreciable properties. A successful challenge by an applicable taxation authority regarding such tax positions could adversely affect the results of operations and financial position of the Corporation.
Development by the Corporation of renewable power generation facilities in the United States depends in part on federal tax credits and other tax incentives. These credits are currently subject to a multi-year step-down. While recently enacted U.S. tax reform legislation did extend some of the credits, at reduced levels, for solar facilities that begin construction in 2021, 2022 and 2023 and for wind facilities that began construction in 2021, there can be no assurance that there will be further extensions in the future or that the reduced credits will be sufficient to support continued development and construction of renewable power facilities in the United States. Moreover, if the Corporation is unable to complete construction on current or planned projects on anticipated schedules, the reduced incentives may be insufficient to support continued development or may result in substantially reduced financial benefits from facilities or long-term investment in facilities that the Corporation is committed to complete. In addition, the Corporation has entered into certain tax equity financing transactions with financial partners for certain of its renewable power facilities in the United States, under which allocations of future cash flows to the Corporation from the applicable facility could be adversely affected in the event that there are changes in U.S. tax laws that apply to facilities previously placed in service.
OPERATIONAL RISK MANAGEMENT
Inflation Risk
AQN's profitability could be impacted by inflation increases above long-term averages. The Regulated Services Group’s facilities are subject to rate setting by its regulatory agencies. The time between the incurrence of costs and the granting of the rates to recover those costs by regulatory agencies is known as regulatory lag. As a result of regulatory lag, inflationary effects and timing delays may impact the ability to recover expenses and/or capital costs, and profitability could be impacted. In the event of significant inflation, the impact of regulatory lag on the Company would be increased. In order to mitigate this exposure, the Regulated Services Group seeks to obtain approval for regulatory constructs in the states in which it operates to allow for timely recovery of operating expenses and capital costs.
The Renewable Energy Group's assets subject to long term PPAs, some of which are not indexed to inflation and could experience declines in profitability if operating costs increase at a rate greater than the offtake price.
Development and construction projects could experience a decrease in expected returns as a result of increased costs. To mitigate the risk of inflation the Company attempts to enter into fixed price constructions agreements and fixed price offtake agreements.
Tariff Risk
Changes in tariffs or duties, such as antidumping and countervailing duty rates that could be put in place as a result of the U.S. Department of Commerce's investigation into an antidumping and countervailing duties circumvention claim on solar cells and panels supplied from Malaysia, Vietnam, Thailand and Cambodia, may adversely affect the capital expenditures required to develop or construct the Corporation’s projects, as well as the timing for completion, or viability, of such
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 43 | ||||
projects. In the U.S., tariffs have been imposed in recent years to imports of solar panels, aluminum and steel, among other goods and raw materials. These occurrences may have adverse impacts to the Corporation, as the buyer of goods, which could adversely affect the Corporation’s expected returns, results of operations and cash flows.
Risks Relating to the Kentucky Power Transaction
The closing of the Kentucky Power Transaction is subject to the normal commercial risks that such acquisition will not close on the terms negotiated or at all. The Kentucky Power Transaction remains subject to closing conditions, including certain regulatory and governmental approvals. The failure to satisfy or waive the conditions may result in the termination of the acquisition agreement. Accordingly, there can be no assurance that the Company will complete the Kentucky Power Transaction in the timeframe or on the basis described herein, if at all. As the Kentucky Power Transaction is subject to various regulatory approvals, it is consequently subject to the risks that such approvals may not be timely obtained or may impose unfavourable conditions that could impair the ability to complete the acquisition or impose adverse conditions on the Company in order to complete the acquisition. The presence of intervenors in the regulatory approval process has the effect of increasing these risks.
If the Kentucky Power Transaction is not completed, the Company could be subject to a number of risks that may adversely affect the Company’s business, financial condition, results of operations, reputation and cash flows, including (i) the requirement to pay costs relating to the Kentucky Power Transaction, including costs relating to the financing thereof and obtaining regulatory approval, (ii) the requirement to find effective new uses for the net proceeds of the Company’s Common Equity Offering and Note Offerings, and (ii) time and resources committed by the Company’s management to matters relating to the Kentucky Power Transaction that could otherwise have been devoted to pursuing other beneficial opportunities. In addition, if the acquisition agreement for the Kentucky Power Transaction is terminated in certain circumstances, the Company may be required to pay a termination fee of $65 million. See “Significant Updates”.
Business combinations such as the Kentucky Power Transaction involve risks that could materially and adversely affect the Company’s business plan, including the failure to realize the results that the Company expects. Transition and integration activities associated with this business combination may not go as planned, creating the potential for increased costs, service disruption, noncompliance, reputational harm and other negative outcomes. There can be no assurance that the Company will be successful in increasing the historical returns earned by either of Kentucky Power or Kentucky Transco, that the load declines experienced by Kentucky Power over recent years will not continue to be a prevailing trend, or that the Company will be able to fully realize some or all of the expected benefits of the Kentucky Power Transaction or succeed in implementing its strategic objectives relating to the acquired entities, including the transfer of operational control of the Mitchell Plant from Kentucky Power to the Wheeling Power Company and the transition of Kentucky Power’s generating mix to greener sources (i.e. “greening the fleet” initiatives). The ability to realize these anticipated benefits and implement these strategic objectives will depend in part on successfully retaining staff, hiring additional staff to replace certain of the vendors’ centralized operations, obtaining favourable regulatory outcomes, realizing growth opportunities, no unanticipated economic changes in the areas where the acquired entities operate, and potential synergies through the coordination of activities and operations with the Company’s existing business. There is a risk that some or all of the expected benefits and strategic objectives will fail to materialize, or may not occur within the time periods anticipated by the Company. A failure to realize the anticipated benefits of or implement strategic objectives relating to the Kentucky Power Transaction on an efficient and effective basis could have a material adverse effect on the Company’s financial condition, results of operations, reputation and cash flows.
