[10-Q] Ovintiv Inc. Quarterly Earnings Report

Rhea-AI Filing Summary

Ovintiv Inc. (OVV) Q2-25 10-Q highlights: Revenue inched up 1% YoY to $2.32 bn, but net income slipped 10% to $307 m ($1.18 diluted EPS). Operating income fell 8% to $511 m as lower product pricing offset a 5% reduction in total operating expenses. Risk-management hedges contributed a $87 m gain versus $77 m a year ago, cushioning commodity volatility.

Cash & capital: Operating cash flow was steady at $1.01 bn; capex fell 16% to $521 m, yielding roughly $492 m of free cash. Ovintiv returned $224 m to shareholders via $77 m dividends ($0.30/sh) and $147 m buybacks, shrinking basic shares to 259 m and period-end shares to 257 m.

Balance sheet: Gross debt decreased to $5.33 bn from $5.45 bn year-end, aided by proceeds from the $1.88 bn Uinta Basin divestiture. Liquidity remained solid with $20 m cash and undrawn revolver capacity; interest expense declined to $95 m (-10%).

Portfolio repositioning: On 31 Jan 25 the company closed the C$3.3 bn Montney acquisition, adding 109 k net acres, funded largely by the Uinta sale and short-term borrowings. No impairments were recorded in Q2, but a $730 m charge hit 1H-25, tied to Canadian assets.

Segment view: USA generated $399 m operating profit (-24%), while Canada delivered $131 m (+39%) helped by higher NGL and gas realizations. Corporate/Other posted a $19 m loss.

Key metrics:

• FCF margin: ~21%
• Net debt/annualized EBITDAX: ~1.3× (est.)
• Effective tax rate: 23.1% (vs. 27% LY)

Insights

Financial Analyst

TL;DR: Mixed quarter—stable cash flow, lower leverage, slight EPS decline; portfolio shift toward Montney increases liquids leverage.

Revenue was flat but commodity hedges and cost control held margins. EPS dipped 7% on softer pricing and higher DD&A. Importantly, Ovintiv redeployed Uinta proceeds into Montney, tilting exposure to liquids-rich gas while trimming net debt by ~$120 m. Free cash comfortably covered dividends and buybacks, supporting a 9% YoY share count reduction. Leverage near 1.3× keeps investment-grade profile intact. Guidance not provided, but lower capex implies potential FCF upside if prices recover.

Energy Industry Specialist

TL;DR: Strategic acreage swap—Uinta exit, Montney entry—positions OVV for long-cycle growth; near-term results pressured by prices.

The $2.3 bn Montney deal secures scalable gas condensate inventory adjacent to Ovintiv’s existing footprint, offering infrastructure synergies and long-term cost advantages. Q2 operating metrics evidence early integration: Canadian segment transport & processing costs rose, but operating cash flow improved. Lack of impairments this quarter suggests reserve economics remain robust post-acquisition. However, Q2 earnings softness and 23% tax rate underline sensitivity to WTI/Henry Hub pricing. Overall impact is strategically positive yet financially neutral short term.

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UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2025

or

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission file number 001-39191

Ovintiv Inc.

(Exact name of registrant as specified in its charter)

Delaware		84-4427672
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

Suite 1700, 370 17th Street, Denver, Colorado, 80202, U.S.A.

(Address of principal executive offices)

Registrant’s telephone number, including area code (303) 623-2300

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Shares	OVV	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer	☒		Accelerated filer	☐
Non-accelerated filer	☐		Smaller reporting company	☐
			Emerging growth company	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes ☐ No ☒

Number of registrant’s shares of common stock outstanding as of July 18, 2025 257,037,322

1

OVINTIV INC.

FORM 10-Q

TABLE OF CONTENTS

	PART I
Item 1.	Financial Statements		6
	Condensed Consolidated Statement of Earnings		6
	Condensed Consolidated Statement of Comprehensive Income		6
	Condensed Consolidated Balance Sheet		7
	Condensed Consolidated Statement of Changes in Shareholders’ Equity		8
	Condensed Consolidated Statement of Cash Flows		10
	Notes to Condensed Consolidated Financial Statements		11
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		33
Item 3.	Quantitative and Qualitative Disclosures about Market Risk		58
Item 4.	Controls and Procedures		60
	PART II
Item 1.	Legal Proceedings		61
Item 1A.	Risk Factors		61
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		61
Item 3.	Defaults Upon Senior Securities		62
Item 4.	Mine Safety Disclosures		62
Item 5.	Other Information		62
Item 6.	Exhibits		62
Signatures			63

2

DEFINITIONS

Unless the context otherwise requires or otherwise expressly stated, all references in this Quarterly Report on Form 10-Q to “Ovintiv,” the “Company,” “us,” “we,” “our,” and “ours” refer to Ovintiv Inc. and its consolidated subsidiaries. In addition, the following are other abbreviations and definitions of certain terms used within this Quarterly Report on Form 10‑Q:

“AECO” means Alberta Energy Company and is the Canadian benchmark price for natural gas.

“ASU” means Accounting Standards Update.

“bbl” or “bbls” means barrel or barrels.

“BOE” means barrels of oil equivalent.

“Btu” means British thermal units, a measure of heating value.

“CORRA” means Canadian Overnight Repo Rate Average.

“DD&A” means depreciation, depletion and amortization expenses.

“FASB” means Financial Accounting Standards Board.

“GHG” means greenhouse gas.

“Mbbls/d” means thousand barrels per day.

“MBOE/d” means thousand barrels of oil equivalent per day.

“Mcf” means thousand cubic feet.

“MD&A” means Management’s Discussion and Analysis of Financial Condition and Results of Operations.

“MMBOE” means million barrels of oil equivalent.

“MMBtu” means million Btu.

“MMcf/d” means million cubic feet per day.

“NCIB” means normal course issuer bid.

“NGL” or “NGLs” means natural gas liquids.

“NYMEX” means New York Mercantile Exchange.

“NYSE” means New York Stock Exchange.

“OPEC” means Organization of the Petroleum Exporting Countries.

“SEC” means United States Securities and Exchange Commission.

“S&P 400” means Standard and Poor’s MidCap 400 index.

“TSX” means Toronto Stock Exchange.

“U.S.”, “United States” or “USA” means United States of America.

“U.S. GAAP” means U.S. Generally Accepted Accounting Principles.

“WTI” means West Texas Intermediate.

CONVERSIONS

In this Quarterly Report on Form 10-Q, a conversion of natural gas volumes to BOE is on the basis of six Mcf to one bbl. BOE is based on a generic energy equivalency conversion method primarily applicable at the burner tip and does not represent economic value equivalency at the wellhead. Given that the value ratio based on the current price of oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value, particularly if used in isolation.

CONVENTIONS

Unless otherwise specified, all dollar amounts are expressed in U.S. dollars, all references to “dollars”, “$” or “US$” are to U.S. dollars and all references to “C$” are to Canadian dollars. All amounts are provided on a before tax basis, unless otherwise stated. In addition, all information provided herein is presented on an after royalties basis.

3

The terms “include”, “includes”, “including” and “included” are to be construed as if they were immediately followed by the words “without limitation”, except where explicitly stated otherwise.

