Pembina Pipeline Corp 6-K, filed Nov 6, 2025
Pembina Pipeline Corp (PBA)
6-K
2025-11-06
For: 2025-09-30
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Added on
April 09, 2026
About this 6-K
Pembina Pipeline Corp filed this 6-K on November 6, 2025.
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 6-K
REPORT OF FOREIGN PRIVATE ISSUER PURSUANT TO RULE 13a-16 OR 15d-16
UNDER THE SECURITIES EXCHANGE ACT OF 1934
For the month of November, 2025
Commission File Number: 001-35563
PEMBINA PIPELINE CORPORATION
(Name of registrant)
(Room #39-095) 4000, 585 8th Avenue S.W.
Calgary, Alberta T2P 1G1
(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.
o Form 20-F | x Form 40-F | ||||||||||
INCORPORATION BY REFERENCE
Exhibit 99.1 to this Report on Form 6-K is hereby incorporated by reference as an exhibit to the Registration Statement on Form F-10 (File No. 333-276023) of Pembina Pipeline Corporation.
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
| PEMBINA PIPELINE CORPORATION | |||||||||||
| Date: | November 6, 2025 | By: | /s/ Cameron J. Goldade | ||||||||
| Name: Cameron J. Goldade | |||||||||||
| Title: Senior Vice President & Chief Financial Officer | |||||||||||
Form 6-K Exhibit Index
| Exhibit Number | Document Description | |||||||
| 99.1 | ||||||||
| 99.2 | ||||||||
| 99.3 | ||||||||
REPORT TO SHAREHOLDERS |  | ||||||||||
| Third Quarter 2025 | |||||||||||
| MANAGEMENT'S DISCUSSION AND ANALYSIS | |||||||||||
| Table of Contents | |||||||||||
6. Capital Expenditures | |||||||||||
Basis of Presentation
The following Management's Discussion and Analysis ("MD&A") of the financial and operating results of Pembina Pipeline Corporation ("Pembina" or the "Company") is dated November 6, 2025, and is supplementary to, and should be read in conjunction with, Pembina's unaudited condensed consolidated interim financial statements for the three and nine months ended September 30, 2025 ("Interim Financial Statements") as well as Pembina's audited consolidated annual financial statements ("Consolidated Financial Statements") and MD&A for the year ended December 31, 2024. All financial information provided in this MD&A has been prepared in accordance with International Accounting Standard ("IAS") 34 Interim Financial Reporting and is expressed in Canadian dollars, unless otherwise noted. A description of Pembina's operating segments and additional information about Pembina is filed with Canadian and U.S. securities commissions, including quarterly and annual reports, annual information forms (which are filed with the U.S. Securities and Exchange Commission under Form 40-F) and management information circulars, which can be found online at www.sedarplus.ca, www.sec.gov and through Pembina's website at www.pembina.com. Information contained in or otherwise accessible through Pembina's website does not form part of this MD&A and is not incorporated into this document by reference.
Abbreviations
For a list of abbreviations that may be used in this MD&A, refer to the "Abbreviations" section of this MD&A.
Non-GAAP and Other Financial Measures
Pembina has disclosed certain financial measures and ratios within this MD&A that management believes provide meaningful information in assessing Pembina's underlying performance, but which are not specified, defined or determined in accordance with the Canadian generally accepted accounting principles ("GAAP") and which are not disclosed in Pembina's Interim Financial Statements or Consolidated Financial Statements. Such non-GAAP financial measures and non-GAAP ratios do not have any standardized meaning prescribed by IFRS and may not be comparable to similar financial measures or ratios disclosed by other issuers. Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A for additional information regarding these non-GAAP financial measures and non-GAAP ratios.
Risk Factors and Forward-Looking Information
Management has identified the primary risk factors that could have a material impact on the financial results and operations of Pembina. Such risk factors are presented in the "Risk Factors" sections of Pembina's MD&A and Annual Information Form ("AIF"), each for the year ended December 31, 2024. The Company's financial and operational performance is potentially affected by a number of factors, including, but not limited to, the factors described within the "Forward-Looking Statements & Information" section of this MD&A. This MD&A contains forward-looking statements based on Pembina's current expectations, estimates, projections and assumptions. This information is provided to assist readers in understanding the Company's future plans and expectations and may not be appropriate for other purposes.
Pembina Pipeline Corporation Third Quarter 2025 1
1. ABOUT PEMBINA
Pembina Pipeline Corporation is a leading energy transportation and midstream service provider that has served North America's energy industry for more than 70 years. Pembina owns an extensive network of strategically located assets, including hydrocarbon liquids and natural gas pipelines, gas gathering and processing facilities, oil and natural gas liquids infrastructure and logistics services, and an export terminals business. Through our integrated value chain, we seek to provide safe and reliable energy solutions that connect producers and consumers across the world, support a more sustainable future and benefit our customers, investors, employees and communities. For more information, please visit www.pembina.com.
Pembina's Purpose and Strategy
We deliver extraordinary energy solutions so the world can thrive.
Pembina will build on its strengths by continuing to invest in and grow the core businesses that provide critical transportation and midstream services to help ensure reliable and secure energy supply. Pembina will capitalize on exciting opportunities to leverage its assets and expertise into new service offerings that enable the transition to a lower-carbon economy. In continuing to meet global energy demand and its customers' needs, while ensuring Pembina's long-term success and resilience, the Company has established four strategic priorities:
1.To be resilient, we will sustain, decarbonize, and enhance our businesses. This priority is focused on strengthening and growing our existing franchise and demonstrating environmental leadership.
2.To thrive, we will invest in the energy transition to improve the basins in which we operate. We will prioritize lighter commodities as we continue to invest in new infrastructure and expand our portfolio to include new businesses associated with lower-carbon commodities.
3.To meet global demand, we will transform and export our products. We will continue our focus on supporting the transformation of Western Canadian Sedimentary Basin commodities into higher margin products and enabling more coastal egress.
4.To set ourselves apart, we will create a differentiated experience for our stakeholders. We remain committed to delivering excellence for our four key stakeholder groups meaning that:
a.Employees say we are the 'employer of choice' and value our safe, respectful, collaborative, and inclusive work culture.
b.Communities welcome us and recognize the net positive impact of our social and environmental commitment.
c.Customers choose us first for reliable and value-added services.
d.Investors receive sustainable industry-leading total returns.
2 Pembina Pipeline Corporation Third Quarter 2025
2. FINANCIAL & OPERATING OVERVIEW
Consolidated Financial Overview for the Three Months Ended September 30
Results of Operations
| ($ millions, except where noted) | 2025 | 2024 | Change | |||||||||||
| Revenue | 1,791 | 1,844 | (53) | |||||||||||
Net revenue(1) | 1,211 | 1,259 | (48) | |||||||||||
| Operating expenses | 259 | 277 | (18) | |||||||||||
Gross profit | 658 | 747 | (89) | |||||||||||
Adjusted EBITDA(1) | 1,034 | 1,019 | 15 | |||||||||||
Earnings | 286 | 385 | (99) | |||||||||||
Earnings per common share – basic and diluted (dollars) | 0.43 | 0.60 | (0.17) | |||||||||||
| Cash flow from operating activities | 810 | 922 | (112) | |||||||||||
Cash flow from operating activities per common share – basic (dollars) | 1.39 | 1.59 | (0.20) | |||||||||||
Adjusted cash flow from operating activities(1) | 648 | 724 | (76) | |||||||||||
Adjusted cash flow from operating activities per common share – basic (dollars)(1) | 1.12 | 1.25 | (0.13) | |||||||||||
| Capital expenditures | 178 | 262 | (84) | |||||||||||
Change in Earnings ($ millions)
Results Overview
Earnings in the third quarter of 2025 decreased by $99 million compared to the prior period. Significant factors impacting the quarter by segment include:
•Pipelines: Increase largely due to the recognition of a gain on the sale of the North segment of the Western Pipeline in the third quarter of 2025, higher revenue on the Peace Pipeline system due to higher tolls mainly related to contractual inflation adjustments and increased volumes, higher demand on seasonal contracts on the Alliance Pipeline, and higher contracted volumes on the Nipisi Pipeline.
•Facilities: Decrease largely due to a share of loss from PGI in the third quarter of 2025 primarily due to an impairment of certain PGI assets compared to a share of profit in the third quarter of 2024, partially offset by the recognition of a gain following the amendment of PGI's credit facility and higher contributions from certain PGI assets.
•Marketing & New Ventures: Lower net revenue due to a decrease in revenue from risk management and physical derivatives combined with lower NGL margins, partially offset by lower share of loss from Cedar LNG primarily due to the impact of hedging activities on the credit facility.
•Corporate and Income Tax: Higher income tax expense resulting from higher taxable earnings, partially offset by lower incentive costs and integration costs.
Further details and additional factors impacting the segments are discussed in the table below and in the "Segment Results" section of this MD&A.
Pembina Pipeline Corporation Third Quarter 2025 3
Changes in Results for the Three Months Ended September 30 | ||||||||
Net revenue(1) | $48 million decrease, largely due to lower net revenue in the Marketing & New Ventures Division as a result of lower gains on crude oil-based derivatives and losses on NGL-based derivatives compared to gains in the third quarter of 2024. This is combined with lower NGL margins as a result of lower NGL prices and higher input natural gas prices, partially offset by higher NGL marketed volumes and no similar impact to the nine-day unplanned outage at Aux Sable in July 2024. Additionally, lower tolls on the Cochin Pipeline due to the replacement of long-term contracts that expired in mid-July 2024, combined with lower volumes on the Cochin Pipeline, contributed to a decrease to net revenue. These results were partially offset by gains on renewable power purchase agreements compared to losses in the third quarter of 2024, higher tolls on the Peace Pipeline system primarily due to contractual inflation adjustments, higher interruptible volumes on the Peace Pipeline system, higher contracted volumes on the Nipisi Pipeline, as well as, higher demand on seasonal contracts on the Alliance Pipeline. | |||||||
| Operating expenses | $18 million decrease, primarily due to lower integrity and geotechnical spend on certain Pipelines assets, partially offset by higher operating expenses in the Facilities Division due to higher utilization at the Redwater Complex and certain other Facilities assets in the third quarter of 2025 compared to the third quarter of 2024. | |||||||
| Cash flow from operating activities | $112 million decrease, primarily driven by a change in non-cash working capital and lower earnings adjusted for items not involving cash, partially offset by lower taxes paid. | |||||||
Adjusted cash flow from operating activities(1) | $76 million decrease, primarily due to the same items impacting cash flow from operating activities, discussed above, excluding the change in non-cash working capital and taxes paid, combined with higher current income tax expense. | |||||||
Adjusted cash flow from operating activities per common share – basic (dollars)(1) | $0.13 decrease, primarily due to the factors impacting adjusted cash flow from operating activities, discussed above, while outstanding common shares remained consistent with prior period. | |||||||
Adjusted EBITDA(1) | $15 million increase, largely due to higher net revenue on the Peace Pipeline system and Alliance Pipeline, combined with lower realized losses on NGL-based derivatives, and higher contributions from certain PGI assets. These results were partially offset by lower realized gains on crude-oil based derivatives and lower NGL margins, which were offset in part by higher NGL marketed volumes and no similar impact to the nine-day unplanned outage at Aux Sable in July 2024. Additionally, lower tolls and volumes on the Cochin Pipeline contributed to the decrease. | |||||||
(1) Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A.
4 Pembina Pipeline Corporation Third Quarter 2025
Consolidated Financial Overview for the Nine Months Ended September 30
Results of Operations
| ($ millions, except where noted) | 2025 | 2024 | Change | |||||||||||
| Revenue | 5,865 | 5,239 | 626 | |||||||||||
Net revenue(1) | 3,738 | 3,393 | 345 | |||||||||||
| Operating expenses | 720 | 706 | 14 | |||||||||||
Gross profit | 2,366 | 2,292 | 74 | |||||||||||
Adjusted EBITDA(1) | 3,214 | 3,154 | 60 | |||||||||||
Earnings | 1,205 | 1,302 | (97) | |||||||||||
Earnings per common share – basic and diluted (dollars) | 1.88 | 2.08 | (0.20) | |||||||||||
| Cash flow from operating activities | 2,440 | 2,312 | 128 | |||||||||||
Cash flow from operating activities per common share – basic (dollars) | 4.20 | 4.06 | 0.14 | |||||||||||
Adjusted cash flow from operating activities(1) | 2,123 | 2,343 | (220) | |||||||||||
Adjusted cash flow from operating activities per common share – basic (dollars)(1) | 3.65 | 4.11 | (0.46) | |||||||||||
| Capital expenditures | 549 | 713 | (164) | |||||||||||
Change in Earnings ($ millions)
Results Overview
Earnings during the first nine months of 2025 decreased by $97 million compared to the prior period. Significant factors impacting the period by segment include:
•Pipelines: Positive impacts from Pembina acquiring a controlling ownership interest in Alliance on April 1, 2024, combined with higher seasonal revenue on the Alliance Pipeline. Additionally, earnings were impacted by higher revenue on the Peace Pipeline system due to increased volumes and higher tolls mainly related to contractual inflation adjustments, higher revenue on the Nipisi Pipeline, and the recognition of a gain on the sale of the North segment of the Western Pipeline in the third quarter of 2025. These impacts were partially offset by lower net revenue on the Cochin Pipeline, Vantage Pipeline, and at the Edmonton Terminals.
•Facilities: Decrease largely due to lower share of profit from PGI primarily due to an impairment of certain PGI assets, partially offset by the positive impacts of Pembina acquiring a controlling ownership interest in Aux Sable on April 1, 2024, the recognition of a gain following the amendment of PGI's credit facility, and higher contributions from certain PGI assets.
•Marketing & New Ventures: Positive impacts from Pembina acquiring a controlling ownership interest in Aux Sable on April 1, 2024, higher revenue from risk management and physical derivative contracts, and lower share of loss from Cedar LNG primarily due to the impact of hedging activities on the credit facility. This was partially offset by lower NGL margins and lower other income.
•Corporate and Income Tax: Lower due to higher income tax expense, lower interest income, and no similar net gain on acquisition to that recognized in the second quarter of 2024, partially offset by lower acquisition and integration costs.
Further details and additional factors impacting the segments are discussed in the table below and in the "Segment Results" section of this MD&A.
Pembina Pipeline Corporation Third Quarter 2025 5
Changes in Results for the Nine Months Ended September 30 | ||||||||
Net revenue(1) | $345 million increase, largely due to Pembina acquiring a controlling ownership interest in Alliance and Aux Sable on April 1, 2024. The Marketing & New Ventures Division had higher net revenue largely due to lower losses on renewable power purchase agreements and gains on NGL-based derivatives in the 2025 period compared to losses in the 2024 period. Higher net revenue was also the result of an increase in demand on seasonal contracts on the Alliance Pipeline, higher net revenue on the Peace Pipeline system due to higher utilization in the 2025 period compared to the same period in 2024 which was impacted by planned outages for the Phase VIII Peace Pipeline Expansion, and increased contracted volumes on the Peace Pipeline system and Nipisi Pipeline, along with higher tolls on the Peace Pipeline system primarily due to contractual inflation adjustments. These results were partially offset by lower gains on crude oil-based derivatives and lower net revenue on the Cochin Pipeline primarily due to lower tolls resulting from the replacement of long-term contracts that expired in mid-July 2024. Also contributing to a decrease to net revenue were lower NGL margins due to lower NGL prices and higher input gas prices, lower volumes and tolls on the Vantage Pipeline, lower revenue at the Edmonton Terminals largely related to the decommissioning of the Edmonton South Rail Terminal in the second quarter of 2024, and lower recoverable power and geotechnical costs. | |||||||
| Operating expenses | $14 million increase, primarily due to operating expenses from Alliance and Aux Sable now being fully consolidated as of April 1, 2024, as well as higher environmental costs in the current period, as the 2024 period included a recovery related to the Northern Pipeline system outage. Additionally, higher transportation costs in the Marketing & New Ventures Division and higher integrity spend in the Facilities Division, also contributed to an increase to operating expenses. These increases were partially offset by lower geotechnical spend on certain Pipelines assets and lower recoverable power costs resulting from the lower power pool price during the 2025 period. | |||||||
| Cash flow from operating activities | $128 million increase, primarily driven by lower taxes paid, an increase in earnings adjusted for items not involving cash, and the change in non-cash working capital. This was partially offset by lower distributions from equity accounted investees and higher net interest paid, both largely the result of Pembina acquiring a controlling ownership interest in Alliance and Aux Sable on April 1, 2024, as well as the net change in contract liabilities. | |||||||
Adjusted cash flow from operating activities(1) | $220 million decrease, primarily driven by the same factors impacting cash flow from operating activities, discussed above. However, when excluding the change in non-cash working capital and taxes paid, the adjusted result reflects a decrease. This is further impacted by higher current income tax expense, partially offset by lower accrued share-based payment expense. | |||||||
Adjusted cash flow from operating activities per common share – basic (dollars)(1) | $0.46 decrease, primarily due to the factors impacting adjusted cash flow from operating activities, discussed above, as well as an increase in outstanding common shares following the conversion of subscription receipts into common shares, concurrent with the closing of Pembina's acquisition of a controlling ownership interest in Alliance and Aux Sable on April 1, 2024. | |||||||
Adjusted EBITDA(1) | $60 million increase, largely due to Pembina acquiring a controlling ownership interest in Alliance and Aux Sable on April 1, 2024, and higher revenue on the Alliance Pipeline due to higher demand on seasonal contracts. Higher revenue on the Peace Pipeline system and Nipisi Pipeline, as well as lower realized losses on NGL-based derivatives, also contributed to an increase to adjusted EBITDA. Additionally, contributions from certain PGI assets were higher as a result of the Whitecap Transactions, higher capital recoveries, and higher volumes at the Duvernay Complex, partially offset by outages at certain PGI assets in the second quarter of 2025 that continued into the third quarter, and third-party restrictions impacting the Dawson Assets. These results were partially offset by lower realized gains on crude oil-based derivatives, lower revenue on the Cochin Pipeline, lower NGL margins, lower volumes and tolls on the Vantage Pipeline, and lower revenue at the Edmonton Terminals. | |||||||
(1) Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A.
6 Pembina Pipeline Corporation Third Quarter 2025
3. SEGMENT RESULTS
Business Overview
The Pipelines Division provides customers with pipeline transportation, terminalling, and storage in key market hubs in Canada and the United States for crude oil, condensate, natural gas liquids and natural gas. The Pipelines Division manages pipeline transportation capacity of 3.0 mmboe/d(1) and above ground storage capacity of approximately 10 mmbbls(1) within its conventional, oil sands and heavy oil, and transmission assets. The conventional assets include strategically located pipelines and terminalling hubs that gather and transport light and medium crude oil, condensate and natural gas liquids from western Alberta and northeast British Columbia to downstream pipelines and processing facilities in the Edmonton, Alberta area. The oil sands and heavy oil assets transport heavy and synthetic crude oil produced within Alberta to the Edmonton, Alberta area and offer associated storage and terminalling. The transmission assets transport natural gas, ethane and condensate throughout Canada and the United States on long haul pipelines linking various key market hubs. In addition, the Pipelines Division assets provide linkages to Pembina's Facilities Division assets across North America, enhancing flexibility and optionality in our customer service offerings. Together, these assets supply products from hydrocarbon producing regions to refineries, fractionators and market hubs in Alberta, British Columbia, and Illinois, as well as other regions throughout North America.
The Facilities Division includes infrastructure that provides Pembina's customers with natural gas, condensate and NGL services. Through its wholly-owned assets and its interest in PGI, Pembina's natural gas gathering and processing facilities are strategically positioned in active, liquids-rich areas of the WCSB and Williston Basin and may be serviced by the Company's other businesses. Pembina provides sweet and sour gas gathering, compression, condensate stabilization, and both shallow cut and deep cut gas processing services with a total capacity of approximately 6.7 bcf/d(1) for its customers. Condensate and NGL extracted at virtually all Canadian-based facilities have access to transportation on Pembina's pipelines. In addition, all NGL transported along the Alliance Pipeline are extracted through the Channahon Facility at the terminus. The Facilities Division includes approximately 430 mbpd(1) of NGL fractionation capacity, 21 mmbbls(1) of cavern storage capacity, various oil batteries, associated pipeline and rail terminalling facilities and a liquefied propane export facility on Canada's West Coast. These facilities are accessible to Pembina's other strategically-located assets and pipeline systems, providing customers with flexibility and optionality to access a comprehensive suite of services to enhance the value of their hydrocarbons. In addition, Pembina owns a bulk marine import/export terminal in Vancouver, British Columbia.
The Marketing & New Ventures Division leverages Pembina's integrated value chain and existing network of pipelines, facilities, and energy infrastructure assets to maximize the value of hydrocarbon liquids and natural gas originating in the basins where the Company operates. Pembina pursues the creation of new markets, and further enhances existing markets, to support both the Company's and its customers' business interests. In particular, Pembina seeks to identify opportunities to connect hydrocarbon production to new demand locations through the development of infrastructure.
Within the Marketing & New Ventures Division, Pembina undertakes value-added commodity marketing activities, including buying and selling products (natural gas, ethane, propane, butane, condensate, crude oil, electricity, and carbon credits), commodity arbitrage, and optimizing storage opportunities. The marketing business enters into contracts for capacity on both Pembina's and third-party infrastructure, handles proprietary and customer volumes and aggregates production for onward sale. Through this infrastructure capacity, including Pembina's Prince Rupert Terminal, as well as utilizing the Company's expansive rail fleet and logistics capabilities, Pembina's marketing business adds incremental value to the commodities by accessing high value markets across North America and globally.
The Marketing & New Ventures Division is also responsible for the development of new large-scale, or value chain extending projects, including those that seek to provide enhanced access to global markets and to support a transition to a lower-carbon economy. The Marketing & New Ventures Division includes Pembina's interest in the Cedar LNG project, a floating liquified natural gas ("LNG") export facility currently under construction (the "Cedar LNG Project"). Additionally, Pembina is pursuing opportunities associated with low-carbon commodities and large-scale greenhouse gas ("GHG") emissions reductions.
(1)Net capacity.
Pembina Pipeline Corporation Third Quarter 2025 7
Financial and Operational Overview by Division
| 3 Months Ended September 30 | ||||||||||||||||||||||||||||||||
| 2025 | 2024 | |||||||||||||||||||||||||||||||
($ millions, except where noted) | Volumes(1) | Earnings (loss) | Adjusted EBITDA(2) | Volumes(1) | Earnings (loss) | Adjusted EBITDA(2) | ||||||||||||||||||||||||||
| Pipelines | 2,750 | 477 | 630 | 2,738 | 433 | 593 | ||||||||||||||||||||||||||
| Facilities | 861 | 58 | 354 | 810 | 131 | 324 | ||||||||||||||||||||||||||
Marketing & New Ventures | 348 | 68 | 99 | 344 | 125 | 159 | ||||||||||||||||||||||||||
| Corporate | — | (205) | (49) | — | (215) | (57) | ||||||||||||||||||||||||||
| Income tax expense | — | (112) | — | — | (89) | — | ||||||||||||||||||||||||||
| Total | 286 | 1,034 | 385 | 1,019 | ||||||||||||||||||||||||||||
| 9 Months Ended September 30 | ||||||||||||||||||||||||||||||||
| 2025 | 2024 | |||||||||||||||||||||||||||||||
($ millions, except where noted) | Volumes(1) | Earnings (loss) | Adjusted EBITDA(2) | Volumes(1) | Earnings (loss) | Adjusted EBITDA(2) | ||||||||||||||||||||||||||
| Pipelines | 2,775 | 1,468 | 1,953 | 2,684 | 1,373 | 1,847 | ||||||||||||||||||||||||||
| Facilities | 861 | 384 | 1,030 | 823 | 489 | 974 | ||||||||||||||||||||||||||
Marketing & New Ventures | 340 | 342 | 383 | 319 | 324 | 490 | ||||||||||||||||||||||||||
| Corporate | — | (624) | (152) | — | (1,210) | (157) | ||||||||||||||||||||||||||
| Income tax (expense) recovery | — | (365) | — | — | 326 | — | ||||||||||||||||||||||||||
| Total | 1,205 | 3,214 | 1,302 | 3,154 | ||||||||||||||||||||||||||||
(1) Volumes in mboe/d. See the "Abbreviations" section of this MD&A for definition. Volumes for Pipelines and Facilities divisions are revenue volumes, which are physical volumes plus volumes recognized from take-or-pay commitments. Volumes for Marketing & New Ventures are marketed crude oil and NGL volumes.
(2) Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A.
8 Pembina Pipeline Corporation Third Quarter 2025
Equity Accounted Investees Overview by Division
| 3 Months Ended September 30 | ||||||||||||||||||||||||||||||||
| 2025 | 2024 | |||||||||||||||||||||||||||||||
| ($ millions, except where noted) | Share of loss | Adjusted EBITDA(5) | Contributions | Distributions | Volumes(6) | Share of (loss) profit | Adjusted EBITDA(5) | Contributions | Distributions | Volumes(6) | ||||||||||||||||||||||
Pipelines(1) | (1) | — | — | — | — | (1) | 1 | — | — | — | ||||||||||||||||||||||
Facilities(2) | (51) | 194 | 74 | 128 | 357 | 34 | 173 | 124 | 133 | 360 | ||||||||||||||||||||||
Marketing & New Ventures(3) | (14) | (1) | 34 | — | — | (50) | (1) | — | — | — | ||||||||||||||||||||||
| Total | (66) | 193 | 108 | 128 | 357 | (17) | 173 | 124 | 133 | 360 | ||||||||||||||||||||||
| 9 Months Ended September 30 | ||||||||||||||||||||||||||||||||
| 2025 | 2024 | |||||||||||||||||||||||||||||||
| ($ millions, except where noted) | Share of profit (loss) | Adjusted EBITDA(5) | Contributions | Distributions | Volumes(6) | Share of profit (loss) | Adjusted EBITDA(5) | Contributions | Distributions | Volumes(6) | ||||||||||||||||||||||
Pipelines(1)(4) | — | 3 | — | — | — | 42 | 88 | 5 | 80 | 49 | ||||||||||||||||||||||
Facilities(2) | 60 | 544 | 198 | 396 | 356 | 172 | 522 | 124 | 384 | 358 | ||||||||||||||||||||||
Marketing & New Ventures(3)(4) | (22) | (3) | 86 | — | — | (19) | 39 | 242 | 31 | 12 | ||||||||||||||||||||||
| Total | 38 | 544 | 284 | 396 | 356 | 195 | 649 | 371 | 495 | 419 | ||||||||||||||||||||||
(1) Pipelines includes Grand Valley.
(2) Facilities includes PGI and Fort Corp.
(3) Marketing and New Ventures includes Greenlight in 2025, Cedar LNG and ACG.
(4) For the comparative 2024 period, the results of Alliance and Aux Sable are equity-accounted for the first three months of the nine months ended September 30, 2024. Pembina owned a 50 percent interest in Alliance, approximately a 42.7 percent interest in Aux Sable's U.S operations, and a 50 percent interest in Aux Sable's Canadian operations up to the closing of the acquisition on April 1, 2024. Following the closing of the acquisition, the results of Alliance and Aux Sable are fully consolidated and incorporated into Pembina's financial results. See Note 3 to the Interim Financial Statements.
