Q3 2026 Financial Statements

(in millions of Canadian dollars except where noted)

Unaudited 2026 2025 2026 2025

See accompanying notes.

(in millions of Canadian dollars)

3 months ended Sept. 30 9 months ended Sept. 30

1. Net of income tax expense of $2 million and $4 million for the three and nine months ended Sept. 30, 2026 (Sept. 30, 2025 - nil and $1 million expense for the three and nine months).

2. Net of income tax recovery of nil and $1 million for the three and nine months ended Sept. 30, 2026 (Sept. 30, 2025 - $1 million recovery and $1 million expense for the three and nine months).

3. Net of income tax expense of $8 million and $11 million for the three and nine months ended Sept. 30, 2026 (Sept. 30, 2025 - $8 million and $2 million expense for the three and nine months).

4. Net of reclassification of income tax expense of $1 million and nil for the three and nine months ended Sept. 30, 2026 (Sept. 30, 2025 - nil and $10 million recovery for the three and nine months).

See accompanying notes.

(in millions of Canadian dollars) (Unaudited)

As at Sept. 30, 2026 Dec. 31, 2025

Commitments and contingencies (Note 15) Subsequent events (Note 18)

See accompanying notes.

(in millions of Canadian dollars)

Attributable

(in millions of Canadian dollars)

3 months ended Sept. 30 9 months ended Sept. 30

Unaudited 2026 2025 2026 2025

See accompanying notes.

(Tabular amounts in millions of Canadian dollars, except as otherwise noted)

1. ‌Corporate Information
   1. Description of the Business

      TransAlta Corporation (TransAlta or the Company) was incorporated under the Canada Business Corporations Act in March 1985 and became a public company in December 1992. The Company's head office is located in Calgary, Alberta.

   2. Basis of Preparation

      These unaudited interim condensed consolidated financial statements have been prepared in compliance with International Financial Reporting Standard (IFRS) and International Accounting Standard (IAS) 34 Interim Financial Reporting using the same accounting policies as those used in the Company's most recent audited annual consolidated financial statements, except as described in Note 2. These unaudited interim condensed consolidated financial statements do not include all of the disclosures included in the Company's audited annual consolidated financial statements. Accordingly, they should be read in conjunction with the Company's most recent audited annual consolidated financial statements which are available on SEDAR+ at https://www.sedarplus.ca and on EDGAR at https://www.sec.gov.

      The unaudited interim condensed consolidated financial statements include the accounts of the Company and the subsidiaries that it controls.

      The unaudited interim condensed consolidated financial statements have been prepared on a historical cost basis except for certain financial instruments, which are stated at fair value.

      These unaudited interim condensed consolidated financial statements reflect all adjustments which consist of normal recurring adjustments and accruals that are, in the opinion of management, necessary for a fair presentation of results. Interim results will fluctuate due to plant maintenance schedules, the seasonal demands for electricity and changes in energy prices. Consequently, interim condensed results are not necessarily indicative of annual results. TransAlta's results are partly seasonal due to the nature of the electricity market and related fuel costs.

      These unaudited interim condensed consolidated financial statements were authorized for issue by the Audit, Finance and Risk Committee on behalf of TransAlta's Board of Directors (the Board) on Nov. 2, 2026.

   3. Significant Accounting Judgments and Key Sources of Estimation Uncertainty

      The preparation of these unaudited interim condensed consolidated financial statements in accordance with IAS 34 requires management to use judgment and make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and disclosures of contingent assets and liabilities. These estimates are subject to uncertainty. Actual results could differ from these estimates due to factors such as fluctuations in interest rates, foreign exchange rates, inflation and commodity prices, and changes in economic conditions, legislation and regulations.

      In the process of applying the Company's accounting policies, management has to make judgments and estimates about matters that are highly uncertain at the time the estimates are made and that could significantly affect the amounts recognized in the unaudited interim condensed consolidated financial statements. Different estimates with respect to key variables used in the calculations, or changes to estimates, could potentially have a material impact on the Company's financial position or performance.

      During the three months ended Sept. 30, 2026, for the purposes of the 2026 goodwill impairment review, the Company determined the recoverable amounts of Wind and Solar, and Gas segments by calculating the fair value less costs of disposal using discounted cash flow projections. In 2026, the Company relied on the recoverable amounts determined in 2025 for the Hydro and Energy Marketing segments in performing the 2026 goodwill impairment review. The recoverable amounts are based on the Company's long-range forecasts for the periods extending to the last planned asset retirement in 2086. The resulting fair value measurements are categorized within Level III of the fair value hierarchy. No impairment of goodwill arose for any segment.

      During three and nine months ended Sept. 30, 2026, there were no significant changes in estimates, however, significant estimation uncertainty and judgment is applied in determining the recoverable amount of the Wind and Solar, and Gas segments, due to the sensitivity of the significant assumptions to the future cash flows and the effect that changes in these assumptions would have on the recoverable amount.

      Refer to Note 2(Q) of the Company's 2025 audited annual consolidated financial statements for further details on the significant accounting judgments and key sources of estimation uncertainty.

      Business Combinations

      The fair value of assets acquired and liabilities assumed in a business combination, is estimated based on information

2. ‌Accounting Changes

   The accounting policies adopted in the preparation of the unaudited interim condensed consolidated financial statements are consistent with those followed in the preparation of the Company's annual consolidated financial statements for the year ended Dec. 31, 2025, except for the adoption of new standards effective as of Jan. 1, 2026.

   1. Current Accounting Changes Amendments to IFRS 9 and IFRS 7 - Nature-Dependent Electricity Contracts

      On Dec. 18, 2024, the IASB issued amendments to IFRS 9 Financial Instruments and IFRS 7 Financial Instruments: Disclosure to improve reporting of the financial effects of nature-dependent electricity (e.g., wind and solar) contracts, which are often structured as power purchase agreements. Under these contracts, the amount of electricity generated can vary based on uncontrollable factors such as weather conditions.

      The amendments clarify the application of own-use requirements, permit hedge accounting if these contracts are used as hedging instruments and add new disclosure requirements about the effect of these contracts on a company's financial performance and cash flows. Specifically, the amendments will now allow for hedge accounting to be applied in instances where there is variability in the underlying amount of electricity because the source of electricity generation depends on uncontrollable natural conditions.

      The amendments are effective for annual reporting periods beginning on or after Jan. 1, 2026.

      available at the date of acquisition. While management uses best estimates and assumptions to accurately value assets acquired and liabilities assumed at the date of acquisition, estimates are inherently uncertain and subject to refinement.

      Accounting for business combinations requires significant judgment, estimates and assumptions at the acquisition date. In developing estimates of fair values at the acquisition date, management uses a variety of factors including market data, market prices, capacity, historical and future expected cash flows, growth rates and discount rates. Information regarding a business combination that occurred during the nine months ended Sept. 30, 2026 has been included in Note 3.

      In accordance with the permitted transitional provisions, effective Jan. 1, 2026, the Company has prospectively designated certain pre-existing Virtual Power Purchase Agreements (VPPAs) within the Wind and Solar segment as held for hedging and has applied hedge accounting. As a result, the effective portion of changes in the fair value of these hedging derivatives, arising on or after Jan. 1, 2026, will be recognised in OCI while any ineffective portion will be recognized in net earnings. The transitional provisions did not permit retrospective designation. Refer to Note 9 Risk Management for details.

      Amendments to IFRS 7 and IFRS 9 - Classification and Measurement of Financial Instruments

      On May 29, 2024, the IASB issued Amendments to the Classification and Measurement of Financial Instruments effective Jan. 1, 2026 impacting IFRS 7 and 9. The amendments clarified the date of recognition and derecognition of financial assets and liabilities, including an exception for certain financial liabilities settled through an electronic payment system. The amendments also clarified the requirements for assessing contractual cash flow characteristics of financial assets, including those with ESG-linked features. The amendments did not have a material impact on the consolidated financial statements.

   2. Future Accounting Changes

      The Company closely monitors both new accounting standards and amendments to existing accounting standards issued by the IASB. The following standard has been issued but is not yet in effect.