A change in the capital structure of the Company could cause credit rating agencies which rate the Company’s outstanding debt obligations to re-evaluate and potentially downgrade the Company’s current credit ratings, which could increase the Company’s borrowing costs and adversely impact the market price of the outstanding securities of the Company.
The Kentucky Power Transaction could also result in a downgrade of the credit rating of Kentucky Power or its outstanding bonds, and could require Kentucky Power to offer to prepay $525 million in principal amount of its outstanding bonds if the credit ratings thereof fall below investment grade (or in the event such bonds are placed on “credit watch” or assigned a “negative outlook” if they are rated BBB- by S&P or Baa3 by Moody’s at such time).
There may be liabilities that the Company failed to discover or was unable to quantify in the Company’s due diligence, and the Company may not have recourse for some or all of these potential liabilities. While the Company has accounted for these potential liabilities for the purposes of making its decision to enter into the acquisition agreement, there can be no assurance that any such liability will not exceed the Company’s estimates. In connection with the Kentucky Power Transaction, the Company has obtained a representation and warranty insurance policy, with coverage up to $255 million, subject to an initial retention of $21 million. Nevertheless, this insurance policy is subject to certain exclusions and limitations and there may be circumstances for which the insurer attempts to limit such coverage or refuses to indemnify the Company or where the coverage provided under the insurance policy may otherwise be insufficient or inapplicable.
Kentucky Power and Kentucky Transco may be a party to agreements that contain change of control and/or termination for convenience provisions which may be triggered following completion of the Kentucky Power Transaction. The operation of these change of control or termination provisions, if triggered, could result in unanticipated expenses and/or cash payments
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 44 | ||||
following the consummation of the Kentucky Power Transaction or adversely affect the acquired entities’ results of operations and financial condition. Unless these change of control provisions are waived, or the termination provisions are not exercised, by the other party, the operation of any of these provisions could adversely affect the results of operations and financial condition of the Company and the acquired entities.
All of the electricity generated by Kentucky Power is produced by the combustion of fossil fuels. As a result, the acquisition of Kentucky Power could result in reputational harm to the Company and adversely affect perceptions regarding the Company’s commitment to environmental and sustainability matters, as well as the Company’s ability to accomplish its environmental and sustainability objectives. The operation of fossil-fueled generation plants, including resulting emissions of nitrogen and sulfur oxides, mercury and particulates and the discharge and disposal of solid waste (including coal-combustion residuals (“CCRs”)), is subject to extensive federal, state and local environmental statutes, rules and regulations relating to air quality, water quality, waste management, natural resources and health and safety. Compliance with these requirements requires Kentucky Power to incur significant costs, including capital expenditures, for environmental monitoring, installation of pollution control equipment, emission fees, disposal activities, decommissioning, and permitting obligations at its facilities. If these compliance costs become uneconomical, Kentucky Power may ultimately be required to retire generating capacity prior to the end of its estimated life. The costs of complying with these legal requirements could also adversely affect Kentucky Power’s results of operations, financial condition and cash flows, and those of the Company following the closing of the Kentucky Power Transaction. In addition, the impacts could become even more significant if existing requirements governing air emissions management and disposal, CCR waste and/or waste matter discharge become more restrictive in the future, more extensive operating and/or permitting requirements are imposed or additional substances associated with power generation are subjected to increased regulation. Although Kentucky Power typically recovers expenditures for pollution control technologies, replacement generation, undepreciated plant balances and associated operating costs from customers, there can be no assurance that Kentucky Power will be able to obtain a rate order to fully recover the remaining costs associated with such plants in the future. The failure to recover these costs could reduce Kentucky Power’s results of operations, financial condition and cash flows, and those of the Company following the closing of the Kentucky Power Transaction.
In addition, future changes to environmental laws, including with respect to the regulation of CO2 emissions, could cause Kentucky Power to incur materially higher costs than it has incurred to date.
Litigation Risks and Other Contingencies
AQN and certain of its subsidiaries are involved in various litigation, claims and other legal and regulatory proceedings that arise from time to time in the ordinary course of business. Any accruals for contingencies related to these items are recorded in the financial statements at the time it is concluded that a material financial loss is likely and the related liability is estimable. Anticipated recoveries under existing insurance policies are recorded when reasonably assured of recovery.
Mountain View Fire
On November 17, 2020, a wildfire now known as the Mountain View fire occurred in the territory of Liberty Utilities (CalPeco Electric) LLC ("Liberty CalPeco"). The cause of the fire is undetermined at this time, and CAL FIRE has not yet issued a report. There are currently 10 active lawsuits that name the Company and/or certain of its subsidiaries as defendants in connection with the Mountain View fire. Five of these lawsuits are brought by groups of individual plaintiffs alleging causes of action including negligence, inverse condemnation, nuisance, trespass, and violations of Cal. Pub. Util. Code 2106 and Cal. Health and Safety Code 13007. In the sixth active lawsuit, County of Mono, Antelope Valley Fire Protection District, Toiyabe Indian Health Project, and Bridgeport Indian Colony allege similar causes of action and seek damages for fire suppression costs, law enforcement costs, property and infrastructure damage, and other costs. In three other lawsuits, insurance companies allege inverse condemnation and negligence and seek recovery of amounts paid and to be paid to their insureds. The tenth lawsuit alleges the wrongful death of an individual, along with causes of action similar to those alleged in the cases filed by groups of individual plaintiffs. The likelihood of success in these lawsuits cannot be reasonably predicted. Liberty CalPeco intends to vigorously defend them. The Company has wildfire liability insurance that is expected to apply up to applicable policy limits.