The term “liquids” is used to represent oil, NGLs and condensate. The term “liquids-rich” is used to represent natural gas streams with associated liquids volumes. The term “play” is used to describe an area in which hydrocarbon accumulations or prospects of a given type occur. Ovintiv’s focus of development is on hydrocarbon accumulations known to exist over a large areal expanse and/or thick vertical section and are developed using hydraulic fracturing. This type of development typically has a lower geological and/or commercial development risk and lower average decline rate, when compared to conventional development.

References to information contained on the Company’s website at www.ovintiv.com are not incorporated by reference into, and does not constitute a part of, this Quarterly Report on Form 10-Q.

FORWARD-LOOKING STATEMENTS AND RISK

This Quarterly Report on Form 10-Q, and the other documents incorporated herein by reference (if any), contain certain forward-looking statements or information (collectively, “forward-looking statements”) within the meaning of applicable securities legislation, including Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements, except for statements of historical fact, that relate to the anticipated future activities, plans, strategies, objectives or expectations of the Company are forward-looking statements. When used in this Quarterly Report on Form 10‑Q, and the other documents incorporated herein by reference (if any), the use of words and phrases including “anticipates,” “believes,” “continue,” “could,” “estimates,” “expects,” “focused on,” “forecast,” “guidance,” “intends,” “maintain,” “may,” “on track,” “opportunities,” “outlook,” “plans,” “potential,” “strategy,” “targets,” “will,” “would” and other similar terminology is intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words or phrases. Without limiting the generality of the foregoing, forward-looking statements contained in this Quarterly Report on Form 10‑Q include: expectations of plans, strategies and objectives of the Company, including anticipated reserves development; the Company’s ability to consummate any future acquisition and divestiture transactions; the Company’s ability to successfully integrate any acquired assets into its business; drilling plans and programs, including the amount and availability of capital to complete these plans and programs; the composition of the Company’s assets and the anticipated capital returns associated with its assets; anticipated oil, NGL and natural gas prices; the anticipated success of, and benefits from, technology and innovation, including the cube development model, Trimulfrac and Simulfrac techniques and other new or advanced drilling techniques or well completion designs; anticipated drilling and completions activity, including the number of drilling rigs and frac crews utilized; anticipated proceeds and future benefits from various joint venture, partnership and other agreements; anticipated or desired benefits from acquisitions; anticipated oil, NGLs and natural gas production and commodity mix; the Company’s ability to access credit facilities, debt and equity capital markets and other sources of liquidity; the ability of the Company to timely achieve its stated environmental, social and governance goals, targets and initiatives; the impact of changes in federal, state, provincial, local and tribal laws, rules and regulations, including the impact of changes in trade policies and tariffs; anticipated compliance with current or proposed environmental legislation; the Company’s ability to manage debt and financial ratios and comply with financial covenants; the implementation and outcomes of risk management programs, including exposure to commodity prices, interest rate and foreign exchange fluctuations and the volume of oil, NGLs and natural gas production hedged; the declaration and payment of future dividends and the anticipated repurchase of the Company’s outstanding common shares; the Company’s ability to manage cost inflation and expected cost structures, including expected operating, transportation, processing and labor expenses; and the outlook of the oil and natural gas industry generally, including impacts from changes to the geopolitical environment.

The forward-looking statements included in this Quarterly Report on Form 10-Q involve risks and uncertainties that could cause actual results to differ materially from projected results. Accordingly, investors should not place undue reliance on forward-looking statements as a prediction of actual results. We have based these forward-looking statements on current expectations and assumptions about future events, taking into account all information currently known by us. While we consider these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks and uncertainties, many of which are difficult to predict and beyond our control. The risks and uncertainties that may affect the operations, performance and results of our business and forward-looking statements include, but are not limited to, those set forth in Item 1A. Risk Factors of the Company’s most recent Annual Report on Form 10‑K for the fiscal year ended December 31, 2024 (the “2024 Annual Report on Form 10-K”); and other risks and uncertainties impacting the Company’s business as described from time to time in the Company’s other periodic filings with the SEC or Canadian securities regulators.

4

Although the Company believes the expectations represented by its forward-looking statements are reasonable based on the information available to it as of the date such statements are made, forward-looking statements are only predictions and statements of our current beliefs and there can be no assurance that such expectations will prove to be correct. All forward-looking statements contained in this Quarterly Report on Form 10‑Q are made as of the date of this document (or in the case of a document incorporated herein by reference, the date of such document) and, except as required by law, the Company undertakes no obligation to update publicly or revise any forward-looking statements. The forward-looking statements contained or incorporated by reference in this Quarterly Report on Form 10‑Q, and all subsequent forward-looking statements attributable to the Company, whether written or oral, are expressly qualified by these cautionary statements.

The reader should carefully read the risk factors described in Item 1A. Risk Factors of the 2024 Annual Report on Form 10‑K for a description of certain risks that could, among other things, cause actual results to differ from these forward-looking statements.

5

PART I

Item 1. Financial Statements

Condensed Consolidated Statement of Earnings (unaudited)

				Three Months Ended								Six Months Ended
				June 30,								June 30,
(US$ millions, except per share amounts)				2025				2024				2025				2024
Revenues		(Note 3)
Product and service revenues (1)		(Note 4)		$	1,764			$	1,849			$	3,729			$	3,787
Sales of purchased product (1)		(Note 4)			450				344				860				793
Gains (losses) on risk management, net		(Note 19)			87				77				71				23
Sublease revenues		(Note 10)			17				18				35				37
Total Revenues					2,318				2,288				4,695				4,640
Operating Expenses		(Note 3)
Production, mineral and other taxes					73				89				160				172
Transportation and processing					435				413				833				832
Operating	(Note 17)				219				237				424				480
Purchased product					440				333				842				773
Depreciation, depletion and amortization					556				580				1,101				1,146
Impairments		(Note 9)			-				-				730				-
Accretion of asset retirement obligation					8				4				14				9
Administrative	(Notes 16, 17)				76				76				169				178
Total Operating Expenses					1,807				1,732				4,273				3,590
Operating Income (Loss)					511				556				422				1,050
Other (Income) Expenses
Interest		(Note 5)			95				105				192				203
Foreign exchange (gain) loss, net		(Note 6)			22				(10	)			32				(38	)
Other (gains) losses, net					(5	)			(5	)			(8	)			(9	)
Total Other (Income) Expenses					112				90				216				156
Net Earnings (Loss) Before Income Tax					399				466				206				894
Income tax expense (recovery)		(Note 7)			92				126				58				216
Net Earnings (Loss)				$	307			$	340			$	148			$	678
Net Earnings (Loss) per Share of Common Stock		(Note 13)
Basic				$	1.19			$	1.28			$	0.57			$	2.53
Diluted					1.18				1.27				0.57				2.51
Weighted Average Shares of Common Stock Outstanding (millions)		(Note 13)
Basic					259.0				266.2				259.7				267.9
Diluted					260.1				268.1				261.6				270.6

(1)See Note 3 regarding the reclassification of the Company’s previously reported Market Optimization segment.