      IFRS 18 - Presentation and Disclosure in Financial Statements

      On April 9, 2024, the IASB issued a new standard, IFRS 18 Presentation and Disclosure in Financial Statements, which introduced new requirements for improved comparability in the statement of profit or loss, enhanced transparency of management-defined performance measures and more useful grouping of information in the financial statements. The standard is effective for annual reporting periods beginning on or after Jan. 1, 2027. The Company is currently preparing for the adoption of IFRS 18 and is advanced in its assessment of the impact of the new standard.

      The Company assessed whether it has a specified main business activity of investing in particular types of assets or providing of financing to customers and concluded that it does not. The application will mainly result in presentation changes to the Consolidated Statements of Earnings and Consolidated Statements of Cash Flows, together with expanded note disclosures. The Consolidated Statements of Earnings (Loss) will incorporate the new operating, investing and financing categories and the required subtotals of operating income and earnings before financing and income taxes. Certain income and expenses will also be reclassified, including foreign exchange gains and losses based on the classification of the underlying item, discount-rate changes on decommissioning provisions from operating to financing, and certain banking and credit-related fees from financing to operating. The Consolidated Statements

3. ‌Business Acquisitions Acquisition of Far North

   On Feb. 2, 2026, the Company acquired all issued and outstanding common shares of Far North Power Corporation (Far North) from an affiliate of Hut 8 Corp. (the Far North Acquisition). The Far North Acquisition, which includes Far North and its subsidiaries' entire business operations in Ontario consisting of four natural gas-fired generation facilities totaling 310 MW, was completed for an aggregate purchase price of $107 million including working capital adjustments of $12 million. The Far North Acquisition was funded through a combination of cash on hand and draws on the Company's credit facilities.

   The acquired tangible assets and assumed liabilities are recorded at their estimated fair values at the date of the Acquisition. The total consideration was allocated to the assets acquired and liabilities assumed, with any excess recorded to goodwill.

   of Cash Flows will use operating income, rather than net earnings, as the starting point. Interest paid will be classified as a financing activity, while interest received will be classified as an investing activity.

   Additional disclosures will be required for management-defined performance measures (MPMs), including an explanation of why each measure provides useful information, the method of calculation, the reconciliation of each MPM to the most directly comparable IFRS total or subtotal. Based on the assessment completed to date, the Company expects Adjusted Earnings Before Interest, Taxes, Depreciation, and Amortization (EBITDA), Adjusted Earnings (Loss) Before Income Taxes and Adjusted Net Earnings (Loss) Attributable to Common Shareholders to qualify as MPMs and to be included in the new MPM note.

   As at Sept. 30, 2026, the Company does not expect the application of IFRS 18 to significantly affect the amounts reported in its primary financial statements, with the identified impacts relating primarily to presentation and disclosure.

   C. Comparative Figures

   Certain comparative figures have been reclassified to conform to the current period's presentation. These reclassifications did not impact previously reported net earnings.

   Goodwill of $6 million recognized on the transaction is a result of net deferred tax liabilities recognized on the transaction, which are recorded at the Company's effective tax rate without discounting. None of the goodwill is expected to be deductible for tax purposes.

   The preliminary purchase price allocation reflects management's best estimate of the fair value of the acquired assets and liabilities based on the analysis of information obtained to date. Management is continuing to obtain specific information to support the valuation of the decommissioning provision, property, plant and equipment, and deferred taxes. Any adjustments to the purchase price allocation will be made as soon as practicable but no later than one year from the date of acquisition.

   The following table summarizes the preliminary fair values that were assigned to the net assets acquired as at the acquisition date.

   Feb. 2, 2026

   Current Assets and Non-Current Assets

   Cash and cash equivalents 1

   Trade and other receivables 9

   Prepaid expenses and other 6

   Inventory 2

   Property, plant and equipment 102

   Current Liabilities and Non-Current Liabilities Accounts payable and accrued liabilities	4
   Decommissioning provision non-current portion	9
   Deferred income tax liabilities	11
   Total identifiable net assets at fair value	101
   Goodwill arising on acquisition	6
   Net assets acquired	107
   Total purchase consideration transferred in cash	107

   Deferred income tax assets 5

   Revenue generated by the Far North Acquisition for the period Feb. 2, 2026 to Sept. 30, 2026 was $27 million. Net earnings before taxes for the same period was $4 million.

   Had Far North been acquired at the beginning of the year, the assets would have contributed $30 million to revenues and $2 million to net earnings before taxes on a proforma basis.

4. ‌Revenue Disaggregation of Revenue

   The majority of the Company's revenues are derived from the sale of power, capacity and environmental and tax attributes, and from asset optimization activities, which the

   Company disaggregates into the following groups to determine how economic factors affect the recognition of revenue.

   Reportable Segments(1)

   		Wind and		Energy		Energy
   3 months ended Sept. 30, 2026	Hydro	Solar	Gas	Marketing	Corporate(2)	Transition	Total

   Revenues from contracts with customers Power and other Environmental and tax attributes(3)	11 16	43 19	158 3	- -	- (15)	1 -	213 23
   Revenue from contracts with customers	27	62	161	-	(15)	1	236
   Revenue from derivatives and other trading activities(4)	11	23	59	31	-	-	124
   Revenue from merchant sales	55	21	92	-	-	-	168
   Other(5)	2	2	3	-	-	1	8
   Total revenue	95	108	315	31	(15)	2	536
   Revenues from contracts with customers
   Timing of revenue recognition
   At a point in time	16	19	3	-	(15)	1	24
   Over time	11	43	158	-	-	-	212
   Total revenue from contracts with customers	27	62	161	-	(15)	1	236

   Reportable Segments(1)

   3 months ended Sept. 30, 2025	Hydro	Wind and Solar	Gas	Energy Marketing	Corporate(2)	Energy Transition	Total
   Revenues from contracts with customers Power and other	15	40	134	-	(2)	4	191
   Environmental and tax attributes(3)	-	18	(4)	-	-	-	14
   Revenue from contracts with customers	15	58	130	-	(2)	4	205
   Revenue from derivatives and other trading activities(4)	23	(76)	88	37	2	78	152
   Revenue from merchant sales	47	15	102	-	-	76	240
   Other(5)	10	2	6	-	-	-	18
   Total revenue	95	(1)	326	37	-	158	615
   Revenues from contracts with customers Timing of revenue recognition At a point in time	-	6	(4)	-	-	4	6
   Over time	15	52	134	-	(2)	-	199
   Total revenue from contracts	15	58	130	-	(2)	4	205

   with customers

   1. Refer to Note 17 Segment disclosures for details.

   2. The elimination of intercompany sales is reflected in the Corporate segment with $15 million attributed to Hydro (Sept. 30, 2025 - nil), nil attributed to Wind and Solar (Sept. 30, 2025 -

      $2 million), and nil attributed to Energy Marketing (Sept. 30, 2025 - $(2) million).

   3. The environmental and tax attributes represent environmental attributes and production tax transfer sales not bundled with power and other sales.

   4. Represents realized and unrealized gains or losses from hedging and derivative positions. Volatility and pricing in commodity markets can vary significantly from period to period and impact movements in derivative positions. Effective Jan. 1, 2026, the Company applied hedge accounting to certain VPPAs within the Wind and Solar segment prospectively. Accordingly, the effective portion of unrealized gains or losses on the hedging instruments was recognized through OCI. Refer to Note 9 for details.

   5. Other revenue includes production tax credits related to U.S. wind facilities subject to tax equity financing arrangements, total lease income from long-term contracts that meet the criteria of operating leases and other miscellaneous revenues.