Apple Valley Condemnation Proceedings
On January 7, 2016, the Town of Apple Valley filed a lawsuit seeking to condemn the utility assets of Liberty Utilities (Apple Valley Ranchos Water) Corp. (“Liberty Apple Valley”). On May 7, 2021, the Court issued a Tentative Statement of Decision denying the Town of Apple Valley’s attempt to take the Apple Valley water system by eminent domain. The ruling confirmed that Liberty Apple Valley’s continued ownership and operation of the water system is in the best interest of the community. The Town filed its objections to the Tentative Decision on June 1, 2021. On October 14, 2021, the Court denied the Town’s objections and issued the Final Statement of Decision. The Court signed and entered an Order of Dismissal and Judgment on November 12, 2021. On January 7, 2022, the Town filed a notice of appeal of the judgment entered by the Court.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 45 | ||||
QUARTERLY FINANCIAL INFORMATION
The following is a summary of unaudited quarterly financial information for the eight quarters ended March 31, 2022:
| (all dollar amounts in $ millions except per share information) | 2nd Quarter 2021 | 3rd Quarter 2021 | 4th Quarter 2021 | 1st Quarter 2022 | |||||||||||||||||||
| Revenue | $ | 527.5 | $ | 528.6 | $ | 594.8 | $ | 735.7 | |||||||||||||||
| Net earnings (loss) attributable to shareholders | 103.2 | (27.9) | 175.6 | 91.0 | |||||||||||||||||||
| Net earnings (loss) per share | 0.16 | (0.05) | 0.27 | 0.13 | |||||||||||||||||||
| Diluted net earnings (loss) per share | 0.16 | (0.05) | 0.26 | 0.13 | |||||||||||||||||||
Adjusted Net Earnings1 | 91.7 | 97.6 | 136.3 | 141.3 | |||||||||||||||||||
Adjusted Net Earnings per common share1 | 0.15 | 0.15 | 0.21 | 0.21 | |||||||||||||||||||
Adjusted EBITDA1 | 244.9 | 252.0 | 297.6 | 330.6 | |||||||||||||||||||
| Total assets | 16,453.7 | 16,699.0 | 16,785.8 | 17,669.9 | |||||||||||||||||||
Long term debt2 | 6,622.6 | 6,870.3 | 6,211.7 | 7,191.6 | |||||||||||||||||||
| Dividend declared per common share | $ | 0.17 | $ | 0.17 | $ | 0.17 | $ | 0.17 | |||||||||||||||
| 2nd Quarter 2020 | 3rd Quarter 2020 | 4th Quarter 2020 | 1st Quarter 2021 | ||||||||||||||||||||
| Revenue | $ | 343.6 | $ | 376.1 | $ | 491.3 | $ | 634.5 | |||||||||||||||
| Net earnings (loss) attributable to shareholders | 286.2 | 55.9 | 504.2 | 13.9 | |||||||||||||||||||
| Net earnings (loss) per share | 0.54 | 0.09 | 0.84 | 0.02 | |||||||||||||||||||
| Diluted net earnings (loss) per share | 0.53 | 0.09 | 0.83 | 0.02 | |||||||||||||||||||
Adjusted Net Earnings1 | 47.4 | 88.1 | 127.0 | 124.5 | |||||||||||||||||||
Adjusted Net Earnings per common share1 | 0.09 | 0.15 | 0.21 | 0.20 | |||||||||||||||||||
Adjusted EBITDA1 | 176.3 | 197.9 | 253.1 | 282.9 | |||||||||||||||||||
| Total assets | 11,188.0 | 11,739.9 | 13,224.1 | 15,286.1 | |||||||||||||||||||
Long term debt2 | 4,155.1 | 3,978.0 | 4,538.8 | 6,353.7 | |||||||||||||||||||
| Dividend declared per common share | $ | 0.16 | $ | 0.16 | $ | 0.16 | $ | 0.16 | |||||||||||||||
| 1 | See Caution Concerning Non-GAAP Measures. | ||||
| 2 | Includes current portion of long-term debt, long-term debt and convertible debentures. | ||||
The quarterly results are impacted by various factors including seasonal fluctuations and acquisitions of facilities as noted in this MD&A.
Quarterly revenues have fluctuated between $343.6 million and $735.7 million over the prior two year period. A number of factors impact quarterly results including acquisitions, seasonal fluctuations, and winter and summer rates built into the PPAs. In addition, a factor impacting revenues year over year is the fluctuation in the strength of the Canadian dollar relative to the U.S. dollar which can result in significant changes in reported revenue from Canadian operations.
Quarterly net earnings attributable to shareholders have fluctuated between a loss of $27.9 million and earnings of $504.2 million over the prior two year period. Earnings have been significantly impacted by non-cash factors such as deferred tax recovery and expense, impairment of intangibles, property, plant and equipment and mark-to-market gains and losses on financial instruments.
DISCLOSURE CONTROLS AND PROCEDURES
AQN's management carried out an evaluation as of March 31, 2022, under the supervision of and with the participation of AQN’s Chief Executive Officer ("CEO") and Chief Financial Officer ("CFO"), of the effectiveness of the design and operations of AQN’s disclosure controls and procedures (as defined in Rule 13a-15(e) and Rule 15d-15 (e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”)). Based on that evaluation, the CEO and the CFO have concluded that as of March 31, 2022, AQN’s disclosure controls and procedures are effective to provide reasonable assurance that information required to be disclosed by AQN in reports that it files or submits under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in rules and forms of the U.S. Securities and Exchange Commission, and is accumulated and communicated to management, including the CEO and CFO, as appropriate, to allow timely decisions regarding required disclosure.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 46 | ||||
Management Report on Internal Controls over Financial Reporting
Management, including the CEO and the CFO, is responsible for establishing and maintaining internal control over financial reporting. Management, as at the end of the period covered by this interim filing, designed internal controls over financial reporting to provide reasonable, but not absolute, assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with U.S. GAAP. The control framework management used to design the Company's internal control over financial reporting is that established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.
The Company acquired Liberty NY Water during the three months ended March 31, 2022. The financial information for this acquisition is included in this MD&A and in Note 3 to the unaudited interim consolidated financial statements. National Instrument 52-109 and the U.S. Securities and Exchange Commission provide an exemption whereby companies undergoing acquisitions can exclude the acquired business in the year of acquisition from the scope of testing and assessment of design and operational effectiveness of controls over financial reporting. Due to the complexity associated with assessing internal controls during integration efforts, the Company plans to utilize the scope exemption as it relates to this acquisition in its management report on internal controls over financial reporting for the year ending December 31, 2022.