(5) Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A.
(6) Volumes in mboe/d. See the "Abbreviations" section of this MD&A for definition.
Refer to the "Segment Results – Changes in Results" sections of this MD&A under each of the divisions for additional information.
For the three and nine months ended September 30, 2025, contributions in the Facilities Division were made to PGI to partially fund growth capital projects. Contributions in Marketing & New Ventures in both 2025 and 2024 were made to Cedar LNG to fund the Cedar LNG Project. Refer to the "Segment Results – Marketing & New Ventures Division – Projects & New Developments" sections of this MD&A for additional information.
Pembina Pipeline Corporation Third Quarter 2025 9
Pipelines
Financial Overview for the Three Months Ended September 30
Results of Operations
| ($ millions, except where noted) | 2025 | 2024 | Change | |||||||||||
Pipelines revenue(1) | 882 | 860 | 22 | |||||||||||
Cost of goods sold(1) | 10 | 9 | 1 | |||||||||||
Net revenue(1)(2) | 872 | 851 | 21 | |||||||||||
Operating expenses(1) | 221 | 244 | (23) | |||||||||||
| Depreciation and amortization included in gross profit | 161 | 151 | 10 | |||||||||||
| Share of loss from equity accounted investees | (1) | (1) | — | |||||||||||
| Gross profit | 489 | 455 | 34 | |||||||||||
| Earnings | 477 | 433 | 44 | |||||||||||
Adjusted EBITDA(2) | 630 | 593 | 37 | |||||||||||
Volumes(3) | 2,750 | 2,738 | 12 | |||||||||||
| Change in Results | ||||||||
Net revenue(1)(2) | Increase largely the result of higher demand on seasonal contracts on the Alliance Pipeline, higher tolls on the Peace Pipeline system mainly related to contractual inflation adjustments, higher interruptible volumes on the Peace Pipeline, and higher contracted volumes on the Nipisi Pipeline. Higher net revenue on the NEBC Pipeline in the third quarter of 2025 was driven by the NEBC MPS Expansion being placed into service in November 2024. These increases were partially offset by lower tolls on the Cochin Pipeline due to the replacement of long-term contracts that expired in mid-July 2024, lower volumes on the Cochin Pipeline, discussed below, and lower recoverable costs. | |||||||
Operating expenses(1) | Decrease largely due to lower integrity and geotechnical spend on certain Pipelines assets, combined with minor decreases across multiple operating costs. | |||||||
| Depreciation and amortization included in gross profit | Higher primarily due to a decrease in the estimated useful life of an intangible asset. | |||||||
| Earnings | Increase largely due to the recognition of a gain on the sale of the North segment of the Western Pipeline in the third quarter of 2025, along with higher net revenue on certain Pipelines assets, discussed above. These increases were partially offset by higher depreciation and amortization expense as a result of a decrease in the estimated useful life of an intangible asset, along with lower revenue on the Cochin Pipeline. | |||||||
Adjusted EBITDA(2) | Increase largely due to higher net revenue on certain Pipelines assets, partially offset by lower tolls and volumes on the Cochin Pipeline. | |||||||
Volumes(3) | Higher largely due to increased contracted volumes on the Nipisi Pipeline and higher interruptible volumes on the Peace Pipeline system, partially offset by lower volumes on AEGS due to a temporary curtailment following a third-party outage that began in the second quarter of 2025 and continued into the third quarter. Additionally, narrower condensate price differentials resulted in lower interruptible volumes on the Cochin Pipeline, which was partially offset by higher contracted volumes as the third quarter in 2024 was impacted by a contracting gap from mid-July to August 1 2024, associated with the return of line fill to certain customers. | |||||||
Change in Adjusted EBITDA ($ millions)(1)(2)
(1) Includes inter-segment transactions. See Note 4 to the Interim Financial Statements.
(2) Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A.
(3) Revenue volumes in mboe/d. See the "Abbreviations" section of this MD&A for definition.
10 Pembina Pipeline Corporation Third Quarter 2025
Financial Overview for the Nine Months Ended September 30
Results of Operations
| ($ millions, except where noted) | 2025 | 2024 | Change | |||||||||||
Pipelines revenue(1) | 2,650 | 2,438 | 212 | |||||||||||
Cost of goods sold(1) | 37 | 35 | 2 | |||||||||||
Net revenue(1)(2) | 2,613 | 2,403 | 210 | |||||||||||
Operating expenses(1) | 604 | 601 | 3 | |||||||||||
| Depreciation and amortization included in gross profit | 477 | 410 | 67 | |||||||||||
| Share of profit from equity accounted investees | — | 42 | (42) | |||||||||||
| Gross profit | 1,532 | 1,434 | 98 | |||||||||||
| Earnings | 1,468 | 1,373 | 95 | |||||||||||
Adjusted EBITDA(2) | 1,953 | 1,847 | 106 | |||||||||||
Volumes(3) | 2,775 | 2,684 | 91 | |||||||||||
| Change in Results | ||||||||
Net revenue(1)(2) | Increase largely due to Pembina acquiring a controlling ownership interest in Alliance on April 1, 2024, and higher demand on seasonal contracts on the Alliance Pipeline. Also contributing to the increase were higher volumes on the Peace Pipeline system due to higher utilization in the 2025 period compared to the 2024 period which was impacted by planned outages for the Phase VIII Peace Pipeline Expansion, higher contracted volumes on the Peace Pipeline system and Nipisi Pipeline, and higher tolls on the Peace Pipeline system mainly related to contractual inflation adjustments. Higher net revenue on the NEBC Pipeline in the 2025 period due to the NEBC MPS Expansion being placed into service in November 2024, along with favourable U.S. dollar foreign exchange rate impacts on certain assets, also contributed to an increase to net revenue. These increases were offset in part by lower net revenue on the Cochin Pipeline largely due to lower tolls as a result of the replacement of long-term contracts that expired in mid-July 2024. In addition, lower volumes and tolls on the Vantage Pipeline, lower revenue at the Edmonton Terminals largely related to the decommissioning of the Edmonton South Rail Terminal in the second quarter of 2024, and lower recoverable power and geotechnical costs, contributed to a decrease to net revenue. | |||||||
Operating expenses(1) | Consistent with prior period. Higher costs related to Pembina acquiring a controlling ownership interest in Alliance on April 1, 2024 and higher environmental costs as the 2024 period included a recovery related to the Northern Pipeline system outage, were largely offset by lower geotechnical spend on certain Pipelines assets, combined with lower recoverable power costs resulting from a lower power pool price during the 2025 period. | |||||||
Depreciation and amortization included in gross profit | Higher largely due to Pembina acquiring a controlling ownership interest in Alliance on April 1, 2024, a decrease in the estimated useful life of an intangible asset in the 2025 period, and new assets placed into service in the second and fourth quarters of 2024. | |||||||
Share of profit from equity accounted investees | Following Pembina acquiring a controlling ownership interest in Alliance on April 1, 2024, the results from Alliance are no longer accounted for in share of profit and are fully consolidated. | |||||||
| Earnings | Higher largely due to the net impacts of Pembina acquiring a controlling ownership interest in Alliance on April 1, 2024 and higher seasonal revenue on the Alliance Pipeline, combined with higher revenue on the Peace Pipeline system, Nipisi Pipeline, and NEBC Pipeline. Earnings were also higher due to the recognition of a gain on the sale of the North segment of the Western Pipeline in the third quarter of 2025 and favourable foreign exchange rate impacts on certain assets. These factors were partially offset by lower net revenue on certain Pipelines assets, discussed above, along with higher depreciation and amortization expense as a result of a decrease in the estimated useful life of an intangible asset. | |||||||
Adjusted EBITDA(2) | Increase largely due to the same factors impacting earnings, discussed above, excluding the gain on the sale of the North segment of the Western Pipeline and the change in depreciation and amortization expense. | |||||||
Volumes(3) | Higher largely due to Pembina acquiring a controlling ownership interest in Alliance on April 1, 2024. Additionally, higher contracted volumes on the Peace Pipeline system and the Nipisi Pipeline, and higher utilization on the Peace Pipeline system in the 2025 period compared to the same period in 2024 which was impacted by planned outages for the Phase VIII Peace Pipeline Expansion, contributed to an increase to volumes. Higher contracted volumes on the Cochin Pipeline was due to the volumes in the third quarter of 2024 being impacted by a contracting gap from mid-July to August 1 2024, associated with the return of line fill to certain customers, which was largely offset by lower interruptible volumes in the third quarter of 2025 due to narrower condensate price differentials. These increases were also offset in part by lower volumes on AEGS due to a temporary curtailment following a third-party outage that began in the second quarter of 2025 and continued into the third quarter. | |||||||
Pembina Pipeline Corporation Third Quarter 2025 11
Change in Adjusted EBITDA ($ millions)(1)(2)
(1) Includes inter-segment transactions. See Note 4 to the Interim Financial Statements.
(2) Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A.
(3) Revenue volumes in mboe/d. See the "Abbreviations" section of this MD&A for definition.
Financial and Operational Overview
| 3 Months Ended September 30 | 9 Months Ended September 30 | |||||||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||||||||||||||||||
| ($ millions, except where noted) | Volumes(1) | Earnings | Adjusted EBITDA(2) | Volumes(1) | Earnings | Adjusted EBITDA(2) | Volumes(1) | Earnings | Adjusted EBITDA(2) | Volumes(1) | Earnings | Adjusted EBITDA(2) | ||||||||||||||||||||||||||
Pipelines(3) | ||||||||||||||||||||||||||||||||||||||
| Conventional | 1,001 | 308 | 351 | 992 | 264 | 318 | 1,013 | 906 | 1,060 | 990 | 828 | 997 | ||||||||||||||||||||||||||
| Transmission | 699 | 135 | 214 | 713 | 136 | 208 | 720 | 461 | 698 | 675 | 432 | 641 | ||||||||||||||||||||||||||
| Oil Sands & Heavy Oil | 1,050 | 34 | 65 | 1,033 | 33 | 67 | 1,042 | 101 | 195 | 1,019 | 113 | 209 | ||||||||||||||||||||||||||
| Total | 2,750 | 477 | 630 | 2,738 | 433 | 593 | 2,775 | 1,468 | 1,953 | 2,684 | 1,373 | 1,847 | ||||||||||||||||||||||||||
(1) Revenue volumes in mboe/d. See the "Abbreviations" section of this MD&A for definition.
(2) Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A.
(3) Includes values attributed to Pembina's conventional, transmission and oil sands and heavy oil assets within the Pipelines Division. Refer to Pembina's AIF for the year ended December 31, 2024.
Projects & New Developments(1)
The following outlines the projects and new developments that have recently come into service within Pipelines:
| Significant Projects | In-service Date | ||||
Phase VIII Peace Pipeline Expansion | May 2024 | ||||
| NEBC MPS Expansion | November 2024 | ||||
(1) For further details on Pembina's significant assets, including definitions for capitalized terms used herein that are not otherwise defined, refer to Pembina's AIF for the year ended December 31, 2024 filed at www.sedarplus.ca (filed with the U.S. Securities and Exchange Commission at www.sec.gov under Form 40-F) and on Pembina's website at www.pembina.com.
Pembina is advancing more than $1.0 billion of conventional NGL and condensate pipeline expansions to reliably and cost-effectively meet rising transportation demand from growing production in the WCSB. Pembina's outlook for volume growth is secured by long-term contracts underpinned by take-or-pay agreements, areas of dedication across the Montney and Duvernay formations, and other long-term agreements that ensure a strong base of committed volumes.
Engineering activities are continuing and subject to regulatory and board approval, Pembina expects to move forward with each of the following expansions:
•Fox Creek-to-Namao Expansion – an expansion of the Peace Pipeline system that, through the addition of new pump stations, would add approximately 70,000 bpd of propane-plus capacity to the market delivery pipelines from Fox Creek, Alberta to Namao, Alberta. A final investment decision is expected by the end of 2025.
•Taylor-to-Gordondale Project – a new approximately 89 kilometer, 16-inch pipeline proposed by Pouce Coupé Pipe Line Ltd. (a subsidiary of Pembina) connecting mostly condensate volumes from Taylor, British Columbia to the Gordondale, Alberta area. A final investment decision is anticipated in 2026.
•Birch-to-Taylor NEBC System Expansion – a new 95-kilometre pipeline and facility upgrades that would add propane-plus and condensate capacity to that segment of the NEBC Pipeline system. A final investment decision is expected in 2026.
12 Pembina Pipeline Corporation Third Quarter 2025
Facilities
Financial Overview for the Three Months Ended September 30
Results of Operations
| ($ millions, except where noted) | 2025 | 2024 | Change | |||||||||||
Facilities revenue(1) | 300 | 282 | 18 | |||||||||||
Operating expenses(1) | 134 | 123 | 11 | |||||||||||
Depreciation and amortization included in gross profit | 48 | 50 | (2) | |||||||||||
Share of (loss) profit from equity accounted investees | (51) | 34 | (85) | |||||||||||
| Gross profit | 67 | 143 | (76) | |||||||||||
| Earnings | 58 | 131 | (73) | |||||||||||
Adjusted EBITDA(2) | 354 | 324 | 30 | |||||||||||
Volumes(3) | 861 | 810 | 51 | |||||||||||
| Changes in Results | ||||||||
Revenue(1) | Increase largely due to higher utilization at the Redwater Complex and certain other Facilities assets in the third quarter of 2025 compared to the third quarter in 2024, which resulted in higher recoveries. | |||||||
Operating expenses(1) | Increase primarily due to higher utilization at the Redwater Complex and certain other Facilities assets in the third quarter of 2025 compared to the third quarter in 2024, which resulted in minor increases across multiple operating costs. | |||||||
| Share of (loss) profit from equity accounted investees | Decrease due to lower earnings from PGI largely the result of impairment of $146 million (net to Pembina, after tax), recognized on certain PGI assets. This was partially offset by the recognition of a $23 million gain (net to Pembina, after tax) following the amendment of PGI's credit facility in the third quarter of 2025, as well as lower losses recognized by PGI on interest rate derivative financial instruments. Additionally, offsets include higher contributions from certain PGI assets related to the net impact of PGI's acquisition of a 50 percent working interest in Whitecap Resources Inc.’s (“Whitecap”) Kaybob Complex and PGI’s acquisition of Whitecap’s Gold Creek and Karr oil batteries, in the fourth quarter of 2024 (collectively, the “Whitecap Transactions”). This is combined with higher capital recoveries due to a turnaround that began in the second quarter of 2025 and continued into the third quarter, and higher volumes at the Duvernay Complex. | |||||||
| Earnings | Decrease largely due to a share of loss from PGI in the third quarter of 2025, compared to a share of profit in the third quarter of 2024, discussed above. | |||||||
Adjusted EBITDA(2) | Increase primarily due to higher contributions from PGI assets related to the Whitecap Transactions, higher capital recoveries, and higher volumes at the Duvernay Complex. Included in adjusted EBITDA is $191 million (2024: $170 million) related to PGI. | |||||||
Volumes(3) | Increase is primarily attributed to higher volumes at the Redwater Complex and at Younger due to a planned outage and a rail strike impacting the Redwater Complex that occurred in the third quarter of 2024, which resulted in volume curtailments. Additionally, increased volumes at Aux Sable due to higher utilization in the 2025 period as the 2024 period was impacted by a nine-day unplanned outage in July 2024. These increases were partially offset by lower volumes at PGI, largely due to volume curtailments at certain PGI assets resulting from a turnaround that began in the second quarter of 2025 and continued into the third quarter, offset in part by higher volumes at the Duvernay Complex and on certain other PGI assets due to the Whitecap Transactions. Volumes include 357 mboe/d (2024: 360 mboe/d) related to PGI. | |||||||
Change in Adjusted EBITDA ($ millions)(1)(2)
(1) Includes inter-segment transactions. See Note 4 to the Interim Financial Statements.
(2) Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A.
(3) Revenue volumes in mboe/d. See the "Abbreviations" section of this MD&A for definition.
Pembina Pipeline Corporation Third Quarter 2025 13
Financial Overview for the Nine Months Ended September 30
Results of Operations
($ millions, except where noted) | 2025 | 2024 | Change | |||||||||||
Facilities revenue(1) | 902 | 807 | 95 | |||||||||||
Operating expenses(1) | 400 | 336 | 64 | |||||||||||
Depreciation and amortization included in gross profit | 152 | 128 | 24 | |||||||||||
Share of profit from equity accounted investees | 60 | 172 | (112) | |||||||||||
| Gross profit | 410 | 515 | (105) | |||||||||||
| Earnings | 384 | 489 | (105) | |||||||||||
Adjusted EBITDA(2) | 1,030 | 974 | 56 | |||||||||||
Volumes(3) | 861 | 823 | 38 | |||||||||||
| Changes in Results | ||||||||
Revenue(1) | Increase largely due to Pembina acquiring a controlling ownership interest in Aux Sable on April 1, 2024, combined with higher operating recoveries at the fractionation facilities within the Redwater Complex, partially offset by the impact of a planned outage at the Redwater Complex related to an asset upgrade in the second quarter of 2025. | |||||||
Operating expenses(1) | Increase largely due to Pembina acquiring a controlling ownership interest in Aux Sable on April 1, 2024, combined with higher integrity spending at the Redwater Complex, the majority of which are recovered in revenue, along with minor increases across multiple operating costs. | |||||||
| Depreciation and amortization included in gross profit | Higher largely due to Pembina acquiring a controlling ownership interest in Aux Sable on April 1, 2024, combined with an asset upgrade and associated retirement at the Redwater Complex in the second quarter of 2025, resulting in a planned outage during the same period. | |||||||
| Share of profit from equity accounted investees | Decrease due to lower earnings from PGI largely the result of impairment of $146 million (net to Pembina, after tax), recognized on certain PGI assets. Additionally, lower revenue driven by lower volumes as a result of outages at certain PGI assets in the second quarter of 2025 that continued into the third quarter, as well as third-party restrictions impacting the Dawson Assets, contributed to a decrease in share of profit from PGI. This was partially offset by the recognition of a $23 million gain (net to Pembina, after tax) following the amendment of PGI's credit facility and lower losses recognized by PGI on interest rate derivative financial instruments. Additionally, higher contributions due to the net impact of the Whitecap Transactions on certain PGI assets, higher capital recoveries due to a turnaround that began in the second quarter of 2025 and continued into the third quarter, and higher volumes at the Duvernay Complex, contributed to the offsetting increase to share of profit from PGI. | |||||||
| Earnings | Decrease primarily due to lower share of profit from PGI and higher depreciation expense. This was partially offset by the net impacts of Pembina acquiring a controlling ownership interest in Aux Sable on April 1, 2024. | |||||||
Adjusted EBITDA(2) | Increase primarily due to the net impacts of Pembina acquiring a controlling ownership interest in Aux Sable on April 1, 2024 and higher contributions from PGI largely the result of the Whitecap Transactions, higher capital recoveries, and higher volumes at the Duvernay Complex. This was partially offset by outages at certain PGI assets in the second quarter of 2025 that continued into the third quarter, and third-party restrictions impacting the Dawson Assets. Included in adjusted EBITDA is $537 million (2024: $516 million) related to PGI. | |||||||
Volumes(3) | Higher largely due to Pembina acquiring a controlling ownership interest in Aux Sable on April 1, 2024, combined with higher utilization in the 2025 period as the 2024 period was impacted by the nine-day unplanned outage at Aux Sable in July 2024. Additionally, higher volumes at the Redwater Complex and Younger were due to a planned outage and a rail strike impacting the Redwater Complex that occurred in the third quarter of 2024, which resulted in volume curtailments. These increases were partially offset by lower volumes at PGI, largely due to volume curtailments at certain PGI assets resulting from a turnaround that began in the second quarter of 2025 and continued into the third quarter, combined with third-party restrictions impacting the Dawson Assets, offset in part by higher volumes at the Duvernay Complex and on certain other PGI assets due to the Whitecap Transactions. Volumes include 356 mboe/d (2024: 358 mboe/d) related to PGI. | |||||||
Change in Adjusted EBITDA ($ millions)(1)(2)
(1) Includes inter-segment transactions. See Note 4 to the Interim Financial Statements.
(2) Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A.
(3) Revenue volumes in mboe/d. See the "Abbreviations" section of this MD&A for definition.
14 Pembina Pipeline Corporation Third Quarter 2025
Financial and Operational Overview
| 3 Months Ended September 30 | 9 Months Ended September 30 | |||||||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||||||||||||||||||
| ($ millions, except where noted) | Volumes(1) | Earnings (loss) | Adjusted EBITDA(2) | Volumes(1) | Earnings | Adjusted EBITDA(2) | Volumes(1) | Earnings | Adjusted EBITDA(2) | Volumes(1) | Earnings | Adjusted EBITDA(2) | ||||||||||||||||||||||||||
Facilities(3) | ||||||||||||||||||||||||||||||||||||||
| Gas Services | 598 | (33) | 219 | 584 | 47 | 194 | 602 | 118 | 623 | 598 | 222 | 595 | ||||||||||||||||||||||||||
| NGL Services | 262 | 91 | 135 | 226 | 84 | 130 | 258 | 266 | 407 | 225 | 267 | 379 | ||||||||||||||||||||||||||
| Total | 861 | 58 | 354 | 810 | 131 | 324 | 861 | 384 | 1,030 | 823 | 489 | 974 | ||||||||||||||||||||||||||
(1) Revenue volumes in mboe/d. See the "Abbreviations" section of this MD&A for definition.
(2) Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A.
(3) Includes values attributed to Pembina's gas services and NGL services assets within the Facilities operating segment. For a description of Pembina's gas and NGL assets, refer to Pembina's AIF for the year ended December 31, 2024.
Projects & New Developments(1)
Facilities continues to grow its natural gas and NGL processing and fractionation assets to service customer demand. The following outlines the projects and new developments within Facilities:
| RFS IV | ||||||||
Capital Budget: $525 million | ||||||||
Revised Capital Cost: $500 million | In-service Date(2): Q2 2026 | Status: On time, trending under budget | ||||||
RFS IV is a 55,000 bpd propane-plus fractionator at the existing Redwater fractionation and storage complex (the "Redwater Complex"). The project includes additional rail loading capacity and will leverage the design, engineering, and operating best practices of the existing facilities at the Redwater Complex. With the addition of RFS IV, the fractionation capacity at the Redwater Complex will total 256,000 bpd. Pembina has entered into a lump-sum engineering, procurement and construction agreement in respect of the project, for more than 70 percent of the project cost. Engineering, procurement, and fabrication is substantially complete, while field construction has progressed to approximately 75 percent complete. | ||||||||
| Wapiti Expansion | ||||||||
Capital Budget: $140 million (net to Pembina) | In-service Date(2): Q1 2026 | Status: On time, trending on budget | ||||||
PGI is developing an expansion that will increase natural gas processing capacity at the Wapiti Plant by 115 mmcf/d (gross to PGI). The expansion opportunity is driven by strong customer demand supported by growing Montney production and is fully underpinned by long-term, take-or-pay contracts. The project includes a new sales gas pipeline and other related infrastructure. During the third quarter of 2025, construction activities progressed, with tie-in work nearing completion. | ||||||||
| K3 Cogeneration Facility | ||||||||
Capital Budget: $70 million (net to Pembina) | In-service Date(2): Q1 2026 | Status: On time, trending under budget | ||||||
PGI is developing a 28 MW cogeneration facility at its K3 Plant, which is expected to reduce overall operating costs by providing power and heat to the gas processing facility, while reducing customers' exposure to power prices. The K3 Cogeneration Facility is expected to fully supply the K3 Plant's power requirements, with excess power sold to the grid at market rates. Further, through the utilization of the cogeneration waste heat and the low-emission power generated, the project is expected to contribute to a reduction in annual emissions compliance costs at the K3 Plant. During the third quarter of 2025, engineering work was completed and construction activities progressed. | ||||||||
| Prince Rupert Terminal Optimization | ||||||||
Capital Budget: $145 million | In-service Date(2): Mid-2028 | Status: Recently sanctioned | ||||||
| Pembina is optimizing its Prince Rupert Terminal ("PRT"), primarily through increasing storage capacity, that will allow PRT to accommodate Medium Gas Carrier vessels. The PRT optimization is expected to expand access to additional markets with higher realized propane prices, while significantly reducing shipping costs per unit, thereby improving netbacks for Pembina and its customers. The project was sanctioned in the second quarter of 2025. | ||||||||
(1) For further details on Pembina's significant assets, including definitions for capitalized terms used herein that are not otherwise defined, refer to Pembina's AIF for the year ended December 31, 2024 filed at www.sedarplus.ca (filed with the U.S. Securities and Exchange Commission at www.sec.gov under Form 40-F) and on Pembina's website at www.pembina.com.
(2) Subject to environmental and regulatory approvals. See the "Forward-Looking Statements & Information" section of this MD&A.
Pembina Pipeline Corporation Third Quarter 2025 15
Pursuant to an agreement with Whitecap, PGI has committed to support infrastructure development in the Lator area, including a new battery and gathering laterals (the "Lator Infrastructure"), which PGI will own. PGI anticipates funding up to $400 million ($240 million net to Pembina) for the battery and gathering laterals within the first phase of the Lator Infrastructure development, with all gas volumes flowing to PGI's Musreau facility upon startup, which is expected in the fourth quarter of 2026, supporting long-term plant utilization. Detailed engineering has been completed, long-lead equipment has been ordered, and site clearing is progressing.
Pursuant to an agreement with Whitecap, PGI has committed to fund capital up to $300 million ($180 million net to Pembina) for battery and gathering infrastructure in the Gold Creek and Karr areas, which is expected to be in service in the first half of 2026. Site clearing is complete, construction of the pipeline and detailed engineering is advancing, and the majority of long-lead equipment has been ordered.
Pursuant to an agreement with a Montney producer, PGI has committed to fund and acquire an under-construction battery and additional infrastructure (the "North Gold Creek Battery") in the Wapiti/North Gold Creek Montney area for a capital commitment up to $150 million ($90 million net to Pembina). The North Gold Creek Battery will be operated by the producer and highly contracted under a long-term, take-or-pay agreement. Site clearing has been completed and initial equipment has been set in place. The expected in-service date of the North Gold Creek Battery is the second quarter of 2026.