Condensed Consolidated Statement of Comprehensive Income (unaudited)

				Three Months Ended								Six Months Ended
				June 30,								June 30,
(US$ millions)				2025				2024				2025				2024
Net Earnings (Loss)				$	307			$	340			$	148			$	678
Other Comprehensive Income (Loss), Net of Tax
Foreign currency translation adjustment		(Note 14)			194				(31	)			202				(107	)
Pension and other post-employment benefit plans		(Note 14)			(1	)			(2	)			(2	)			(3	)
Other Comprehensive Income (Loss)					193				(33	)			200				(110	)
Comprehensive Income (Loss)				$	500			$	307			$	348			$	568

See accompanying Notes to the unaudited Condensed Consolidated Financial Statements

6

Condensed Consolidated Balance Sheet (unaudited)

				As at				As at
				June 30,				December 31,
(US$ millions)				2025				2024
Assets
Current Assets
Cash and cash equivalents				$	20			$	42
Accounts receivable and accrued revenues (net of allowances
of $6 million (2024: $5 million))		(Note 4)			1,121				1,183
Risk management		(Notes 18, 19)			98				108
Income tax receivable					5				36
					1,244				1,369
Property, Plant and Equipment, at cost:		(Notes 8, 9)
Oil and natural gas properties, based on full cost accounting
Proved properties					68,848				66,009
Unproved properties					649				764
Other					879				865
Property, plant and equipment					70,376				67,638
Less: Accumulated depreciation, depletion and amortization					(55,993	)			(53,274	)
Property, plant and equipment, net		(Note 3)			14,383				14,364
Other Assets	(Note 8)				1,336				965
Risk Management		(Notes 18, 19)			2				-
Deferred Income Taxes					190				10
Goodwill		(Note 3)			2,579				2,546
		(Note 3)		$	19,734			$	19,254
Liabilities and Shareholders’ Equity
Current Liabilities
Accounts payable and accrued liabilities				$	1,801			$	1,883
Current portion of operating lease liabilities					108				82
Income tax payable					18				9
Risk management		(Notes 18, 19)			7				107
Current portion of long-term debt		(Note 11)			940				600
					2,874				2,681
Long-Term Debt		(Note 11)			4,393				4,853
Operating Lease Liabilities		(Note 8)			1,147				737
Other Liabilities and Provisions	(Notes 12, 15)				130				114
Risk Management		(Notes 18, 19)			16				21
Asset Retirement Obligation		(Note 8)			438				315
Deferred Income Taxes					359				202
					9,357				8,923
Commitments and Contingencies		(Note 21)
Shareholders’ Equity
Share capital - authorized 775 million shares of stock
2025 issued and outstanding: 257.0 million shares (2024: 260.4 million shares)		(Note 13)			3				3
Paid in surplus		(Note 13)			7,898				8,045
Retained earnings					1,499				1,506
Accumulated other comprehensive income		(Note 14)			977				777
Total Shareholders’ Equity					10,377				10,331
				$	19,734			$	19,254

See accompanying Notes to the unaudited Condensed Consolidated Financial Statements

7

Condensed Consolidated Statement of Changes in Shareholders’ Equity (unaudited)

Three Months Ended June 30, 2025 (US$ millions)							Share Capital				Paid in Surplus			Retained Earnings				Accumulated Other Comprehensive Income				Total Shareholders’ Equity
Balance, March 31, 2025							$	3			$	8,024			$	1,269			$	784			$	10,080
Net Earnings (Loss)								-				-				307				-				307
Dividends on Shares of Common Stock ($0.30 per share)					(Note 13)			-				-				(77	)			-				(77	)
Shares of Common Stock Purchased					(Note 13)			-				(147	)			-				-				(147	)
Equity-Settled Compensation Costs								-				21				-				-				21
Other Comprehensive Income (Loss)					(Note 14)			-				-				-				193				193
Balance, June 30, 2025							$	3			$	7,898			$	1,499			$	977			$	10,377
Three Months Ended June 30, 2024 (US$ millions)							Share Capital				Paid in Surplus			Retained Earnings				Accumulated Other Comprehensive Income				Total Shareholders’ Equity
Balance, March 31, 2024							$	3			$	8,331			$	955			$	973			$	10,262
Net Earnings (Loss)								-				-				340				-				340
Dividends on Shares of Common Stock ($0.30 per share)					(Note 13)			-				-				(80	)			-				(80	)
Shares of Common Stock Purchased					(Note 13)			-				(184	)			-				-				(184	)
Equity-Settled Compensation Costs								-				23				-				-				23
Other Comprehensive Income (Loss)					(Note 14)			-				-				-				(33	)			(33	)
Balance, June 30, 2024							$	3			$	8,170			$	1,215			$	940			$	10,328

See accompanying Notes to the unaudited Condensed Consolidated Financial Statements

8

Condensed Consolidated Statement of Changes in Shareholders’ Equity (unaudited)

Six Months Ended June 30, 2025 (US$ millions)							Share Capital				Paid in Surplus			Retained Earnings				Accumulated Other Comprehensive Income				Total Shareholders’ Equity
Balance, December 31, 2024							$	3			$	8,045			$	1,506			$	777			$	10,331
Net Earnings (Loss)								-				-				148				-				148
Dividends on Shares of Common Stock ($0.60 per share)					(Note 13)			-				-				(155	)			-				(155	)
Shares of Common Stock Purchased					(Note 13)			-				(147	)			-				-				(147	)
Equity-Settled Compensation Costs								-				-				-				-				-
Other Comprehensive Income (Loss)					(Note 14)			-				-				-				200				200
Balance, June 30, 2025							$	3			$	7,898			$	1,499			$	977			$	10,377
Six Months Ended June 30, 2024 (US$ millions)							Share Capital				Paid in Surplus			Retained Earnings				Accumulated Other Comprehensive Income				Total Shareholders’ Equity
Balance, December 31, 2023							$	3			$	8,620			$	697			$	1,050			$	10,370
Net Earnings (Loss)								-				-				678				-				678
Dividends on Shares of Common Stock ($0.60 per share)					(Note 13)			-				-				(160	)			-				(160	)
Shares of Common Stock Purchased					(Note 13)			-				(434	)			-				-				(434	)
Equity-Settled Compensation Costs								-				(16	)			-				-				(16	)
Other Comprehensive Income (Loss)					(Note 14)			-				-				-				(110	)			(110	)
Balance, June 30, 2024							$	3			$	8,170			$	1,215			$	940			$	10,328

See accompanying Notes to the unaudited Condensed Consolidated Financial Statements

9

Condensed Consolidated Statement of Cash Flows (unaudited)