   Reportable Segments(1)

   		Wind and		Energy		Energy
   9 months ended Sept. 30, 2026	Hydro	Solar	Gas	Marketing	Corporate(2)	Transition	Total

   Revenues from contracts with customers Power and other Environmental and tax attributes(3)	31 44	170 82	479 9	4 2	- (61)	6 -	690 76
   Revenue from contracts with customers	75	252	488	6	(61)	6	766
   Revenue from derivatives and other trading activities(4)	32	19	216	91	1	-	359
   Revenue from merchant sales	137	54	244	-	-	-	435
   Other(5)	8	11	8		-	1	28
   Total revenue	252	336	956	97	(60)	7	1,588
   Revenues from contracts with customers
   Timing of revenue recognition
   At a point in time	44	82	9	2	(61)	6	82
   Over time	31	170	479	4	-	-	684
   Total revenue from contracts with customers	75	252	488	6	(61)	6	766

   Reportable Segments(1)

   Wind and

   Energy

   Energy

   9 months ended Sept. 30, 2025	Hydro	Solar	Gas	Marketing	Corporate(2)	Transition	Total
   Revenues from contracts with customers
   Power and other	33	184	494	9	-	9	729
   Environmental and tax attributes(3)	70	83	7	-	(68)	-	92
   Revenue from contracts with customers	103	267	501	9	(68)	9	821
   Revenue from derivatives and other trading activities(4)	29	(171)	124	93	2	197	274
   Revenue from merchant sales	163	48	282	-	-	178	671
   Other(5)	15	11	13	-	-	1	40
   Total revenue	310	155	920	102	(66)	385	1,806
   Revenues from contracts with customers
   Timing of revenue recognition
   At a point in time	70	38	7	-	(68)	9	56
   Over time	33	229	494	9	-	-	765
   Total revenue from contracts with customers	103	267	501	9	(68)	9	821

   1. Refer to Note 17 Segment disclosures for details.

   2. The elimination of intercompany sales is reflected in the Corporate segment with $40 million attributed to Hydro (Sept. 30, 2025 - $52 million), $18 million attributed to Wind and Solar (Sept. 30, 2025 - $18 million), and $2 million attributed to Energy Marketing (Sept. 30, 2025 - $(4) million).

   3. The environmental and tax attributes represent environmental attributes and production tax transfer sales not bundled with power and other sales.

   4. Represents realized and unrealized gains or losses from hedging and derivative positions. Volatility and pricing in commodity markets can vary significantly from period to period and impact movements in derivative positions. Effective Jan. 1, 2026, the Company applied hedge accounting to certain VPPAs within the Wind and Solar segment prospectively. Accordingly, the effective portion of unrealized gains or losses on the hedging instruments was recognized through OCI. Refer to Note 9 for details.

   5. Other revenue includes production tax credits related to U.S. wind facilities subject to tax equity financing arrangements, total lease income from long-term contracts that meet the criteria of operating leases and other miscellaneous revenues.

5. ‌Expenses by Nature Fuel, Purchased Power and Operations, Maintenance and Administration (OM&A)

   Fuel and purchased power and OM&A expenses classified by nature are as follows:

   3 months ended Sept. 30 9 months ended Sept. 30

   2026 2025 2026 2025

   Fuel and purchased

   power OM&A

   Fuel and purchased

   power OM&A

   Fuel and purchased

   power OM&A

   Fuel and purchased

   power OM&A

   Gas fuel costs	116 -	91	-
   Coal fuel costs	- -	42	-
   Royalty, land lease, other direct costs	(3) -	6	-
   Purchased power	23 -	88	-
   Salaries and benefits	- 70	-	81
   Other operating expenses(1)	- 104	-	98
   Total	136 174	227	179

   330	-	321	-
   -	-	96	-
   15	-	22	-
   62	-	238	-
   -	257	-	234
   -	273	-	291
   407	530	677	525

   (1) Other operating expenses include contracted manpower, materials, insurance, office costs and other administrative and overhead costs.

   Carbon Compliance (Recovery) Costs

   As at Sept. 30, 2026, the Company holds 692,907 emission credits in inventory that were purchased externally with a recorded book value of $26 million (Dec. 31, 2025 - 383,192 emission credits with a recorded book value of $14 million). The Company also has 1,792,975 (Dec. 31, 2025 - 1,860,384) of internally generated eligible emission credits, including credits pending serialization by the issuing authority, from the Company's Wind and Solar and Hydro segments which have no recorded book value.

   Emission credits can be sold externally or can be used to offset future emission obligations from our gas facilities located in Alberta. The compliance price of carbon for 2025 and 2026 obligation was $95 per tonne in Alberta.

   During the three and nine months ended Sept. 30, 2026, the Company reduced its 2026 carbon compliance obligation by

   $51 million through the planned utilization of 606,367 emission credits, which also decreased accounts payable and accrued liabilities as at Sept. 30, 2026.

   During the nine months ended Sept. 30, 2026, the Company utilized 924,899 emission credits (Sept. 30, 2025 -1,498,447 emission credits) with a carrying value of $9 million (Sept. 30, 2025 - $17 million), to settle a portion of the 2025 carbon compliance obligation (Sept. 30, 2025 -2024 carbon compliance obligation). During the nine months ended Sept. 30, 2026, $78 million (Sept. 30, 2025 - $103 million) was recognized as a reduction in the Company's carbon compliance costs, which also decreased accounts payable and accrued liabilities as at Sept. 30, 2026.

6. ‌Asset Impairment (Reversals) Charges

   The Company recognized the following asset impairment (reversals) charges:

   3 months ended Sept. 30 9 months ended Sept. 30

   Segment 2026 2025 2026 2025

   Changes in decommissioning and restoration provisions(1)	Energy Transition and Gas	(14)	4	(19)	22
   Impairment charges, net of reversals, related to equipment and Required Divestitures(2)	Energy Transition and Gas	4	3	4	6
   Project development costs(3)	Corporate	-	-	10	7
   Impairment charges, net of impairment reversals	Wind and Solar	-	20	-	20
   Asset impairment (reversals) charges		(10)	27	(5)	55

   1. During the three and nine months ended Sept. 30, 2026, the Company recorded asset impairment reversals driven by an increase in discount rates with rates ranging from 4.50 to 7.30 per cent as at Dec. 31, 2025 to rates ranging from 5.10 to 7.50 per cent as at Sept. 30, 2026 (2025 - asset impairment charges driven by a decrease in discount rates with rates ranging from 5.3 to 8.4 per cent as at Dec. 31, 2024 to rates ranging from 4.6 to 7.6 per cent as at Sept. 30, 2025).

   2. To meet the requirements of the federal Competition Bureau related to the acquisition of Heartland, the Company entered into a consent agreement with the Commissioner of Competition, under which the Company divested Heartland's Poplar Hill and Rainbow Lake facilities ("Required Divestitures") following the closing of the acquisition on Dec. 4, 2024.

   3. During the nine months ended Sept. 30, 2026 and Sept. 30, 2025, the Company recognized an asset impairment charge in the Corporate segment related to projects that are no longer proceeding.

   Energy Transition Equipment Sale

   On Aug. 31, 2026, the Company completed the sale of the generation equipment in the Energy Transition segment for total proceeds of $27 million. Accordingly, the Company recorded an asset impairment reversal of $2 million,

7. ‌Interest Expense

   The components of interest expense are as follows:

   in addition to the $31 million asset impairment reversal recorded during the nine months ended Sept. 30, 2025, and derecognized Assets Held for Sale of $33 million and Liabilities Held for Sale of $6 million.

   Interest on debt	43	53	142	156
   Interest on exchangeable debentures	6	6	18	18
   Interest on exchangeable preferred shares(1)	7	7	21	21
   Interest on lease liabilities	3	1	8	8
   Credit facility fees, bank charges and other interest	3	5	14	21
   Accretion of provisions	13	13	38	42
   Interest expense	75	85	241	266

   3 months ended Sept. 30 9 months ended Sept. 30 2026 2025 2026 2025

   (1) On Oct. 27, 2026, the Company declared a dividend of $7 million in aggregate on the Series I Preferred Shares at the fixed rate of 1.764 per cent, per share, payable on Nov. 30, 2026.

8. ‌Financial Instruments
   1. Financial Assets and Liabilities - Classification and Measurement

      Financial assets and financial liabilities are measured on an ongoing basis at cost, fair value or amortized cost.

      The fair value measurement of a financial instrument is included in only one of the three levels, the determination of which is based on the lowest level input that is significant to the derivation of the fair value. The Level III classification is the lowest level classification in the fair value hierarchy.

      There were no changes in the Company's valuation processes, valuation techniques and types of inputs used in the fair value measurements during the period. Refer to Note 14 of the 2025 audited annual consolidated financial statements for further details.