16 Pembina Pipeline Corporation Third Quarter 2025
Marketing & New Ventures
Financial Overview for the Three Months Ended September 30
Results of Operations
| ($ millions, except where noted) | 2025 | 2024 | Change | |||||||||||
Marketing revenue(1) | 861 | 938 | (77) | |||||||||||
Cost of goods sold(1) | 739 | 732 | 7 | |||||||||||
Net revenue(1)(2) | 122 | 206 | (84) | |||||||||||
Operating expenses(1) | 7 | 5 | 2 | |||||||||||
| Depreciation and amortization included in gross profit | 16 | 15 | 1 | |||||||||||
| Share of loss from equity accounted investees | (14) | (50) | 36 | |||||||||||
| Gross profit | 85 | 136 | (51) | |||||||||||
| Earnings | 68 | 125 | (57) | |||||||||||
Adjusted EBITDA(2) | 99 | 159 | (60) | |||||||||||
Crude oil sales volumes(3) | 111 | 117 | (6) | |||||||||||
NGL sales volumes(3) | 237 | 227 | 10 | |||||||||||
| Change in Results | ||||||||
Net revenue(1)(2) | Lower net revenue from contracts with customers was largely due to a decrease in NGL margins as a result of lower NGL prices and higher input natural gas prices at Aux Sable, partially offset by higher NGL marketed volumes and no similar impact to the nine-day unplanned outage at Aux Sable in July 2024. Lower revenue from risk management and physical derivative contracts was primarily due to lower realized gains on crude-oil based derivatives and lower unrealized gains on NGL-based derivatives in the third quarter of 2025 compared to the third quarter of 2024. These results were partially offset by unrealized gains on renewable power purchase agreements in the third quarter of 2025 compared to losses in the third quarter of 2024, along with lower realized losses on NGL-based derivatives. The third quarter of 2025 includes unrealized gains on commodity-related derivatives of $1 million (2024: $18 million gain) and realized gains on commodity-related derivatives of $39 million (2024: $70 million gain). | |||||||
| Share of loss from equity accounted investees | Increase due to lower unrealized losses on interest rate derivative financial instruments recognized by Cedar LNG, partially offset by unrealized foreign exchange losses on U.S. dollar denominated debt recognized in the third quarter of 2025 compared to gains in the third quarter of 2024. | |||||||
| Earnings | Decrease primarily due to lower revenue from risk management and physical derivative contracts, discussed above, combined with lower NGL margins. These decreases were partially offset by lower share of loss from Cedar LNG, higher NGL marketed volumes, and no similar impact to the nine-day unplanned outage at Aux Sable in July 2024. | |||||||
Adjusted EBITDA(2) | Decrease largely due to lower realized gains on crude-oil based derivatives and lower NGL margins, partially offset by lower realized losses on NGL-based derivative, higher NGL marketed volumes, and no similar impact to the nine-day unplanned outage at Aux Sable in July 2024. | |||||||
NGL sales volumes(3) | Increase primarily driven by higher supply volumes from the Redwater Complex as the third quarter of 2024 was impacted by a planned outage and a rail strike, which resulted in volume curtailments, combined with no similar impact to the nine-day unplanned outage at Aux Sable in July 2024. This was partially offset by lower ethane sales at Aux Sable. | |||||||
Change in Adjusted EBITDA ($ millions)(1)(2)
(1) Includes inter-segment transactions. See Note 4 to the Interim Financial Statements.
(2) Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A.
(3) Marketed crude oil and NGL volumes in mboe/d. See the "Abbreviations" section of this MD&A for definition.
Pembina Pipeline Corporation Third Quarter 2025 17
Financial Overview for the Nine Months Ended September 30
Results of Operations
| ($ millions, except where noted) | 2025 | 2024 | Change | |||||||||||
Marketing revenue(1) | 3,080 | 2,663 | 417 | |||||||||||
Cost of goods sold(1) | 2,597 | 2,279 | 318 | |||||||||||
Net revenue(1)(2) | 483 | 384 | 99 | |||||||||||
Operating expenses(1) | 24 | 13 | 11 | |||||||||||
| Depreciation and amortization included in gross profit | 53 | 47 | 6 | |||||||||||
| Share of loss from equity accounted investees | (22) | (19) | (3) | |||||||||||
| Gross profit | 384 | 305 | 79 | |||||||||||
| Earnings | 342 | 324 | 18 | |||||||||||
Adjusted EBITDA(2) | 383 | 490 | (107) | |||||||||||
Crude oil sales volumes(3) | 98 | 99 | (1) | |||||||||||
NGL sales volumes(3) | 242 | 220 | 22 | |||||||||||
| Change in Results | ||||||||
Net revenue(1)(2) | Higher revenue from risk management and physical derivative contracts was primarily due to unrealized gains on renewable power purchase agreements, largely due to improved forward power price, and on NGL-based derivatives in the 2025 period, compared to losses in the same period in 2024. In addition, lower realized losses on NGL-based derivatives compared to the 2024 period, contributed to an increase in net revenue. These increases were partially offset by lower realized gains on crude oil-based derivatives. The 2025 period includes unrealized gains on commodity-related derivatives of $41 million (2024: $129 million loss) and realized gains on commodity-related derivatives of $98 million (2024: $189 million gain). Lower net revenue from contracts with customers was largely due to a decrease in NGL margins from Aux Sable primarily due to higher input natural gas prices and lower volumes resulting from third-party restrictions and planned outages. This was partially offset by no similar impact to the nine-day unplanned outage at Aux Sable in July 2024. Additionally, WCSB NGL margins decreased largely due to lower NGL prices, which was partially offset by Pembina acquiring a controlling ownership interest in Aux Sable on April 1, 2024. | |||||||
| Operating expenses | Increase due to higher transportation costs. | |||||||
| Share of loss from equity accounted investees | Consistent with prior period. The share of loss in the 2025 period is due to unrealized losses on interest rate derivatives recognized by Cedar LNG, partially offset by unrealized foreign exchange gains on U.S. dollar denominated debt. The share of loss in the 2024 period relates to Cedar LNG's unrealized losses on interest rate derivatives, partially offset by the results from Aux Sable from the first quarter of 2024, which is now fully consolidated following Pembina acquiring a controlling ownership interest on April 1, 2024. | |||||||
| Earnings | Increase largely due to the net impacts of Pembina acquiring a controlling ownership interest in Aux Sable on April 1, 2024, higher revenue from risk management and physical derivative contracts, and lower share of loss from Cedar LNG. These increases were partially offset by lower NGL margins, and no similar gain to that recognized in the 2024 period associated with the derecognition of the provision related to financial assurances provided by Pembina which were assumed by Cedar LNG following the positive final investment decision in respect of the Cedar LNG Project in June 2024. | |||||||
Adjusted EBITDA(2) | Decrease primarily due to lower realized gains on crude oil-based derivatives, lower NGL margins, partially offset by the net impacts of Pembina acquiring a controlling ownership interest in Aux Sable on April 1, 2024 and lower realized losses on NGL-based derivatives. | |||||||
NGL sales volumes(3) | Increase due to higher ethane, propane, and butane sales largely due to the increase in Pembina's ownership interest in Aux Sable and no similar impact to the nine-day unplanned outage at Aux Sable in July 2024. | |||||||
Change in Adjusted EBITDA ($ millions)(1)(2)
(1) Includes inter-segment transactions. See Note 4 to the Interim Financial Statements.
(2) Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A.
(3) Marketed crude oil and NGL volumes in mboe/d. See the "Abbreviations" section of this MD&A for definition.
18 Pembina Pipeline Corporation Third Quarter 2025
Financial and Operational Overview
| 3 Months Ended September 30 | 9 Months Ended September 30 | |||||||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||||||||||||||||||
| ($ millions, except where noted) | Volumes(1) | Earnings (loss) | Adjusted EBITDA(2) | Volumes(1) | Earnings (loss) | Adjusted EBITDA(2) | Volumes(1) | Earnings (loss) | Adjusted EBITDA(2) | Volumes(1) | Earnings (loss) | Adjusted EBITDA(2) | ||||||||||||||||||||||||||
Marketing & New Ventures(3) | ||||||||||||||||||||||||||||||||||||||
| Marketing | 348 | 88 | 106 | 344 | 178 | 163 | 340 | 381 | 399 | 319 | 336 | 494 | ||||||||||||||||||||||||||
New Ventures(4) | — | (20) | (7) | — | (53) | (4) | — | (39) | (16) | — | (12) | (4) | ||||||||||||||||||||||||||
| Total | 348 | 68 | 99 | 344 | 125 | 159 | 340 | 342 | 383 | 319 | 324 | 490 | ||||||||||||||||||||||||||
(1) Marketed crude oil and NGL volumes in mboe/d. See the "Abbreviations" section of this MD&A for definition.
(2) Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A.
(3) Includes values attributed to Pembina's marketing activities and new ventures projects within the Marketing & New Ventures operating segment. For further details on Pembina's marketing activities and projects, refer to Pembina's AIF for the year ended December 31, 2024.
(4) All New Ventures projects have not yet commenced operations and therefore have no volumes.
Projects & New Developments(1)
The New Ventures group is responsible for the development of new large-scale, or value chain extending projects, including those that provide enhanced access to global markets and support a transition to a lower-carbon economy.
| Cedar LNG | ||||||||
Capital Budget: U.S. $2 billion (net) | In-service Date: Late-2028 | Status: On time, on budget | ||||||
The Haisla Nation and Pembina are partners in Cedar LNG Partners LP ("Cedar LNG"), which is constructing the Cedar LNG Project, a floating liquefied natural gas ("LNG") facility with a nameplate capacity of 3.3 million tonnes per annum ("mtpa"), located in the traditional territory of the Haisla Nation, on Canada’s West Coast. The project is strategically positioned to leverage Canada's abundant natural gas supply and deliver a lower-carbon energy option to global markets. The facility will be powered by renewable electricity from BC Hydro, making it one of the lowest emitting LNG facilities in the world. Construction of the floating LNG vessel, including the hull and top side facilities remains on schedule. Pipeline construction is ahead of schedule, including the completion of all horizontal direct drill ("HDD") crossings. Tree clearing on the transmission line right of way is underway and work on the marine terminal site continues with construction of the retaining wall progressing. | ||||||||
| Cedar LNG has secured a 20-year take-or-pay, fixed toll contract with ARC Resources Ltd. ("ARC") for 1.5 mtpa of LNG. Pembina previously signed a 20-year take-or-pay liquefaction tolling service agreement for 1.5 mtpa of LNG to support the final investment decision on Cedar LNG in June 2024 with the expectation of remarketing the capacity at a later stage. Subsequent to the quarter, Pembina announced a 20-year take-or-pay agreement with PETRONAS related to 1.0 mtpa of liquefaction capacity at Cedar LNG, marking the first step in Pembina's remarketing efforts. Pembina expects to reach definitive agreements for the remaining 0.5mtpa of capacity by the end of 2025. | ||||||||
Pembina, and its partner Kineticor, an OPTrust portfolio company, continue to make significant progress towards the commercialization of the Greenlight Electricity Centre ("Greenlight"). Greenlight is a proposed multi-phased natural gas-fired combined cycle power generation facility, to be located in Sturgeon County, Alberta, with a capacity of up to approximately 1,800 megawatts designed to advance Alberta's innovation economy. The partners continue to progress towards a final investment decision in the first half of 2026.
(1) For further details on Pembina's significant assets, including definitions for capitalized terms used herein that are not otherwise defined, refer to Pembina's AIF for the year ended December 31, 2024 filed at www.sedarplus.ca (filed with the U.S. Securities and Exchange Commission at www.sec.gov under Form 40-F) and on Pembina's website at www.pembina.com.
Pembina Pipeline Corporation Third Quarter 2025 19
Corporate and Income Tax
Financial Overview for the Three Months Ended September 30
Results of Operations
| ($ millions) | 2025 | 2024 | Change | |||||||||||
Revenue(1)(2) | 13 | 11 | 2 | |||||||||||
| General and administrative | 83 | 84 | (1) | |||||||||||
| Other (income) expense | (1) | 5 | (6) | |||||||||||
| Net finance costs | 140 | 139 | 1 | |||||||||||
| Earnings (loss) | (205) | (215) | 10 | |||||||||||
Adjusted EBITDA(3) | (49) | (57) | 8 | |||||||||||
| Income tax expense | 112 | 89 | 23 | |||||||||||
| Change in Results | ||||||||
| Earnings (loss) | Increase largely due to lower incentive costs and integration costs, partially offset by minor increases in other general and administrative expenses. | |||||||
Adjusted EBITDA(3) | Consistent with prior period. Lower incentive costs were largely offset by minor increases across multiple other general and administrative expenses. | |||||||
| Income tax expense | Increase largely due to higher taxable earnings in the current period. | |||||||
Financial Overview for the Nine Months Ended September 30
Results of Operations
| ($ millions) | 2025 | 2024 | Change | |||||||||||
Revenue(1)(2) | 35 | 34 | 1 | |||||||||||
General and administrative | 246 | 238 | 8 | |||||||||||
| Other (income) expense | (1) | 27 | (28) | |||||||||||
| Loss on acquisition | — | 616 | (616) | |||||||||||
| Net finance costs | 419 | 367 | 52 | |||||||||||
| Earnings (loss) | (624) | (1,210) | 586 | |||||||||||
Adjusted EBITDA(3) | (152) | (157) | 5 | |||||||||||
| Income tax expense (recovery) | 365 | (326) | 691 | |||||||||||
| Change in Results | ||||||||
| General and administrative | Consistent with prior period. Increases in salaries and wages as well as other general and administrative expenses, were largely offset by lower long-term incentives costs, driven by the change in Pembina's share price in the 2025 period compared to the same period in 2024. | |||||||
| Other (income) expense | Decrease primarily due to lower acquisition fees and integration costs compared to those incurred in the prior period following Pembina acquiring a controlling ownership interest in Alliance and Aux Sable on April 1, 2024. | |||||||
| Loss on acquisition | In the second quarter of 2024, Pembina recognized a $616 million loss from the disposition of Pembina's previous investments in the Alliance, Aux Sable, and NRGreen joint ventures following Pembina's acquisition of a controlling interest in the joint ventures, offset by a $626 million deferred tax recovery recognized from the acquisition, resulting in a net gain of $10 million. | |||||||
| Net finance costs | Increase primarily due to lower interest income, along with higher interest expense on long-term debt, resulting from a combination of both additional borrowing following Pembina acquiring a controlling ownership interest in Alliance and Aux Sable on April 1, 2024 and higher interest rates. | |||||||
| Earnings (loss) | Increase largely due to no similar loss recognized in 2025, compared to the loss recognized in the second quarter of 2024 following Pembina acquiring a controlling ownership interest in Alliance and Aux Sable on April 1, 2024, combined with lower acquisition fees and integration costs, discussed above. This was partially offset by higher net finance costs. | |||||||
Adjusted EBITDA(3) | Consistent with prior period. Minor increases in other general and administrative expenses, were largely offset by lower long-term incentives costs. | |||||||
| Income tax expense (recovery) | Income tax expense in the current period was due to no similar items to that recognized in the 2024 period. These included a deferred tax recovery in connection with Pembina acquiring a controlling ownership interest in Alliance and Aux Sable, and an adjustment in the tax basis of an investment in partnership. Additionally, higher taxable earnings contributed to the tax expense this period. As a result, the effective tax rate for the current period was 23 percent compared to a 33 percent effective tax recovery rate in the 2024 period. | |||||||
(1) Excludes inter-segment eliminations.
(2) Primarily consists of fixed fee income related to shared service agreements with PGI.
(3) Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A.
20 Pembina Pipeline Corporation Third Quarter 2025
4. LIQUIDITY & CAPITAL RESOURCES
Available Sources of Liquidity
($ millions) | September 30, 2025 | December 31, 2024 | ||||||
Working capital(1) | (1,163) | (1,335) | ||||||
Variable rate debt | ||||||||
Senior unsecured credit facilities(2) | 1,477 | 1,148 | ||||||
| Interest rate swapped debt | — | (360) | ||||||
Total variable rate loans and borrowings outstanding (weighted average interest rate of 4.6% (2024: 5.2%)) | 1,477 | 788 | ||||||
Fixed rate debt | ||||||||
| Senior unsecured medium-term notes | 10,350 | 10,900 | ||||||
| Interest rate swapped debt | — | 360 | ||||||
Total fixed rate loans and borrowings outstanding (weighted average interest rate of 4.5% (2024: 4.4%)) | 10,350 | 11,260 | ||||||
| Total loans and borrowings outstanding | 11,827 | 12,048 | ||||||
| Cash and unutilized debt facilities | 2,063 | 2,518 | ||||||
Subordinated hybrid notes (weighted average interest rate of 5.1% (2024: 4.8%)) | 800 | 600 | ||||||
(1) Current assets of $1.3 billion (December 31, 2024: $1.6 billion) less current liabilities of $2.5 billion (December 31, 2024: $2.9 billion). As at September 30, 2025, working capital included $1,093 million (December 31, 2024: $1.5 billion) associated with the current portion of long-term debt and $149 million (December 31, 2024: $141 million) in cash.
(2) Includes U.S. $250 million variable rate debt outstanding at September 30, 2025 (December 31, 2024: U.S. $250 million).
Pembina currently anticipates that its cash flow from operating activities, the majority of which is derived from fee-based contracts, will be more than sufficient to meet its operating obligations, to fund its dividends and to fund its capital expenditures in the short term and long term. Pembina expects to source funds required for debt maturities from cash, its credit facilities and by accessing the capital markets, as required. Based on its successful access to financing in the capital markets over the past several years, Pembina expects to continue to have access to additional funds as required. Refer to "Risk Factors – General Risk Factors – Additional Financing and Capital Resources" in Pembina's MD&A for the year ended December 31, 2024 and Note 24 to the Consolidated Financial Statements for more information. Management continues to monitor Pembina's liquidity and remains satisfied that the leverage employed in Pembina's capital structure is sufficient and appropriate given the characteristics and operations of the underlying asset base.
Management may adjust Pembina's capital structure as a result of changes in economic conditions or the risk characteristics of the underlying assets. To maintain or modify Pembina's capital structure in the future, Pembina may renegotiate debt terms, repay existing debt, seek new borrowings, issue additional equity or hybrid securities and/or repurchase or redeem additional common or preferred shares.
As at September 30, 2025, Pembina's credit facilities (collectively, the "Credit Facilities") consisted of: an unsecured $2.5 billion (December 31, 2024: $1.5 billion) revolving credit facility, which includes a $750 million (December 31, 2024: $750 million) accordion feature, which provides Pembina with the ability to increase the credit facility subject to lender approval, and matures in June 2030 (the "Revolving Facility"); an unsecured U.S. $250 million (December 31, 2024: U.S. $250 million) non-revolving term loan, which matures in April 2030; and an operating facility of $50 million (December 31, 2024: $50 million), which matures in June 2026 and is typically renewed on an annual basis. Additionally, Pembina's Credit Facilities includes a $270 million (December 31, 2024: $270 million) term loan and a U.S. $160 million (December 31, 2024: $240 million) term loan assumed from Alliance, which both mature in December 2025. The increase in the Revolving Facility reflects the cancellation of the $1.0 billion (December 31, 2024: $1.0 billion) sustainability-linked revolving credit facility in September 2025, which previously matured in June 2027, and its addition to the Revolving Facility.
There are no mandatory principal repayments due over the term of the Credit Facilities. Pembina is required to meet certain specific and customary affirmative and negative financial covenants under the indenture governing its medium-term notes and the agreements governing its Credit Facilities, including a requirement to maintain certain financial ratios. See "Liquidity & Capital Resources – Covenants" below for more information.
Pembina Pipeline Corporation Third Quarter 2025 21
Pembina is also subject to customary restrictions on its operations and activities under the indenture governing its medium-term notes and the agreements governing its Credit Facilities, including restrictions on the granting of security, incurring indebtedness and the sale of its assets.
Financing Activity
On April 2, 2025, Pembina completed an extension on its unsecured U.S. $250 million non-revolving term loan, which now matures in April 2030.
On June 6, 2025, Pembina closed a $200 million offering of Fixed-to-Fixed Rate Subordinated Notes, Series 2 (the "Series 2 Subordinated Notes") due June 6, 2055. The Series 2 Subordinated Notes bear interest at a rate of 5.95 percent, which will reset on June 6, 2035, and on every fifth anniversary thereafter, based on the five-year Government of Canada yield plus 2.713 percent, provided that the interest rate during any subsequent fixed rate period will not be less than 5.95 percent. Pembina's Series 2 Subordinated Notes are subject to optional redemption by Pembina from March 6, 2035 to June 6, 2035, and thereafter, on any interest payment date or any interest reset date, as applicable. Pembina may also redeem the Series 2 Subordinated Notes in certain other limited circumstances. Pembina used the net proceeds of the offering of the Series 2 Subordinated Notes to fund the redemption of its outstanding Cumulative Redeemable Rate Reset Class A Preferred Shares, Series 19 ("Series 19 Class A Preferred Shares") on June 30, 2025.
On July 23, 2025, Pembina announced the approval of amendments (the "Amendments") to the indenture governing Pembina's 4.80 percent Fixed-to-Fixed Rate Subordinated Notes, Series 1 (the "Series 1 Subordinated Notes") due January 25, 2081. The Amendments provided for, among other things, the exchange (the "Note Exchange") of all of the outstanding Series 1 Subordinated Notes for an equal principal amount of 4.80 percent Fixed-to-Fixed Rate Subordinated Notes, Series 3 of Pembina (the "Series 3 Subordinated Notes") due January 25, 2081. The Series 3 Subordinated Notes have the same economic terms as the Series 1 Subordinated Notes, including interest rate, interest payment dates, interest reset dates, maturity date and redemption provisions, but do not provide for an entitlement to delivery of preferred shares upon the occurrence of certain bankruptcy and related events. The Note Exchange was completed on July 25, 2025, following the execution of the supplemental indenture implementing the Amendments. The Series 3 Subordinated Notes rank equally in right of payment with the Series 2 Subordinated Notes. Pursuant to the mandatory redemption provisions attached to the Class A Preferred Shares, Series 2021-A (the "Series 2021-A Class A Preferred Shares"), in connection with the Note Exchange, on July 28, 2025, Pembina redeemed all of the issued and outstanding Series 2021-A Class A Preferred Shares (refer to the "Share Capital - Preferred Shares" section of this MD&A for further information).
On September 9, 2025, Pembina completed an extension on its $2.5 billion Revolving Facility, which now matures on June 1, 2030.
Subsequent to the end of the third quarter of 2025, on October 10, 2025, Pembina closed a $225 million offering of Series 2 Subordinated Notes pursuant to a re-opening. Following closing of the offering of the Series 2 Subordinated Notes, $425 million aggregate principal amount of Series 2 Subordinated Notes are issued and outstanding. Pembina intends to use the net proceeds of the offering to fund the redemption of its outstanding Cumulative Redeemable Rate Reset Class A Preferred Shares, Series 9 (the "Series 9 Class A Preferred Shares") and for general corporate purposes.
Subsequent to the end of third quarter of 2025, on October 31, 2025, Pembina closed a $600 million non-revolving term loan ("Two-Year Term Loan") with certain existing lenders. The proceeds of the Two-Year Term Loan have been used to repay the $270 million term loan outstanding at Alliance, and existing amounts drawn under Pembina's $2.5 billion revolving credit facility. The Two-Year Term Loan has an initial term of two years and is pre-payable at the option of Pembina. The other terms and conditions of the Two-Year Term Loan, including financial covenants, are substantially similar to Pembina's $2.5 billion revolving credit facility.
22 Pembina Pipeline Corporation Third Quarter 2025
Covenants
Pembina is subject to certain financial covenants under the indentures governing its medium-term notes and the agreements governing the credit facilities. As at September 30, 2025, Pembina was in compliance with those covenants (December 31, 2024: in compliance).
| Debt | Financial Covenant(1) | Ratio | Ratio as at September 30, 2025 | |||||||||||
| Senior unsecured medium-term notes | Funded Debt to Capitalization | Maximum 0.70(2) | 0.40 | |||||||||||
| Credit facilities | Debt to Capital | Maximum 0.70(3) | 0.40 | |||||||||||
(1) Terms as defined in relevant agreements.
(2) Covenant must be met at the reporting date and filed within 90 days after the end of each fiscal year and within 10 business days after filing of the Consolidated Financial Statements.
(3) Covenant must be met at the reporting date and filed within 120 days after the end of each fiscal year and 60 days after each quarter.
Credit Risk
Pembina continues to actively monitor and reassess the creditworthiness of its counterparties. The majority of Pembina's credit exposure is to investment grade counterparties. Pembina assesses all high exposure counterparties during the on-boarding process and actively monitors credit limits and exposure across the business. Pembina may reduce or mitigate its exposure to certain counterparties where it is deemed warranted and permitted under contractual terms. Where warranted, financial assurances may be sought from counterparties to mitigate and reduce risk, and such assurances may include guarantees, letters of credit and cash collateral. Letters of credit totaling $245 million (December 31, 2024: $276 million) were held by Pembina as at September 30, 2025, primarily in respect of customer trade receivables.
Credit Ratings
The following information with respect to Pembina's credit ratings is provided as such information relates to Pembina's financing costs and liquidity. Specifically, credit ratings affect Pembina's ability to obtain short-term and long-term financing and the cost of such financing. A reduction in the current ratings of Pembina's debt by its rating agencies, particularly a downgrade below investment-grade ratings, could adversely affect Pembina's cost of financing and its access to sources of liquidity and capital. In addition, changes in credit ratings and the associated costs may affect Pembina's ability to enter into normal course derivative or hedging transactions. Credit ratings are intended to provide investors with an independent measure of the credit quality of any issues of securities. The credit ratings assigned by the rating agencies are not recommendations to purchase, hold or sell the securities, nor do the credit rating agencies comment on the market price or suitability for a particular investor. Any credit rating may not remain in effect for a given period of time or may be revised or withdrawn entirely by a rating agency in the future if, in its judgment, circumstances so warrant.
DBRS Limited ("DBRS") rates Pembina's senior unsecured medium-term notes 'BBB (high)'. DBRS has also assigned a debt rating of 'BBB (low)' to Pembina's subordinated notes and a rating of 'Pfd-3 (high)' for each issued series of Pembina's Class A Preferred Shares.
The long-term corporate credit rating assigned by S&P Global Ratings ("S&P") on Pembina is 'BBB'. S&P has also assigned a debt rating of 'BBB' to Pembina's senior unsecured medium-term notes, a debt rating of 'BB+' to Pembina's Fixed-To-Fixed Rate Subordinated Notes, and a rating of 'P-3 (High)' to each issued series of Pembina's Class A Preferred Shares.
Refer to "Description of the Capital Structure of Pembina – Credit Ratings" in the AIF for the year ended December 31, 2024 for further information.
Pembina Pipeline Corporation Third Quarter 2025 23
Commitments and Off-Balance Sheet Arrangements
Commitments
Pembina had the following contractual obligations outstanding as at September 30, 2025:
Contractual Obligations(1) | Payments Due By Period | ||||||||||||||||
| ($ millions) | Total | Less than 1 year | 1 – 3 years | 3 – 5 years | After 5 years | ||||||||||||
Long-term debt(2) | 19,493 | 1,714 | 2,176 | 3,054 | 12,549 | ||||||||||||
Transportation and processing(3) | 11,270 | 46 | 165 | 1,091 | 9,968 | ||||||||||||
Leases(4) | 857 | 116 | 210 | 154 | 377 | ||||||||||||
Construction commitments(5) | 438 | 295 | 113 | 30 | — | ||||||||||||
Other commitments related to lease contracts(6) | 613 | 45 | 98 | 161 | 309 | ||||||||||||
| Funding commitments, software, and other | 125 | 100 | 24 | 1 | — | ||||||||||||
Total contractual obligations | 32,796 | 2,316 | 2,786 | 4,491 | 23,203 | ||||||||||||
(1)Pembina enters into product purchase agreements and power purchase agreements to secure supply for future operations. Purchase prices of both NGL and power are dependent on current market prices. Volumes and prices for NGL and power contracts cannot be reasonably determined, and therefore, an amount has not been included in the contractual obligations schedule. Product purchase agreements range from one to 16 years and involve the purchase of NGL products from producers. Assuming product is available, Pembina has secured between 25 and 197 mbpd of NGL each year up to and including 2040. Power purchase agreements range from one to 25 years and involve the purchase of power from electrical service providers. Pembina has secured up to 76 megawatts per day each year up to and including 2049.