Changes in Internal Controls over Financial Reporting
For the three months ended March 31, 2022, there has been no change in the Company’s internal controls over financial reporting that has materially affected, or is reasonably likely to materially affect, the Company’s internal controls over financial reporting. AQN continues to apply its internal control structure over the operations of the acquired business discussed above.
Inherent Limitations on Effectiveness of Controls
Due to its inherent limitations, disclosure controls and procedures or internal control over financial reporting may not prevent or detect all misstatements based on error or fraud. Further, the effectiveness of internal control is subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with policies or procedures may change.
CRITICAL ACCOUNTING ESTIMATES AND POLICIES
AQN prepared its unaudited interim consolidated financial statements in accordance with U.S. GAAP. The preparation of the unaudited interim consolidated financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, related amounts of revenues and expenses, and disclosure of contingent assets and liabilities. Significant areas requiring the use of management judgment relate to the scope of consolidated entities, useful lives and recoverability of depreciable assets, the measurement of deferred taxes and the recoverability of deferred tax assets, rate-regulation, unbilled revenue, pension and post-employment benefits, fair value of derivatives and fair value of assets and liabilities acquired in a business combination. Actual results may differ from these estimates.
AQN’s significant accounting policies and new accounting standards are discussed in Notes 1 and 2 in the unaudited interim consolidated financial statements, respectively.
| Algonquin Power & Utilities Corp. - Management Discussion & Analysis | 47 | ||||
FORM 52-109F2
CERTIFICATION OF INTERIM FILINGS
FULL CERTIFICATE
I, Arun Banskota, President and Chief Executive Officer of Algonquin Power & Utilities Corp., certify the following:
1. Review: I have reviewed the interim financial report and interim MD&A (together, the “interim filings”) of Algonquin Power & Utilities Corp. (the “issuer”) for the interim period ended March 31, 2022.
2. No misrepresentations: Based on my knowledge, having exercised reasonable diligence, the interim filings do not contain any untrue statement of a material fact or omit to state a material fact required to be stated or that is necessary to make a statement not misleading in light of the circumstances under which it was made, with respect to the period covered by the interim filings.
3. Fair presentation: Based on my knowledge, having exercised reasonable diligence, the interim financial report together with the other financial information included in the interim filings fairly present in all material respects the financial condition, financial performance and cash flows of the issuer, as of the date of and for the periods presented in the interim filings.
4. Responsibility: The issuer’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (DC&P) and internal control over financial reporting (ICFR), as those terms are defined in National Instrument 52-109 Certification of Disclosure in Issuers’ Annual and Interim Filings, for the issuer.
5. Design: Subject to the limitations, if any, described in paragraphs 5.2 and 5.3, the issuer’s other certifying officer(s) and I have, as at the end of the period covered by the interim filings
a.designed DC&P, or caused it to be designed under our supervision, to provide reasonable assurance that
i.material information relating to the issuer is made known to us by others, particularly during the period in which the interim filings are being prepared; and
ii.information required to be disclosed by the issuer in its annual filings, interim filings or other reports filed or submitted by it under securities legislation is recorded, processed, summarized and reported within the time periods specified in securities legislation; and
b.designed ICFR, or caused it to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with the issuer’s GAAP.
5.1 Control framework: The control framework the issuer’s other certifying officer(s) and I used to design the issuer’s ICFR is Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.
5.2 ICFR - material weakness relating to design: N/A
5.3 Limitation on scope of design: The issuer has disclosed in its interim MD&A
a.The fact that the issuer’s other certifying officer(s) and I have limited the scope of our design of DC&P and ICFR to exclude controls, policies and procedures of a business that the issuer acquired not more than 365 days before the issuer’s financial year end; and
b.Summary financial information about the business that the issuer acquired that has been consolidated in the issuer’s financial statements.
6. Reporting changes in ICFR: The issuer has disclosed in its interim MD&A any change in the issuer’s ICFR that occurred during the period beginning on January 1, 2022 and ended on March 31, 2022 that has materially affected, or is reasonably likely to materially affect, the issuer’s ICFR.
Date: May 12, 2022
/s/ Arun Banskota
_______________________
Arun Banskota
President and Chief Executive Officer
FORM 52-109F2
CERTIFICATION OF INTERIM FILINGS
FULL CERTIFICATE
I, Arthur Kacprzak, Chief Financial Officer of Algonquin Power & Utilities Corp., certify the following:
1. Review: I have reviewed the interim financial report and interim MD&A (together, the “interim filings”) of Algonquin Power & Utilities Corp. (the “issuer”) for the interim period ended March 31, 2022.
2. No misrepresentations: Based on my knowledge, having exercised reasonable diligence, the interim filings do not contain any untrue statement of a material fact or omit to state a material fact required to be stated or that is necessary to make a statement not misleading in light of the circumstances under which it was made, with respect to the period covered by the interim filings.
3. Fair presentation: Based on my knowledge, having exercised reasonable diligence, the interim financial report together with the other financial information included in the interim filings fairly present in all material respects the financial condition, financial performance and cash flows of the issuer, as of the date of and for the periods presented in the interim filings.
4. Responsibility: The issuer’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (DC&P) and internal control over financial reporting (ICFR), as those terms are defined in National Instrument 52-109 Certification of Disclosure in Issuers’ Annual and Interim Filings, for the issuer.
5. Design: Subject to the limitations, if any, described in paragraphs 5.2 and 5.3, the issuer’s other certifying officer(s) and I have, as at the end of the period covered by the interim filings
a.designed DC&P, or caused it to be designed under our supervision, to provide reasonable assurance that
i.material information relating to the issuer is made known to us by others, particularly during the period in which the interim filings are being prepared; and
ii.information required to be disclosed by the issuer in its annual filings, interim filings or other reports filed or submitted by it under securities legislation is recorded, processed, summarized and reported within the time periods specified in securities legislation; and
b.designed ICFR, or caused it to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with the issuer’s GAAP.