      B. Net Risk Management Assets and Liabilities
      Aggregate net risk management assets (liabilities) are as follows:
      As at Sept. 30, 2026
      	Cash flow	Not designated
      	hedges(1)	as a hedge	Total
      Commodity risk management
      Current	13	20	33
      Long-term	(369)	(74)	(443)
      Net commodity risk management liabilities	(356)	(54)	(410)
      Other
      Current	-	10	10
      Long-term	-	8	8
      Net other risk management assets	-	18	18
      Total net risk management liabilities	(356)	(36)	(392)

      1. Effective Jan. 1, 2026, the Company has prospectively designated certain pre-existing VPPAs within the Wind and Solar segment as held for hedging and has applied hedge accounting. Refer to Note 15, section A of the annual consolidated financial statements for the year ended Dec. 31, 2025 for additional disclosure related to the designation of hedges.

         As at Dec. 31, 2025
         	Cash flow	Not designated
         	hedges	as a hedge	Total
         Commodity risk management
         Current	-	4	4
         Long-term	-	(494)	(494)
         Net commodity risk management liabilities	-	(490)	(490)
         Other
         Current	-	2	2
         Long-term	-	7	7
         Net other risk management assets	-	9	9
         Total net risk management liabilities	-	(481)	(481)

         1. Commodity Risk Management Assets and Liabilities

            Commodity risk management assets and liabilities classified by fair value levels as at Sept. 30, 2026, are as follows: Level I - $18 million net liability (Dec. 31, 2025 - $10 million net liability), Level II - $39 million net asset (Dec. 31, 2025 -

            $33 million net liability) and Level III - $431 million net liability (Dec. 31, 2025 - $447 million net liability).

            Significant changes in commodity net risk management assets and liabilities during the nine months ended Sept. 30, 2026, are primarily attributable to lower market prices across multiple markets on existing and new contracts and volume changes, partially offset by contract settlements and changes in foreign exchange rates.

            The following table summarizes the key factors impacting the fair value of the Level III commodity risk management assets and liabilities by classification during the nine months ended Sept. 30, 2026 and 2025, respectively:

            9 months ended Sept. 30, 2026 9 months ended Sept. 30, 2025

            Hedge

            Non-

            hedge Total Hedge

            Non-

            hedge Total

            Opening balance	-	(447)	(447)	-	(153)	(153)
            Changes attributable to:
            Change in hedge designation due to IFRS 9 amendment	(442)	442	-	-	-	-
            Market price and volume changes on existing contracts	106	(45)	61	-	(184)	(184)
            Market price changes on new contracts	-	13	13	-	4	4
            Contracts settled	(8)	(37)	(45)	-	(46)	(46)
            Change in foreign exchange rates	(12)	(1)	(13)	-	4	4
            Net risk management liabilities at end of period	(356)	(75)	(431)	-	(375)	(375)
            Additional Level III information:
            Gains recognized in other comprehensive earnings	48	-	48	-	-	-
            Total gains (losses) included in earnings before income taxes	59	12	71	-	(176)	(176)
            Unrealized gains (losses) included in earnings before income taxes relating to net assets (liabilities) held at period end	57	(32)	25	-	(222)	(222)

            As at Sept. 30, 2026, the total Level III risk management asset balance was $29 million (Dec. 31, 2025 - $65 million) and the Level III risk management liability balance was

            $460 million (Dec. 31, 2025 - $512 million).

            Included in the Level III classification are several long-term wind energy sales agreements, including contracts for differences and VPPAs, that are recognized as derivatives for accounting purposes. Effective Jan. 1, 2026, the Company prospectively designated certain pre-existing VPPAs within the Wind and Solar segment as held for

            hedging and has applied hedge accounting. The effective portion of changes in the fair value of these hedging derivatives will be recognised in other comprehensive income while any ineffective portion will be recognized in net earnings

            For a detailed description of the long-term wind energy sales agreements, please refer to Note 14 of the 2025 audited annual consolidated financial statements.

            The sensitivity tables below reflect the potential impacts of the key unobservable inputs on the fair value of the long-term wind energy sales agreements for both derivatives designated as hedges and derivatives without hedge designation. These agreements are backed by physical assets to effectively reduce our market exposure.

            As at Sept. 30, 2026

            Description Valuation technique

            Unobservable input and reasonably possible change

            Potential change in fair value(1)

            Long-term wind energy sale - Eastern U.S.	Long-term forecast	Wind capture prices(2) (per MWh), an increase or a decrease of 10 per cent	+/-	17
            		Illiquid future REC(3) prices (per MWh), an increase or a decrease of 10 per cent	+/-	1
            		Delivery volumes (MWh), an increase or a decrease of 5 per cent	+/-	6
            Long-term wind energy sale -	Long-term forecast	Wind capture prices(2) (per MWh), an	+/-	17
            Canada		increase or a decrease of 10 per cent
            		Delivery volumes (MWh), an increase or	+/-	4
            		a decrease of 5 per cent
            Long-term wind energy sale -	Long-term forecast	Wind capture prices(2) (per MWh), an	+/-	90
            Central U.S.		increase or a decrease of 10 per cent
            		Delivery volumes (MWh), an increase or	+/-	32
            		a decrease of 5 per cent

            1. Potential change in fair value represents the total increase or decrease in recognized fair value that could arise from the use of the reasonably possible change of the unobservable input.

            2. Wind capture prices represent the net forward power price exposure of the derivative after deducting the estimated wind discount (reflecting hourly generation timing and localized market conditions). Sensitivity is assessed using a 10% increase or decrease in the expected capture price per MWh, which reflects both forward power price movements and wind discounts.

            3. Renewable energy credits.

               As at Dec. 31, 2025

               Description

               Valuation technique

               Unobservable input and reasonably possible change

               Potential change in fair value(1)

               Long-term wind energy sale - Eastern U.S.

               Long-term wind energy sale - Canada

               Long-term forecast Wind capture prices(2) (per MWh), an

               increase or a decrease of 10 per cent

               Illiquid future REC(3) prices (per MWh), an increase or a decrease of 10 per cent

               Delivery volumes (MWh), an increase or a decrease of 5 per cent

               Long-term forecast Wind capture prices(2) (per MWh), an

               increase or a decrease of 10 per cent

               +/- 14

               +/- 2

               +/- 4

               +/- 24

               		Delivery volumes (MWh), an increase or a decrease of 5 per cent	+/- 9
               Long-term wind energy sale - Central U.S.	Long-term forecast	Wind capture prices(2) (per MWh), an increase or a decrease of 10 per cent	+/-	99
               		Delivery volumes (MWh), an increase or a decrease of 5 per cent	+/-	36

               1. Potential change in fair value represents the total increase or decrease in recognized fair value that would arise from the use of the reasonably possible change of the unobservable input.

               2. Wind capture prices represent the net forward power price exposure of the derivative after deducting the estimated wind discount (reflecting hourly generation timing and localized market conditions). Sensitivity is assessed using a 10% increase or decrease in the expected capture price per MWh, which reflects both forward power price movements and wind discounts.

               3. Renewable energy credits.

         2. Other Risk Management Assets and Liabilities

         Other risk management assets and liabilities primarily include risk management assets and liabilities that are used to manage exposures on non-energy marketing transactions such as interest rates, the net investment in foreign operations and other foreign currency risks. Hedge accounting is not always applied.

         C. Other Financial Assets and Liabilities

         Other risk management assets with a net fair value of $18 million as at Sept. 30, 2026 (Dec. 31, 2025 - $9 million net assets) are classified as Level II fair value measurements.

         The fair value of financial assets and liabilities measured at other than fair value is as follows:

         Fair value(2) Total

         	Level I	Level II	Level III	Total	value(2)
         Long-term debt - Sept. 30, 2026	-	2,981	-	2,981	3,322
         Exchangeable securities - Sept. 30, 2026	-	745	-	745	750
         Long-term financial asset - Sept. 30, 2026	-	-	134	134	134
         Loan receivable - Sept. 30, 2026(1)	-	30	-	30	30
         Long-term debt - Dec. 31, 2025	-	3,255	-	3,255	3,447
         Exchangeable securities - Dec. 31, 2025	-	752	-	752	750
         Long-term financial asset - Dec. 31, 2025	-	-	140	140	140
         Loan receivable - Dec. 31, 2025(1)	-	31	-	31	31

         1. Included within Other assets.

         2. Includes current and non-current portions.

         carrying

         The fair values of the Company's debentures, senior notes and exchangeable securities are determined using prices observed in secondary markets. Non-recourse and other long-term debt fair values are determined by calculating an implied price based on a current assessment of the yield to maturity.