(2)Includes loans and borrowings, subordinated hybrid notes and interest payments on Pembina's senior unsecured medium-term notes and subordinated hybrid notes. Excludes deferred financing costs.
(3)Pembina signed two transportation and processing related agreements relating to the Cedar LNG Project: (a) Liquefaction Tolling Services Agreement ("LTSA"); and, (b) Gas Supply Agreement ("GSA"). The LTSA is a 20-year take-or-pay fixed toll contract for 1.5 million tonnes per annum, while the GSA will allow for transport on the Coastal GasLink Pipeline of approximately 200 million cubic feet per day of Canadian natural gas to Cedar LNG. These commercial agreements account for approximately 50 percent of the operating capacity for the Cedar LNG Project and a total commitment of approximately $10.5 billion. These commitments are expected to commence upon the anticipated in-service date of the Cedar LNG Project in late 2028.
(4)Includes pipelines, facilities, terminals, rail, office space, land and vehicle leases.
(5)Excludes projects that are executed by equity accounted investees.
(6)Relates to expected variable lease payments excluded from the measurement of the lease liability, payments under lease contracts which have not yet commenced, and payments related to non-lease components in lessee lease contracts.
Contingencies
Pembina, including its subsidiaries and its investments in equity accounted investees, are subject to various legal and regulatory and tax proceedings, actions and audits arising in the normal course of business. Pembina represents its interests vigorously in all proceedings in which it is involved. Legal and administrative proceedings involving possible losses are inherently complex, and the Company applies significant judgment in estimating probable outcomes. As at September 30, 2025, there were no significant claims filed against Pembina for which management believes the resolution of any such actions or proceedings would have a material impact on Pembina's financial position or results of operations.
Off-Balance Sheet Arrangements
As at September 30, 2025, Pembina did not have any off-balance sheet arrangements that have, or are reasonably likely to have, a current or future effect on Pembina's financial condition, results of operations, liquidity or capital expenditures.
Letters of Credit
Pembina has provided letters of credit to various third parties in the normal course of conducting business. The letters of credit include financial guarantees to counterparties for product purchases and sales, transportation services, utilities, engineering and construction services. The letters of credit have not had, and are not expected to have, a material impact on Pembina's financial position, earnings, liquidity or capital resources. As at September 30, 2025, Pembina had $121 million (December 31, 2024: $209 million) in letters of credit issued.
24 Pembina Pipeline Corporation Third Quarter 2025
5. SHARE CAPITAL
Common Shares
On May 14, 2025, the Toronto Stock Exchange ("TSX") accepted the renewal of Pembina's normal course issuer bid (the "NCIB") that allows the Company to repurchase, at its discretion, up to five percent of the Company's outstanding common shares (representing approximately 29 million common shares) through the facilities of the TSX, the New York Stock Exchange and/or alternative Canadian trading systems or as otherwise permitted by applicable securities law, subject to certain restrictions on the number of common shares that may be purchased on a single day. The NCIB commenced on May 16, 2025 and will expire on the earlier of May 15, 2026, the date on which Pembina has acquired the maximum number of common shares allowable under the NCIB or the date on which Pembina otherwise decides not to make any further repurchases under the NCIB. No common shares were purchased by Pembina during the three and nine months ended September 30, 2025.
Common Share Dividends
Common share dividends are payable if, as and when declared by Pembina's Board of Directors. The amount and frequency of dividends declared and payable is at the discretion of Pembina's Board of Directors, which considers earnings, cash flow, capital requirements, the financial condition of Pembina and other relevant factors when making its dividend determination.
Preferred Shares
On January 8, 2025, Pembina redeemed all of the approximately one million issued and outstanding Cumulative Redeemable Floating Rate Class A Preferred Shares, Series 22 ("Series 22 Class A Preferred Shares") at a redemption price of $25.50 per Series 22 Class A Preferred Share, plus all accrued and unpaid dividends thereon. Pembina had announced its intention to redeem the Series 22 Class A Preferred Shares during the fourth quarter of 2024 and, as a result, the equity was reclassified as a financial liability of approximately $26 million for the total redemption price in that same quarter.
On June 30, 2025, Pembina redeemed all of the eight million issued and outstanding Series 19 Class A Preferred Shares at a redemption price of $25.00 per Series 19 Class A Preferred Share. The total redemption price for the Series 19 Class A Preferred Shares was $200 million.
On July 28, 2025, in connection with the Note Exchange, Pembina redeemed all of the 600,000 issued and outstanding Series 2021-A Class A Preferred Shares, which were deliverable to holders of the Series 1 Subordinated Notes following the occurrence of certain bankruptcy and related events. The Series 2021-A Class A Preferred Shares were issued by Pembina to Computershare Trust Company of Canada to be held in trust to satisfy its obligations under the indenture governing the Series 1 Subordinated Notes.
Subsequent to the end of the third quarter, on October 10, 2025, in connection with the closing of the offering of the Series 2 Subordinated Notes, Pembina announced its intention to use the net proceeds to fund the redemption of all of its outstanding Series 9 Class A Preferred Shares on December 1, 2025 at a price equal to $25.00 per Series 9 Class A Preferred Share. The total redemption price for the Series 9 Class A Preferred Shares will be $225 million.
Preferred Share Dividends
The holders of Pembina's Class A Preferred Shares are entitled to receive fixed or floating cumulative dividends, as applicable. Dividends on the Series 1, 3, 5, 7, 9, and 21 Class A Preferred Shares are payable quarterly on the first day of March, June, September and December, if, as and when declared by the Board of Directors of Pembina. Dividends on the Series 15 and 17 Class A Preferred Shares are payable on the last day of March, June, September and December in each year, if, as and when declared by the Board of Directors of Pembina. Dividends on the Series 25 Class A Preferred Shares are payable on the 15th day of February, May, August and November in each year, if, as and when declared by the Board of Directors of Pembina.
Pembina Pipeline Corporation Third Quarter 2025 25
Outstanding Share Data
Issued and outstanding (thousands) | November 3, 2025 | ||||
| Common shares | 581,048 | ||||
Stock options(1) | 2,733 | ||||
| Series 1 Class A Preferred Shares | 10,000 | ||||
| Series 3 Class A Preferred Shares | 6,000 | ||||
| Series 5 Class A Preferred Shares | 10,000 | ||||
| Series 7 Class A Preferred Shares | 10,000 | ||||
| Series 9 Class A Preferred Shares | 9,000 | ||||
| Series 15 Class A Preferred Shares | 8,000 | ||||
| Series 17 Class A Preferred Shares | 6,000 | ||||
| Series 21 Class A Preferred Shares | 14,972 | ||||
| Series 25 Class A Preferred Shares | 10,000 | ||||
(1) Balance includes 2.4 million exercisable stock options.
26 Pembina Pipeline Corporation Third Quarter 2025
6. CAPITAL EXPENDITURES
| 3 Months Ended September 30 | 9 Months Ended September 30 | |||||||||||||
| ($ millions) | 2025 | 2024 | 2025 | 2024 | ||||||||||
| Pipelines | 84 | 130 | 216 | 442 | ||||||||||
| Facilities | 84 | 110 | 294 | 218 | ||||||||||
| Marketing & New Ventures | 3 | 10 | 14 | 21 | ||||||||||
| Corporate and other projects | 7 | 12 | 25 | 32 | ||||||||||
Total capital expenditures(1) | 178 | 262 | 549 | 713 | ||||||||||
(1) Includes $15 million for the three months ended September 30, 2025 (2024: $53 million) and $86 million for the nine months ended September 30, 2025 (2024: $100 million) related to non-recoverable sustainment activities.
In both the third quarter and first nine months of 2025 and 2024, Pipelines capital expenditures largely related to expansions to support volume growth in NEBC and investments in smaller growth projects. Additionally, 2024 capital expenditures were associated with Pembina's Phase VIII Peace Pipeline expansion, which was placed into service in May 2024. Facilities capital expenditures during these periods in 2025 and 2024 primarily related to Redwater expansion projects. Marketing & New Ventures had no significant capital expenditures during these periods, while Corporate capital expenditures during these periods related mainly to information technology infrastructure and systems development.
In both the third quarter and first nine months of 2025, the change in non-recoverable sustaining capital expenditure was primarily attributed to supporting safe and reliable operations.
Future capital expenditures for the remainder of 2025 are estimated to be approximately $225 million and are primarily related to the construction of RFS IV, expansions to support volume growth in NEBC, investments in smaller growth projects, including various laterals and terminals, and spending on projects previously placed into service. Of the total future capital expenditure, approximately $35 million is designated for non-recoverable sustaining capital, which will continue to support safe and reliable operations.
For contributions to equity accounted investees, refer to the "Segment Results – Equity Accounted Investees Overview by Division" section of this MD&A.
Pembina Pipeline Corporation Third Quarter 2025 27
7. SELECTED QUARTERLY INFORMATION
Selected Quarterly Operating Information
| (mboe/d) | 2025 | 2024 | 2023 | ||||||||||||||||||||||||||||||||
| Q3 | Q2 | Q1 | Q4 | Q3 | Q2 | Q1 | Q4 | ||||||||||||||||||||||||||||
Volumes(1)(2) | |||||||||||||||||||||||||||||||||||
Pipelines – transportation volumes | |||||||||||||||||||||||||||||||||||
Conventional Pipelines | 1,001 | 1,006 | 1,033 | 1,034 | 992 | 969 | 1,007 | 1,054 | |||||||||||||||||||||||||||
| Transmission Pipelines | 699 | 722 | 740 | 720 | 713 | 726 | 588 | 590 | |||||||||||||||||||||||||||
| Oil Sands and Heavy Oil Pipelines | 1,050 | 1,040 | 1,035 | 1,036 | 1,033 | 1,021 | 1,003 | 1,008 | |||||||||||||||||||||||||||
Facilities – processing and fractionation volumes | |||||||||||||||||||||||||||||||||||
Gas Services | 598 | 590 | 619 | 597 | 584 | 599 | 612 | 602 | |||||||||||||||||||||||||||
| NGL Services | 262 | 236 | 277 | 280 | 226 | 256 | 193 | 199 | |||||||||||||||||||||||||||
| Total revenue volumes | 3,610 | 3,594 | 3,704 | 3,667 | 3,548 | 3,571 | 3,403 | 3,453 | |||||||||||||||||||||||||||
Marketing & New Ventures – sales volumes | |||||||||||||||||||||||||||||||||||
| Marketed crude oil | 111 | 95 | 88 | 96 | 117 | 100 | 80 | 82 | |||||||||||||||||||||||||||
| Marketed NGL | 237 | 207 | 281 | 252 | 227 | 219 | 215 | 217 | |||||||||||||||||||||||||||
(1) Volumes in mboe/d. See the "Abbreviations" section of this MD&A for definition. Volumes for Pipelines and Facilities divisions are revenue volumes, which are physical volumes plus volumes recognized from take-or-pay commitments. Volumes for Marketing & New Ventures are marketed crude oil and NGL volumes and are excluded from total volumes to avoid double counting.
(2) Includes Pembina's proportionate share of volumes from equity accounted investees.
Take-or-pay Contract Liabilities
| ($ millions) | 2025 | 2024 | 2023 | ||||||||||||||||||||||||||||||||||||||
| Q3 | Q2 | Q1 | Q4 | Q3 | Q2 | Q1 | Q4 | ||||||||||||||||||||||||||||||||||
Opening balance | 9 | 7 | 1 | 11 | 12 | 7 | 1 | 22 | |||||||||||||||||||||||||||||||||
Revenue deferred | 51 | 57 | 58 | 58 | 67 | 55 | 52 | 56 | |||||||||||||||||||||||||||||||||
| Revenue recognized | (54) | (55) | (52) | (68) | (68) | (50) | (46) | (77) | |||||||||||||||||||||||||||||||||
Ending take-or-pay contract liability balance | 6 | 9 | 7 | 1 | 11 | 12 | 7 | 1 | |||||||||||||||||||||||||||||||||
Selected Quarterly Market Pricing
| 2025 | 2024 | 2023 | ||||||||||||||||||||||||||||||||||||
| ($ average) | Q3 | Q2 | Q1 | Q4 | Q3 | Q2 | Q1 | Q4 | ||||||||||||||||||||||||||||||
WTI (USD/bbl) | 64.93 | 63.74 | 71.42 | 70.27 | 75.10 | 80.57 | 76.96 | 78.32 | ||||||||||||||||||||||||||||||
FX (USD/CAD) | 1.38 | 1.38 | 1.43 | 1.40 | 1.36 | 1.37 | 1.35 | 1.36 | ||||||||||||||||||||||||||||||
AECO Natural Gas (CAD/GJ) | 0.94 | 1.96 | 1.92 | 1.38 | 0.77 | 1.36 | 1.94 | 2.52 | ||||||||||||||||||||||||||||||
Station 2 Natural Gas (CAD/GJ) | 0.45 | 0.43 | 1.22 | 0.85 | 0.47 | 0.72 | 2.45 | 1.95 | ||||||||||||||||||||||||||||||
| Chicago Citygate Natural Gas (USD/mmbtu) | 2.71 | 2.99 | 3.91 | 2.71 | 1.76 | 1.60 | 2.49 | 2.63 | ||||||||||||||||||||||||||||||
Mt Belvieu Propane (USD/gal) | 0.70 | 0.79 | 0.90 | 0.77 | 0.73 | 0.75 | 0.84 | 0.67 | ||||||||||||||||||||||||||||||
| Alberta Power Pool (CAD/MWh) | 51.53 | 40.48 | 40.30 | 51.72 | 55.23 | 45.28 | 98.89 | 81.74 | ||||||||||||||||||||||||||||||
Pembina 20-day volume-weighted average share price at quarter end | 54.11 | 51.30 | 55.90 | 54.05 | 55.19 | 50.22 | 47.54 | 45.13 | ||||||||||||||||||||||||||||||
28 Pembina Pipeline Corporation Third Quarter 2025
Quarterly Financial Information
($ millions, except where noted) | 2025 | 2024 | 2023 | |||||||||||||||||||||||||||||||||||
| Q3 | Q2 | Q1 | Q4 | Q3 | Q2 | Q1 | Q4 | |||||||||||||||||||||||||||||||
| Revenue | 1,791 | 1,792 | 2,282 | 2,145 | 1,844 | 1,855 | 1,540 | 1,836 | ||||||||||||||||||||||||||||||
Net revenue(1) | 1,211 | 1,184 | 1,343 | 1,383 | 1,259 | 1,222 | 912 | 1,142 | ||||||||||||||||||||||||||||||
| Operating expenses | 259 | 235 | 226 | 270 | 277 | 240 | 189 | 217 | ||||||||||||||||||||||||||||||
| Share of (loss) profit from equity accounted investees | (66) | 74 | 30 | 133 | (17) | 61 | 151 | 94 | ||||||||||||||||||||||||||||||
| Gross profit | 658 | 780 | 928 | 1,024 | 747 | 815 | 730 | 850 | ||||||||||||||||||||||||||||||
Adjusted EBITDA(1) | 1,034 | 1,013 | 1,167 | 1,254 | 1,019 | 1,091 | 1,044 | 1,033 | ||||||||||||||||||||||||||||||
| Earnings | 286 | 417 | 502 | 572 | 385 | 479 | 438 | 698 | ||||||||||||||||||||||||||||||
Earnings per common share – basic (dollars) | 0.43 | 0.65 | 0.80 | 0.92 | 0.60 | 0.75 | 0.74 | 1.21 | ||||||||||||||||||||||||||||||
Earnings per common share – diluted (dollars) | 0.43 | 0.65 | 0.80 | 0.92 | 0.60 | 0.75 | 0.73 | 1.21 | ||||||||||||||||||||||||||||||
| Cash flow from operating activities | 810 | 790 | 840 | 902 | 922 | 954 | 436 | 880 | ||||||||||||||||||||||||||||||
Cash flow from operating activities per common share – basic (dollars) | 1.39 | 1.36 | 1.45 | 1.55 | 1.59 | 1.64 | 0.79 | 1.60 | ||||||||||||||||||||||||||||||
Adjusted cash flow from operating activities(1) | 648 | 698 | 777 | 922 | 724 | 837 | 782 | 747 | ||||||||||||||||||||||||||||||
Adjusted cash flow from operating activities per common share – basic (dollars)(1) | 1.12 | 1.20 | 1.34 | 1.59 | 1.25 | 1.44 | 1.42 | 1.36 | ||||||||||||||||||||||||||||||
Common shares outstanding (millions): | ||||||||||||||||||||||||||||||||||||||
| Weighted average – basic | 581 | 581 | 581 | 581 | 580 | 580 | 549 | 549 | ||||||||||||||||||||||||||||||
| Weighted average – diluted | 582 | 582 | 582 | 582 | 581 | 581 | 550 | 550 | ||||||||||||||||||||||||||||||
| End of period | 581 | 581 | 581 | 581 | 580 | 580 | 549 | 549 | ||||||||||||||||||||||||||||||
| Common share dividends declared | 413 | 412 | 401 | 401 | 401 | 400 | 367 | 367 | ||||||||||||||||||||||||||||||
Dividends per common share | 0.71 | 0.71 | 0.69 | 0.69 | 0.69 | 0.69 | 0.67 | 0.67 | ||||||||||||||||||||||||||||||
| Preferred share dividends declared | 32 | 35 | 35 | 34 | 34 | 33 | 31 | 30 | ||||||||||||||||||||||||||||||
| Capital expenditures | 178 | 197 | 174 | 242 | 262 | 265 | 186 | 177 | ||||||||||||||||||||||||||||||
| Contributions to equity accounted investees | 108 | 126 | 50 | — | 124 | 144 | 103 | 202 | ||||||||||||||||||||||||||||||
| Distributions from equity accounted investees | 128 | 136 | 132 | 131 | 133 | 123 | 239 | 227 | ||||||||||||||||||||||||||||||
(1) Refer to the "Non-GAAP & Other Financial Measures" section of this MD&A.
During the periods highlighted in the table above, there were new growth projects across Pembina's business being placed into service. The Company's financial and operating results have also been impacted by the volatility of commodity market prices, fluctuations in foreign exchange rates, and inflation. In addition to these factors, several other notable elements have impacted Pembina's financial and operating results during the specified periods above, including:
•an impairment of $146 million (net to Pembina, after tax), recognized in the third quarter of 2025 within Pembina's equity accounted investee, related to certain PGI assets;
•contributions made by Pembina to PGI of $198 million in the first nine months of 2025, to partially fund growth capital projects;
•contributions made by Pembina to Cedar LNG of $241 million in 2024, to fund the Cedar LNG Project;
•the completion of the Alliance and Aux Sable acquisition in the second quarter of 2024;
•the closing of the offering of 29.9 million subscription receipts of the Company in December 2023 to fund a portion of the purchase price of the Alliance and Aux Sable acquisition and the conversion of 29.9 million subscription receipts into common shares of the Company, concurrent with the closing of the Alliance and Aux Sable Acquisition;
•an impairment reversal of $231 million recognized in the fourth quarter of 2023 in the Pipelines Division related to successful contract negotiations on the Nipisi Pipeline and the pipeline being put back into service in October 2023; and
•contributions made by Pembina of $145 million to Aux Sable in the fourth quarter of 2023, representing Pembina's proportionate share of a claim filed by a counterparty to an NGL supply agreement with Aux Sable which was settled and discontinued in the fourth quarter of 2023.
Pembina Pipeline Corporation Third Quarter 2025 29
8. SELECTED EQUITY ACCOUNTED INVESTEE INFORMATION
Loans and Borrowings of Equity Accounted Investees
Under equity accounting, the assets and liabilities of an investee are reported as a single line item in the Consolidated Statement of Financial Position, "Investments in Equity Accounted Investees". To assist readers' understanding and to evaluate the capitalization of Pembina's investments, loans and borrowings associated with investments in equity accounted investees are presented below based on Pembina's proportionate ownership in such investees, as at September 30, 2025. The loans and borrowings are presented and classified by the division in which the results for the investee are reported. Please refer to the "Abbreviations" section for a summary of Pembina's investments in equity accounted investees and the division in which their results are reported.
($ millions)(1) | September 30, 2025 | December 31, 2024 | ||||||
| Pipelines | 17 | 19 | ||||||
| Facilities | 3,148 | 2,941 | ||||||
Marketing & New Ventures(2) | 559 | 373 | ||||||
| Total | 3,724 | 3,333 | ||||||
(1) Balances reflect Pembina's ownership percentage of the outstanding balance face value.
(2) Relates to the U.S. $2.7 billion senior unsecured construction/term loan facility entered into by Cedar LNG.
Cash and Cash Equivalents of Equity Accounted Investees
As at September 30, 2025, Pembina's ownership percentage of the cash balance associated with Pembina's investments in equity accounted investees totaled $35 million (December 31, 2024: $43 million) of which $30 million (December 31, 2024: $39 million) related to Cedar LNG and nil (December 31, 2024: nil) related to PGI.
Financing Activities for Equity Accounted Investees
PGI
On March 21, 2025, pursuant to an amended and restated credit agreement, PGI exercised the accordion feature under its existing revolving credit facility and opened a new $500 million revolving credit facility, maturing on March 21, 2027. Concurrently, PGI reestablished a $500 million accordion under the credit facility.
Commitments to Equity Accounted Investees
Pembina has commitments to provide contributions to certain equity accounted investees based on its ownership interest. These contributions are determined and approved by the joint venture partners to fund operating budgets, growth capital, and significant projects development costs, including the Cedar LNG Project and Greenlight.
Credit Risk for Equity Accounted Investees
As at September 30, 2025, Pembina's various equity accounted investees held letters of credit totaling $159 million (December 31, 2024: $164 million) primarily in respect of obligations for engineering, procurement and construction.
30 Pembina Pipeline Corporation Third Quarter 2025
9. RELATED PARTY TRANSACTIONS
Pembina enters into transactions with related parties in the normal course of business and all transactions are measured at their exchange amount, unless otherwise noted. Pembina provides management and operational oversight services, on a fixed fee and cost recovery basis, to certain equity accounted investees. Pembina also contracts for services and capacity from certain of its equity accounted investees, advances funds to support operations and provides letters of credit, including financial guarantees.
A summary of the significant related party transactions and balances are as follows:
| 3 Months Ended September 30 | 9 Months Ended September 30 | |||||||||||||
| ($ millions) | 2025 | 2024 | 2025 | 2024 | ||||||||||
| PGI | 58 | 43 | 179 | 175 | ||||||||||
| Cedar LNG | 5 | 12 | 14 | 18 | ||||||||||
Aux Sable(1) | — | — | — | 32 | ||||||||||
Alliance(1) | — | — | — | 4 | ||||||||||
Other(2) | — | — | — | 2 | ||||||||||
Total services provided(3) | 63 | 55 | 193 | 231 | ||||||||||
| PGI | 2 | 2 | 6 | 6 | ||||||||||
Alliance(1) | — | — | — | 3 | ||||||||||
| Total services received | 2 | 2 | 6 | 9 | ||||||||||
As at ($ millions) | September 30, 2025 | December 31, 2024 | ||||||||||||
Trade receivables and other(4) | 35 | 37 | ||||||||||||
Right-of-use assets(5) | 33 | — | ||||||||||||
Lease liabilities(5) | 33 | — | ||||||||||||
(1) As of April 1, 2024, following the completion of Pembina's acquisition of a controlling interest in Alliance and Aux Sable, these entities became consolidated subsidiaries of Pembina and, as such, are no longer related parties.
(2) Other includes transactions with Grand Valley, ACG, and Greenlight.
(3) Services provided by Pembina include payments made by Pembina on behalf of related parties.
(4) As at September 30, 2025, trade receivables and other includes $30 million due from PGI (December 31, 2024: $34 million), and $5 million due from Cedar LNG (December 31, 2024: $2 million).
(5) As at September 30, 2025, Pembina had a lease arrangement with PGI for the use of a natural gas storage asset. Under the terms of the agreement, Pembina recognized a right-of-use asset and a corresponding lease liability. The lease commenced on September 1, 2025 and has a term of 15.2 years. Lease payments are made on a monthly basis and are structured as a combination of a fixed fee and flow-through charges.
Pembina Pipeline Corporation Third Quarter 2025 31
10. ACCOUNTING POLICIES & ESTIMATES
Changes in Accounting Policies
The accounting policies used in preparing the Interim Financial Statements are described in Note 3 of Pembina's Consolidated Financial Statements. There were no new accounting standards or amendments to existing standards adopted in the nine months ended September 30, 2025 that have a material impact on Pembina's financial statements.
New Standards and Interpretations Not Yet Adopted
IFRS 18 Presentation and Disclosure in Financial Statements ("IFRS 18")
IFRS 18 was issued in April 2024 and effective January 1, 2027, with early application permitted. The standard introduces key changes to the structure of the statement of earnings and comprehensive income, required disclosures for certain management-defined performance measures, and aggregation and disaggregation of line items in the financial statements. Pembina is currently reviewing the impact of this standard on its Consolidated Financial Statements.
Amendments to IFRS 9 and IFRS 7 - Contracts referencing Nature-dependent Electricity ("Contracts referencing NDE")
Contracts referencing NDE was issued in December 2024 and effective January 1, 2026, with early adoption permitted. The amendments provide relief as it relates to accounting for contracts to purchase or sell electricity from nature-dependent sources such as wind and solar power, including clarifying the application of own-use requirements, permitting hedge accounting if these contracts are used as hedging instruments, and adding new disclosure to enable investors to understand the effect of these contracts to Pembina. Pembina is currently reviewing the impact of this amendment as it relates to Pembina's wind-based power purchase agreements.
Critical Accounting Judgments & Estimates
Critical accounting judgments and estimates used in preparing the Interim Financial Statements are described in Note 2 of Pembina's Consolidated Financial Statements. The preparation of financial statements in conformity with IFRS requires management to make both judgments and estimates that could materially affect the amounts recognized in the financial statements. By their nature, judgments and estimates may change in light of new facts and circumstances in the internal and external environment. There have been no material changes to Pembina's critical accounting estimates and judgments during the three and nine months ended September 30, 2025.
32 Pembina Pipeline Corporation Third Quarter 2025
11. NON-GAAP & OTHER FINANCIAL MEASURES
Throughout this MD&A, Pembina has disclosed certain financial measures and ratios that are not specified, defined or determined in accordance with GAAP and which are not disclosed in Pembina's financial statements. Non-GAAP financial measures either exclude an amount that is included in, or include an amount that is excluded from, the composition of the most directly comparable financial measure specified, defined and determined in accordance with GAAP. These non-GAAP financial measures and non-GAAP ratios, together with financial measures and ratios specified, defined and determined in accordance with GAAP, are used by management to evaluate the performance and cash flows of Pembina and its businesses and to provide additional useful information respecting Pembina's financial performance and cash flows to investors and analysts.
In this MD&A, Pembina has disclosed the following non-GAAP financial measures and non-GAAP ratios: net revenue, earnings before interest, taxes, depreciation, and amortization ("adjusted EBITDA"), adjusted EBITDA per common share, adjusted EBITDA from equity accounted investees, adjusted cash flow from operating activities and adjusted cash flow from operating activities per common share.