5.1 Control framework: The control framework the issuer’s other certifying officer(s) and I used to design the issuer’s ICFR is Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.
5.2 ICFR - material weakness relating to design: N/A
5.3 Limitation on scope of design: The issuer has disclosed in its interim MD&A
a.The fact that the issuer’s other certifying officer(s) and I have limited the scope of our design of DC&P and ICFR to exclude controls, policies and procedures of a business that the issuer acquired not more than 365 days before the issuer’s financial year end; and
b.Summary financial information about the business that the issuer acquired that has been consolidated in the issuer’s financial statements.
6. Reporting changes in ICFR: The issuer has disclosed in its interim MD&A any change in the issuer’s ICFR that occurred during the period beginning on January 1, 2022 and ended on March 31, 2022 that has materially affected, or is reasonably likely to materially affect, the issuer’s ICFR.
Date: May 12, 2022
/s/ Arthur Kacprzak
_______________________
Arthur Kacprzak
Chief Financial Officer
Algonquin Power & Utilities Corp. Announces 2022 First Quarter Financial Results
OAKVILLE, Ontario - May 12, 2022 - Algonquin Power & Utilities Corp. (TSX/NYSE: AQN) (“AQN” or the “Company”) today announced financial results for the first quarter ended March 31, 2022. All amounts are shown in United States dollars (“U.S. $” or “$”), unless otherwise noted.
“We are pleased to announce that today our Board of Directors approved a 6% increase in our quarterly common share dividend, supported by solid operating results from the Company's diversified and resilient business model,” said Arun Banskota, President and Chief Executive Officer of AQN. “We remain committed to delivering on the Company's $12.4 billion capital plan from 2022 through 2026 to drive growth in earnings and cash flows which we expect will, in turn, support compelling returns for shareholders.”
Q1 2022 Financial Highlights
•Revenue of $735.7 million, an increase of 16% compared to the first quarter of 2021
•Adjusted EBITDA1 of $330.6 million, an increase of 17% compared to the first quarter of 2021;
•Adjusted Net Earnings1 of $141.3 million, an increase of 13% compared to the first quarter of 2021; and
•Adjusted Net Earnings1 per share of $0.21, an increase of 5% compared to the first quarter of 2021.
All amounts in U.S. $ millions except per share information | Three months ended March 31 | |||||||||||||||||||||||||
| 2022 | 2021 | Change | ||||||||||||||||||||||||
| Revenue | $ | 735.7 | $ | 634.5 | 16% | |||||||||||||||||||||
| Net earnings attributable to shareholders | 91.0 | 13.9 | 555% | |||||||||||||||||||||||
| Per share | 0.13 | 0.02 | 550% | |||||||||||||||||||||||
| Cash provided by operating activities | 166.2 | (243.5) | 168% | |||||||||||||||||||||||
Adjusted Net Earnings1 | 141.3 | 124.5 | 13% | |||||||||||||||||||||||
| Per share | 0.21 | 0.20 | 5% | |||||||||||||||||||||||
Adjusted EBITDA1 | 330.6 | 282.9 | 17% | |||||||||||||||||||||||
Adjusted Funds from Operations1 | 220.2 | 205.3 | 7% | |||||||||||||||||||||||
| Dividends per share | 0.1706 | 0.1551 | 10% | |||||||||||||||||||||||
1.Please refer to "Non-GAAP Measures" at the end of this document for further details.
Corporate Highlights
•Approval by Kentucky Public Service Commission ("KPSC") – On May 4, 2022, the KPSC issued an order, including an approval of the pending acquisition of Kentucky Power Company and AEP Kentucky Transmission Company, Inc. (the “Kentucky Power Transaction”) by Liberty Utilities Co. ("Liberty Utilities"), an indirect, wholly-owned subsidiary of AQN, subject to certain conditions set forth in the order, including those agreed to by Liberty Utilities in the course of the docket. The Kentucky Power Transaction was
originally announced on October 26, 2021. Closing of the Kentucky Power Transaction is subject to the satisfaction of certain conditions precedent, including the approval of the U.S. Federal Energy Regulatory Commission (“FERC”) for the Kentucky Power Transaction and certain approvals from FERC, the KPSC and the Public Service Commission of West Virginia with respect to the termination and replacement of the existing operating agreement for the Mitchell coal generating facility (in which Kentucky Power Company owns a 50% interest).
•Liberty New York Water Acquisition & Integration – Effective January 1, 2022, the Company closed the previously-announced acquisition of New York American Water Company, Inc. (subsequently renamed Liberty Utilities (New York Water) Corp.) from American Water Works Company, Inc. for a purchase price of approximately $609 million. The transition and integration are progressing well as the Company continues to deliver safe and reliable water service to customers in New York.
•Issuance of approximately $1.1 Billion of Subordinated Notes – On January 18, 2022, the Company completed concurrent public offerings of junior subordinated notes in the United States and Canada in an aggregate principal amount of $750 million and C$400 million, respectively (the "Note Offerings"). The Company intends to use the net proceeds of the Note Offerings to partially finance the Kentucky Power Transaction provided that, in the short-term, prior to closing of the Kentucky Power Transaction, the Company has used a portion of, and expects to use the remainder of such net proceeds to repay certain indebtedness of the Corporation and its subsidiaries.
•Empire Missouri Rate Case Outcome – On May 28, 2021, the Empire District Electric Company ("Empire") filed a rate review based on a 12 month historical test year ending September 30, 2020, with an update period through June 30, 2021, requesting an increase in rates of $79.9 million which included $29.9 million related to recovery of fuel and power pass-through costs related to the February 2021 Midwest Extreme Weather Event. Empire subsequently amended the rate request to $50.0 million after deferring the recovery of the extraordinary fuel pass-through costs as well as certain costs related to the retirement of the Asbury coal plant to a subsequent docket requesting securitization. On April 6, 2022, the Missouri Public Service Commission issued its final Report and Order resulting in an annual base rate revenue increase of $39.5 million.