         The carrying amount of other short-term financial assets and liabilities (cash and cash equivalents, restricted cash, trade accounts receivable, collateral provided, accounts payable and accrued liabilities, collateral held and dividends payable) approximates fair value due to the liquid nature of the asset or liability. The fair values of the finance lease receivables approximate the carrying amounts as the amounts receivable represent cash flows from repayments of principal and interest.

9. ‌Risk Management
   1. Risk Management Strategy

      The Company is exposed to market risk from changes in commodity prices, foreign exchange rates, interest rates, credit risk and liquidity risk. These risks affect the Company's earnings and the value of associated financial instruments that the Company holds. In certain cases, the Company seeks to minimize the effects of these risks by using derivatives to hedge its risk exposures.

      Long-term Financial Asset

      As at Sept. 30, 2026 the carrying amount of Nova facilities totalled $134 million, which approximates fair value. Nova facilities are classified as Level III within the fair value hierarchy as it is determined using a binomial model with multiple inputs such as volatility and equity value for which observable market data is not available. A reasonably possible change in inputs would not result in a material impact in the fair value of the Nova facilities.

      Refer to Note 14, Section IV of the 2025 consolidated financial statements for the year ended Dec. 31, 2025 for details.

      The Company's risk management strategy, policies and controls are designed to ensure that the risks it assumes comply with the Company's internal objectives and risk tolerance. Refer to Note 15 of the 2025 audited annual consolidated financial statements for further details of the Company's risk management activities.

   2. Nature and Extent of Risks Arising from Financial Instruments
      1. Market Risk

         1. Commodity Price Risk Management - Proprietary Trading The Company's Energy Marketing segment conducts proprietary trading activities and uses a variety of instruments to manage risk, earn trading revenue and gain market information.

         2. Commodity Price Risk Management - Generation

            The generation segments use various commodity contracts to manage the commodity price risk associated with electricity generation, fuel purchases, emissions and byproducts, as considered appropriate.

            For an estimate of the uncertainty related to long-term power sale and long-term wind energy sales contracts, refer to the Level III measurements table and the related unobservable inputs and sensitivities in Note 8(B)(I).

         3. Commodity Price Risk Management - Hedges

            Effective Jan. 1, 2026, the Company has prospectively designated certain pre-existing VPPAs within the Wind and Solar segment as held for hedging and has applied hedge accounting. Any ineffectiveness, such as locational price basis differences, is recognized in net earnings. Refer to Note 2 for details.

      2. Credit Risk

         The Company uses external credit ratings, as well as internal ratings in circumstances where external ratings are not available, to establish credit limits for customers and counterparties.

         The following table outlines the Company's maximum exposure to credit risk without taking into account collateral held, including the distribution of credit ratings, as at Sept. 30, 2026:

         	Investment grade (per cent)	Non-investment grade (per cent)	Total amount
         Trade and other receivables(1)	89	11	692
         Long-term finance lease receivable	100	-	305
         Risk management assets(1)	87	13	164
         Long-term financial assets(2)	-	100	134
         Loans receivable(3)	-	100	30
         Total			1,325

         1. Letters of credit and cash and cash equivalents are the primary types of collateral held as security related to these amounts.

         2. Included within long-term financial assets with counterparties that have no external credit rating. Refer to Note 8 for further details.

         3. Includes $30 million loans receivable included within other assets with counterparties that have no external credit rating.

         The Company did not have material expected credit losses as at Sept. 30, 2026. The Company's maximum exposure to credit risk at Sept. 30, 2026, without taking into account collateral held or right of set-off, is represented by the current carrying amounts of receivables and risk management assets as per the Condensed Consolidated Statements of Financial Position. Letters of credit, cash and first priority liens on assets are the primary types of collateral held as security related to these amounts.

      3. Liquidity Risk

      The Company has sufficient existing liquidity available to meet its upcoming debt maturities. Our highly diversified asset portfolio, by both fuel type and operating region, and our long-term contracted asset base provide stability in our cash flows.

      The maximum credit exposure to any one customer for commodity trading operations and hedging, including the fair value of open trading, net of any collateral held, at Sept. 30, 2026, was $29 million (Dec. 31, 2025 - $51 million). The Company has counterparty credit insurance programs that mitigate our exposure to credit risk.

      Liquidity risk relates to the Company's ability to access capital to be used for capital projects, debt refinancing, proprietary trading activities, commodity hedging and general corporate purposes.

      A maturity analysis of the Company's financial liabilities is as follows:

      	2026	2027	2028	2029	2030	2031 and thereafter	Total
      Accounts payable, accrued liabilities and other current liabilities	535	-	-	-	-	-	535
      Long-term debt(1)	52	332	166	245	284	2,277	3,356
      Exchangeable securities(2)	-	-	-	-	-	750	750
      Commodity risk management (assets) liabilities(3)	(27)	(10)	23	30	28	366	410
      Other risk management (assets) liabilities	-	(9)	(1)	2	1	(11)	(18)
      Lease liabilities	2	6	6	6	5	123	148
      Interest on long-term debt and lease liabilities(4)	31	184	167	158	143	733	1,416
      Interest on exchangeable securities(2)(4)	13	53	53	53	53	456	681
      Dividends payable	22	-	-	-	-	-	22
      Total	628	556	414	494	514	4,694	7,300

      1. Excludes impact of hedge accounting and derivatives.

      2. The exchangeable debentures are due May 1, 2039 and the exchangeable preferred shares are perpetual. However, a cash payment could occur after Dec. 31, 2028, at the Company's option, if the exchangeable securities are not exchanged by Brookfield Renewable Partners or its affiliates (collectively Brookfield). At Brookfield's option, the exchangeable securities are currently exchangeable into an equity ownership interest in TransAlta's Alberta Hydro Assets.

      3. Negative amount represents a receivable position or cash inflow.

      4. Not recognized as a financial liability on the Condensed Consolidated Statements of Financial Position and excludes the impact of interest rate swaps.

   3. Collateral
      1. Financial Assets Provided as Collateral

         At Sept. 30, 2026, the Company provided $48 million (Dec. 31, 2025 - $92 million) in cash and cash equivalents as collateral to regulated clearing agents as security for commodity trading activities. These funds are held in segregated accounts by the clearing agents. Collateral provided is included within trade and other receivables in the Condensed Consolidated Statements of Financial Position. At Sept. 30, 2026, the Company provided $21 million (Dec. 31, 2025 - $20 million) in surety bonds as security for commodity trading activities.

      2. Financial Assets Held as Collateral

         At Sept. 30, 2026, the Company held $27 million (Dec. 31, 2025 - $3 million) in cash collateral associated with counterparty obligations. Under the terms of the contracts, the Company may be obligated to pay interest on the outstanding balances and to return the principal when the counterparties have met their contractual obligations or when the amount of the obligation declines as a result of changes in market value.

         Interest payable to the counterparties on the collateral received is calculated in accordance with each contract. Collateral held is related to physical and financial derivative transactions in a net asset position and is included in accounts payable and accrued liabilities in the Condensed Consolidated Statements of Financial Position.

      3. Contingent Features in Derivative Instruments

      Collateral is posted in the normal course of business based on the Company's senior unsecured credit rating as determined by certain major credit rating agencies. Certain of the Company's derivative instruments contain financial assurance provisions that require collateral to be posted only if a material adverse credit-related event occurs.

      At Sept. 30, 2026, the Company had posted collateral of

      $194 million (Dec. 31, 2025 - $338 million) in the form of letters of credit on physical and financial derivative transactions in a net liability position. Certain derivative agreements contain credit-risk-contingent features, which if triggered could result in the Company having to post an additional $59 million (Dec. 31, 2025 - $92 million) of collateral to its counterparties.