				Three Months Ended								Six Months Ended
				June 30,								June 30,
(US$ millions)				2025				2024				2025				2024
Operating Activities
Net earnings (loss)				$	307			$	340			$	148			$	678
Depreciation, depletion and amortization					556				580				1,101				1,146
Impairments		(Note 9)			-				-				730				-
Accretion of asset retirement obligation					8				4				14				9
Deferred income taxes		(Note 7)			66				103				(11	)			161
Unrealized (gain) loss on risk management		(Note 19)			(54	)			(8	)			(8	)			92
Unrealized foreign exchange (gain) loss		(Note 6)			2				(5	)			(43	)			(28	)
Foreign exchange (gain) loss on settlements		(Note 6)			1				(5	)			(41	)			(7	)
Other					27				16				27				9
Net change in other assets and liabilities					(11	)			(42	)			(22	)			(54	)
Net change in non-cash working capital		(Note 20)			111				37				(9	)			(327	)
Cash From (Used in) Operating Activities					1,013				1,020				1,886				1,679
Investing Activities
Capital expenditures		(Note 3)			(521	)			(622	)			(1,138	)			(1,213	)
Acquisitions		(Note 8)			(3	)			(5	)			(2,313	)			(195	)
Corporate acquisition					-				-				-				12
Proceeds from divestitures		(Note 8)			12				2				1,896				4
Net change in investments and other					(46	)			(16	)			102				(10	)
Cash From (Used in) Investing Activities					(558	)			(641	)			(1,453	)			(1,402	)
Financing Activities
Net issuance (repayment) of revolving debt		(Note 11)			396				(111	)			481				350
Repayment of long-term debt		(Note 11)			(600	)			-				(600	)			-
Purchase of shares of common stock		(Note 13)			(147	)			(184	)			(147	)			(434	)
Dividends on shares of common stock		(Note 13)			(77	)			(80	)			(155	)			(160	)
Finance lease payments and other					(2	)			(1	)			(21	)			(30	)
Cash From (Used in) Financing Activities					(430	)			(376	)			(442	)			(274	)
Foreign Exchange Gain (Loss) on Cash, Cash Equivalents
and Restricted Cash Held in Foreign Currency					(13	)			-				(13	)			2
Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash					12				3				(22	)			5
Cash, Cash Equivalents and Restricted Cash, Beginning of Period					8				5				42				3
Cash, Cash Equivalents and Restricted Cash, End of Period				$	20			$	8			$	20			$	8
Cash, End of Period				$	19			$	6			$	19			$	6
Cash Equivalents, End of Period					1				2				1				2
Restricted Cash, End of Period					-				-				-				-
Cash, Cash Equivalents and Restricted Cash, End of Period				$	20			$	8			$	20			$	8
Supplementary Cash Flow Information		(Note 20)

See accompanying Notes to the unaudited Condensed Consolidated Financial Statements

10

1. Basis of Presentation and Principles of Consolidation

Ovintiv is in the business of the exploration for, the development of, and the production and marketing of oil, NGLs and natural gas.

The interim Condensed Consolidated Financial Statements include the accounts of Ovintiv and entities in which it holds a controlling interest. All intercompany balances and transactions are eliminated on consolidation. Undivided interests in oil and natural gas exploration and production joint ventures and partnerships are consolidated on a proportionate basis. Investments in non-controlled entities over which the Company has the ability to exercise significant influence are accounted for using the equity method.

The interim Condensed Consolidated Financial Statements are prepared in conformity with U.S. GAAP and the rules and regulations of the SEC. Pursuant to these rules and regulations, certain information and disclosures normally required under U.S. GAAP have been condensed or have been disclosed on an annual basis only. Accordingly, the interim Condensed Consolidated Financial Statements should be read in conjunction with the annual audited Consolidated Financial Statements and the notes thereto for the year ended December 31, 2024, which are included in Item 8 of Ovintiv’s 2024 Annual Report on Form 10‑K.

The interim Condensed Consolidated Financial Statements have been prepared following the same accounting policies and methods of computation as the annual audited Consolidated Financial Statements for the year ended December 31, 2024.

These unaudited interim Condensed Consolidated Financial Statements reflect, in the opinion of Management, all normal and recurring adjustments necessary to present fairly the financial position and results of the Company as at and for the periods presented. Interim condensed consolidated financial results are not necessarily indicative of consolidated financial results expected for the fiscal year.

2. Recent Accounting Pronouncements

Changes in Accounting Policies and Practices

On January 1, 2025, Ovintiv adopted ASU 2023-09 “Improvements to Income Tax Disclosures” for annual disclosures. The standard requires disaggregated information about the Company’s effective tax rate reconciliation as well as information on income taxes paid. The amendment requires the tabular rate reconciliation to be presented using both percentages and amounts, with additional separate disclosure for any reconciling items within certain categories equal to or greater than five percent of net earnings or loss before income tax and the applicable statutory federal income tax rate. The amendment also requires the disaggregation of income taxes paid by federal, state, and foreign jurisdictions, as well as additional disaggregated information on income taxes paid to an individual jurisdiction equal to or greater than five percent of total income taxes paid. Amendments will be applied prospectively and will not have a material impact on the Company’s annual Consolidated Financial Statements.

New Standards Issued Not Yet Adopted

As of January 1, 2027, Ovintiv will be required to adopt ASU 2024-03 “Disaggregation of Income Statement Expenses” for annual disclosures with interim disclosures required beginning in the first quarter of 2028. The new standard requires that an entity disclose tabular information about certain expenses including, but not limited to, purchases of inventory, employee compensation, and depreciation, depletion, and amortization expense that are presented within expense line captions reported on the statement of earnings. A qualitative description of the remaining other amounts within those expense line captions will be required. The Company will also be required to determine and disclose its definition of selling expenses and the total amount of selling expenses. The amendments are to be applied prospectively, with the option for retrospective application, and are not expected to have a material impact on the Company’s Consolidated Financial Statements.

11

3. Segmented Information

Ovintiv’s exploration and production activities are subdivided into two geographic segments, including the USA Operations and Canadian Operations. These segments’ activities also include third-party purchases and sales of product to provide operational flexibility and cost mitigation for transportation commitments, product type, delivery points and customer diversification. The Company considers sales of purchased commodities as ancillary to its oil and gas development, exploration and producing activities and manages them to support such activities. In addition, the Company has a single, company-wide management team that allocates capital resources to maximize profitability and measures financial performance as a single enterprise.

Corporate and Other mainly includes unrealized gains or losses recorded on derivative financial instruments. Once the instruments are settled, the realized gains and losses are recorded in the reporting segment to which the derivative instruments relate. Corporate and Other also includes amounts related to sublease rentals and administrative costs not allocated to the operating segments.

In 2024, Ovintiv reassessed its reportable segments and determined the Chief Operating Decision Makers (“CODMs”) no longer separately reviewed the Market Optimization operational results and activities. Accordingly, Ovintiv’s Market Optimization segment was reclassified to present the Company’s market optimization activities in their respective USA and Canadian operating segments, which they support. The Market Optimization revenues, which were previously included in Product and service revenues, are presented as Sales of purchased product in the Condensed Consolidated Statement of Earnings. In conjunction with this segment reclassification, intercompany marketing fees formerly transacted between operating segments are excluded from Product and service revenues, and Sales of purchased product. Prior periods have been reclassified for comparative purposes. Additionally, intersegment eliminations are no longer required in this Segmented Information note as marketing activities are reflected in the corresponding operating segment they relate to.

The tables below summarize the results of operations and total assets by segment that are provided to the CODMs which have been identified as the Company’s President & Chief Executive Officer, Executive Vice President & Chief Operating Officer, and the Executive Vice President & Chief Financial Officer. The CODMs evaluate the performance of each of the reportable segments based on Operating Income (Loss) which is also used to assess performance and allocate capital for these segments.

The Company evaluates the effects of debt financing, interest expense and/or interest income, foreign exchange gains (losses) and other gains (losses) at a consolidated level.