•Completion of the Blue Hill Wind Facility – On April 14, 2022, the Renewable Energy Group achieved full commercial operations at its 175 MW Blue Hill Wind Facility, located in southwest Saskatchewan. The Blue Hill Facility is the Renewable Energy Group's 15th wind powered electric generating facility and is expected to generate approximately 683 GW-hrs of energy per year, with the output being sold through a long-term power purchase agreement with an investment grade rated entity.
•Ongoing Execution of C&I Strategy – The Company continues to execute on its relationship with commercial and industrial ("C&I") customers to help them achieve their sustainability objectives. On May 10, 2022, AQN announced its collaboration with Meta, formerly known as Facebook, Inc., on AQN's 112 MW Deerfield II Wind Project in Huron County, Michigan. Pursuant to the long-term power purchase agreement entered into by the parties, Meta will purchase 100 percent of the energy and environmental
attributes from Deerfield II, building upon the existing relationship the companies have at the operating Altavista Solar Facility in Virginia. Construction on Deerfield II began in April 2022.
•Increase in Common Share Dividend – Consistent with AQN's history of delivering total shareholder return comprised of an attractive dividend yield and capital appreciation, on May 12, 2022, AQN's board of directors approved a 6% dividend increase from a total annualized dividend of $0.6824 per common share to a total annualized dividend of $0.7233 per common share. The dividend is expected to be paid quarterly at a rate of $0.1808 per common share, up from $0.1706 per common share.
Additional information regarding AQN is available on its web site at www.AlgonquinPowerandUtilities.com and in its corporate filings on SEDAR at www.sedar.com (for Canadian filings) and EDGAR at www.sec.gov/edgar (for U.S. filings).
Earnings Conference Call
AQN will hold an earnings conference call at 10:00 a.m. eastern time on Friday, May 13, 2022 hosted by President and Chief Executive Officer, Arun Banskota and Chief Financial Officer, Arthur Kacprzak.
Date: | Friday, May 13, 2022 | |||||||
Time: | 10:00 a.m. ET | |||||||
Conference Call: | Toll Free Dial-In Number | (888) 330-2454 | ||||||
| Toll Dial-In Number | (240) 789-2714 | |||||||
| Event Passcode | 5079453 | |||||||
Webcast: | https://event.on24.com/wcc/r/3730565/B0D9DC01E26134ED73A4E3E39A879DBE | |||||||
Presentation also available at: www.algonquinpowerandutilities.com | ||||||||
About Algonquin Power & Utilities Corp. and Liberty
Algonquin Power & Utilities Corp., parent company of Liberty, is a diversified international generation, transmission, and distribution utility with over $17 billion of total assets. Through its two business groups, the Regulated Services Group and the Renewable Energy Group, Algonquin is committed to providing safe, secure, reliable, cost-effective, and sustainable energy and water solutions through its portfolio of electric generation, transmission, and distribution utility investments to over one million customer connections, largely in the United States and Canada. Algonquin is a global leader in renewable energy through its portfolio of long-term contracted wind, solar, and hydroelectric generating facilities. Algonquin owns, operates, and/or has net interests in over 4 GW of installed renewable energy capacity.
Algonquin is committed to delivering growth and the pursuit of operational excellence in a sustainable manner through an expanding global pipeline of renewable energy and electric transmission development projects, organic growth within its rate-regulated generation, distribution, and transmission businesses, and the pursuit of accretive acquisitions and value enhancing recycling of assets.
Algonquin's common shares, preferred shares, Series A, and preferred shares, Series D are listed on the Toronto Stock Exchange under the symbols AQN, AQN.PR.A, and AQN.PR.D, respectively. AQN's common shares, Series
2018-A subordinated notes, Series 2019-A subordinated notes and equity units are listed on the New York Stock Exchange under the symbols AQN, AQNA, AQNB, and AQNU, respectively.
Visit AQN at www.algonquinpowerandutilities.com and follow us on Twitter @AQN_Utilities.
Investor Inquiries:
Amelia Tsang
Vice President, Investor Relations
Algonquin Power & Utilities Corp.
E-mail: InvestorRelations@APUCorp.com
Telephone: (905) 465-4500
Media Inquiries:
Stephanie Bose
Director, Corporate Communications
Liberty
E-mail: Corporate.Communications@libertyutilities.com
Telephone: (905) 465-4500
Caution Regarding Forward-Looking Information
Certain statements included in this news release constitute ‘‘forward-looking information’’ within the meaning of applicable securities laws in each of the provinces and territories of Canada and the respective policies, regulations and rules under such laws and ‘‘forward-looking statements’’ within the meaning of the U.S. Private Securities Litigation Reform Act of 1995 (collectively, ‘‘forward-looking statements”). The words “will”, “expects”, “intends”, “plans” and similar expressions are often intended to identify forward-looking statements, although not all forward-looking statements contain these identifying words. Specific forward-looking statements in this news release include, but are not limited to, statements regarding: the expected future earnings, performance and growth of AQN; capital expenditure plans; the expected generating capacity of the Blue Hill Wind Facility; the expected use of proceeds from completed offerings; and expected dividends to shareholders. These statements are based on factors or assumptions that were applied in drawing a conclusion or making a forecast or projection, including assumptions based on historical trends, current conditions and expected future developments. Since forward-looking statements relate to future events and conditions, by their very nature they require making assumptions and involve inherent risks and uncertainties. AQN cautions that although it is believed that the assumptions are reasonable in the circumstances, these risks and uncertainties give rise to the possibility that actual results may differ materially from the expectations set out in the forward-looking statements. Material risk factors and assumptions include those set out in AQN's Management Discussion & Analysis and Annual Information Form for the year ended December 31, 2021, and in AQN's Management Discussion & Analysis for the three months ended March 31, 2022 (the “Interim MD&A”), each of which is or will be available on SEDAR and EDGAR. Given these risks, undue reliance should not be placed on these forward-looking statements, which apply
only as of their dates. Other than as specifically required by law, AQN undertakes no obligation to update any forward-looking statements to reflect new information, subsequent or otherwise
Non-GAAP Measures
AQN uses a number of financial measures to assess the performance of its business lines. Some measures are calculated in accordance with generally accepted accounting principles in the United States (“U.S. GAAP”), while other measures do not have a standardized meaning under U.S. GAAP. These non-GAAP measures include non-GAAP financial measures and non-GAAP ratios, each as defined in Canadian National Instrument 52-112 – Non-GAAP and Other Financial Measures Disclosure. AQN’s method of calculating these measures may differ from methods used by other companies and therefore may not be comparable to similar measures presented by other companies.