10. ‌Property, Plant and Equipment

    During the three and nine months ended Sept. 30, 2026, the Company had additions of $53 million and $125 million primarily related to the Centralia Coal-to-Gas conversion project and spending in Gas and other segments. In addition, Property, Plant and Equipment increased by $102 million due to the acquisition of Far North.

    During the nine months ended Sept. 30, 2026, the Mount Keith West Network Upgrade project was completed. As a result, the Company derecognized assets under construction and recognized a finance lease receivable of

    $39 million.

11. ‌Credit Facilities, Long-Term Debt and Lease Liabilities
    1. Amounts Outstanding

       As at Sept. 30, 2026 Dec. 31, 2025

       Senior unsecured debt	1,673	1,639
       Credit facilities	-	95
       Non-recourse debt	1,446	1,471
       Recourse debt - OCP LP Bond	139	166
       Tax equity financing	64	76
       Lease liabilities	148	146
       Total Credit facilities, long-term debt and lease liabilities	3,470	3,593

       Current portion Non-current portion	189 3,281	175 3,418
       Total Credit facilities, long-term debt and lease liabilities	3,470	3,593

       The Company's credit facilities are summarized in the table below:

       As at Sept. 30, 2026 Utilized

       Outstanding

       Credit facilities	Facility size	letters of credit(1)	Cash drawings	Available capacity	Maturity date
       Committed
       Syndicated credit facility	1,900	327	-	1,573	Q2 2030
       Bilateral credit facilities	240	140		100	Q2 2028
       Heartland EDC letter of credit facility	30	8	-	22	Q4 2026
       Heartland DSR letter of credit facility	27	14	-	13	Q4 2027
       Heartland revolving facility	25	-	-	25	Q4 2027
       Total committed Non-committed Demand facility	2,222 400	489 211	- -	1,733 189
       Total Non-committed	400	211	-	189

       1. TransAlta has obligations to issue letters of credit and cash collateral to secure potential liabilities to certain parties, including those related to potential environmental obligations, commodity risk management and hedging activities, pension plan obligations, construction projects and purchase obligations. Letters of credit drawn against the non-committed facilities reduce the available capacity under the committed syndicated credit facilities.

          The credit facilities are the primary source of short-term liquidity after the cash flow generated from the Company's business.

          As at Sept. 30, 2026 the Company provided $74 million in surety-backed letters of credits as security for commodity trading activities.

          TransAlta's debt has terms and conditions, including financial covenants, that are considered ordinary and customary. As at Sept. 30, 2026, the Company was in compliance with all of its debt covenants and all undrawn amounts under the credit facilities are fully available.

    2. Restrictions Related to Non-Recourse and Other Debt

       All non-recourse debt and the OCP LP Bond, with a total carrying value of $1.6 billion as at Sept. 30, 2026 (Dec. 31, 2025 - $1.6 billion), are subject to customary financing conditions and covenants that may restrict the Company's ability to access funds generated by the facilities' operations. At Sept. 30, 2026, $84 million (Dec. 31, 2025 -

       $101 million) of cash was subject to these financial restrictions.

       Upon meeting certain distribution tests, typically performed once per quarter, the funds can be distributed by the subsidiary entities to their respective parent entity. These conditions include meeting a debt service coverage ratio prior to distribution, which was met by these entities in the third quarter of 2026, with the exception of Melancthon Wolfe Wind LP. The funds in Melancthon that have accumulated will remain there until the debt-service coverage ratio distribution threshold is met.

       At Sept. 30, 2026, $16 million (AU$16 million) of funds held by TEC Hedland Pty Ltd. cannot be accessed by other corporate entities as the funds must be solely used by the project entities and to pay major maintenance costs. Additionally, certain non-recourse bonds require that certain reserve accounts be established and funded through cash held on deposit and/or by providing letters of credit.

    3. Restricted Cash

       As at Sept. 30, 2026, the Company had $17 million (Dec. 31, 2025 - $17 million) of restricted cash related to the TransAlta OCP bonds, which is required to be held in a debt service reserve account in the third and fourth quarters of the year to fund scheduled future debt repayments.

       The Company also had $3 million (Dec. 31, 2025 - $4 million) of restricted cash related to holdbacks associated with the sale of the Poplar Hill and Rainbow Lake facilities, which the Company divested in accordance with a consent agreement entered into with the Commissioner of Competition for Canada and $60 million (Dec. 31, 2025 -

       $57 million) of restricted cash related to the TEC Hedland Pty Ltd. bond. These cash reserves are required to be held under commercial arrangements and for debt service, which may be replaced by letters of credit in the future.

12. ‌Common Shares
    1. Issued and Outstanding

       D. Currency Impacts

       The strengthening of the U.S. dollar has increased the U.S. dollar-denominated long-term debt balances, mainly the senior notes and tax equity financings, by $35 million during the nine months ended Sept. 30, 2026 (Sept. 30, 2025 -decreased $33 million due to the weakening of the U.S. dollar). Almost all of the U.S.-dollar-denominated debt is hedged either through financial contracts or a hedge of net investments in U.S. operations.

       Additionally, the strengthening of the Australian dollar has increased the Australian-dollar-denominated non-recourse senior secured notes balance by approximately $55 million during the nine months ended Sept. 30, 2026 (Sept. 30, 2025 - increased by $11 million due to strengthening of the Australian dollar). As this debt is issued by an Australian subsidiary, the foreign currency translation impacts are recognized within other comprehensive income (loss).

       E. Credit Facility Extension

       On July 17, 2026, the Company executed agreements to extend its committed credit facilities totalling $2.1 billion with a syndicate of lenders. The revised agreements extend the maturity dates of the syndicated credit facility from June 30, 2029 to June 30, 2030 and the bilateral credit

       facilities from June 30, 2027 to June 30, 2028.

       2026		2025
       Common shares (millions)	Amount	Common shares (millions) Amount

       TransAlta is authorized to issue an unlimited number of voting common shares without nominal or par value.

       9 months ended Sept. 30,

       Issued and outstanding, beginning of period Issued under public offering(1) Purchased and cancelled under the NCIB(2) Share-based payment plans Stock options exercised	296.7 3,169 18.2 338 - - 0.9 4 0.4 5	297.5 3,179 - - (1.9) (20) 0.8 7 0.3 3
       Issued and outstanding, end of period	316.2 3,516	296.7 3,169

       1. Net of after-tax issuance costs of $12 million (issuance costs of $16 million less tax-effect of $4 million).

       2. Shares purchased by the Company under the NCIB are recognized as a reduction to share capital equal to the average carrying value of the common shares. Any difference between the aggregate purchase price and the average carrying value of the common shares is recorded in retained earnings (deficit).

    2. Public Offering

       On June 9, 2026, TransAlta completed a public offering of 18,230,000 common shares at a price of $19.20 per share for total gross proceeds of approximately $350 million.

    3. Dividends

       On Oct. 27, 2026, the Company declared a quarterly dividend of $0.070 per common share, payable on Jan. 1, 2027. There have been no material transactions involving common shares between the reporting date and the date of

13. ‌Preferred Shares
    1. Issued and Outstanding

       All preferred shares issued and outstanding are non-voting cumulative redeemable fixed or floating rate first preferred shares.

       Series B Cumulative Redeemable Floating Rate First Series B Preferred Shares conversion

       On March 31, 2026, holders of Series B preferred shares converted 1,148,549 of the 2,370,087 outstanding Series B shares into Series A shares on a one-for-one basis.

14. ‌Cash Flow Information

    completion of these condensed consolidated financial statements.

    D. Earnings Per Share

    Net earnings (loss) attributable to common shareholders used in calculating basic and diluted net earnings (loss) per share reflects net earnings (loss) attributable to TransAlta shareholders, less preferred-share dividends declared and any cumulative preferred-share dividend entitlements for the period.

    As a result, on Sept. 30, 2026, the Company had 10,778,462 Series A preferred shares issued and outstanding and 1,221,538 Series B preferred shares issued and outstanding.

    The number of Series C, D, E and G preferred shares issued and outstanding remains unchanged since Dec. 31, 2025.

    B. Dividends

    On Oct. 27, 2026, the Company declared quarterly preferred share dividends, payable on Dec. 31, 2026, as follows: $0.29888 per Series A share, $0.27216 per Series B share, $0.36588 per Series C share, $0.33958 per Series D share, $0.43088 per Series E share and $0.42331 per Series G share.