12

Results of Operations (For the three months ended June 30)

Segment Information

						USA Operations								Canadian Operations
						2025				2024				2025				2024
Revenues
Product and service revenues (1)						$	1,118			$	1,424			$	646			$	425
Sales of purchased product (1)							396				314				54				30
Gains (losses) on risk management, net							9				31				24				38
Sublease revenues							-				-				-				-
Total Revenues							1,523				1,769				724				493
Operating Expenses
Production, mineral and other taxes							67				85				6				4
Transportation and processing (1)							115				143				320				270
Operating (1)							177				209				42				28
Purchased product (1)							395				312				45				21
Depreciation, depletion and amortization							370				498				180				76
Impairments							-				-				-				-
Total Operating Expenses							1,124				1,247				593				399
Operating Income (Loss)						$	399			$	522			$	131			$	94
						Corporate & Other								Consolidated
						2025				2024				2025				2024
Revenues
Product and service revenues (1)						$	-			$	-			$	1,764			$	1,849
Sales of purchased product (1)							-				-				450				344
Gains (losses) on risk management, net							54				8				87				77
Sublease revenues							17				18				17				18
Total Revenues							71				26				2,318				2,288
Operating Expenses
Production, mineral and other taxes							-				-				73				89
Transportation and processing (1)							-				-				435				413
Operating (1)							-				-				219				237
Purchased product (1)							-				-				440				333
Depreciation, depletion and amortization							6				6				556				580
Impairments							-				-				-				-
Accretion of asset retirement obligation							8				4				8				4
Administrative							76				76				76				76
Total Operating Expenses							90				86				1,807				1,732
Operating Income (Loss)						$	(19	)		$	(60	)			511				556
Other (Income) Expenses
Interest															95				105
Foreign exchange (gain) loss, net															22				(10	)
Other (gains) losses, net															(5	)			(5	)
Total Other (Income) Expenses															112				90
Net Earnings (Loss) Before Income Tax															399				466
Income tax expense (recovery)															92				126
Net Earnings (Loss)														$	307			$	340

(1)See above regarding the reclassification of the Company’s previously reported Market Optimization segment.

13

Results of Operations (For the six months ended June 30)

Segment Information

						USA Operations								Canadian Operations
						2025				2024				2025				2024
Revenues
Product and service revenues (1)						$	2,430			$	2,891			$	1,299			$	896
Sales of purchased product (1)							764				712				96				81
Gains (losses) on risk management, net							9				55				54				60
Sublease revenues							-				-				-				-
Total Revenues							3,203				3,658				1,449				1,037
Operating Expenses
Production, mineral and other taxes							150				165				10				7
Transportation and processing (1)							227				303				606				529
Operating (1)							346				425				78				55
Purchased product (1)							763				711				79				62
Depreciation, depletion and amortization							745				987				345				148
Impairments							-				-				730				-
Total Operating Expenses							2,231				2,591				1,848				801
Operating Income (Loss)						$	972			$	1,067			$	(399	)		$	236
						Corporate & Other								Consolidated
						2025				2024				2025				2024
Revenues
Product and service revenues (1)						$	-			$	-			$	3,729			$	3,787
Sales of purchased product (1)							-				-				860				793
Gains (losses) on risk management, net							8				(92	)			71				23
Sublease revenues							35				37				35				37
Total Revenues							43				(55	)			4,695				4,640
Operating Expenses
Production, mineral and other taxes							-				-				160				172
Transportation and processing (1)							-				-				833				832
Operating (1)							-				-				424				480
Purchased product (1)							-				-				842				773
Depreciation, depletion and amortization							11				11				1,101				1,146
Impairments							-				-				730				-
Accretion of asset retirement obligation							14				9				14				9
Administrative							169				178				169				178
Total Operating Expenses							194				198				4,273				3,590
Operating Income (Loss)						$	(151	)		$	(253	)			422				1,050
Other (Income) Expenses
Interest															192				203
Foreign exchange (gain) loss, net															32				(38	)
Other (gains) losses, net															(8	)			(9	)
Total Other (Income) Expenses															216				156
Net Earnings (Loss) Before Income Tax															206				894
Income tax expense (recovery)															58				216
Net Earnings (Loss)														$	148			$	678

(1)See above regarding the reclassification of the Company’s previously reported Market Optimization segment.

14

Capital Expenditures by Segment

						Three Months Ended								Six Months Ended
						June 30,								June 30,
						2025				2024				2025				2024
USA Operations						$	350			$	504			$	808			$	961
Canadian Operations							170				117				328				250
Corporate & Other							1				1				2				2
						$	521			$	622			$	1,138			$	1,213

Goodwill, Property, Plant and Equipment and Total Assets by Segment

		Goodwill								Property, Plant and Equipment								Total Assets
		As at								As at								As at
		June 30,				December 31,				June 30,				December 31,				June 30,				December 31,
		2025				2024				2025				2024				2025				2024
USA Operations		$	1,938			$	1,938			$	11,422			$	13,263			$	14,234			$	16,233
Canadian Operations			641				608				2,834				970				4,240				1,917
Corporate & Other			-				-				127				131				1,260				1,104
		$	2,579			$	2,546			$	14,383			$	14,364			$	19,734			$	19,254

4. Revenues from Contracts with Customers

The following table summarizes Ovintiv’s revenues from contracts with customers:

Revenues (For the three months ended June 30)

						USA Operations								Canadian Operations
						2025				2024				2025				2024
Revenues from Customers
Product revenues (1)
Oil						$	831			$	1,192			$	2			$	4
NGLs							177				176				367				271
Natural gas							104				55				274				150
Sales of purchased product (1)							396				314				54				30
Service revenues
Gathering and processing							6				1				3				-
						$	1,514			$	1,738			$	700			$	455
						Corporate & Other								Consolidated
						2025				2024				2025				2024
Revenues from Customers
Product revenues (1)
Oil						$	-			$	-			$	833			$	1,196
NGLs							-				-				544				447
Natural gas							-				-				378				205
Sales of purchased product (1)							-				-				450				344
Service revenues
Gathering and processing							-				-				9				1
						$	-			$	-			$	2,214			$	2,193

(1)See Note 3 regarding the reclassification of the Company’s previously reported Market Optimization segment.

15

Revenues (For the six months ended June 30)

						USA Operations								Canadian Operations
						2025				2024				2025				2024
Revenues from Customers
Product revenues (1)
Oil						$	1,806			$	2,373			$	4			$	5
NGLs							367				364				690				505
Natural gas							249				152				601				385
Sales of purchased product (1)							764				712				96				81
Service revenues
Gathering and processing							8				2				4				1
						$	3,194			$	3,603			$	1,395			$	977
						Corporate & Other								Consolidated
						2025				2024				2025				2024
Revenues from Customers
Product revenues (1)
Oil						$	-			$	-			$	1,810			$	2,378
NGLs							-				-				1,057				869
Natural gas							-				-				850				537
Sales of purchased product (1)							-				-				860				793
Service revenues
Gathering and processing							-				-				12				3
						$	-			$	-			$	4,589			$	4,580

(1)See Note 3 regarding the reclassification of the Company’s previously reported Market Optimization segment.

The Company’s revenues from contracts with customers consists of product sales including oil, NGLs and natural gas, sales of purchased product, as well as the provision of gathering and processing services to third parties. Ovintiv had no contract asset or liability balances during the periods presented. As at June 30, 2025, receivables and accrued revenues from contracts with customers were $819 million ($921 million as at December 31, 2024).

Ovintiv’s product sales are sold under short-term contracts with terms that are less than one year at either fixed or market index prices or under long-term contracts exceeding one year at market index prices.

The Company’s gathering and processing services are provided on an interruptible basis with transaction prices that are for fixed prices and/or variable consideration. Variable consideration received is related to recovery of plant operating costs or escalation of the fixed price based on a consumer price index. As the service contracts are interruptible, with service provided on an “as available” basis, there are no unsatisfied performance obligations remaining at June 30, 2025.