The terms “Adjusted Net Earnings”, “Adjusted EBITDA” and “Adjusted Funds from Operations”, which are used in this news release, are non-GAAP financial measures. An explanation of each of these non-GAAP financial measures can be found in the section entitled “Caution Concerning Non-GAAP Measures” in the Interim MD&A, which section is incorporated by reference into this news release, and a reconciliation to the most directly comparable U.S. GAAP measure, in each case, can be found below. In addition, “Adjusted Net Earnings” is presented in this news release on a per share basis. Adjusted Net Earnings per share is a non-GAAP ratio and is calculated by dividing Adjusted Net Earnings by the weighted average number of common shares outstanding during the applicable period.
Reconciliation of Adjusted EBITDA to Net Earnings
The following table is derived from and should be read in conjunction with the consolidated statement of operations. This supplementary disclosure is intended to more fully explain disclosures related to Adjusted EBITDA and provides additional information related to the operating performance of AQN. Investors are cautioned that this measure should not be construed as an alternative to U.S. GAAP consolidated net earnings.
| Three months ended March 31 | |||||||||||||||||||||||
| (all dollar amounts in $ millions) | 2022 | 2021 | |||||||||||||||||||||
| Net earnings attributable to shareholders | $ | 91.0 | $ | 13.9 | |||||||||||||||||||
| Add (deduct): | |||||||||||||||||||||||
Net earnings attributable to the non-controlling interest, exclusive of HLBV1 | 4.1 | 6.4 | |||||||||||||||||||||
| Income tax expense (recovery) | 9.5 | (21.6) | |||||||||||||||||||||
| Interest expense | 57.9 | 49.6 | |||||||||||||||||||||
Other net losses3 | 4.7 | 8.4 | |||||||||||||||||||||
| Pension and post-employment non-service costs | 2.6 | 3.7 | |||||||||||||||||||||
Change in value of investments carried at fair value2 | 40.5 | 71.7 | |||||||||||||||||||||
Impacts from the Market Disruption Event4 on the Senate Wind Facility | — | 53.4 | |||||||||||||||||||||
| Loss (gain) on derivative financial instruments | (0.3) | (1.1) | |||||||||||||||||||||
| Realized loss on energy derivative contracts | 0.3 | 0.2 | |||||||||||||||||||||
| Loss (gain) on foreign exchange | 0.3 | 0.9 | |||||||||||||||||||||
| Depreciation and amortization | 120.0 | 97.4 | |||||||||||||||||||||
| Adjusted EBITDA | $ | 330.6 | $ | 282.9 | |||||||||||||||||||
| 1 | Hypothetical liquidation at book value (“HLBV”) represents the value of net tax attributes earned during the period primarily from electricity generated by certain U.S. wind power and U.S. solar generation facilities. HLBV earned in the three months ended March 31, 2022 amounted to $42.5 million, as compared to $23.9 million during the same period in 2021. | ||||
| 2 | See Note 6 in the unaudited interim consolidated financial statements. | ||||
| 3 | See Note 16 in the unaudited interim consolidated financial statements. | ||||
| 4 | The “Market Disruption Event” refers to the significantly elevated pricing that persisted in the Electric Reliability Council of Texas market over several days as a result of the February 2021 extreme winter storm conditions experienced in Texas and parts of the central U.S. | ||||
Reconciliation of Adjusted Net Earnings to Net Earnings
The following table is derived from and should be read in conjunction with the consolidated statement of operations. This supplementary disclosure is intended to more fully explain disclosures related to Adjusted Net Earnings and provides additional information related to the operating performance of AQN. Investors are cautioned that this measure should not be construed as an alternative to consolidated net earnings in accordance with U.S. GAAP.
The following table shows the reconciliation of net earnings to Adjusted Net Earnings exclusive of these items:
| Three months ended March 31 | |||||||||||||||||||||||
| (all dollar amounts in $ millions except per share information) | 2022 | 2021 | |||||||||||||||||||||
| Net earnings attributable to shareholders | $ | 91.0 | $ | 13.9 | |||||||||||||||||||
| Add (deduct): | |||||||||||||||||||||||
| Loss (gain) on derivative financial instruments | (0.3) | (1.1) | |||||||||||||||||||||
| Realized loss on energy derivative contracts | 0.3 | 0.2 | |||||||||||||||||||||
Other net losses2 | 4.7 | 8.4 | |||||||||||||||||||||
| Loss (gain) on foreign exchange | 0.3 | 0.9 | |||||||||||||||||||||
Change in value of investments carried at fair value1 | 40.5 | 71.7 | |||||||||||||||||||||
| Impacts from the Market Disruption Event on the Senate Wind Facility | — | 53.4 | |||||||||||||||||||||
| Adjustment for taxes related to above | 4.8 | (22.9) | |||||||||||||||||||||
| Adjusted Net Earnings | $ | 141.3 | $ | 124.5 | |||||||||||||||||||
| Adjusted Net Earnings per common share | $ | 0.21 | $ | 0.20 | |||||||||||||||||||
| 1 | See Note 6 in the unaudited interim consolidated financial statements. | ||||
| 2 | See Note 16 in the unaudited interim consolidated financial statements. | ||||
Reconciliation of Adjusted Funds from Operations to Cash Provided by Operating Activities
The following table is derived from and should be read in conjunction with the consolidated statement of operations and consolidated statement of cash flows. This supplementary disclosure is intended to more fully explain disclosures related to Adjusted Funds from Operations and provides additional information related to the operating performance of AQN. Investors are cautioned that this measure should not be construed as an alternative to cash provided by operating activities in accordance with U.S. GAAP.