    Change in Non-Cash Operating Working Capital

    Source (use):
    Accounts receivable	(48)	(17)	49	(1)
    Prepaid expenses	20	19	(5)	2
    Income taxes receivable	4	16	(18)	(22)
    Inventory	(5)	(1)	(17)	(5)
    Accounts payable, accrued liabilities and provisions	66	89	(67)	(69)
    Income taxes payable	(5)	(2)	(11)	1
    Change in non-cash operating working capital	32	104	(69)	(94)

    3 months ended Sept. 30 9 months ended Sept. 30 2026 2025 2026 2025

15. ‌Commitments and Contingencies

    During the nine months ended Sept. 30, 2026, the Company entered into a $45 million maintenance agreement for one of its facilities, running until 2036, and signed a turbine reservation contract with a remaining expected payment of

    $28 million due in Oct. 2026. The Company has not incurred any other additional material contractual commitments, either directly or through its interests in joint operations and joint ventures.

16. ‌Related-Party Transactions

    The Company may, in the normal course of operations, enter into transactions on market terms with associates that have been measured at exchange value and recognized in the Consolidated Financial Statements, including power purchase and sale agreements, and derivative contracts. Transactions and balances between the Company and associates do not eliminate.

17. ‌Segment Disclosures
    1. Description of Reportable Segments

       The Company is comprised of four generation segments: Hydro, Wind and Solar, Gas and Energy Transition and two non-generation segments: Energy Marketing and Corporate.

       During the first quarter of 2026, the Company updated its assessment of reportable segments to reflect changes in how the Chief Operating Decision Maker (CODM) makes operating decisions, assesses performance and allocates resources. As a result of the reassessment, the Company concluded that the Energy Transition segment no longer meets the quantitative thresholds under IFRS 8 to be presented as a reportable segment, primarily due to Centralia Unit 2 ceasing coal-fired operations, as scheduled at the end of 2025 in the normal course, however the unit remains available to operate in accordance with and for the duration of the order received from the United States Department of Energy.

       There were no material changes to the contingencies during the nine months ended Sept. 30, 2026.

       Refer to Note 36 of the 2025 audited annual consolidated financial statements for the current material outstanding commitments and contingencies.

       There were no material related party transactions during the nine months ended Sept. 30, 2026.

       Refer to Note 35 of the 2025 audited annual consolidated financial statements for further details.

       Accordingly, as at Sept. 30, 2026 the Company has five reportable segments, reflecting the revised assessment for the Energy Transition segment compared to six reportable segments as at Dec. 31, 2025.

       The segment results are presented using Adjusted EBITDA, consistent with the measure reviewed by the CODM when assessing performance and making operating decisions across the Company's segments.

       The tables below show the reconciliation of the total segment results and Adjusted EBITDA (non-IFRS measure) to the statement of earnings reported under IFRS.

    2. Reported Adjusted Segment Earnings Reconciliation of Adjusted EBITDA to Earnings (Loss) before Income Tax

       Reportable Segments

       3 months ended Sept. 30, 2026	Hydro	Wind & Solar(1)	Gas	Energy Marketing	Corporate	Energy Transition(2)	Total	Equity-accounted investments	Reclass adjustments	IFRS financials
       Revenues	95	110	315	31	(15)	2	538	(2)	-	536
       Reclassifications and adjustments:
       Unrealized mark-to-market (gain) loss	-	(24)	(3)	7	-	-	(20)	-	20	-
       Decrease in finance lease receivable	-	1	7	-	-	-	8	-	(8)	-
       Finance lease income	-	1	6	-	-	-	7	-	(7)	-
       Adjusted Revenue	95	88	325	38	(15)	2	533	(2)	5	536
       Fuel and purchased power	(5)	(6)	(126)	-	1	-	(136)	-	-	(136)
       Carbon compliance (cost) recovery	-	-	(3)	-	14	-	11	-	-	11
       Adjusted Gross Margin	90	82	196	38	-	2	408	(2)	5	411
       OM&A	(13)	(26)	(63)	(8)	(32)	(34)	(176)	2	-	(174)
       Reclassifications and adjustments:
       Centralia Order compliance costs and community fund expense	- - - - -					27	27	-	(27)	-
       ERP integration costs	- - - - 2					-	2	-	(2)	-
       Acquisition-related transaction and restructuring costs	- - - - 3					-	3	-	(3)	-
       Adjusted OM&A	(13)	(26)	(63)	(8)	(27)	(7)	(144)	2	(32)	(174)
       Taxes, other than income taxes	(1)	(5)	(5)	-	(1)	-	(12)	-	-	(12)
       Net other operating income	-	1	14	-	-	-	15	-	-	15
       Reclassifications and adjustments:
       Insurance recovery	-	-	(3)	-	-	-	(3)	-	3	-
       Adjusted Net Other Operating Income	-	1	11	-	-	-	12	-	3	15
       Adjusted EBITDA(3)	76	52	139	30	(28)	(5)	264
       Equity loss										(1)
       Finance lease income										7
       Depreciation and amortization										(104)
       Asset impairment reversals										10
       Interest income										7
       Interest expense										(75)
       Foreign exchange gain										4
       Gain on sale of assets and other										12
       Earnings before income taxes										100

       1. The Skookumchuck wind facility has been included on a proportionate basis in the Wind and Solar segment.

       2. The Energy Transition segment no longer meets the quantitative thresholds under IFRS 8 to be presented as a reportable segment starting Jan. 1, 2026.

       3. Adjusted EBITDA is not defined, has no standardized meaning under IFRS and may not be comparable to similar measures presented by other issuers.

          3 months ended Sept. 30, 2025	Hydro	Wind & Solar(1)	Gas	Energy Marketing	Corporate	Energy Transition(2)	Total	accounted investments	Reclass adjustments	IFRS financials
          Revenues	95	3	326	37	-	158	619	(4)	-	615
          Reclassifications and adjustments:
          Unrealized mark-to-market (gain) loss	(3)	78	(12)	(8)	-	(10)	45	-	(45)	-
          Decrease in finance lease receivable	-	1	7	-	-	-	8	-	(8)	-
          Finance lease income	-	1	5	-	-	-	6	-	(6)	-
          Revenues from Required Divestitures	-	-	(4)	-	-	-	(4)	-	4	-
          Unrealized foreign exchange (gain) loss on commodity	-	-	(1)	1	-	-	-	-	-	-
          Adjusted Revenue	92	83	321	30	-	148	674	(4)	(55)	615
          Fuel and purchased power	(5)	(5)	(119)	-	-	(98)	(227)	-	-	(227)
          Reclassifications and adjustments:
          Fuel and purchased power related to	-	-	(1)	-	-	-	(1)	-	1	-
          Required Divestitures
          Adjusted Fuel and Purchased Power	(5)	(5)	(120)	-	-	(98)	(228)	-	1	(227)
          Carbon compliance costs	-	-	(35)	-	-	-	(35)	-	-	(35)
          Adjusted Gross Margin	87	78	166	30	-	50	411	(4)	(54)	353
          OM&A	(14)	(28)	(64)	(13)	(41)	(20)	(180)	1	-	(179)
          Reclassifications and adjustments:
          OM&A related to the Required	- - 2			- -		-	2	-	(2)	-
          Divestitures
          ERP integration costs	- - -			- 6		-	6	-	(6)	-
          Acquisition-related transaction and	- - -			- 1		-	1	-	(1)	-
          restructuring costs
          Adjusted OM&A	(14)	(28)	(62)	(13)	(34)	(20)	(171)	1	(9)	(179)
          Taxes, other than income taxes	-	(5)	(5)	-	(1)	(2)	(13)	1	-	(12)
          Net other operating income	-	-	11	-	-	-	11	-	-	11
          Adjusted EBITDA(3)	73	45	110	17	(35)	28	238
          Equity loss										(1)
          Finance lease income										6
          Depreciation and amortization										(135)
          Asset impairment charges										(27)
          Interest income										7
          Interest expense										(85)
          Foreign exchange gain										3
          Fair value change in contingent consideration										3
          Gain on sale of assets and other										3
          Loss before income taxes										(53)

          1. The Skookumchuck wind facility has been included on a proportionate basis in the Wind and Solar segment.

          2. The Energy Transition segment no longer meets the quantitative thresholds under IFRS 8 to be presented as a reportable segment starting Jan. 1, 2026.