As at June 30, 2025, all remaining performance obligations are priced at market index prices or are variable volume delivery contracts. As such, the variable consideration is allocated entirely to the wholly unsatisfied performance obligation or promise to deliver units of production, and revenue is recognized at the amount for which the Company has the right to invoice the product delivered. As the period between when the product sales are transferred and Ovintiv receives payments is generally 30 to 60 days, there is no financing element associated with customer contracts. In addition, Ovintiv does not disclose unsatisfied performance obligations for customer contracts with terms less than 12 months or for variable consideration related to unsatisfied performance obligations.

16

5. Interest

		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2025				2024				2025				2024
Interest Expense on:
Debt		$	91			$	100			$	188			$	197
Finance leases			1				1				1				1
Other			3				4				3				5
		$	95			$	105			$	192			$	203

For the six months ended June 30, 2025, interest expense on debt includes $5 million of financing fees associated with two term facilities which were terminated in January 2025, following the closing of the Uinta divestiture and the Montney Acquisition as described in Note 8.

6. Foreign Exchange (Gain) Loss, Net

		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2025				2024				2025				2024
Unrealized Foreign Exchange (Gain) Loss on:
Translation of U.S. dollar risk management contracts issued from Canada		$	2			$	1			$	(85	)		$	7
Translation of intercompany notes			-				(6	)			42				(35	)
			2				(5	)			(43	)			(28	)
Foreign Exchange (Gain) Loss on Settlements of:
U.S. dollar financing debt issued from Canada			-				1				-				1
U.S. dollar risk management contracts issued from Canada			-				1				98				1
Intercompany notes			1				(6	)			(41	)			(8	)
Other Monetary Revaluations			19				(1	)			18				(4	)
		$	22			$	(10	)		$	32			$	(38	)

In 2024, the Company entered into $2.4 billion notional U.S. dollar denominated currency swaps at an average exchange rate of C$1.3825 to US$1 to manage the foreign exchange risk associated with the Montney Acquisition, which was denominated in Canadian dollars (see Note 8). In conjunction with the closing of the transaction, the Company settled the currency swaps and recognized a realized foreign exchange loss of approximately $97 million during the six months ended June 30, 2025.

7. Income Taxes

		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2025				2024				2025				2024
Current Tax
United States		$	1			$	10			$	12			$	24
Canada			25				13				57				31
Total Current Tax Expense (Recovery)			26				23				69				55
Deferred Tax
United States			63				77				159				135
Canada			3				26				(170	)			26
Total Deferred Tax Expense (Recovery)			66				103				(11	)			161
Income Tax Expense (Recovery)		$	92			$	126			$	58			$	216
Effective Tax Rate			23.1	%			27.0	%			28.2	%			24.2	%

17

Ovintiv’s interim income tax expense is determined using the estimated annual effective income tax rate applied to year-to-date net earnings before income tax plus the effect of legislative changes and amounts in respect of prior periods. The estimated annual effective income tax rate is impacted by expected annual earnings, changes in valuation allowances, income tax related to foreign operations, state taxes, the effect of legislative changes, non-taxable items and tax differences on transactions, which can produce interim effective tax rate fluctuations.

The effective tax rate of 23.1 percent for the three months ended June 30, 2025, is higher than the U.S. federal statutory rate of 21 percent primarily due to state tax.

The effective tax rate of 28.2 percent for the six months ended June 30, 2025, is higher than the U.S. federal statutory rate of 21 percent primarily due to the resolution of prior period tax items.

8. Acquisitions and Divestitures

		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2025				2024				2025				2024
Acquisitions
USA Operations		$	2			$	5			$	4			$	195
Canadian Operations			1				-				2,309				-
Total Acquisitions			3				5				2,313				195
Divestitures
USA Operations			(12	)			(2	)			(1,896	)			(4	)
Total Divestitures			(12	)			(2	)			(1,896	)			(4	)
Net Acquisitions & (Divestitures)		$	(9	)		$	3			$	417			$	191

Acquisitions

On January 31, 2025, the Company completed the acquisition of approximately 109,000 net acres in the core of the Montney formation from Paramount Resources Ltd. for total cash consideration of approximately $2.308 billion (C$3.328 billion), after preliminary closing adjustments (the “Montney Acquisition”). The Company funded the Montney Acquisition with cash on hand, including proceeds from the Uinta Basin divestiture as discussed below, and proceeds from short-term borrowings. The Montney Acquisition was accounted for as an asset acquisition as substantially all of the fair value of the assets acquired were concentrated in a single asset group, largely comprising proved oil and natural gas properties. The Company recognized the assets acquired in the Montney Acquisition at the purchase cost, including transaction costs, on a relative fair value basis. The Company recorded $2,292 million in proved properties, $162 million in unproved properties, $146 million related to asset retirement obligations, and $396 million in operating lease assets and lease liabilities related to a long-term midstream agreement for a natural gas processing facility.

For the three and six months ended June 30, 2024, acquisitions in the USA Operations were $5 million and $195 million, respectively, which primarily included property purchases in Permian with oil and liquids-rich potential.

Divestitures

For the three and six months ended June 30, 2025, divestitures in the USA Operations were $12 million and $1,896 million, respectively, which primarily included the sale of the Uinta Basin assets located in Utah for proceeds of approximately $1,882 million, after preliminary closing and other adjustments.

Amounts received from the Company’s divestiture transactions have been deducted from the U.S. full cost pool.

18

9. Property, Plant and Equipment, Net

		As at June 30, 2025												As at December 31, 2024
						Accumulated												Accumulated
		Cost				DD&A				Net				Cost				DD&A				Net
USA Operations
Proved properties		$	49,435			$	(38,515	)		$	10,920			$	50,246			$	(37,770	)		$	12,476
Unproved properties			478				-				478				741				-				741
Other			26				(2	)			24				48				(2	)			46
			49,939				(38,517	)			11,422				51,035				(37,772	)			13,263
Canadian Operations
Proved properties			19,413				(16,755	)			2,658				15,763				(14,821	)			942
Unproved properties			171				-				171				23				-				23
Other			10				(5	)			5				10				(5	)			5
			19,594				(16,760	)			2,834				15,796				(14,826	)			970
Corporate & Other			843				(716	)			127				807				(676	)			131
		$	70,376			$	(55,993	)		$	14,383			$	67,638			$	(53,274	)		$	14,364

USA and Canadian Operations’ property, plant and equipment include internal costs directly related to exploration, development and construction activities of $76 million, which have been capitalized during the six months ended June 30, 2025 (2024 - $99 million).

For the three months ended June 30, 2025, the Company did not recognize ceiling test impairments in the USA and Canadian Operations (2024 - nil). For the six months ended June 30, 2025, the Company recognized a before-tax non-cash ceiling test impairment in the Canadian Operations of $730 million (2024 - nil). The non-cash impairment is included with accumulated DD&A in the table above and primarily resulted from the 12-month average trailing prices used in the ceiling test at March 31, 2025, which were lower than the market prices used for the Montney Acquisition on January 31, 2025.

The 12-month average trailing prices used in the ceiling test calculations were based on the benchmark prices presented below. The benchmark prices were adjusted for basis differentials to determine local reference prices, transportation costs and tariffs, heat content and quality.

		Oil & NGLs								Natural Gas
						Edmonton
		WTI				Condensate				Henry Hub				AECO
		($/bbl)				(C$/bbl)				($/MMBtu)				(C$/MMBtu)
12-Month Average Trailing Reserves Pricing (1)
June 30, 2025		$	70.48			$	97.10			$	2.86			$	1.48
December 31, 2024			75.48				99.60				2.13				1.26
June 30, 2024			79.00				102.56				2.32				2.11

(1)All prices were held constant in all future years when estimating net revenues and reserves.