The following table shows the reconciliation of cash provided by operating activities to Adjusted Funds from Operations exclusive of these items:
| Three months ended March 31 | |||||||||||||||||||||||
| (all dollar amounts in $ millions) | 2022 | 2021 | |||||||||||||||||||||
| Cash provided by operating activities | $ | 166.2 | $ | (243.5) | |||||||||||||||||||
| Add (deduct): | |||||||||||||||||||||||
| Changes in non-cash operating items | 48.1 | 388.5 | |||||||||||||||||||||
| Production based cash contributions from non-controlling interests | 3.7 | 4.8 | |||||||||||||||||||||
| Impacts from the Market Disruption Event on the Senate Wind Facility | — | 53.4 | |||||||||||||||||||||
| Acquisition-related costs | 2.2 | 2.1 | |||||||||||||||||||||
| Adjusted Funds from Operations | $ | 220.2 | $ | 205.3 | |||||||||||||||||||
Algonquin Power & Utilities Corp. Announces 6% Common Share Dividend Increase, Declares Second Quarter 2022 Common Share Dividend of U.S.$0.1808 (C$0.2345), and Declares Second Quarter 2022 Preferred Share Dividends
Oakville, Ontario – May 12, 2022 - Algonquin Power & Utilities Corp. (“AQN”) (TSX: AQN, AQN.PR.A, AQN.PR.D, NYSE: AQN) announced today that its board of directors has approved and declared the following common and preferred share dividends:
1.US$0.1808 per common share, payable on July 15, 2022, to the shareholders of record on June 30, 2022, for the period from April 1, 2022 to June 30, 2022. Shareholders receiving dividends in cash can elect to receive the dividend in Canadian dollars in the amount of C$0.2345.
2.C$0.32263 per preferred share, Series A, payable in cash on June 30, 2022 to preferred share, Series A holders of record on June 15, 2022, for the period from March 31, 2022 to, but excluding, June 30, 2022.
3.C$0.31819 per preferred share, Series D, payable in cash on June 30, 2022 to preferred share, Series D holders of record on June 15, 2022, for the period from March 31, 2022 to, but excluding, June 30, 2022.
The common share dividend will be paid in cash or, if a shareholder has enrolled in the shareholder dividend reinvestment plan (the “Plan”), dividends will be reinvested in additional common shares (“Plan Shares”) of AQN as per the Plan. Plan Shares will be acquired by way of a treasury purchase at the average market price as defined in the Plan less a 3% discount.
The quarterly dividends payable on common shares are declared in U.S. dollars. Beneficial shareholders (those who hold common shares through a financial intermediary) who are resident in Canada or the United States may request to receive their dividends in either U.S. dollars or the Canadian dollar equivalent by contacting the financial intermediary with whom the common shares are held. Unless the Canadian dollar equivalent is requested, holders of common shares will receive dividends in U.S. dollars, which, as is often the case, the financial intermediary may convert to Canadian dollars. Registered shareholders receive dividend payments in the currency of residency. Registered shareholders may opt to change the payment currency by contacting TSX Trust Company at 1-800-387-0825 prior to the record date of the dividend.
The Canadian dollar equivalent of the quarterly dividend is based on the Bank of Canada daily average exchange rate on the day before the declaration date.
Pursuant to the Income Tax Act (Canada) and corresponding provincial legislation, AQN hereby notifies holders of common shares, preferred shares, Series A, and preferred shares, Series D that such dividends declared qualify as eligible dividends.
About Algonquin Power & Utilities Corp. and Liberty
Algonquin Power & Utilities Corp., parent company of Liberty, is a diversified international generation, transmission, and distribution utility with over $17 billion of total assets. Through its two business groups, the Regulated Services Group and the Renewable Energy Group, AQN is committed to providing safe, secure, reliable, cost-effective, and sustainable energy and water solutions through its portfolio of electric generation,
transmission, and distribution utility investments to over one million customer connections, largely in the United States and Canada. AQN is a global leader in renewable energy through its portfolio of long-term contracted wind, solar, and hydroelectric generating facilities. AQN owns, operates, and/or has net interests in over 4 GW of installed renewable energy capacity.
AQN is committed to delivering growth and the pursuit of operational excellence in a sustainable manner through an expanding global pipeline of renewable energy and electric transmission development projects, organic growth within its rate-regulated generation, distribution, and transmission businesses, and the pursuit of accretive acquisitions and value enhancing recycling of assets.
AQN's common shares, preferred shares, Series A, and preferred shares, Series D are listed on the Toronto Stock Exchange under the symbols AQN, AQN.PR.A, and AQN.PR.D, respectively. AQN's common shares, Series 2018-A subordinated notes, Series 2019-A subordinated notes and equity units are listed on the New York Stock Exchange under the symbols AQN, AQNA, AQNB, and AQNU, respectively.
Visit AQN at www.algonquinpowerandutilities.com and follow us on Twitter @AQN_Utilities.
Investor Inquiries:
Amelia Tsang
Vice President, Investor Relations
Algonquin Power & Utilities Corp.
354 Davis Road, Oakville, Ontario, L6J 2X1
E-mail: InvestorRelations@APUCorp.com
Telephone: (905) 465-4500
Media Inquiries:
Stephanie Bose
Director, Corporate Communications
Liberty
354 Davis Road, Oakville, Ontario, L6J 2X1
E-mail: Corprorate.Communications@libertyutilities.com
Telephone: (905) 465-4500