          3. Adjusted EBITDA is not defined, has no standardized meaning under IFRS and may not be comparable to similar measures presented by other issuers.

          Reportable Segments

          9 months ended Sept. 30, 2026	Hydro	Wind & Solar(1)	Gas	Energy Marketing	Corporate	Energy Transition(2)	Total	Equity-accounted investments	Reclass adjustments	IFRS financials
          Revenues	252	350	956	97	(60)	7	1,602	(14)	-	1,588
          Reclassifications and adjustments:
          Unrealized mark-to-market gain	-	(11)	(21)	(12)	-	-	(44)	-	44	-
          Decrease in finance lease receivable	-	2	22	-	-	-	24	-	(24)	-
          Finance lease income	-	4	16	-	-	-	20	-	(20)	-
          Unrealized foreign exchange gain on commodity	-	-	(2)	-	-	-	(2)	-	2	-
          Adjusted Revenue	252	345	971	85	(60)	7	1,600	(14)	2	1,588
          Fuel and purchased power	(13)	(17)	(377)	-	-	-	(407)	-	-	(407)
          Carbon compliance (costs) recovery	-	-	(36)	-	60	-	24	-	-	24
          Adjusted Gross Margin	239	328	558	85	-	7	1,217	(14)	2	1,205
          OM&A	(38)	(77)	(202)	(28)	(137)	(52)	(534)	4	-	(530)
          Reclassifications and adjustments:
          Termination and restructuring costs	- - - - 18					-	18	-	(18)	-
          Legal costs related to arbitration proceedings	- - - - 9					-	9	-	(9)	-
          Centralia Order compliance costs and community fund expense	- - - - -					38	38	-	(38)	-
          ERP integration costs	- - - - 6					-	6	-	(6)	-
          Acquisition-related transaction and restructuring costs	- - - - 4					-	4	-	(4)	-
          Adjusted OM&A	(38)	(77)	(202)	(28)	(100)	(14)	(459)	4	(75)	(530)
          Taxes, other than income taxes	(3)	(17)	(15)	-	(1)	-	(36)	-	-	(36)
          Net other operating income	-	15	36	-	-	1	52	-	-	52
          Reclassifications and adjustments:
          Legal settlement recoveries	- (12)		-	- - -			(12)	-	12	-
          Insurance recovery	- -		(3)	- - -			(3)	-	3	-
          Adjusted Net Other Operating Income	-	3	33	-	-	1	37	-	15	52
          Adjusted EBITDA(3)	198	237	374	57	(101)	(6)	759
          Equity income										3
          Finance lease income										20
          Depreciation and amortization										(314)
          Asset impairment reversals										5
          Interest income										21
          Interest expense										(241)
          Foreign exchange gain										8
          Gain on sale of assets and other										10
          Earnings before income taxes										203

          1. The Skookumchuck wind facility has been included on a proportionate basis in the Wind and Solar segment.

          2. The Energy Transition segment no longer meets the quantitative thresholds under IFRS 8 to be presented as a reportable segment starting Jan. 1, 2026.

          3. Adjusted EBITDA is not defined, has no standardized meaning under IFRS and may not be comparable to similar measures presented by other issuers.

          9 months ended Sept. 30, 2025	Hydro	Wind & Solar(1)	Gas	Energy Marketing	Corporate	Energy Transition(2)	Total	accounted investments	Reclass adjustments	IFRS financials
          Revenues	310	169	920	102	(66)	385	1,820	(14)	-	1,806
          Reclassifications and adjustments:
          Unrealized mark-to-market (gain) loss	(6)	182	27	(9)	-	4	198	-	(198)	-
          Decrease in finance lease receivable	-	2	21	-	-	-	23	-	(23)	-
          Finance lease income	-	4	13	-	-	-	17	-	(17)	-
          Revenues from Required Divestitures	-	-	(11)	-	-	-	(11)	-	11	-
          Unrealized foreign exchange gain on commodity	-	-	(1)	(1)	-	-	(2)	-	2	-
          Adjusted Revenue	304	357	969	92	(66)	389	2,045	(14)	(225)	1,806
          Fuel and purchased power	(16)	(24)	(388)	-	(2)	(247)	(677)	-	-	(677)
          Reclassifications and adjustments:
          Fuel and purchased power related to	-	-	2	-	-	-	2	-	(2)	-
          Required Divestitures
          Adjusted Fuel and Purchased Power	(16)	(24)	(386)	-	(2)	(247)	(675)	-	(2)	(677)
          Carbon compliance (costs) recovery	-	(2)	(76)	-	68	-	(10)	-	-	(10)
          Adjusted Gross Margin	288	331	507	92	-	142	1,360	(14)	(227)	1,119
          OM&A	(40)	(82)	(188)	(28)	(135)	(55)	(528)	3	-	(525)
          Reclassifications and adjustments:
          OM&A related to the Required	- - 5 - - -						5	-	(5)	-
          Divestitures
          ERP integration costs	- - - - 16 -						16	-	(16)	-
          Acquisition-related transaction and	- - - - 6 -						6	-	(6)	-
          restructuring costs
          Adjusted OM&A	(40) (82) (183) (28) (113) (55)						(501)	3	(27)	(525)
          Taxes, other than income taxes	(2) (15) (15) - (2) (3)						(37)	1	-	(36)
          Net other operating income	- 4 33 - - -						37	-	-	37
          Reclassifications and adjustments:
          Insurance recovery	- (2) - - - -						(2)	-	2	-
          Adjusted Net Other Operating Income	-	2	33	-	-	-	35	-	2	37
          Adjusted EBITDA(3)	246	236	342	64	(115)	84	857
          Equity income										2
          Finance lease income										17
          Depreciation and amortization										(431)
          Asset impairment charges										(55)
          Interest income										18
          Interest expense										(266)
          Foreign exchange loss										(18)
          Fair value change in contingent consideration										37
          Gain on sale of assets and other										2
          Loss before income taxes										(99)

          1. The Skookumchuck wind facility has been included on a proportionate basis in the Wind and Solar segment.

          2. The Energy Transition segment no longer meets the quantitative thresholds under IFRS 8 to be presented as a reportable segment starting Jan. 1, 2026.

          3. Adjusted EBITDA is not defined, has no standardized meaning under IFRS and may not be comparable to similar measures presented by other issuers.

18. ‌Subsequent Events

On Oct. 22, 2026, the Company acquired all issued and outstanding common shares of Mountain Peak Power and Canyon Peak Power (Colorado) from an indirect subsidiary of Blackstone Inc. (the Colorado Acquisition). The Colorado Acquisition, which includes Mountain Peak Power and Canyon Peak Power's entire business operations in Colorado consisting of two natural gas-fired generation facilities totaling 318 MW, was completed for an aggregate purchase price of US$1.0 billion, subject to working capital and other adjustments, including the assumption of US$750 million of project debt. The US$250 million purchase price was funded by a common share offering for $350 million completed during the three months ended June 30, 2026.

The Colorado Acquisition will be accounted for as a business combination using the acquisition method where the acquired tangible assets and intangible assets, if any, and assumed liabilities are recorded at their estimated fair values at the date of acquisition. Any amount less than or exceeding the purchase price will be presented as goodwill or a bargain purchase gain, respectively.

The fair values of Colorado's identifiable assets and liabilities to be assumed and the impact of applying acquisition accounting has not been fully determined. Due to the proximity of the acquisition date to the release date of the Company's Condensed Consolidated Financial Statements, the preliminary purchase price allocation will be disclosed in the Consolidated Financial Statements for the year ended Dec. 31, 2026.

On Oct. 22, 2026, the Company completed the sale of a 49 per cent minority ownership interest in its 500 MW Oklahoma wind portfolio for cash proceeds of US$305 million, before customary closing adjustments.

The portfolio comprises the 100 MW White Rock West, 200 MW White Rock East and 200 MW Horizon Hill wind facilities, which are part of the Wind and Solar segment.