Non-GAAP financial measures and non-GAAP ratios disclosed in this MD&A do not have any standardized meaning under IFRS and may not be comparable to similar financial measures disclosed by other issuers. The financial measures and ratios should not, therefore, be considered in isolation or as a substitute for, or superior to, measures and ratios of Pembina's financial performance, or cash flows specified, defined or determined in accordance with IFRS, including revenue, earnings, share of profit from equity accounted investees and cash flow from operating activities.
Except as otherwise described herein, these non-GAAP financial measures and non-GAAP ratios are calculated on a consistent basis from period to period. Specific reconciling items may only be relevant in certain periods.
Below is a description of each non-GAAP financial measure and non-GAAP ratio disclosed in this MD&A, together with, as applicable, disclosure of: the most directly comparable financial measure that is specified, defined and determined in accordance with GAAP to which each non-GAAP financial measure relates; a quantitative reconciliation of each non-GAAP financial measure to such directly comparable GAAP financial measure; the composition of each non-GAAP financial measure and non-GAAP ratio; an explanation of how each non-GAAP financial measure and non-GAAP ratio provides useful information to investors and the additional purposes, if any, for which management uses each non-GAAP financial measure and non-GAAP ratio; and an explanation of the reason for any change in the label or composition of each non-GAAP financial measure and non-GAAP ratio from what was previously disclosed.
Net Revenue
Net revenue is a non-GAAP financial measure which is defined as total revenue less cost of goods sold. Management believes that net revenue provides investors with a single measure to indicate the margin on sales before non-product operating expenses that is comparable between periods. Management utilizes net revenue to compare consecutive results, to aggregate revenue generated by each of the Company's divisions and to set comparable objectives. The most directly comparable financial measure to net revenue that is specified, defined and determined in accordance with GAAP and disclosed in Pembina's financial statements is revenue.
| 3 Months Ended September 30 | Pipelines | Facilities | Marketing & New Ventures | Corporate & Inter-segment Eliminations | Total | |||||||||||||||||||||||||||
| ($ millions) | ||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||||||
| Revenue | 882 | 860 | 300 | 282 | 861 | 938 | (252) | (236) | 1,791 | 1,844 | ||||||||||||||||||||||
Cost of goods sold | 10 | 9 | — | — | 739 | 732 | (169) | (156) | 580 | 585 | ||||||||||||||||||||||
| Net revenue | 872 | 851 | 300 | 282 | 122 | 206 | (83) | (80) | 1,211 | 1,259 | ||||||||||||||||||||||
Pembina Pipeline Corporation Third Quarter 2025 33
| 9 Months Ended September 30 | Pipelines | Facilities | Marketing & New Ventures | Corporate & Inter-segment Eliminations | Total | |||||||||||||||||||||||||||
| ($ millions) | ||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||||||
| Revenue | 2,650 | 2,438 | 902 | 807 | 3,080 | 2,663 | (767) | (669) | 5,865 | 5,239 | ||||||||||||||||||||||
Cost of goods sold | 37 | 35 | — | — | 2,597 | 2,279 | (507) | (468) | 2,127 | 1,846 | ||||||||||||||||||||||
| Net revenue | 2,613 | 2,403 | 902 | 807 | 483 | 384 | (260) | (201) | 3,738 | 3,393 | ||||||||||||||||||||||
Adjusted EBITDA and Adjusted EBITDA per Common Share
Adjusted EBITDA is a non-GAAP financial measure and is calculated as earnings before net finance costs, income taxes, depreciation and amortization (included in gross profit and general and administrative expense), and unrealized gains or losses from derivative instruments. The exclusion of unrealized gains or losses from derivative instruments eliminates the non-cash impact of such gains or losses.
Adjusted EBITDA also includes adjustments to earnings for non-controlling interest, losses (gains) on disposal of assets, transaction costs incurred in respect of acquisitions, dispositions and restructuring, impairment charges or reversals in respect of goodwill, intangible assets, investments in equity accounted investees and property, plant and equipment, certain non-cash provisions and other amounts not reflective of ongoing operations. These additional adjustments are made to exclude various non-cash and other items that are not reflective of ongoing operations. Following completion of Pembina acquiring a controlling ownership interest in Alliance and Aux Sable on April 1, 2024, Pembina revised the definition of adjusted EBITDA to deduct earnings for the 14.6 percent non-controlling interest in the Aux Sable U.S. operations. Pembina's subsequent acquisition of the remaining interest in Aux Sable's U.S. operations in the third quarter of 2024 resulted in all of Aux Sable's results being included in the adjusted EBITDA calculation beginning on August 1, 2024.
Management believes that adjusted EBITDA provides useful information to investors as it is an important indicator of Pembina's ability to generate liquidity through cash flow from operating activities and equity accounted investees. Management also believes that adjusted EBITDA provides an indicator of operating income generated from capital expenditures, which includes operational finance income and gains from lessor lease arrangements. Adjusted EBITDA is also used by investors and analysts for assessing financial performance and for the purpose of valuing Pembina, including calculating financial and leverage ratios. Management utilizes adjusted EBITDA to set objectives and as a key performance indicator of the Company's success. Pembina presents adjusted EBITDA as management believes it is a measure frequently used by analysts, investors and other stakeholders in evaluating the Company's financial performance. The most directly comparable financial measure to adjusted EBITDA that is specified, defined and determined in accordance with GAAP and disclosed in Pembina's financial statements is earnings.
Adjusted EBITDA per common share is a non-GAAP ratio which is calculated by dividing adjusted EBITDA by the weighted average number of common shares outstanding.
34 Pembina Pipeline Corporation Third Quarter 2025
| 3 Months Ended September 30 | Pipelines | Facilities | Marketing & New Ventures | Corporate & Inter-segment Eliminations | Total | |||||||||||||||||||||||||||
| ($ millions, except per share amounts) | ||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||||||
Earnings (loss) | 477 | 433 | 58 | 131 | 68 | 125 | (205) | (215) | 286 | 385 | ||||||||||||||||||||||
| Income tax expense | — | — | — | — | — | — | — | — | 112 | 89 | ||||||||||||||||||||||
| Adjustments to share of profit from equity accounted investees | 1 | 2 | 245 | 139 | 13 | 49 | — | — | 259 | 190 | ||||||||||||||||||||||
Net finance costs | 7 | 6 | 3 | 3 | 3 | 1 | 140 | 139 | 153 | 149 | ||||||||||||||||||||||
Depreciation and amortization | 162 | 153 | 48 | 50 | 16 | 15 | 15 | 13 | 241 | 231 | ||||||||||||||||||||||
Unrealized gain from derivative instruments | — | — | — | — | (1) | (18) | — | — | (1) | (18) | ||||||||||||||||||||||
Non-controlling interest(1) | — | — | — | — | — | (2) | — | — | — | (2) | ||||||||||||||||||||||
| Transaction and integration costs in respect of acquisitions | — | — | — | — | — | — | 1 | 4 | 1 | 4 | ||||||||||||||||||||||
| (Gain) loss on disposal of assets, other non-cash provisions, and other | (17) | (1) | — | 1 | — | (11) | — | 2 | (17) | (9) | ||||||||||||||||||||||
| Adjusted EBITDA | 630 | 593 | 354 | 324 | 99 | 159 | (49) | (57) | 1,034 | 1,019 | ||||||||||||||||||||||
Adjusted EBITDA per common share – basic (dollars) | 1.78 | 1.76 | ||||||||||||||||||||||||||||||
| 9 Months Ended September 30 | Pipelines | Facilities | Marketing & New Ventures | Corporate & Inter-segment Eliminations | Total | |||||||||||||||||||||||||||
| ($ millions, except per share amounts) | ||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||||||
| Earnings (loss) | 1,468 | 1,373 | 384 | 489 | 342 | 324 | (624) | (1,210) | 1,205 | 1,302 | ||||||||||||||||||||||
| Income tax expense (recovery) | — | — | — | — | — | — | — | — | 365 | (326) | ||||||||||||||||||||||
| Adjustments to share of profit from equity accounted investees | 3 | 46 | 484 | 350 | 19 | 58 | — | — | 506 | 454 | ||||||||||||||||||||||
| Net finance costs | 19 | 19 | 9 | 8 | 7 | 4 | 419 | 367 | 454 | 398 | ||||||||||||||||||||||
| Depreciation and amortization | 479 | 412 | 152 | 128 | 53 | 47 | 47 | 40 | 731 | 627 | ||||||||||||||||||||||
| Unrealized (gain) loss from derivative instruments | — | — | — | — | (41) | 129 | — | — | (41) | 129 | ||||||||||||||||||||||
Non-controlling interest(1) | — | — | — | — | — | (12) | — | — | — | (12) | ||||||||||||||||||||||
| Loss on acquisition | — | — | — | — | — | — | — | 616 | — | 616 | ||||||||||||||||||||||
| Derecognition of insurance contract provision | — | — | — | — | — | (34) | — | — | — | (34) | ||||||||||||||||||||||
| Transaction and integration costs in respect of acquisition | — | — | — | — | — | — | 5 | 18 | 5 | 18 | ||||||||||||||||||||||
| (Gain) loss on disposal of assets, other non-cash provisions, and other | (16) | (3) | 1 | (1) | 3 | (26) | 1 | 12 | (11) | (18) | ||||||||||||||||||||||
| Adjusted EBITDA | 1,953 | 1,847 | 1,030 | 974 | 383 | 490 | (152) | (157) | 3,214 | 3,154 | ||||||||||||||||||||||
Adjusted EBITDA per common share – basic (dollars) | 5.53 | 5.53 | ||||||||||||||||||||||||||||||
(1) Presented net of adjusting items.
Pembina Pipeline Corporation Third Quarter 2025 35
Adjusted EBITDA from Equity Accounted Investees
In accordance with IFRS, Pembina's joint ventures are accounted for using equity accounting. Under equity accounting, the assets and liabilities of the investment are presented net in a single line item in the Consolidated Statement of Financial Position, "Investments in Equity Accounted Investees". Earnings from investments in equity accounted investees are recognized in a single line item in the Consolidated Statement of Earnings and Comprehensive Income "Share of Profit from Equity Accounted Investees". The adjustments made to earnings, in adjusted EBITDA above, are also made to share of profit from investments in equity accounted investees. Cash contributions and distributions from investments in equity accounted investees represent Pembina's share paid and received in the period to and from the investments in equity accounted investees.
To assist in understanding and evaluating the performance of these investments, Pembina is supplementing the IFRS disclosure with non-GAAP proportionate consolidation of Pembina's interest in the investments in equity accounted investees. Pembina's proportionate interest in equity accounted investees has been included in adjusted EBITDA.
| 3 Months Ended September 30 | Pipelines | Facilities | Marketing & New Ventures | Total | ||||||||||||||||||||||||||||
| ($ millions) | ||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||||||||
Share of (loss) profit from equity accounted investees | (1) | (1) | (51) | 34 | (14) | (50) | (66) | (17) | ||||||||||||||||||||||||
| Adjustments to share of profit (loss) from equity accounted investees: | ||||||||||||||||||||||||||||||||
Net finance costs | — | 1 | 7 | 69 | 13 | 49 | 20 | 119 | ||||||||||||||||||||||||
| Income tax (recovery) expense | — | — | (17) | 9 | — | — | (17) | 9 | ||||||||||||||||||||||||
Depreciation and amortization | 1 | 1 | 62 | 53 | — | — | 63 | 54 | ||||||||||||||||||||||||
| Unrealized loss on commodity-related derivative financial instruments | — | — | — | 8 | — | — | — | 8 | ||||||||||||||||||||||||
| Impairment expense | — | — | 193 | — | — | — | 193 | — | ||||||||||||||||||||||||
| Total adjustments to share of profit from equity accounted investees | 1 | 2 | 245 | 139 | 13 | 49 | 259 | 190 | ||||||||||||||||||||||||
| Adjusted EBITDA from equity accounted investees | — | 1 | 194 | 173 | (1) | (1) | 193 | 173 | ||||||||||||||||||||||||
| 9 Months Ended September 30 | Pipelines | Facilities | Marketing & New Ventures | Total | ||||||||||||||||||||||||||||
| ($ millions) | ||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||||||||
Share of profit (loss) from equity accounted investees | — | 42 | 60 | 172 | (22) | (19) | 38 | 195 | ||||||||||||||||||||||||
| Adjustments to share of profit (loss) from equity accounted investees: | ||||||||||||||||||||||||||||||||
Net finance costs | 1 | 7 | 81 | 138 | 19 | 51 | 101 | 196 | ||||||||||||||||||||||||
| Income tax expense | — | — | 19 | 50 | — | — | 19 | 50 | ||||||||||||||||||||||||
Depreciation and amortization | 2 | 39 | 191 | 155 | — | 7 | 193 | 201 | ||||||||||||||||||||||||
| Unrealized loss on commodity-related derivative financial instruments | — | — | 1 | 5 | — | — | 1 | 5 | ||||||||||||||||||||||||
| Impairment expense and other non-cash provisions | — | — | 192 | 2 | — | — | 192 | 2 | ||||||||||||||||||||||||
| Total adjustments to share of profit from equity accounted investees | 3 | 46 | 484 | 350 | 19 | 58 | 506 | 454 | ||||||||||||||||||||||||
| Adjusted EBITDA from equity accounted investees | 3 | 88 | 544 | 522 | (3) | 39 | 544 | 649 | ||||||||||||||||||||||||
36 Pembina Pipeline Corporation Third Quarter 2025
Adjusted Cash Flow from Operating Activities and Adjusted Cash Flow from Operating Activities per Common Share
Adjusted cash flow from operating activities is a non-GAAP measure which is defined as cash flow from operating activities adjusting for the change in non-cash operating working capital, adjusting for current tax and share-based compensation payments, and deducting distributions to non-controlling interests and preferred share dividends paid. Adjusted cash flow from operating activities deducts distributions to non-controlling interest and preferred share dividends paid because they are not attributable to common shareholders. The calculation has been modified to exclude current tax expense and accrued share-based payment expense, and to include the impact of cash paid for taxes and share-based compensation, as it allows management to better assess the obligations discussed below.
Management believes that adjusted cash flow from operating activities provides comparable information to investors for assessing financial performance during each reporting period. Management utilizes adjusted cash flow from operating activities to set objectives and as a key performance indicator of the Company's ability to meet interest obligations, dividend payments and other commitments. Adjusted cash flow from operating activities per common share is a non-GAAP financial ratio which is calculated by dividing adjusted cash flow from operating activities by the weighted average number of common shares outstanding.
Following completion of Pembina acquiring a controlling ownership interest in Alliance and Aux Sable on April 1, 2024, Pembina revised the definition of adjusted cash flow from operating activities to deduct distributions related to non-controlling interest in the Aux Sable U.S. operations. On August 1, 2024, Pembina acquired the remaining interest in Aux Sable's U.S. operations.
| 3 Months Ended September 30 | 9 Months Ended September 30 | |||||||||||||
| ($ millions, except per share amounts) | 2025 | 2024 | 2025 | 2024 | ||||||||||
| Cash flow from operating activities | 810 | 922 | 2,440 | 2,312 | ||||||||||
Cash flow from operating activities per common share – basic (dollars) | 1.39 | 1.59 | 4.20 | 4.06 | ||||||||||
| Add (deduct): | ||||||||||||||
| Change in non-cash operating working capital | (23) | (136) | (57) | (30) | ||||||||||
| Current tax expense | (102) | (48) | (338) | (188) | ||||||||||
| Taxes paid, net of foreign exchange | 30 | 62 | 157 | 352 | ||||||||||
| Accrued share-based payment expense | (38) | (40) | (66) | (79) | ||||||||||
| Share-based compensation payment | 3 | — | 89 | 86 | ||||||||||
| Preferred share dividends paid | (32) | (34) | (102) | (98) | ||||||||||
| Distributions to non-controlling interest | — | (2) | — | (12) | ||||||||||
| Adjusted cash flow from operating activities | 648 | 724 | 2,123 | 2,343 | ||||||||||
Adjusted cash flow from operating activities per common share – basic (dollars) | 1.12 | 1.25 | 3.65 | 4.11 | ||||||||||
Pembina Pipeline Corporation Third Quarter 2025 37
12. OTHER
Risk Management
Pembina's risk management strategies, policies and limits, ensure risks and exposures are aligned to its business strategy and risk tolerance. Pembina's Board of Directors is responsible for providing risk management oversight at Pembina and oversees how management monitors compliance with Pembina's risk management policies and procedures and reviews the adequacy of this risk framework in relation to the risks faced by Pembina.
Pembina has exposure to counterparty credit risk, liquidity risk and market risk. Pembina utilizes derivative instruments to stabilize the results of its business and, as at September 30, 2025, the Company has entered into certain financial derivative contracts in order to manage commodity price, cost of power, and foreign exchange risk. Pembina has also entered into power purchase agreements to secure cost-competitive renewable energy, fix the price for a portion of the power Pembina consumes, and reduce its emissions.
Financial Instruments
Fair Values
The fair value of financial instruments utilizes a variety of valuation inputs. When measuring fair value, Pembina uses observable market data to the greatest extent possible. Depending on the nature of these valuation inputs, financial instruments are categorized as follows:
a. Level 1
Level 1 fair values are based on inputs that are unadjusted observable quoted prices from active markets for identical assets or liabilities as at the measurement date.
b. Level 2
Level 2 fair values are based on inputs, other than quoted market prices included in Level 1, that are either directly or indirectly observable. Level 2 fair value inputs include quoted forward market prices, time value, and broker quotes that are observable for the duration of the financial instrument's contractual term. These inputs are often adjusted for factors specific to the asset or liability, such as, location differentials and credit risk.
Financial instruments that utilize Level 2 fair valuation inputs include derivatives arising from physical commodity forward contracts, commodity swaps and options, and forward interest rate and foreign-exchange swaps. In addition, Pembina's loans and borrowings utilize Level 2 fair valuation inputs, whereby the valuation technique is based on discounted future interest and principal payments using the current market interest rates of instruments with similar terms.
c. Level 3
Level 3 fair values utilize inputs that are not based on observable market data. Rather, various valuation techniques are used to develop inputs.
Financial instruments that utilize Level 3 fair valuation inputs include embedded derivative instruments arising from long-term power purchase agreements. The fair value of long-term power purchase agreements is measured using a pricing and cash flow model that accounts for forward power prices, renewable wind power pricing discounts and differentials, and inflationary metrics. The rate used to discount the respective estimated cash flows is a government risk-free interest rate that is adjusted for an appropriate credit spread. The fair valuation of the embedded derivative instruments is judged to be a significant management estimate. These assumptions and inputs are susceptible to change and may differ from actual future developments. This estimation uncertainty could materially impact the quantified fair value; and therefore, the gains and losses on commodity-related derivative financial instruments.
38 Pembina Pipeline Corporation Third Quarter 2025
Gains and Losses from Derivative Instruments
| 3 Months Ended September 30 | 9 Months Ended September 30 | |||||||||||||
| ($ millions) | 2025 | 2024 | 2025 | 2024 | ||||||||||
| Derivative instruments held at fair value through earnings | ||||||||||||||
| Realized gain | ||||||||||||||
Commodity-related gain recorded in revenue from risk management and physical derivative contracts | (39) | (70) | (98) | (189) | ||||||||||
| Unrealized (gain) loss | ||||||||||||||
Commodity-related (gain) loss recorded in revenue from risk management and physical derivative contracts | (1) | (18) | (41) | 129 | ||||||||||
| Derivative instruments in hedging relationships | ||||||||||||||
Interest rate loss recorded in other comprehensive income(1) | — | 6 | 4 | 8 | ||||||||||
(1) Unrealized losses or gains for designated cash flow hedges are recognized in impact of hedging activities in the Consolidated Statements of Earnings and Comprehensive Income, with realized losses or gains being reclassified to net finance costs. The movement in other comprehensive income relates to realized losses or gains on interest rate forward swaps, which expired on March 31, 2025. A gain of $4 million was recognized during the first quarter of 2025, prior to the expiration date that was reclassified to net finance costs (three and nine month ended September 30, 2024: $4 million and $13 million realized gain, respectively). No losses or gains have been recognized in net income relating to discontinued cash flow hedges.
Alliance Settlement
On September 15, 2025, the Canada Energy Regulator approved the negotiated settlement (the "Settlement") between Alliance Pipeline Limited Partnership ("Alliance") and shippers and interested parties on the Canadian portion of the Alliance Pipeline. The Settlement includes a revised toll schedule, effective November 1, 2025, which is expected to reduce long-term firm tolls by an average of 14 percent on a volume weighted average basis and introduces a 10-year toll option. The agreement also includes a revenue-sharing mechanism for seasonal and interruptible transportation services and provides shippers with a one-time term extension option. Pembina anticipates the Settlement to result in an approximately $50 million annual reduction in long-term firm service revenue over the next 10 years, plus impacts from the new revenue-sharing provision, which will depend on future commodity prices. The settlement outcome approved by the CER was within the expected range of outcomes used in the impairment test performed in the first quarter of 2025.
Tax Regulations
The One Big Beautiful Bill was enacted in the United States on July 4, 2025. Pembina has assessed the impact of this legislation and does not anticipate any material impact to Pembina.
Disclosure Controls and Procedures ("DC&P") and Internal Control over Financial Reporting ("ICFR")
Management's Report on Internal Control over Financial Reporting
Pembina's management is responsible for establishing and maintaining disclosure controls and procedures and internal control over financial reporting, as those terms are defined in National Instrument 52-109 Certification of Disclosure in Issuers' Annual and Interim Filings. The objective of this instrument is to improve the quality, reliability and transparency of information that is filed or submitted under Canadian securities legislation.
The President and Chief Executive Officer and Senior Vice President and Chief Financial Officer have designed, with the assistance of management, DC&P and ICFR to provide reasonable assurance that material information relating to Pembina's business is made known to them, is reported on a timely basis, that financial reporting is reliable and that financial statements prepared for external purposes are in accordance with IFRS.
Changes in Internal Control Over Financial Reporting
There were no changes in the third quarter of 2025 that had or are likely to have a material impact on Pembina's ICFR.
Pembina Pipeline Corporation Third Quarter 2025 39
13. ABBREVIATIONS
The following is a list of abbreviations that may be used in this MD&A:
Other | |||||
| AECO | Alberta Energy Company benchmark price for natural gas | ||||
B.C. | British Columbia | ||||
GAAP | Canadian generally accepted accounting principles | ||||
IFRS | International Financial Reporting Standards | ||||
NGL | Natural gas liquids | ||||
| LNG | Liquefied natural gas | ||||
U.S. | United States | ||||
WCSB | Western Canadian Sedimentary Basin | ||||
Deep cut | Ethane-plus capacity extraction gas processing capabilities | ||||
Shallow cut | Sweet gas processing with propane and/or condensate-plus extraction capabilities | ||||
Volumes | Volumes for Pipelines and Facilities are revenue volumes, defined as physical volumes plus volumes from take-or-pay commitments. Volumes for Marketing & New Ventures are marketed crude oil and NGL volumes. Volumes are stated in mboe/d, with natural gas volumes converted to mboe/d from MMcf/d at a 6:1 ratio, and also include revenue volumes from Pembina's equity accounted investees. | ||||
Measurement | |||||||||||||||||
bpd | barrels per day | mmboe/d | millions of barrels of oil equivalent per day | ||||||||||||||
mbbls | thousands of barrels | mtpa | million tonnes per annum | ||||||||||||||
mbpd | thousands of barrels per day | MMcf/d | millions of cubic feet per day | ||||||||||||||
mmbpd | millions of barrels per day | bcf/d | billions of cubic feet per day | ||||||||||||||
mmbbls | millions of barrels | km | kilometer | ||||||||||||||
mboe/d | thousands of barrels of oil equivalent per day | ||||||||||||||||
Investments in Equity Accounted Investees | |||||
| Pipelines: | |||||
| Grand Valley | 75 percent interest in Grand Valley 1 Limited Partnership wind farm | ||||
| Alliance | Prior to the completion of Pembina acquiring a controlling ownership interest in Alliance on April 1, 2024, Pembina owned a 50 percent interest in Alliance Pipeline Limited Partnership, Alliance Pipeline L.P., and NRGreen Power Limited Partnership | ||||
| Facilities: | |||||
| PGI | 60 percent interest in Pembina Gas Infrastructure Inc., a premier gas processing entity in western Canada serving customers throughout the Montney and Duvernay trends from central Alberta to northeast British Columbia | ||||
| Fort Corp | 50 percent interest in Fort Saskatchewan Ethylene Storage Limited Partnership and Fort Saskatchewan Ethylene Storage Corporation | ||||
| Marketing & New Ventures: | |||||
| Cedar LNG | 49.9 percent interest in Cedar LNG Partners LP and the proposed floating LNG facility in Kitimat, British Columbia, Canada | ||||
| ACG | 50 percent interest in Alberta Carbon Grid Heartland Limited Partnership and the proposed Heartland carbon dioxide transportation and sequestration system. | ||||
| Greenlight | 50 percent interest in the Greenlight Electricity Centre Limited Partnership, which is developing a gas-fired combined cycle power generation facility to be located in Alberta’s Industrial Heartland. | ||||
| Aux Sable | Prior to the completion of Pembina acquiring a controlling ownership interest in Aux Sable on April 1, 2024, Pembina owned an ownership interest of approximately 42.7 percent in Aux Sable U.S. and 50 percent in Aux Sable Canada, which includes an NGL fractionation facility and gas processing capacity near Chicago, Illinois and other natural gas and NGL processing facilities, logistics and distribution assets in the U.S. and Canada, and transportation contracts on Alliance. | ||||
Readers are referred to the AIF for the year ended December 31, 2024 for additional descriptions, which is available at www.sedarplus.ca, www.sec.gov and through Pembina's website at www.pembina.com.
40 Pembina Pipeline Corporation Third Quarter 2025
14. FORWARD-LOOKING STATEMENTS & INFORMATION
In the interest of providing Pembina's security holders and potential investors with information regarding Pembina, including management's assessment of the Company's future plans and operations, certain statements contained in this MD&A constitute forward-looking statements or forward-looking information (collectively, "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "may", "will", "project", "should", "could", "would", "believe", "plan", "intend", "design", "target", "undertake", "view", "indicate", "maintain", "explore", "entail", "schedule", "objective", "strategy", "likely", "potential", "outlook", "aim", "purpose", "goal" and similar expressions suggesting future events or future performance.
By their nature, such forward-looking statements involve known and unknown risks, uncertainties and other factors that may cause actual results or events to differ materially from those anticipated in such forward-looking statements. Pembina believes the expectations reflected in those forward-looking statements are reasonable but no assurance can be given that these expectations will prove to be correct and such forward-looking statements included in this MD&A should not be unduly relied upon. These forward-looking statements speak only as of the date of this MD&A.