10. Leases

The following table outlines Ovintiv’s estimated future sublease income as at June 30, 2025. All subleases are classified as operating leases.

(undiscounted)		2025				2026				2027				2028				2029				Thereafter				Total
Sublease Income		$	27			$	53			$	48			$	42			$	38			$	329			$	537

For the three and six months ended June 30, 2025, operating lease income was $13 million and $26 million, respectively (2024 - $12 million and $26 million, respectively), and variable lease income was $4 million and $9 million, respectively (2024 - $6 million and $11 million, respectively).

19

11. Long-Term Debt

				As at				As at
				June 30,				December 31,
				2025				2024
U.S. Dollar Denominated Debt
Revolving credit and term loan borrowings				$	481			$	-
U.S. Unsecured Notes:
5.65% due May 15, 2025					-				600
5.375% due January 1, 2026					459				459
5.65% due May 15, 2028					700				700
8.125% due September 15, 2030					300				300
7.20% due November 1, 2031					350				350
7.375% due November 1, 2031					500				500
6.25% due July 15, 2033					600				600
6.50% due August 15, 2034					599				599
6.625% due August 15, 2037					390				390
6.50% due February 1, 2038					430				430
5.15% due November 15, 2041					148				148
7.10% due July 15, 2053					400				400
Total Principal					5,357				5,476
Increase in Value of Debt Acquired					13				16
Unamortized Debt Discounts and Issuance Costs					(37	)			(39	)
Total Long-Term Debt				$	5,333			$	5,453
Current Portion				$	940			$	600
Long-Term Portion					4,393				4,853
				$	5,333			$	5,453

As at June 30, 2025, the Company had outstanding commercial paper of $331 million maturing at various dates with a weighted average interest rate of approximately 5.03 percent. As at June 30, 2025, the Company also had $150 million drawn on its revolving credit facilities. The credit facilities are unsecured and bear interest at the lender’s U.S. base rate, Canadian prime, SOFR or CORRA, plus applicable margins.

As at June 30, 2025, total long-term debt had a carrying value of $5,333 million and a fair value of $5,532 million (as at December 31, 2024 - carrying value of $5,453 million and a fair value of $5,649 million). The estimated fair value of long-term borrowings is categorized within Level 2 of the fair value hierarchy and has been determined based on market information of long-term debt with similar terms and maturity, or by discounting future payments of interest and principal at interest rates expected to be available to the Company at period end.

12. Other Liabilities and Provisions

		As at				As at
		June 30,				December 31,
		2025				2024
Finance Lease Obligations		$	8			$	12
Unrecognized Tax Benefits			12				12
Pensions and Other Post-Employment Benefits			76				74
Reclamation and Take or Pay Commitments			28				7
Other			6				9
		$	130			$	114

20

13. Share Capital

Authorized

Ovintiv is authorized to issue 750 million shares of common stock, par value $0.01 per share, and 25 million shares of preferred stock, par value $0.01 per share. No shares of preferred stock are outstanding.

Issued and Outstanding

		As at								As at
		June 30, 2025								December 31, 2024
		Number								Number
		(millions)				Amount				(millions)				Amount
Shares of Common Stock Outstanding, Beginning of Year			260.4			$	3				271.7			$	3
Shares of Common Stock Purchased			(4.1	)			-				(12.7	)			-
Shares of Common Stock Issued			0.7				-				1.4				-
Shares of Common Stock Outstanding, End of Period			257.0			$	3				260.4			$	3

Ovintiv’s Performance Share Units (“PSU”) and Restricted Share Units (“RSU”) stock-based compensation plans allow the Company to settle the awards either in cash or in the Company’s common stock. Accordingly, Ovintiv issued 0.7 million shares of common stock during the six months ended June 30, 2025 (1.4 million shares of common stock during the twelve months ended December 31, 2024), as certain PSU and RSU grants vested during the period.

Normal Course Issuer Bid

On September 26, 2024, the Company announced it had received regulatory approval for the renewal of its NCIB program, which enables the Company to purchase, for cancellation or return to treasury, up to approximately 25.9 million shares of common stock over a 12-month period from October 3, 2024 to October 2, 2025.

During the three and six months ended June 30, 2025, the Company purchased approximately 4.1 million shares, respectively, under its 2024 NCIB program, for total consideration of approximately $147 million, respectively. Of the amounts paid during the same three and six month periods, $41 thousand, respectively, was charged to share capital and $147 million, respectively, was charged to paid in surplus.

During the three and six months ended June 30, 2024, the Company purchased approximately 3.6 million shares and 9.0 million shares, respectively, under its 2023 NCIB program which extended from October 3, 2023 to October 2, 2024, for total consideration of approximately $184 million and $434 million, respectively. Of the amounts paid during the same three and six month periods, $36 thousand and $90 thousand, respectively, were charged to share capital and $184 million and $434 million, respectively, were charged to paid in surplus.

For the twelve months ended December 31, 2024, the Company purchased approximately 12.7 million shares under its 2023 NCIB program for total consideration of approximately $597 million, of which $127 thousand was charged to share capital and $597 million was charged to paid in surplus.

All NCIB purchases were made in accordance with their respective programs at prevailing market prices plus brokerage fees, with consideration allocated to share capital up to the par value of the shares, with any excess allocated to paid in surplus.

Dividends

During the three months ended June 30, 2025, the Company declared and paid dividends of $0.30 per share of common stock totaling $77 million (2024 - $0.30 per share of common stock totaling $80 million).

During the six months ended June 30, 2025, the Company declared and paid dividends of $0.60 per share of common stock totaling $155 million (2024 - $0.60 per share of common stock totaling $160 million).

On July 24, 2025, the Board of Directors declared a dividend of $0.30 per share of common stock payable on September 29, 2025, to shareholders of record as of September 15, 2025.

21

Earnings Per Share of Common Stock

The following table presents the calculation of net earnings (loss) per share of common stock:

		Three Months Ended								Six Months Ended
		June 30,								June 30,
(US$ millions, except per share amounts)		2025				2024				2025				2024
Net Earnings (Loss)		$	307			$	340			$	148			$	678
Number of Shares of Common Stock:
Weighted average shares of common stock outstanding - Basic			259.0				266.2				259.7				267.9
Effect of dilutive securities			1.1				1.9				1.9				2.7
Weighted Average Shares of Common Stock Outstanding - Diluted			260.1				268.1				261.6				270.6
Net Earnings (Loss) per Share of Common Stock
Basic		$	1.19			$	1.28			$	0.57			$	2.53
Diluted			1.18				1.27				0.57				2.51

Stock-Based Compensation Plans

Shares issued as a result of awards granted from stock-based compensation plans are generally funded out of the common stock authorized for issuance as approved by the Company’s shareholders. As at June 30, 2025, the Company has sufficient common stock held in reserve for issuance in accordance with its equity-settled stock-based compensation plans.