In particular, this MD&A contains forward-looking statements pertaining to the following:
•future levels and sustainability of cash dividends that Pembina intends to pay to its shareholders and anticipated dividend payment dates;
•planning, construction, locations, capital expenditure and funding estimates, schedules, regulatory and environmental applications and anticipated approvals, expected capacity, incremental volumes, contractual arrangements, in-service dates, sources of product, activities, benefits and operations with respect to new construction of, or expansions on existing, pipelines, systems, gas services facilities, processing and fractionation facilities, terminalling, storage and hub facilities and other facilities or energy infrastructure, as well as the impact of Pembina's new projects on its future financial performance;
•future pipeline, processing, fractionation, and storage facility and system operations;
•treatment under existing and proposed governmental laws, policies and regulations, including those relating to taxes, the environmental, tariffs and project assessments;
•Pembina's strategy and the development and expected timing of new business initiatives and growth opportunities and the impact thereof;
•increased processing capacity and fractionation capacity due to increased oil and gas industry activity and new connections and other initiatives on Pembina's pipelines and at Pembina's facilities;
•expected future cash flows and the sufficiency thereof, financial strength, sources of and access to funds, future contractual obligations, future financing options, availability of capital for capital expenditures, operating obligations, debt maturities, letters of credit and the use of proceeds from financings;
•Pembina's capital structure, including the sufficiency of the amount of leverage employed therein and future actions that may be taken with respect thereto, including expectations regarding the repurchase or redemption of common shares or other securities, repayments of existing debt, new borrowings, equity or hybrid securities issuances and the timing thereof;
•potential actions undertaken by Pembina to mitigate counterparty risk;
•tolls and tariffs, and processing, transportation, fractionation, storage and services commitments and contracts;
•the outcomes and effectiveness of Pembina's DC&P and ICFR;
•the expected demand for, and prices and inventory levels of, crude oil and other petroleum products, including NGL;
•the development and anticipated benefits of Pembina's new projects and developments, including RFS IV, the Wapiti Expansion, the K3 Cogeneration Facility, the Taylor-to-Gordondale Project, the Fox Creek-to-Namao Expansion, Birch-to-Taylor NEBC System Expansion, Prince Rupert Terminal Optimization, the Greenlight Electricity Centre and the Cedar LNG Project, including the timing thereof;
•expectations in respect of PGI's infrastructure development commitments, including the amounts and timing thereof;
•the expected costs, timing and impact of the Settlement; and
•the impact of current and future market conditions on Pembina.
Various factors or assumptions are typically applied by Pembina in drawing conclusions or making the forecasts, projections, predictions or estimations set out in forward-looking statements based on information currently available to Pembina. These factors and assumptions include, but are not limited to:
•oil and gas industry exploration and development activity levels and the geographic region of such activity;
•the success of Pembina's operations;
•prevailing commodity prices, interest rates, carbon prices, tax rates, exchange rates and inflation rates;
•the ability of Pembina to maintain current credit ratings;
•the availability and cost of capital to fund future capital requirements relating to existing assets, projects and the repayment or refinancing existing debt as it becomes due;
•future operating costs, including geotechnical and integrity costs being consistent with historical costs;
•oil and gas industry compensation levels remaining consistent with historical levels;
•in respect of current developments, expansions, planned capital expenditures, completion dates and capacity expectations: that third parties will provide any necessary support; that any third-party projects relating to Pembina's growth projects will be sanctioned and completed as expected; that any required commercial agreements can be reached; that all required regulatory and environmental approvals can be obtained on acceptable terms in a timely manner; that there are no supply chain disruptions impacting Pembina's ability to obtain required equipment, materials or labour; that counterparties will comply with contracts in a timely manner; that there are no unforeseen events preventing the performance of contracts or the completion of the relevant facilities, and that there are no unforeseen material costs relating to the facilities which are not recoverable from customers;
•in respect of the stability of Pembina's dividends: prevailing commodity prices, margins and exchange rates; that Pembina's future results of operations will be consistent with past performance and management expectations in relation thereto; the continued availability of capital at attractive prices to fund future capital requirements relating to existing assets and projects, including but not limited to future capital expenditures relating to expansion, upgrades and maintenance shutdowns; the success of growth projects; future operating costs; that counterparties to agreements will continue to perform their obligations in a timely manner; that there are no unforeseen events preventing the performance of contracts; and that there are no unforeseen material construction or other costs related to current growth projects; current operations or the repayment or refinancing of existing debt as it becomes due;
•the inputs used by Pembina's management in the fair valuation of embedded derivative instruments remaining consistent;
•prevailing regulatory, tax and environmental laws and regulations and tax pool utilization; and
•the amount of future liabilities relating to lawsuits and environmental incidents and the availability of coverage under Pembina's insurance policies (including in respect of Pembina's business interruption insurance policy).
The actual results of Pembina could differ materially from those anticipated in these forward-looking statements as a result of the material risk factors set forth below:
•the regulatory environment and decisions, including the outcome of regulatory hearings, and Indigenous and landowner consultation requirements;
•the impact of competitive entities and pricing;
•reliance on third parties to successfully operate and maintain certain assets;
•labour and material shortages;
•reliance on key relationships and agreements and the outcome of stakeholder engagement;
•the strength and operations of the oil and natural gas production industry and related commodity prices;
•non-performance or default by counterparties to agreements which Pembina or one or more of its subsidiaries has entered into in respect of its business;
•actions by joint venture partners or other partners which hold interests in certain of Pembina's assets;
•actions by governmental or regulatory authorities including changes in tax laws and treatment, the imposition of new tariffs or other changes in international trade policies or relations, changes in royalty rates, regulatory decisions, changes in regulatory processes or increased environmental regulation;
•fluctuations in operating results;
•adverse general economic and market conditions, including potential recessions in Canada, North America and worldwide, resulting in changes, or prolonged weaknesses, as applicable, in interest rates, foreign currency exchange rates, inflation rates, commodity prices, supply/demand trends and overall industry activity levels;
•constraints on, or the unavailability of adequate infrastructure;
•the political environment and public opinion in North America and elsewhere, including changes in trade relations between Canada and the U.S.;
•ability to access various sources of debt and equity capital on acceptable terms;
•adverse changes in credit ratings;
•counterparty credit risk;
•operating risks, including the amount of future liabilities related to pipelines spills and other environmental incidents;
•technology and security risks, including cyber-security risks;
•natural catastrophes; and
•the other factors discussed under "Risk Factors" in the MD&A for the year ended December 31, 2024 and in the AIF for the year ended December 31, 2024, which are available at www.sedarplus.ca, www.sec.gov and through Pembina's website at www.pembina.com.
These factors should not be construed as exhaustive. Unless required by law, Pembina does not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. Management approved the 2025 capital expenditure guidance contained herein as of the date of this MD&A. The purpose of the 2025 capital expenditure guidance is to assist readers in understanding Pembina's expected future capital expenditures, and this information may not be appropriate for other purposes. Any forward-looking statements contained herein are expressly qualified by this cautionary statement.
Pembina Pipeline Corporation Third Quarter 2025 41
CONDENSED CONSOLIDATED INTERIM STATEMENTS OF FINANCIAL POSITION
(unaudited)
($ millions) | September 30, 2025 | December 31, 2024 | ||||||||||||
| Assets Current assets | ||||||||||||||
| Cash and cash equivalents | 149 | 141 | ||||||||||||
| Trade receivables and other | 868 | 1,005 | ||||||||||||
| Income tax receivable | — | 113 | ||||||||||||
| Inventory | 304 | 301 | ||||||||||||
Derivative financial instruments (Note 14) | 15 | 13 | ||||||||||||
| 1,336 | 1,573 | |||||||||||||
| Non-current assets | ||||||||||||||
Property, plant and equipment (Note 5) | 22,599 | 22,738 | ||||||||||||
Intangible assets and goodwill (Note 6) | 6,402 | 6,528 | ||||||||||||
Investments in equity accounted investees (Note 7) | 4,194 | 4,267 | ||||||||||||
| Right-of-use assets | 554 | 530 | ||||||||||||
| Finance lease receivables | 241 | 223 | ||||||||||||
| Other assets | 119 | 108 | ||||||||||||
| 34,109 | 34,394 | |||||||||||||
| Total assets | 35,445 | 35,967 | ||||||||||||
| Liabilities and equity Current liabilities | ||||||||||||||
| Trade payables and other | 1,253 | 1,202 | ||||||||||||
Loans and borrowings (Note 8) | 1,093 | 1,525 | ||||||||||||
| Lease liabilities | 85 | 89 | ||||||||||||
Contract liabilities (Note 11) | 47 | 43 | ||||||||||||
Derivative financial instruments (Note 14) | 21 | 49 | ||||||||||||
| 2,499 | 2,908 | |||||||||||||
| Non-current liabilities | ||||||||||||||
Loans and borrowings (Note 8) | 10,745 | 10,535 | ||||||||||||
Subordinated hybrid notes (Note 8) | 795 | 596 | ||||||||||||
| Lease liabilities | 572 | 576 | ||||||||||||
Decommissioning provision (Note 9) | 521 | 426 | ||||||||||||
Contract liabilities (Note 11) | 144 | 255 | ||||||||||||
| Deferred tax liabilities | 2,897 | 2,868 | ||||||||||||
Derivative financial instruments (Note 14) | 104 | 110 | ||||||||||||
| Other liabilities | 167 | 183 | ||||||||||||
| 15,945 | 15,549 | |||||||||||||
| Total liabilities | 18,444 | 18,457 | ||||||||||||
| Total equity | 17,001 | 17,510 | ||||||||||||
| Total liabilities and equity | 35,445 | 35,967 | ||||||||||||
See accompanying notes to the condensed consolidated interim financial statements
42 Pembina Pipeline Corporation Third Quarter 2025
CONDENSED CONSOLIDATED INTERIM STATEMENTS OF EARNINGS AND COMPREHENSIVE INCOME
(unaudited)
| 3 Months Ended September 30 | 9 Months Ended September 30 | |||||||||||||
| ($ millions, except per share amounts) | 2025 | 2024 | 2025 | 2024 | ||||||||||
Revenue (Note 11) | 1,791 | 1,844 | 5,865 | 5,239 | ||||||||||
Cost of sales (Note 4) | 1,067 | 1,080 | 3,537 | 3,142 | ||||||||||
Share of (loss) profit from equity accounted investees (Note 7) | (66) | (17) | 38 | 195 | ||||||||||
| Gross profit | 658 | 747 | 2,366 | 2,292 | ||||||||||
| General and administrative | 126 | 120 | 357 | 340 | ||||||||||
| Other (income) expense | (19) | 4 | (15) | (38) | ||||||||||
Loss on acquisition (Note 3) | — | — | — | 616 | ||||||||||
| Results from operating activities | 551 | 623 | 2,024 | 1,374 | ||||||||||
Net finance costs (Note 12) | 153 | 149 | 454 | 398 | ||||||||||
| Earnings before income tax | 398 | 474 | 1,570 | 976 | ||||||||||
| Current tax expense | 102 | 48 | 338 | 188 | ||||||||||
| Deferred tax expense (recovery) | 10 | 41 | 27 | (514) | ||||||||||
| Income tax expense (recovery) | 112 | 89 | 365 | (326) | ||||||||||
| Earnings | 286 | 385 | 1,205 | 1,302 | ||||||||||
| Earnings attributable to: | ||||||||||||||
| Shareholders | 286 | 383 | 1,205 | 1,292 | ||||||||||
| Non-controlling interest | — | 2 | — | 10 | ||||||||||
Other comprehensive income (loss), net of tax (Note 13) | ||||||||||||||
| Exchange gain (loss) on translation of foreign operations | 128 | (82) | (186) | 61 | ||||||||||
| Impact of hedging activities | (7) | (2) | 1 | (17) | ||||||||||
| Other comprehensive income (loss), net of tax | 121 | (84) | (185) | 44 | ||||||||||
| Total comprehensive income attributable to shareholders | 407 | 301 | 1,020 | 1,346 | ||||||||||
| Comprehensive income attributable to: | ||||||||||||||
| Shareholders | 407 | 299 | 1,020 | 1,336 | ||||||||||
| Non-controlling interest | — | 2 | — | 10 | ||||||||||
Earnings attributable to common shareholders, net of preferred share dividends | 251 | 346 | 1,095 | 1,186 | ||||||||||
Earnings per common share – basic (dollars) | 0.43 | 0.60 | 1.88 | 2.08 | ||||||||||
Earnings per common share – diluted (dollars) | 0.43 | 0.60 | 1.88 | 2.08 | ||||||||||
Weighted average number of common shares (millions) | ||||||||||||||
| Basic | 581 | 580 | 581 | 570 | ||||||||||
| Diluted | 582 | 581 | 582 | 571 | ||||||||||
See accompanying notes to the condensed consolidated interim financial statements
Pembina Pipeline Corporation Third Quarter 2025 43
CONDENSED CONSOLIDATED INTERIM STATEMENTS OF CHANGES IN EQUITY
(unaudited)
| Attributable to Shareholders of the Company | Total Equity | |||||||||||||||||||||||||
($ millions) | Common Share Capital | Preferred Share Capital | Deficit | AOCI(1) | Total | Non-Controlling Interest | ||||||||||||||||||||
| December 31, 2024 | 17,008 | 2,164 | (2,303) | 641 | 17,510 | — | 17,510 | |||||||||||||||||||
Total comprehensive income (loss) | ||||||||||||||||||||||||||
Earnings | — | — | 1,205 | — | 1,205 | — | 1,205 | |||||||||||||||||||
Other comprehensive loss (Note 13) | — | — | — | (185) | (185) | — | (185) | |||||||||||||||||||
Total comprehensive income (loss) | — | — | 1,205 | (185) | 1,020 | — | 1,020 | |||||||||||||||||||
Transactions with shareholders of the Company (Note 10) | ||||||||||||||||||||||||||
Part VI.1 tax on preferred shares | — | (8) | — | — | (8) | — | (8) | |||||||||||||||||||
Preferred shares redemption | — | (200) | — | — | (200) | — | (200) | |||||||||||||||||||
Share-based payment transactions | 7 | — | — | — | 7 | — | 7 | |||||||||||||||||||
Dividends declared – common | — | — | (1,226) | — | (1,226) | — | (1,226) | |||||||||||||||||||
Dividends declared – preferred | — | — | (102) | — | (102) | — | (102) | |||||||||||||||||||
| Total transactions with shareholders of the Company | 7 | (208) | (1,328) | — | (1,529) | — | (1,529) | |||||||||||||||||||
| September 30, 2025 | 17,015 | 1,956 | (2,426) | 456 | 17,001 | — | 17,001 | |||||||||||||||||||
| December 31, 2023 | 15,765 | 2,199 | (2,372) | 221 | 15,813 | — | 15,813 | |||||||||||||||||||
Total comprehensive income | ||||||||||||||||||||||||||
Earnings | — | — | 1,292 | — | 1,292 | 10 | 1,302 | |||||||||||||||||||
Other comprehensive income | — | — | — | 44 | 44 | — | 44 | |||||||||||||||||||
| Total comprehensive income | — | — | 1,292 | 44 | 1,336 | 10 | 1,346 | |||||||||||||||||||
| Transactions with shareholders of the Company | ||||||||||||||||||||||||||
Common shares issued, net of issue costs | 1,230 | — | — | — | 1,230 | — | 1,230 | |||||||||||||||||||
Part VI.1 tax on preferred shares | — | (7) | — | — | (7) | — | (7) | |||||||||||||||||||
Share-based payment transactions | 11 | — | — | — | 11 | — | 11 | |||||||||||||||||||
Dividends declared – common | — | — | (1,168) | — | (1,168) | — | (1,168) | |||||||||||||||||||
Dividends declared – preferred | — | — | (98) | — | (98) | — | (98) | |||||||||||||||||||
Dividend equivalent payment – subscription receipts | — | — | (20) | — | (20) | — | (20) | |||||||||||||||||||
| Distributions to non-controlling interests | — | — | — | — | — | (12) | (12) | |||||||||||||||||||
| Non-controlling interest recognized on acquisition | — | — | — | — | — | 148 | 148 | |||||||||||||||||||
| Purchase of non-controlling interest | — | — | (74) | — | (74) | (146) | (220) | |||||||||||||||||||
| Total transactions with shareholders of the Company | 1,241 | (7) | (1,360) | — | (126) | (10) | (136) | |||||||||||||||||||
| September 30, 2024 | 17,006 | 2,192 | (2,440) | 265 | 17,023 | — | 17,023 | |||||||||||||||||||
(1) Accumulated Other Comprehensive Income ("AOCI").
See accompanying notes to the condensed consolidated interim financial statements
44 Pembina Pipeline Corporation Third Quarter 2025
CONDENSED CONSOLIDATED INTERIM STATEMENTS OF CASH FLOWS
(unaudited)
| 3 Months Ended September 30 | 9 Months Ended September 30 | |||||||||||||
| ($ millions) | 2025 | 2024 | 2025 | 2024 | ||||||||||
| Cash provided by (used in) | ||||||||||||||
| Operating activities | ||||||||||||||
| Earnings | 286 | 385 | 1,205 | 1,302 | ||||||||||
| Adjustments for items not involving cash: | ||||||||||||||
Share of profit (loss) from equity accounted investees (Note 7) | 66 | 17 | (38) | (195) | ||||||||||
| Depreciation and amortization | 241 | 231 | 731 | 627 | ||||||||||
Loss on acquisition (Note 3) | — | — | — | 616 | ||||||||||
Unrealized (gain) loss from derivative instruments | (1) | (18) | (41) | 129 | ||||||||||
| Net finance costs | 153 | 149 | 454 | 398 | ||||||||||
| Share-based compensation expense | 39 | 41 | 68 | 81 | ||||||||||
| Income tax expense (recovery) | 112 | 89 | 365 | (326) | ||||||||||
| Gain on asset disposal | (19) | (4) | (23) | (24) | ||||||||||
| Derecognition of insurance contract provision | — | — | — | (34) | ||||||||||
| Cash items paid or received: | ||||||||||||||
| Distributions from equity accounted investees | 128 | 133 | 396 | 495 | ||||||||||
| Net interest paid | (172) | (171) | (464) | (382) | ||||||||||
| Share-based compensation payment | (3) | — | (89) | (86) | ||||||||||
| Taxes paid | (30) | (62) | (157) | (352) | ||||||||||
| Change in non-cash operating working capital | 23 | 136 | 57 | 30 | ||||||||||
| Net change in contract liabilities | (8) | (1) | (1) | 31 | ||||||||||
| Other | (5) | (3) | (23) | 2 | ||||||||||
Cash flow from operating activities | 810 | 922 | 2,440 | 2,312 | ||||||||||
| Financing activities | ||||||||||||||
| Net (decrease) increase in bank borrowings | (8) | 77 | 461 | (370) | ||||||||||
| Proceeds from issuance of long-term debt, net of issue costs | (2) | (2) | 195 | 2,733 | ||||||||||
| Proceeds from subscription receipts | — | — | — | 1,228 | ||||||||||
| Repayment of long-term debt | (110) | (150) | (660) | (800) | ||||||||||
| Repayment of lease liability | (21) | (19) | (62) | (57) | ||||||||||
| Issuance of common shares on exercise of options | 3 | — | 6 | 10 | ||||||||||
Redemption of preferred shares (Note 10) | — | — | (226) | — | ||||||||||
| Common share dividends paid | (413) | (401) | (1,226) | (1,168) | ||||||||||
| Preferred share dividends paid | (32) | (34) | (102) | (98) | ||||||||||
| Distributions to non-controlling interest | — | (2) | — | (12) | ||||||||||
| Purchase of non-controlling interest | — | (220) | — | (220) | ||||||||||
| Cash flow (used in) from financing activities | (583) | (751) | (1,614) | 1,246 | ||||||||||
| Investing activities | ||||||||||||||
| Capital expenditures | (178) | (262) | (549) | (713) | ||||||||||
| Contributions to equity accounted investees | (108) | (124) | (283) | (371) | ||||||||||
Acquisition net of cash acquired (Note 3) | — | — | — | (2,621) | ||||||||||
| Proceeds from sale of assets | 2 | 11 | 6 | 34 | ||||||||||
| Interest paid during construction | (7) | (5) | (19) | (21) | ||||||||||
| Return of capital from equity accounted investees | — | — | — | 63 | ||||||||||
| Changes in non-cash investing working capital and other | (3) | 59 | 28 | 19 | ||||||||||
| Cash flow used in investing activities | (294) | (321) | (817) | (3,610) | ||||||||||
| Change in cash and cash equivalents | (67) | (150) | 9 | (52) | ||||||||||
| Effect of movement in exchange rates on cash held | 6 | (2) | (1) | 5 | ||||||||||
| Cash and cash equivalents, beginning of period | 210 | 256 | 141 | 151 | ||||||||||
| Cash and cash equivalents, end of period | 149 | 104 | 149 | 104 | ||||||||||
See accompanying notes to the condensed consolidated interim financial statements
Pembina Pipeline Corporation Third Quarter 2025 45
NOTES TO THE CONDENSED CONSOLIDATED INTERIM FINANCIAL STATEMENTS
1. REPORTING ENTITY
Pembina Pipeline Corporation ("Pembina" or the "Company") is a Calgary-based, leading transportation and midstream service provider serving North America's energy industry. These condensed consolidated unaudited interim financial statements ("Interim Financial Statements") include the accounts of the Company, its subsidiary companies, partnerships and any investments in associates and joint arrangements as at and for the three and nine months ended September 30, 2025.
Pembina owns an extensive network of strategically located assets which include hydrocarbon liquids and natural gas pipelines, gas gathering and processing facilities, oil and natural gas liquids infrastructure and logistics services, and an export terminals business. Pembina's network of strategically located assets and commercial operations along the majority of the hydrocarbon value chain allow it to offer a full spectrum of midstream and marketing services to the energy sector.
These Interim Financial Statements and the notes hereto have been prepared in accordance with International Accounting Standard 34, Interim Financial Reporting. The accounting policies applied are in accordance with International Financial Reporting Standards ("IFRS") Accounting Standards as issued by the International Accounting Standards Board and are consistent with the audited annual consolidated financial statements of the Company as at and for the year ended December 31, 2024 ("Consolidated Financial Statements"), and should be read in conjunction with those Consolidated Financial Statements. The Interim Financial Statements were authorized for issue by Pembina's Board of Directors on November 6, 2025.
Use of Estimates and Judgments
Management is required to make estimates and assumptions and use judgment in the application of accounting policies that could have a significant impact on the amounts recognized in the Interim Financial Statements. Actual results may differ from estimates and those differences may be material. By their nature, judgments and estimates may change in light of new facts and circumstances in the internal and external environment. There have been no material changes to Pembina's critical accounting estimates and judgments during the three and nine months ended September 30, 2025.
2. CHANGES IN ACCOUNTING POLICIES
The accounting policies used in preparing the Interim Financial Statements are described in Note 3 of Pembina's Consolidated Financial Statements. There were no new accounting standards or amendments to existing standards adopted in the nine months ended September 30, 2025 that have a material impact on Pembina's financial statements.
New Standards and Interpretations Not Yet Adopted
IFRS 18 Presentation and Disclosure in Financial Statements ("IFRS 18")
IFRS 18 was issued in April 2024 and effective January 1, 2027, with early application permitted. The standard introduces key changes to the structure of the statement of earnings and comprehensive income, required disclosures for certain management-defined performance measures, and aggregation and disaggregation of line items in the financial statements. Pembina is currently reviewing the impact of this standard on its Consolidated Financial Statements.
Amendments to IFRS 9 and IFRS 7 - Contracts referencing Nature-dependent Electricity ("Contracts referencing NDE")
Contracts referencing NDE was issued in December 2024 and effective January 1, 2026, with early adoption permitted. The amendments provide relief as it relates to accounting for contracts to purchase or sell electricity from nature-dependent sources such as wind and solar power, including clarifying the application of own-use requirements, permitting hedge accounting if these contracts are used as hedging instruments, and adding new disclosure to enable investors to understand the effect of these contracts to Pembina. Pembina is currently reviewing the impact of this amendment as it relates to Pembina's wind-based power purchase agreements.
46 Pembina Pipeline Corporation Third Quarter 2025
3. ACQUISITION
On April 1, 2024, Pembina completed the acquisition of Enbridge Inc.'s interests in the Alliance, Aux Sable, and NRGreen joint ventures (the "Acquirees") for an aggregate purchase price of $2.8 billion, net of $327 million of assumed debt, representing Enbridge's proportionate share of the indebtedness of Alliance (the "Alliance/Aux Sable Acquisition"). Pembina made no adjustments to the purchase price allocation during the first quarter of 2025 and finalized it as at March 31, 2025.
The final purchase price allocation is based on assessed fair values and is as follows:
| As at April 1, 2024 | Previously reported | Adjustments | Final | ||||||||||||||||||||||||||
| ($ millions) | in Q2 2024 | ||||||||||||||||||||||||||||
| Purchase Price Consideration | |||||||||||||||||||||||||||||
| Cash (net of cash acquired) | 2,620 | — | 2,620 | ||||||||||||||||||||||||||
| Equity investment in Acquirees | 2,562 | — | 2,562 | ||||||||||||||||||||||||||
| Other | 12 | — | 12 | ||||||||||||||||||||||||||
| 5,194 | — | 5,194 | |||||||||||||||||||||||||||
| Fair Value of Net Assets Acquired | |||||||||||||||||||||||||||||
| Current assets | 240 | — | 240 | ||||||||||||||||||||||||||
| Property, plant and equipment | 6,339 | 6 | 6,345 | ||||||||||||||||||||||||||
| Other long-term assets | 38 | 19 | 57 | ||||||||||||||||||||||||||
| Goodwill | 805 | (2) | 803 | ||||||||||||||||||||||||||
| Current liabilities | (219) | (17) | (236) | ||||||||||||||||||||||||||
| Long-term debt | (596) | — | (596) | ||||||||||||||||||||||||||
| Deferred tax liabilities | (937) | 1 | (936) | ||||||||||||||||||||||||||
| Provisions | (52) | — | (52) | ||||||||||||||||||||||||||
| Other long-term liabilities | (276) | (7) | (283) | ||||||||||||||||||||||||||
| Non-controlling interest in Aux Sable's U.S. operations | (148) | — | (148) | ||||||||||||||||||||||||||
| 5,194 | — | 5,194 | |||||||||||||||||||||||||||
Pembina Pipeline Corporation Third Quarter 2025 47
4. OPERATING SEGMENTS
Pembina's operating segments are organized by three divisions: Pipelines, Facilities and Marketing & New Ventures.
| 3 Months Ended September 30, 2025 | Pipelines(1) | Facilities | Marketing & New Ventures(2) | Corporate & Inter-segment Eliminations | Total | ||||||||||||
| ($ millions) | |||||||||||||||||
| Revenue from external customers | 829 | 88 | 861 | 13 | 1,791 | ||||||||||||
| Inter-segment revenue | 53 | 212 | — | (265) | — | ||||||||||||
Total revenue(3) | 882 | 300 | 861 | (252) | 1,791 | ||||||||||||
| Operating expenses | 221 | 134 | 7 | (103) | 259 | ||||||||||||
| Cost of goods sold | 10 | — | 739 | (169) | 580 | ||||||||||||
| Depreciation and amortization included in gross profit | 161 | 48 | 16 | 3 | 228 | ||||||||||||
| Cost of sales | 392 | 182 | 762 | (269) | 1,067 | ||||||||||||
| Share of loss from equity accounted investees | (1) | (51) | (14) | — | (66) | ||||||||||||
| Gross profit | 489 | 67 | 85 | 17 | 658 | ||||||||||||
| Depreciation included in general and administrative | 1 | — | — | 12 | 13 | ||||||||||||
| Other general and administrative | 22 | 6 | 14 | 71 | 113 | ||||||||||||
| Other income | (18) | — | — | (1) | (19) | ||||||||||||
Results from operating activities | 484 | 61 | 71 | (65) | 551 | ||||||||||||
| Net finance costs | 7 | 3 | 3 | 140 | 153 | ||||||||||||
Earnings (loss) before tax | 477 | 58 | 68 | (205) | 398 | ||||||||||||
| Income tax expense | — | — | — | — | 112 | ||||||||||||
Earnings (loss) | 477 | 58 | 68 | (205) | 286 | ||||||||||||
Capital expenditures | 84 | 84 | 3 | 7 | 178 | ||||||||||||
| Contributions to equity accounted investees | — | 74 | 34 | — | 108 | ||||||||||||
| 3 Months Ended September 30, 2024 | Pipelines(1) | Facilities | Marketing & New Ventures(2) | Corporate & Inter-segment Eliminations | Total | ||||||||||||
| ($ millions) | |||||||||||||||||
| Revenue from external customers | 810 | 86 | 937 | 11 | 1,844 | ||||||||||||
| Inter-segment revenue | 50 | 196 | 1 | (247) | — | ||||||||||||
Total revenue(3) | 860 | 282 | 938 | (236) | 1,844 | ||||||||||||
| Operating expenses | 244 | 123 | 5 | (95) | 277 | ||||||||||||
| Cost of goods sold | 9 | — | 732 | (156) | 585 | ||||||||||||
| Depreciation and amortization included in gross profit | 151 | 50 | 15 | 2 | 218 | ||||||||||||
| Cost of sales | 404 | 173 | 752 | (249) | 1,080 | ||||||||||||
| Share of (loss) profit from equity accounted investees | (1) | 34 | (50) | — | (17) | ||||||||||||
| Gross profit | 455 | 143 | 136 | 13 | 747 | ||||||||||||
| Depreciation included in general and administrative | 2 | — | — | 11 | 13 | ||||||||||||
| Other general and administrative | 14 | 8 | 12 | 73 | 107 | ||||||||||||
| Other expense (income) | — | 1 | (2) | 5 | 4 | ||||||||||||
Results from operating activities | 439 | 134 | 126 | (76) | 623 | ||||||||||||
| Net finance costs | 6 | 3 | 1 | 139 | 149 | ||||||||||||
| Earnings (loss) before tax | 433 | 131 | 125 | (215) | 474 | ||||||||||||
| Income tax expense | — | — | — | — | 89 | ||||||||||||
Earnings (loss) | 433 | 131 | 125 | (215) | 385 | ||||||||||||
Capital expenditures | 130 | 110 | 10 | 12 | 262 | ||||||||||||
| Contributions to equity accounted investees | — | 124 | — | — | 124 | ||||||||||||
(1) Pipelines revenue includes $118 million (2024: $130 million) associated with U.S. pipeline revenue.
(2) Marketing & New Ventures includes revenue of $236 million (2024: $234 million) associated with U.S. midstream sales.
(3) During the three months ended September 30, 2025, one customer accounted for 10 percent or more of total revenues with $236 million reported throughout all segments. During the three months ended September 30, 2024, no customer accounted for 10 percent or more of total revenues reported throughout all segments.
48 Pembina Pipeline Corporation Third Quarter 2025
| 9 Months Ended September 30, 2025 | Pipelines(1) | Facilities | Marketing & New Ventures(2) | Corporate & Inter-segment Eliminations | Total | ||||||||||||
| ($ millions) | |||||||||||||||||
| Revenue from external customers | 2,496 | 260 | 3,074 | 35 | 5,865 | ||||||||||||
| Inter-segment revenue | 154 | 642 | 6 | (802) | — | ||||||||||||
Total revenue(3) | 2,650 | 902 | 3,080 | (767) | 5,865 | ||||||||||||
| Operating expenses | 604 | 400 | 24 | (308) | 720 | ||||||||||||
| Cost of goods sold | 37 | — | 2,597 | (507) | 2,127 | ||||||||||||
| Depreciation and amortization included in gross profit | 477 | 152 | 53 | 8 | 690 | ||||||||||||
| Cost of sales | 1,118 | 552 | 2,674 | (807) | 3,537 | ||||||||||||
| Share of profit (loss) from equity accounted investees | — | 60 | (22) | — | 38 | ||||||||||||
| Gross profit | 1,532 | 410 | 384 | 40 | 2,366 | ||||||||||||
| Depreciation included in general and administrative | 2 | — | — | 39 | 41 | ||||||||||||
| Other general and administrative | 60 | 16 | 33 | 207 | 316 | ||||||||||||
| Other (income) expense | (17) | 1 | 2 | (1) | (15) | ||||||||||||
Results from operating activities | 1,487 | 393 | 349 | (205) | 2,024 | ||||||||||||
| Net finance costs | 19 | 9 | 7 | 419 | 454 | ||||||||||||
Earnings (loss) before tax | 1,468 | 384 | 342 | (624) | 1,570 | ||||||||||||
| Income tax expense | — | — | — | — | 365 | ||||||||||||
| Earnings (loss) | 1,468 | 384 | 342 | (624) | 1,205 | ||||||||||||
Capital expenditures | 216 | 294 | 14 | 25 | 549 | ||||||||||||
| Contributions to equity accounted investees | — | 198 | 86 | — | 284 | ||||||||||||
| 9 Months Ended September 30, 2024 | Pipelines(1) | Facilities | Marketing & New Ventures(2) | Corporate & Inter-segment Eliminations | Total | ||||||||||||
| ($ millions) | |||||||||||||||||
| Revenue from external customers | 2,285 | 259 | 2,661 | 34 | 5,239 | ||||||||||||
| Inter-segment revenue | 153 | 548 | 2 | (703) | — | ||||||||||||
Total revenue(3) | 2,438 | 807 | 2,663 | (669) | 5,239 | ||||||||||||
| Operating expenses | 601 | 336 | 13 | (244) | 706 | ||||||||||||
| Cost of goods sold | 35 | — | 2,279 | (468) | 1,846 | ||||||||||||
| Depreciation and amortization included in gross profit | 410 | 128 | 47 | 5 | 590 | ||||||||||||
| Cost of sales | 1,046 | 464 | 2,339 | (707) | 3,142 | ||||||||||||
| Share of profit (loss) from equity accounted investees | 42 | 172 | (19) | — | 195 | ||||||||||||
| Gross profit | 1,434 | 515 | 305 | 38 | 2,292 | ||||||||||||
| Depreciation included in general and administrative | 2 | — | — | 35 | 37 | ||||||||||||
| Other general and administrative | 42 | 19 | 39 | 203 | 303 | ||||||||||||
| Other (income) expense | (2) | (1) | (62) | 27 | (38) | ||||||||||||
| Loss on acquisition | — | — | — | 616 | 616 | ||||||||||||
| Results from operating activities | 1,392 | 497 | 328 | (843) | 1,374 | ||||||||||||
| Net finance costs | 19 | 8 | 4 | 367 | 398 | ||||||||||||
| Earnings (loss) before tax | 1,373 | 489 | 324 | (1,210) | 976 | ||||||||||||
| Income tax recovery | — | — | — | — | (326) | ||||||||||||
| Earnings (loss) | 1,373 | 489 | 324 | (1,210) | 1,302 | ||||||||||||
| Capital expenditures | 442 | 218 | 21 | 32 | 713 | ||||||||||||
| Contributions to equity accounted investees | 5 | 124 | 242 | — | 371 | ||||||||||||
(1) Pipelines revenue includes $388 million (2024: $360 million) associated with U.S. pipeline revenue.
(2) Marketing & New Ventures includes revenue of $854 million (2024: $535 million) associated with U.S. midstream sales.
(3) During the nine months ended September 30, 2025, one customer accounted for 10 percent or more of total revenues with $822 million reported throughout all segments. During the nine months ended September 30, 2024, no customer accounted for 10 percent or more of total gross profit reported throughout all segments.
Pembina Pipeline Corporation Third Quarter 2025 49
5. PROPERTY, PLANT AND EQUIPMENT
| ($ millions) | Land and Land Rights | Pipelines | Facilities and Equipment | Cavern Storage and Other | Assets Under Construction | Total | ||||||||||||||
| Cost | ||||||||||||||||||||
| Balance at December 31, 2024 | 694 | 14,789 | 9,095 | 2,121 | 565 | 27,264 | ||||||||||||||
| Additions and transfers | (2) | 51 | 145 | 28 | 319 | 541 | ||||||||||||||
| Change in decommissioning provision | — | 48 | 20 | 3 | — | 71 | ||||||||||||||
| Foreign exchange | (6) | (111) | (55) | (2) | (1) | (175) | ||||||||||||||
| Dispositions and other | — | (20) | (33) | (28) | (4) | (85) | ||||||||||||||
| Balance at September 30, 2025 | 686 | 14,757 | 9,172 | 2,122 | 879 | 27,616 | ||||||||||||||
| Depreciation | ||||||||||||||||||||
| Balance at December 31, 2024 | 47 | 2,335 | 1,594 | 550 | — | 4,526 | ||||||||||||||
| Depreciation | 6 | 233 | 226 | 62 | — | 527 | ||||||||||||||
| Transfers | (1) | 15 | 4 | (18) | — | — | ||||||||||||||
| Dispositions and other | — | (17) | (19) | — | — | (36) | ||||||||||||||
| Balance at September 30, 2025 | 52 | 2,566 | 1,805 | 594 | — | 5,017 | ||||||||||||||
| Carrying amounts | ||||||||||||||||||||
| Balance at December 31, 2024 | 647 | 12,454 | 7,501 | 1,571 | 565 | 22,738 | ||||||||||||||
| Balance at September 30, 2025 | 634 | 12,191 | 7,367 | 1,528 | 879 | 22,599 | ||||||||||||||
Alliance Settlement
On December 12, 2024, Pembina announced that the Canada Energy Regulatory ("CER") had initiated a toll review of the Alliance Canada pipeline assets. As the toll review continued into the first quarter of 2025, Pembina performed an impairment test during that quarter for the Cash-Generating Unit ("CGU") that includes the Alliance Canada assets. The test determined that the recoverable amount of the CGU exceeded the carrying value of $6.3 billion as of March 31, 2025 and as a result, no impairment was recognized.
The recoverable amount calculated in the first quarter of 2025, was determined using a fair value less costs of disposal approach by discounting the expected future cash flows, including probability-weighted settlement outcomes for the Alliance Canada assets. The recoverable amount was sensitive to changes in key assumptions, including the outcome of the CER toll review, and the after-tax discount rate of 7.9 percent used to discount the future cash flows of the CGU. A 1.1 percent increase in the discount rate would have reduced the recoverable amount of the CGU to its carrying value.
On September 15, 2025, the CER approved the negotiated settlement (the "Settlement") between Alliance Pipeline Limited Partnership ("Alliance") and shippers and interested parties on the Canadian portion of the Alliance Pipeline. The settlement outcome approved by the CER was within the expected range of outcomes used in the impairment test performed in the first quarter of 2025.
50 Pembina Pipeline Corporation Third Quarter 2025
6. INTANGIBLE ASSETS AND GOODWILL
| Intangible Assets | ||||||||||||||||||||
| ($ millions) | Goodwill | Purchase and Sale Contracts and Other | Customer Relationships | Total | Total Goodwill & Intangible Assets | |||||||||||||||
| Cost | ||||||||||||||||||||
| Balance at December 31, 2024 | 5,024 | 324 | 1,877 | 2,201 | 7,225 | |||||||||||||||
| Additions | — | 25 | — | 25 | 25 | |||||||||||||||
| Foreign exchange adjustments | (25) | — | (24) | (24) | (49) | |||||||||||||||
| Balance at September 30, 2025 | 4,999 | 349 | 1,853 | 2,202 | 7,201 | |||||||||||||||
| Amortization | ||||||||||||||||||||
| Balance at December 31, 2024 | — | 65 | 632 | 697 | 697 | |||||||||||||||
| Amortization | — | 16 | 90 | 106 | 106 | |||||||||||||||
| Dispositions and other | — | — | (4) | (4) | (4) | |||||||||||||||
| Balance at September 30, 2025 | — | 81 | 718 | 799 | 799 | |||||||||||||||
| Carrying amounts | ||||||||||||||||||||
| Balance at December 31, 2024 | 5,024 | 259 | 1,245 | 1,504 | 6,528 | |||||||||||||||
| Balance at September 30, 2025 | 4,999 | 268 | 1,135 | 1,403 | 6,402 | |||||||||||||||
Pembina Pipeline Corporation Third Quarter 2025 51
7. INVESTMENTS IN EQUITY ACCOUNTED INVESTEES
Ownership Interest (percent) | Share of Profit (Loss) from Equity Accounted Investees | Investments in Equity Accounted Investees | ||||||||||||||||||
| 9 Months Ended September 30 | ||||||||||||||||||||
| ($ millions) | September 30, 2025 | December 31, 2024 | 2025 | 2024 | September 30, 2025 | December 31, 2024 | ||||||||||||||
PGI(1) | 60 | 60 | 58 | 169 | 3,605 | 3,740 | ||||||||||||||
| Cedar LNG | 49.9 | 49.9 | (21) | (52) | 475 | 430 | ||||||||||||||
Alliance(2) | 100 | 100 | — | 42 | — | — | ||||||||||||||
Aux Sable(2) | 100 | 100 | — | 33 | — | — | ||||||||||||||
Other(3) | 50 - 75 | 50 - 75 | 1 | 3 | 114 | 97 | ||||||||||||||
| 38 | 195 | 4,194 | 4,267 | |||||||||||||||||
(1) PGI share of profit for the nine months ended September 30, 2025, includes an impairment of a single cash generating unit and an impairment of an asset within PGI of $146 million (net to Pembina, after tax), due to contract expirations and future utilization uncertainty.
(2) On April 1, 2024, Pembina completed its acquisition of Enbridge's interests in the Alliance, Aux Sable, and NRGreen joint ventures. On August 1, 2024, Pembina acquired the remaining non-controlling interest in Aux Sable's U.S. operations. Refer to Note 3 for further information.
(3) Other includes Pembina's interest in Grand Valley, Fort Corp, ACG, and Greenlight.
Financing Activities for Equity Accounted Investees
PGI
On March 21, 2025, pursuant to an amended and restated credit agreement, PGI exercised the accordion feature under its existing revolving credit facility and opened a new $500 million revolving credit facility, maturing on March 21, 2027. Concurrently, PGI reestablished a $500 million accordion under the credit facility.
PGI Goodwill Impairment Testing
At each reporting date, Pembina determines whether there is objective evidence that its equity accounted investments are impaired. For the period ended September 30, 2025, it was determined that there is no objective evidence indicating that Pembina's equity accounted investments are impaired. Pembina's assessment of whether there is objective evidence the equity accounted investment in PGI is impaired requires significant judgment as it is sensitive to a decrease in PGI's projected cash flows, a decrease in the long-term growth rate, or an increase in the after-tax discount rate, any of which could be objective evidence that Pembina's equity accounted investment in PGI is impaired. Pembina also believes an impairment expense recognized by PGI as a result of its annual goodwill impairment test would provide objective evidence that Pembina's equity accounted investment in PGI is impaired.
PGI performed its annual goodwill impairment test in the third quarter of 2025 calculating the recoverable amount based on the fair value less cost to sell. No impairment expense was recognized.
There is measurement uncertainty associated with PGI's annual impairment test. The key assumptions used by PGI that impact the recoverable amount were the projected cash flows for the remaining useful life of the assets, the after-tax discount rate and the long-term growth rate. The following table provides sensitivities to reasonably possible changes in each estimate that could result in an impairment of PGI's goodwill.
| September 30, 2025 | September 30, 2024 | |||||||||||||
| Actual | Increase (decrease) required for impairment (percent) | Actual | Increase (decrease) required for impairment (percent) | |||||||||||
| Key assumptions used | ||||||||||||||
Average annual pre-tax cash flow ($ millions)(1) | 1,303 | (20.8) | 1,232 | (6.0) | ||||||||||
After-tax discount rate (percent) | 6.9 | 2.3 | 7.6 | 0.6 | ||||||||||
Long-term growth rate (percent) | 1.9 | (4.7) | 1.8 | (0.9) | ||||||||||
(1) Average annual forecasted pre-tax cash flows represent 100 percent of PGI's forecasted cash flows.
52 Pembina Pipeline Corporation Third Quarter 2025
8. LONG-TERM DEBT
This note provides information about the contractual terms of Pembina's interest-bearing long-term debt, which is measured at amortized cost.
Carrying Value, Terms and Conditions, and Debt Maturity Schedule
Carrying Value | |||||||||||||||||
($ millions) | Authorized at September 30, 2025 | Nominal Interest Rate | Year of Maturity | September 30, 2025 | December 31, 2024 | ||||||||||||
| Variable rate debt | |||||||||||||||||
Senior unsecured credit facilities(1)(2) | 3,391 | 4.58(3) | Various(1) | 1,477 | 1,148 | ||||||||||||
| Fixed rate debt | |||||||||||||||||
| Senior unsecured medium-term notes series 3 | 450 | 4.75 | 2043 | 450 | 450 | ||||||||||||
| Senior unsecured medium-term notes series 4 | 600 | 4.81 | 2044 | 600 | 600 | ||||||||||||
| Senior unsecured medium-term notes series 5 | — | 3.54 | 2025 | — | 550 | ||||||||||||
| Senior unsecured medium-term notes series 6 | 600 | 4.24 | 2027 | 600 | 600 | ||||||||||||
| Senior unsecured medium-term notes series 7 | 600 | 3.71 | 2026 | 600 | 600 | ||||||||||||
| Senior unsecured medium-term notes series 9 | 550 | 4.74 | 2047 | 550 | 550 | ||||||||||||
| Senior unsecured medium-term notes series 10 | 650 | 4.02 | 2028 | 650 | 650 | ||||||||||||
| Senior unsecured medium-term notes series 11 | 800 | 4.75 | 2048 | 800 | 800 | ||||||||||||
| Senior unsecured medium-term notes series 12 | 650 | 3.62 | 2029 | 650 | 650 | ||||||||||||
| Senior unsecured medium-term notes series 13 | 700 | 4.54 | 2049 | 700 | 700 | ||||||||||||
| Senior unsecured medium-term notes series 15 | 600 | 3.31 | 2030 | 600 | 600 | ||||||||||||
| Senior unsecured medium-term notes series 16 | 400 | 4.67 | 2050 | 400 | 400 | ||||||||||||
| Senior unsecured medium-term notes series 17 | 500 | 3.53 | 2031 | 500 | 500 | ||||||||||||
| Senior unsecured medium-term notes series 18 | 500 | 4.49 | 2051 | 500 | 500 | ||||||||||||
| Senior unsecured medium-term notes series 20 | 750 | 5.02 | 2032 | 750 | 750 | ||||||||||||
| Senior unsecured medium-term notes series 21 | 600 | 5.21 | 2034 | 600 | 600 | ||||||||||||
| Senior unsecured medium-term notes series 22 | 750 | 5.67 | 2054 | 750 | 750 | ||||||||||||
| Senior unsecured medium-term notes series 23 | 650 | 5.22 | 2033 | 650 | 650 | ||||||||||||
| Total fixed rate loans and borrowings outstanding | 10,350 | 10,900 | |||||||||||||||
| Deferred financing costs | 11 | 12 | |||||||||||||||
| Total loans and borrowings | 11,838 | 12,060 | |||||||||||||||
| Less current portion loans and borrowings | (1,093) | (1,525) | |||||||||||||||
| Total non-current loans and borrowings | 10,745 | 10,535 | |||||||||||||||
| Subordinated notes | |||||||||||||||||
| Subordinated notes, series 1 | — | 4.80 | 2081 | — | 600 | ||||||||||||
| Subordinated notes, series 2 | 200 | 5.95 | 2055 | 200 | — | ||||||||||||
| Subordinated notes, series 3 | 600 | 4.80 | 2081 | 600 | — | ||||||||||||
| 800 | 600 | ||||||||||||||||
| Deferred financing costs | (5) | (4) | |||||||||||||||
| Total subordinated notes | 795 | 596 | |||||||||||||||
(1) Pembina's unsecured credit facilities include a $2.5 billion revolving facility that matures in June 2030, a U.S. $250 million non-revolving term loan that matures in April 2030, a $270 million term loan and a U.S. $160 million term loan, both of which mature in December 2025, and a $50 million operating facility that matures in June 2026, which is typically renewed on an annual basis. The $2.5 billion revolving facility reflects the cancellation of the $1.0 billion sustainability-linked revolving credit facility in September 2025, which previously matured in June 2027, and its addition into the Revolving Facility.
(2) Includes U.S. $250 million variable rate debt outstanding at September 30, 2025 (2024: U.S. $250 million). The U.S. dollar denominated non-revolving term loan is designated as a hedge of the Company's net investment in selected foreign operations with a U.S. dollar functional currency.
(3) The nominal interest rate is the weighted average of all drawn credit facilities based on Pembina's credit rating at September 30, 2025. Borrowings under the credit facilities bear interest at prime rates, the Canadian Overnight Repo Rate Average ("CORRA"), or the USD Secured Overnight Financing Rate ("SOFR"), plus applicable margins.
Pembina Pipeline Corporation Third Quarter 2025 53
On April 2, 2025, Pembina completed an extension on its unsecured U.S. $250 million non-revolving term loan, which now matures in April 2030.
On June 6, 2025, Pembina closed a $200 million offering of Fixed-to-Fixed Rate Subordinated Notes, Series 2 (the "Series 2 Subordinated Notes") due June 6, 2055. The Series 2 Subordinated Notes bear interest at a rate of 5.95 percent, which will reset on June 6, 2035, and on every fifth anniversary thereafter, based on the five-year Government of Canada yield plus 2.713 percent, provided that the interest rate during any subsequent fixed rate period will not be less than 5.95 percent. Pembina's Series 2 Subordinated Notes are subject to optional redemption by Pembina from March 6, 2035 to June 6, 2035, and thereafter, on any interest payment date or any interest reset date, as applicable. Pembina may also redeem the Series 2 Subordinated Notes in certain other limited circumstances. Pembina used the net proceeds of the offering of the Series 2 Subordinated Notes to fund the redemption of its outstanding Cumulative Redeemable Rate Reset Class A Preferred Shares, Series 19 ("Series 19 Class A Preferred Shares") on June 30, 2025.
On July 23, 2025, Pembina announced the approval of amendments (the "Amendments") to the indenture governing Pembina's 4.80 percent Fixed-to-Fixed Rate Subordinated Notes, Series 1 (the "Series 1 Subordinated Notes") due January 25, 2081. The Amendments provided for, among other things, the exchange (the "Note Exchange") of all of the outstanding Series 1 Subordinated Notes for an equal principal amount of 4.80 percent Fixed-to-Fixed Rate Subordinated Notes, Series 3 of Pembina (the "Series 3 Subordinated Notes") due January 25, 2081. The Series 3 Subordinated Notes have the same economic terms as the Series 1 Subordinated Notes, including interest rate, interest payment dates, interest reset dates, maturity date and redemption provisions, but do not provide for an entitlement to delivery of preferred shares upon the occurrence of certain bankruptcy and related events. The Note Exchange was completed on July 25, 2025, following the execution of the supplemental indenture implementing the Amendments. The Series 3 Subordinated Notes rank equally in right of payment with the Series 2 Subordinated Notes. Pursuant to the mandatory redemption provisions attached to the Class A Preferred Shares, Series 2021-A (the "Series 2021-A Class A Preferred Shares"), in connection with the Note Exchange, on July 28, 2025, Pembina redeemed all of the issued and outstanding Series 2021-A Class A Preferred Shares (refer to Note 10 for further information).
On September 9, 2025, Pembina completed an extension on its $2.5 billion Revolving Facility, which now matures on June 1, 2030.
Subsequent to the end of the third quarter of 2025, on October 10, 2025, Pembina closed a $225 million offering of Series 2 Subordinated Notes pursuant to a re-opening. Following closing of the offering of the Series 2 Subordinated Notes, $425 million aggregate principal amount of Series 2 Subordinated Notes are issued and outstanding. Pembina intends to use the net proceeds of the offering to fund the redemption of its outstanding Cumulative Redeemable Rate Reset Class A Preferred Shares, Series 9 (the "Series 9 Class A Preferred Shares") and for general corporate purposes.
Subsequent to the end of third quarter of 2025, on October 31, 2025, Pembina closed a $600 million non-revolving term loan ("Two-Year Term Loan") with certain existing lenders. The proceeds of the Two-Year Term Loan have been used to repay the $270 million term loan outstanding at Alliance, and existing amounts drawn under Pembina's $2.5 billion revolving credit facility. The Two-Year Term Loan has an initial term of two years and is pre-payable at the option of Pembina. The other terms and conditions of the Two-Year Term Loan, including financial covenants, are substantially similar to Pembina's $2.5 billion revolving credit facility.
54 Pembina Pipeline Corporation Third Quarter 2025
Covenants
Pembina is subject to certain financial covenants under its medium-term note indentures and credit facilities agreements and complies with all financial covenants as of September 30, 2025. Pembina's financial covenants under the indenture governing its medium-term notes and the agreements governing the credit facilities include the following:
| Debt | Financial Covenant(1) | Ratio | ||||||||||||
| Senior unsecured medium-term notes | Funded Debt to Capitalization | Maximum 0.70(2) | ||||||||||||
| Credit facilities | Debt to Capital | Maximum 0.70(3) | ||||||||||||
(1) Terms as defined in relevant agreements.
(2) Covenant must be met at the reporting date and filed within 90 days after the end of each fiscal year and within 10 business days after filing of the Consolidated Financial Statements.
(3) Covenant must be met at the reporting date and filed within 120 days after the end of each fiscal year and 60 days after each quarter.
Pembina Pipeline Corporation Third Quarter 2025 55
9. DECOMMISSIONING PROVISION
| ($ millions) | 2025 | ||||||||||
| Balance at January 1 | 432 | ||||||||||
| Unwinding of discount rate | 19 | ||||||||||
| Change in rates | 6 | ||||||||||
| Disposition | (20) | ||||||||||
| Change in cost estimates and other | 93 | ||||||||||
| Total | 530 | ||||||||||
Current portion of provision(1) | 9 | ||||||||||
Balance at September 30 | 521 | ||||||||||
(1) Included in trade payables and other on the condensed consolidated interim financial statements.
10. SHARE CAPITAL
Common Share Capital
| ($ millions, except as noted) | Number of Common Shares (millions) | Common Share Capital | ||||||
| Balance at December 31, 2024 | 581 | 17,008 | ||||||
Share-based payment transactions(1) | — | 7 | ||||||
| Balance at September 30, 2025 | 581 | 17,015 | ||||||
(1) Exercised options are settled by issuing the net number of common shares equivalent to the gain upon exercise.
Share Repurchase Program
On May 14, 2025, the Toronto Stock Exchange ("TSX") accepted the renewal of Pembina's normal course issuer bid (the "NCIB") that allows the Company to repurchase, at its discretion, up to five percent of the Company's outstanding common shares (representing approximately 29 million common shares) through the facilities of the TSX, the New York Stock Exchange and/or alternative Canadian trading systems or as otherwise permitted by applicable securities law, subject to certain restrictions on the number of common shares that may be purchased on a single day. The NCIB commenced on May 16, 2025 and will expire on the earlier of May 15, 2026, the date on which Pembina has acquired the maximum number of common shares allowable under the NCIB or the date on which Pembina otherwise decides not to make any further repurchases under the NCIB. No common shares were purchased by Pembina during the three and nine months ended September 30, 2025.
Preferred Share Capital
| ($ millions, except as noted) | Number of Preferred Shares (millions) | Preferred Share Capital | ||||||
| Balance at December 31, 2024 | 93 | 2,164 | ||||||
| Class A, Series 22 Preferred Shares redeemed | (1) | — | ||||||
| Class A, Series 19 Preferred Shares redeemed | (8) | (200) | ||||||
| Part VI.1 tax | — | (8) | ||||||
| Balance at September 30, 2025 | 84 | 1,956 | ||||||
On January 8, 2025, Pembina redeemed all of the approximately one million issued and outstanding Cumulative Redeemable Floating Rate Class A Preferred Shares, Series 22 ("Series 22 Class A Preferred Shares") at a redemption price of $25.50 per Series 22 Class A Preferred Share, plus all accrued and unpaid dividends thereon. Pembina had announced its intention to redeem the Series 22 Class A Preferred Shares during the fourth quarter of 2024 and, as a result, the equity was reclassified as a financial liability of approximately $26 million for the total redemption price in that same quarter.
56 Pembina Pipeline Corporation Third Quarter 2025
On June 30, 2025, Pembina redeemed all of the eight million issued and outstanding Series 19 Class A Preferred Shares at a redemption price of $25.00 per Series 19 Class A Preferred Share. The total redemption price for the Series 19 Class A Preferred Shares was $200 million.
On July 28, 2025, in connection with the Note Exchange, Pembina redeemed all of the 600,000 issued and outstanding Series 2021-A Class A Preferred Shares, which were deliverable to holders of the Series 1 Subordinated Notes following the occurrence of certain bankruptcy and related events. The Series 2021-A Class A Preferred Shares were issued by Pembina to Computershare Trust Company of Canada to be held in trust to satisfy its obligations under the indenture governing the Series 1 Subordinated Notes.
Subsequent to the end of the third quarter, on October 10, 2025, in connection with the closing of the offering of the Series 2 Subordinated Notes, Pembina announced its intention to use the net proceeds to fund the redemption of all of its outstanding Series 9 Class A Preferred Shares on December 1, 2025 at a price equal to $25.00 per Series 9 Class A Preferred Share. The total redemption price for the Series 9 Class A Preferred Shares will be $225 million.
Dividends
The following dividends were declared and paid by Pembina:
| 9 Months Ended September 30 | ||||||||
| ($ millions) | 2025 | 2024 | ||||||
| Common shares | ||||||||
| Common share | 1,226 | 1,168 | ||||||
| Class A preferred shares | ||||||||
| Series 1 Class A Preferred Share | 12 | 12 | ||||||
| Series 3 Class A Preferred Share | 7 | 6 | ||||||
| Series 5 Class A Preferred Share | 13 | 10 | ||||||
| Series 7 Class A Preferred Share | 11 | 8 | ||||||
| Series 9 Class A Preferred Share | 7 | 7 | ||||||
| Series 15 Class A Preferred Share | 9 | 9 | ||||||
| Series 17 Class A Preferred Share | 8 | 7 | ||||||
| Series 19 Class A Preferred Share | 5 | 7 | ||||||
| Series 21 Class A Preferred Share | 18 | 18 | ||||||
| Series 22 Class A Preferred Share | — | 2 | ||||||
| Series 25 Class A Preferred Share | 12 | 12 | ||||||
| 102 | 98 | |||||||
On November 6, 2025, Pembina announced that its Board of Directors had declared a common share cash dividend for the fourth quarter of 2025 of $0.71 per share to be paid on December 31, 2025, to shareholders of record on December 15, 2025.
Pembina's Board of Directors also declared quarterly dividends for Pembina's Class A preferred shares on October 8, 2025 as outlined in the following table:
| Series | Record Date | Payable Date | Dividend Amount ($ millions) | ||||||||
| Series 1, 3, 5, 7, 9 and 21 | November 3, 2025 | December 1, 2025 | 23 | ||||||||
| Series 15 and 17 | December 15, 2025 | December 31, 2025 | 5 | ||||||||
| Series 25 | October 31, 2025 | November 17, 2025 | 4 | ||||||||
| 32 | |||||||||||
Pembina Pipeline Corporation Third Quarter 2025 57
11. REVENUE
Revenue has been disaggregated into categories to reflect how the nature, timing and uncertainty of revenue and cash flows are affected by economic factors.
a.Revenue Disaggregation
| 2025 | 2024 | |||||||||||||||||||||||||||||||
| 3 Months Ended September 30 | Pipelines | Facilities | Marketing & New Ventures | Corporate | Total | Pipelines | Facilities | Marketing & New Ventures | Corporate | Total | ||||||||||||||||||||||
| ($ millions) | ||||||||||||||||||||||||||||||||
Take-or-pay(1) | 632 | 55 | 2 | — | 689 | 634 | 44 | 3 | — | 681 | ||||||||||||||||||||||
Fee-for-service(1) | 141 | 16 | 38 | — | 195 | 121 | 21 | 37 | — | 179 | ||||||||||||||||||||||
Product sales(2) | 1 | — | 776 | — | 777 | — | — | 804 | — | 804 | ||||||||||||||||||||||
| Revenue from contracts with customers | 774 | 71 | 816 | — | 1,661 | 755 | 65 | 844 | — | 1,664 | ||||||||||||||||||||||
| Realized gain from derivative instruments | — | — | 39 | — | 39 | — | — | 70 | — | 70 | ||||||||||||||||||||||
| Unrealized gain from derivative instruments | — | — | 1 | — | 1 | — | — | 18 | — | 18 | ||||||||||||||||||||||
Revenue from risk management and physical derivative contracts | — | — | 40 | — | 40 | — | — | 88 | — | 88 | ||||||||||||||||||||||
| Lease income | 45 | 12 | 1 | — | 58 | 54 | 14 | 3 | — | 71 | ||||||||||||||||||||||
Shared service revenue(3) and other | 10 | 5 | 4 | 13 | 32 | 1 | 7 | 2 | 11 | 21 | ||||||||||||||||||||||
| Total external revenue | 829 | 88 | 861 | 13 | 1,791 | 810 | 86 | 937 | 11 | 1,844 | ||||||||||||||||||||||
| 2025 | 2024 | |||||||||||||||||||||||||||||||||||||
| 9 Months Ended September 30 | Pipelines | Facilities | Marketing & New Ventures | Corporate | Total | Pipelines | Facilities | Marketing & New Ventures | Corporate | Total | ||||||||||||||||||||||||||||
($ millions) | ||||||||||||||||||||||||||||||||||||||
Take-or-pay(1) | 1,905 | 154 | 12 | — | 2,071 | 1,723 | 155 | 3 | — | 1,881 | ||||||||||||||||||||||||||||
Fee-for-service(1) | 418 | 56 | 107 | — | 581 | 382 | 56 | 94 | — | 532 | ||||||||||||||||||||||||||||
Product sales(2) | 6 | — | 2,802 | — | 2,808 | — | — | 2,497 | — | 2,497 | ||||||||||||||||||||||||||||
| Revenue from contracts with customers | 2,329 | 210 | 2,921 | — | 5,460 | 2,105 | 211 | 2,594 | — | 4,910 | ||||||||||||||||||||||||||||
| Realized gain from derivative instruments | — | — | 98 | — | 98 | — | — | 189 | — | 189 | ||||||||||||||||||||||||||||
| Unrealized gain (loss) from derivative instruments | — | — | 41 | — | 41 | — | — | (129) | — | (129) | ||||||||||||||||||||||||||||
Revenue from risk management and physical derivative contracts | — | — | 139 | — | 139 | — | — | 60 | — | 60 | ||||||||||||||||||||||||||||
| Lease income | 140 | 32 | 4 | — | 176 | 170 | 29 | 3 | — | 202 | ||||||||||||||||||||||||||||
Shared service revenue(3) and other | 27 | 18 | 10 | 35 | 90 | 10 | 19 | 4 | 34 | 67 | ||||||||||||||||||||||||||||
| Total external revenue | 2,496 | 260 | 3,074 | 35 | 5,865 | 2,285 | 259 | 2,661 | 34 | 5,239 | ||||||||||||||||||||||||||||
(1) Revenue recognized over time.
(2) Revenue recognized at a point in time.
(3) Includes $13 million for the three months ended September 30, 2025 (2024: $14 million) and $41 million for the nine months ended September 30, 2025 (2024: $44 million) of fixed fee income related to shared service agreements with joint ventures.
58 Pembina Pipeline Corporation Third Quarter 2025
b.Contract Liabilities
Significant changes in the contract liabilities balances during the period are as follows:
| 9 Months Ended September 30, 2025 | 12 Months Ended December 31, 2024 | |||||||||||||||||||
($ millions) | Take-or-Pay | Other Contract Liabilities | Total Contract Liabilities | Take-or-Pay | Other Contract Liabilities | Total Contract Liabilities | ||||||||||||||
| Opening balance | 1 | 297 | 298 | 1 | 158 | 159 | ||||||||||||||
| Additions (net in the period) | 5 | 26 | 31 | — | 49 | 49 | ||||||||||||||
| Alliance/Aux Sable Acquisition | — | — | — | — | 144 | 144 | ||||||||||||||
Revenue recognized from contract liabilities(1) | — | (37) | (37) | — | (44) | (44) | ||||||||||||||
Transfers to trade payables and other(3) | — | (101) | (101) | — | — | — | ||||||||||||||
| Disposition | — | — | — | — | (10) | (10) | ||||||||||||||
Closing balance | 6 | 185 | 191 | 1 | 297 | 298 | ||||||||||||||
Less current portion(2) | (6) | (41) | (47) | (1) | (42) | (43) | ||||||||||||||
| Ending balance | — | 144 | 144 | — | 255 | 255 | ||||||||||||||
(1) Recognition of revenue related to performance obligations satisfied in the period that were included in the opening balance of contract liabilities.
(2) Represents cash collected under take-or-pay contracts which will be recognized within one year as the customer chooses to ship, process, or otherwise forego the associated service.
(3) Represents a refundable liability following the CER Settlement on Alliance.
Contract liabilities depict Pembina's obligation to perform services in the future for cash and non-cash consideration which have been received from customers. Contract liabilities include up-front payments or non-cash consideration received from customers for future transportation, gas processing, terminalling, storage services, and construction. Contract liabilities also include consideration received from customers for take-or-pay commitments where the customer has a make-up right to ship or process future volumes under a firm contract. These amounts are non-refundable should the customer not use its make-up rights. In all instances where goods or services have been transferred to a customer in advance of the receipt of customer consideration, Pembina's right to consideration is unconditional and has therefore been presented as a receivable.
12. NET FINANCE COSTS
| 3 Months Ended September 30 | 9 Months Ended September 30 | |||||||||||||
($ millions) | 2025 | 2024 | 2025 | 2024 | ||||||||||
| Interest expense on financial liabilities measured at amortized cost: | ||||||||||||||
| Loans and borrowings | 131 | 136 | 391 | 380 | ||||||||||
| Subordinated hybrid notes | 11 | 7 | 26 | 22 | ||||||||||
| Leases | 9 | 8 | 25 | 24 | ||||||||||
| Interest income | (4) | (7) | (8) | (45) | ||||||||||
| Unwinding of discount rate | 6 | 5 | 18 | 15 | ||||||||||
| Foreign exchange losses and other | — | — | 2 | 2 | ||||||||||
| Net finance costs | 153 | 149 | 454 | 398 | ||||||||||
Pembina Pipeline Corporation Third Quarter 2025 59
13. ACCUMULATED OTHER COMPREHENSIVE INCOME
| ($ millions) | Currency Translation Reserve | Cash Flow Hedge Reserve | Pension and other Post-Retirement Benefit Plan Adjustments(2) | Total | ||||||||||
| Balance at December 31, 2024 | 620 | 8 | 13 | 641 | ||||||||||
| Other comprehensive loss before hedging activities | (186) | — | — | (186) | ||||||||||
Other comprehensive gain (loss) resulting from hedging activities, net of tax(1) | 9 | (8) | — | 1 | ||||||||||
| Balance at September 30, 2025 | 443 | — | 13 | 456 | ||||||||||
(1) Amounts relate to hedges of the Company's net investment in foreign operations (reported in Currency Translation Reserve) and interest rate forward swaps (reported in Cash Flow Hedge Reserve) (Note 14), which expired on March 31, 2025. At September 30, 2025, the other comprehensive loss resulting from hedging activities for interest rate forward swaps includes a realized loss of $4 million that was reclassified to net finance costs (2024: $13 million realized gain).
(2) Pension and other Post-Retirement Benefit Plan Adjustments will not be reclassified into earnings.
14. FINANCIAL INSTRUMENTS & RISK MANAGEMENT
Fair Values
The fair value of financial instruments utilizes a variety of valuation inputs. When measuring fair value, Pembina uses observable market data to the greatest extent possible. Depending on the nature of these valuation inputs, financial instruments are categorized as follows:
a. Level 1
Level 1 fair values are based on inputs that are unadjusted observable quoted prices from active markets for identical assets or liabilities as at the measurement date.
b. Level 2
Level 2 fair values are based on inputs, other than quoted market prices included in Level 1, that are either directly or indirectly observable. Level 2 fair value inputs include quoted forward market prices, time value, and broker quotes that are observable for the duration of the financial instrument's contractual term. These inputs are often adjusted for factors specific to the asset or liability, such as, location differentials and credit risk.
Financial instruments that utilize Level 2 fair valuation inputs include derivatives arising from physical commodity forward contracts, commodity swaps and options, and forward interest rate and foreign-exchange swaps. In addition, Pembina's loans and borrowings utilize Level 2 fair valuation inputs, whereby the valuation technique is based on discounted future interest and principal payments using the current market interest rates of instruments with similar terms.
c. Level 3
Level 3 fair values utilize inputs that are not based on observable market data. Rather, various valuation techniques are used to develop inputs.
Financial instruments that utilize Level 3 fair valuation inputs include embedded derivative instruments arising from long-term power purchase agreements. The fair value of long-term power purchase agreements is measured using a pricing and cash flow model that accounts for forward power prices, renewable wind power pricing discounts and differentials, and inflationary metrics. The rate used to discount the respective estimated cash flows is a government risk-free interest rate that is adjusted for an appropriate credit spread. The fair valuation of the embedded derivative instruments is judged to be a significant management estimate. These assumptions and inputs are susceptible to change and may differ from actual future developments. This estimation uncertainty could materially impact the quantified fair value; and therefore, the gains and losses on commodity-related derivative financial instruments.
60 Pembina Pipeline Corporation Third Quarter 2025
The carrying values of financial assets and liabilities in relation to their respective fair values, together with their appropriate fair value categorization are illustrated in the table below. Certain other non-derivative financial instruments measured at amortized cost, including cash and cash equivalents, trade receivables and other, trade payables and other, and other liabilities have been excluded since their carrying values are judged to approximate their fair values due to their nature and short maturity. These instruments would be categorized as Level 2 in the fair value hierarchy.
| September 30, 2025 | December 31, 2024 | ||||||||||||||||||||||||||||
| Carrying Value | Fair Value | Carrying Value | Fair Value | ||||||||||||||||||||||||||
| ($ millions) | Level 1 | Level 2 | Level 3 | Level 1 | Level 2 | Level 3 | |||||||||||||||||||||||
Financial assets carried at fair value | |||||||||||||||||||||||||||||
Derivative financial instruments(1) | 15 | — | 15 | — | 13 | — | 13 | — | |||||||||||||||||||||
Financial liabilities carried at fair value | |||||||||||||||||||||||||||||
Derivative financial instruments(1) | 125 | — | 11 | 114 | 159 | — | 42 | 117 | |||||||||||||||||||||
Financial liabilities carried at amortized cost | |||||||||||||||||||||||||||||
Long-term debt(2) | 12,633 | — | 12,648 | — | 12,656 | — | 12,649 | — | |||||||||||||||||||||
(1) At September 30, 2025, all derivative financial instruments are carried at fair value through earnings. At December 31, 2024, all derivative financial instruments are carried at fair value through earnings, except for $5 million in interest rate derivative financial assets that were designated as cash flow hedges and expired on March 31, 2025.
(2) Carrying value of current and non-current balances. Includes loans and borrowings and subordinated notes.
Changes in fair value of the derivative net liabilities classified as Level 3 in the fair value hierarchy were as follows:
| ($ millions) | 2025 | |||||||
| Level 3 derivative net liability at January 1 | (117) | |||||||
Gain included in revenue from risk management and physical derivative contracts | 3 | |||||||
Level 3 derivative liability at September 30 | (114) | |||||||
There were no transfers into or out of Level 3 during the nine months ended September 30, 2025.
Gains and Losses from Derivative Instruments
| 3 Months Ended September 30 | 9 Months Ended September 30 | |||||||||||||
| ($ millions) | 2025 | 2024 | 2025 | 2024 | ||||||||||
| Derivative instruments held at fair value through earnings | ||||||||||||||
| Realized gain | ||||||||||||||
Commodity-related gain recorded in revenue from risk management and physical derivative contracts | (39) | (70) | (98) | (189) | ||||||||||
| Unrealized (gain) loss | ||||||||||||||
Commodity-related (gain) loss recorded in revenue from risk management and physical derivative contracts | (1) | (18) | (41) | 129 | ||||||||||
| Derivative instruments in hedging relationships | ||||||||||||||
Interest rate loss recorded in other comprehensive income(1) | — | 6 | 4 | 8 | ||||||||||
(1) Unrealized losses or gains for designated cash flow hedges are recognized in impact of hedging activities in the Consolidated Statements of Earnings and Comprehensive Income, with realized losses or gains being reclassified to net finance costs. The movement in other comprehensive income relates to realized losses or gains on interest rate forward swaps, which expired on March 31, 2025. A gain of $4 million was recognized during the first quarter of 2025, prior to the expiration date that was reclassified to net finance costs (three and nine month ended September 30, 2024: $4 million and $13 million realized gain, respectively). No losses or gains have been recognized in net income relating to discontinued cash flow hedges.
Pembina Pipeline Corporation Third Quarter 2025 61
15. RELATED PARTIES
Pembina enters into transactions with related parties in the normal course of business and all transactions are measured at their exchange amount, unless otherwise noted. Pembina provides management and operational oversight services, on a fixed fee and cost recovery basis, to certain equity accounted investees. Pembina also contracts for services and capacity from certain of its equity accounted investees, advances funds to support operations and provides letters of credit, including financial guarantees.
A summary of the significant related party transactions and balances are as follows:
3 Months Ended September 30 | 9 Months Ended September 30 | |||||||||||||
| ($ millions) | 2025 | 2024 | 2025 | 2024 | ||||||||||
| PGI | 58 | 43 | 179 | 175 | ||||||||||
| Cedar LNG | 5 | 12 | 14 | 18 | ||||||||||
Aux Sable(1) | — | — | — | 32 | ||||||||||
Alliance(1) | — | — | — | 4 | ||||||||||
Other(2) | — | — | — | 2 | ||||||||||
Total services provided(3) | 63 | 55 | 193 | 231 | ||||||||||
| PGI | 2 | 2 | 6 | 6 | ||||||||||
Alliance(1) | — | — | — | 3 | ||||||||||
| Total services received | 2 | 2 | 6 | 9 | ||||||||||
As at ($ millions) | September 30, 2025 | December 31, 2024 | ||||||||||||
Trade receivables and other(4) | 35 | 37 | ||||||||||||
Right-of-use assets(5) | 33 | — | ||||||||||||
Lease liabilities(5) | 33 | — | ||||||||||||
(1) As of April 1, 2024, following the completion of Pembina's acquisition of a controlling interest in Alliance and Aux Sable, these entities became consolidated subsidiaries of Pembina and, as such, are no longer related parties.
(2) Other includes transactions with Grand Valley, ACG, and Greenlight.
(3) Services provided by Pembina include payments made by Pembina on behalf of related parties.
(4) As at September 30, 2025, trade receivables and other includes $30 million due from PGI (December 31, 2024: $34 million), and $5 million due from Cedar LNG (December 31, 2024: $2 million).
(5) As at September 30, 2025, Pembina had a lease arrangement with PGI for the use of a natural gas storage asset. Under the terms of the agreement, Pembina recognized a right-of-use asset and a corresponding lease liability. The lease commenced on September 1, 2025 and has a term of 15.2 years. Lease payments are made on a monthly basis and are structured as a combination of a fixed fee and flow-through charges.
62 Pembina Pipeline Corporation Third Quarter 2025
16. COMMITMENTS AND CONTINGENCIES
Commitments
Pembina was committed for the following amounts under its contracts and arrangements as at September 30, 2025:
Contractual Obligations(1) | Payments Due by Period | ||||||||||||||||
| ($ millions) | Total | Less than 1 year | 1 – 3 years | 3 – 5 years | After 5 years | ||||||||||||
Transportation and processing(2) | 11,270 | 46 | 165 | 1,091 | 9,968 | ||||||||||||
Construction commitments(3) | 438 | 295 | 113 | 30 | — | ||||||||||||
Other commitments related to lease contracts(4) | 613 | 45 | 98 | 161 | 309 | ||||||||||||
Funding commitments, software, and other | 125 | 100 | 24 | 1 | — | ||||||||||||
Total contractual obligations | 12,446 | 486 | 400 | 1,283 | 10,277 | ||||||||||||
(1)Pembina enters into product purchase agreements and power purchase agreements to secure supply for future operations. Purchase prices of both NGL and power are dependent on current market prices. Volumes and prices for NGL and power contracts cannot be reasonably determined, and therefore, an amount has not been included in the contractual obligations schedule. Product purchase agreements range from one to 16 years and involve the purchase of NGL products from producers. Assuming product is available, Pembina has secured between 25 and 197 mbpd of NGL each year up to and including 2040. Power purchase agreements range from one to 25 years and involve the purchase of power from electrical service providers. Pembina has secured up to 76 megawatts per day each year up to and including 2049.
(2)Pembina signed two transportation and processing related agreements relating to the Cedar LNG Project: (a) Liquefaction Tolling Services Agreement ("LTSA"); and, (b) Gas Supply Agreement ("GSA"). The LTSA is a 20-year take-or-pay fixed toll contract for 1.5 million tonnes per annum, while the GSA will allow for transport on the Coastal GasLink Pipeline of approximately 200 million cubic feet per day of Canadian natural gas to Cedar LNG. These commercial agreements account for approximately 50 percent of the operating capacity for the Cedar LNG Project and a total commitment of approximately $10.5 billion. These commitments are expected to commence upon the anticipated in-service date of the Cedar LNG Project in late 2028.
(3)Excludes projects that are executed by equity accounted investees.
(4)Relates to expected variable lease payments excluded from the measurement of the lease liability, payments under lease contracts which have not yet commenced, and payments related to non-lease components in lessee lease contracts.
Commitments to Equity Accounted Investees
Pembina has commitments to provide contributions to certain equity accounted investees based on its ownership interest. These contributions are determined and approved by the joint venture partners to fund operating budgets, growth capital, and significant projects development costs, including the Cedar LNG Project and Greenlight.
Contingencies
Pembina, including its subsidiaries and its investments in equity accounted investees, are subject to various legal and regulatory and tax proceedings, actions and audits arising in the normal course of business. Pembina represents its interests vigorously in all proceedings in which it is involved. Legal and administrative proceedings involving possible losses are inherently complex, and the Company applies significant judgment in estimating probable outcomes. As at September 30, 2025, there were no significant claims filed against Pembina for which management believes the resolution of any such actions or proceedings would have a material impact on Pembina's financial position or results of operations.
Letters of Credit
Pembina has provided letters of credit to various third parties in the normal course of conducting business. The letters of credit include financial guarantees to counterparties for product purchases and sales, transportation services, utilities, engineering and construction services. The letters of credit have not had and are not expected to have a material impact on Pembina's financial position, earnings, liquidity or capital resources. As at September 30, 2025, Pembina had $121 million (December 31, 2024: $209 million) in letters of credit issued.
Pembina Pipeline Corporation Third Quarter 2025 63
HEAD OFFICE Pembina Pipeline Corporation Suite 4000, 585 - 8th Avenue SW Calgary, Alberta T2P 1G1 AUDITORS KPMG LLP Chartered Professional Accountants Calgary, Alberta TRUSTEE, REGISTRAR & TRANSFER AGENT Computershare Trust Company of Canada Suite 600, 530 - 8th Avenue SW Calgary, Alberta T2P 3S8 1.800.564.6253 STOCK EXCHANGE Pembina Pipeline Corporation Toronto Stock Exchange listing symbols for: COMMON SHARES PPL PREFERRED SHARES PPL.PR.A, PPL.PR.C, PPL.PR.E, PPL.PR.G, PPL.PR.I, PPL.PR.O, PPL.PR.Q, PPL.PF.A and PPL.PF.E New York Stock Exchange listing symbol for: COMMON SHARES PBA INVESTOR INQUIRIES PHONE 403.231.3156 FAX 403.237.0254 TOLL FREE 1.855.880.7404 EMAIL investor-relations@pembina.com WEBSITE www.pembina.com | |||||
FORM 52-109F2
CERTIFICATION OF INTERIM FILINGS
FULL CERTIFICATE
I, J. Scott Burrows, President and Chief Executive Officer of Pembina Pipeline Corporation, certify the following:
1. Review: I have reviewed the interim financial report and interim MD&A (together, the "interim filings") of Pembina Pipeline Corporation (the "issuer") for the interim period ended September 30, 2025.
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 issued by the Committee of Sponsoring Organizations of the Treadway Commission.
5.2 N/A
5.3 N/A
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 July 1, 2025 and ended on September 30, 2025 that has materially affected, or is reasonably likely to materially affect, the issuer's ICFR.
Date: November 6, 2025
/s/ "J. Scott Burrows" | |||||
J. Scott Burrows | |||||
President and Chief Executive Officer | |||||
of Pembina Pipeline Corporation | |||||
FORM 52-109F2
CERTIFICATION OF INTERIM FILINGS
FULL CERTIFICATE
I, Cameron J. Goldade, Senior Vice President & Chief Financial Officer of Pembina Pipeline Corporation, certify the following:
1. Review: I have reviewed the interim financial report and interim MD&A (together, the "interim filings") of Pembina Pipeline Corporation (the "issuer") for the interim period ended September 30, 2025.
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 issued by the Committee of Sponsoring Organizations of the Treadway Commission.
5.2 N/A
5.3 N/A
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 July 1, 2025 and ended on September 30, 2025 that has materially affected, or is reasonably likely to materially affect, the issuer's ICFR.
Date: November 6, 2025
/s/ "Cameron J. Goldade" | |||||
| Cameron J. Goldade | |||||
Senior Vice President & Chief Financial Officer | |||||
of Pembina Pipeline Corporation | |||||