14. Accumulated Other Comprehensive Income

		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2025				2024				2025				2024
Foreign Currency Translation Adjustment
Balance, Beginning of Period		$	739			$	924			$	731			$	1,000
Change in Foreign Currency Translation Adjustment			194				(31	)			202				(107	)
Balance, End of Period		$	933			$	893			$	933			$	893
Pension and Other Post-Employment Benefit Plans
Balance, Beginning of Period		$	45			$	49			$	46			$	50
Amounts Reclassified from Other Comprehensive Income:
Reclassification of net actuarial (gains) and losses to net earnings			(2	)			(2	)			(3	)			(3	)
Income taxes			1				-				1				-
Balance, End of Period		$	44			$	47			$	44			$	47
Total Accumulated Other Comprehensive Income		$	977			$	940			$	977			$	940

15. Variable Interest Entities

Veresen Midstream Limited Partnership

Veresen Midstream Limited Partnership (“VMLP”) provides gathering, compression and processing services under various agreements related to the Company’s development of liquids and natural gas production in the Montney play. As at June 30, 2025, VMLP provides approximately 1,152 MMcf/d of natural gas gathering and compression and 913 MMcf/d of natural gas processing under long-term service agreements with remaining terms ranging from six to 20 years and have various renewal terms providing up to a potential maximum of 10 years.

22

Ovintiv has determined that VMLP is a variable interest entity and that Ovintiv holds variable interests in VMLP. Ovintiv is not the primary beneficiary as the Company does not have the power to direct the activities that most significantly impact VMLP’s economic performance. These key activities relate to the construction, operation, maintenance and marketing of the assets owned by VMLP. The variable interests arise from certain terms under the various long-term service agreements and include: i) a take or pay for volumes in certain agreements; ii) an operating fee of which a portion can be converted into a fixed fee once VMLP assumes operatorship of certain assets; and iii) a potential payout of minimum costs in certain agreements. The potential payout of minimum costs will be assessed in the eighth year of the assets’ service period and is based on whether there is an overall shortfall of total system cash flows from natural gas gathered and compressed under certain agreements. The potential payout amount can be reduced in the event VMLP markets unutilized capacity to third-party users. Ovintiv is not required to provide any financial support or guarantees to VMLP.

As a result of Ovintiv’s involvement with VMLP, the maximum total exposure to loss related to the commitments under the agreements is estimated to be $892 million as at June 30, 2025. The estimate comprises the take or pay volume commitments and the potential payout of minimum costs. The take or pay volume commitments associated with certain gathering and processing assets are included in Note 21 under Transportation and Processing. The potential payout requirement is highly uncertain as the amount is contingent on future production estimates, pace of development and downstream transportation constraints. As at June 30, 2025, other liabilities and provisions, and accounts payable and accrued liabilities, included $21 million and $1 million, respectively, related to the take or pay commitment and payout of minimum costs.

16. Restructuring Charges

In 2024, Ovintiv undertook a plan to reduce its workforce by approximately 10 percent as part of a corporate reorganization. During the three and six months ended June 30, 2025, the Company incurred restructuring charges of $1 million and $11 million, respectively, before tax, related to severance costs (2024 - nil, respectively). Of the $38 million in restructuring charges incurred to date, $1 million remains accrued as at June 30, 2025 ($19 million as at December 31, 2024). The remaining amount accrued is expected to be paid in 2026.

Restructuring charges are included in administrative expense presented in the Corporate and Other segment in the Condensed Consolidated Statement of Earnings.

		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2025				2024				2025				2024
Severance and Outplacement		$	1			$	-			$	11			$	-
Restructuring Expenses		$	1			$	-			$	11			$	-

		As at				As at
		June 30,				December 31,
		2025				2024
Outstanding Restructuring Accrual, Beginning of Year		$	19			$	-
Restructuring Expenses Incurred			11				27
Restructuring Costs Paid			(29	)			(8	)
Outstanding Restructuring Accrual, End of Period (1)		$	1			$	19

(1)Included in accounts payable and accrued liabilities in the Condensed Consolidated Balance Sheet.

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17. Compensation Plans

As at June 30, 2025, the Company has sufficient common stock held in reserve for issuance in accordance with its equity-settled stock-based compensation plans.

The Company has recognized the following share-based compensation costs:

		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2025				2024				2025				2024
Total Compensation Costs of Transactions Classified as Cash-Settled		$	(2	)		$	(3	)		$	(1	)		$	2
Total Compensation Costs of Transactions Classified as Equity-Settled			21				24				37				48
Less: Total Share-Based Compensation Costs Capitalized			(5	)			(8	)			(9	)			(14	)
Total Share-Based Compensation Expense (Recovery)		$	14			$	13			$	27			$	36
Recognized in the Condensed Consolidated Statement of Earnings in:
Operating		$	6			$	5			$	9			$	13
Administrative			8				8				18				23
		$	14			$	13			$	27			$	36

As at June 30, 2025, the liability for cash-settled share-based payment transactions totaled $8 million ($10 million as at December 31, 2024), which is recognized in accounts payable and accrued liabilities in the Condensed Consolidated Balance Sheet.

The following weighted average assumptions were used to determine the fair value of Stock Appreciation Rights (“SAR”) and Tandem Stock Appreciation Rights (“TSAR”) units outstanding:

		As at June 30, 2025					As at June 30, 2024
		US$ SAR		C$ TSAR			US$ SAR		C$ TSAR
		Share Units		Share Units			Share Units		Share Units
Risk Free Interest Rate		2.60%		2.60%			4.04%		4.04%
Dividend Yield		3.15%		3.26%			2.56%		2.54%
Expected Volatility Rate (1)		43.36%		41.08%			48.63%		45.21%
Expected Term		0.6 yrs		0.6 yrs			1.0 yrs		1.0 yrs
Market Share Price		US$38.05		C$51.86			US$46.87		C$64.13
Weighted Average Grant Date Fair Value		US$34.67		C$46.75			US$40.91		C$54.84

(1)Volatility was estimated using historical rates.

The following units were granted primarily in conjunction with the Company’s annual grant of long-term incentive awards. The PSUs and RSUs were granted at the volume-weighted average trading price of shares of Ovintiv common stock for the five days prior to the grant date.

Six Months Ended June 30, 2025 (thousands of units)
RSUs			1,641
PSUs			593
DSUs (1)			6

(1)Deferred Share Units (“DSUs”)

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18. Fair Value Measurements

The fair values of cash and cash equivalents, accounts receivable and accrued revenues, and accounts payable and accrued liabilities approximate their carrying amounts due to the short-term maturity of those instruments. The fair values of restricted cash and marketable securities included in other assets approximate their carrying amounts due to the nature of the instruments held.

Recurring fair value measurements are performed for risk management assets and liabilities and other derivative contracts, as discussed further in Note 19. These items are carried at fair value in the Condensed Consolidated Balance Sheet and are classified within the three levels of the fair value hierarchy in the following tables.

Fair value changes and settlements for amounts related to risk management assets and liabilities are recognized in revenues and foreign exchange gains and losses according to their purpose.

As at June 30, 2025		Level 1 Quoted Prices in Active Markets				Level 2 Other Observable Inputs			Level 3 Significant Unobservable Inputs					Total Fair Value				Netting (1)				Carrying Amount
Risk Management Assets
Commodity Derivatives:
Current assets		$	3			$	104			$	-			$	107			$	(9	)		$	98
Long-term assets			-				3				-				3				(1	)			2
Risk Management Liabilities
Commodity Derivatives:
Current liabilities		$	-			$	16			$	-			$	16			$	(9	)		$	7
Long-term liabilities			-				15				2				17				(1	)			16
As at December 31, 2024		Level 1 Quoted Prices in Active Markets				Level 2 Other Observable Inputs			Level 3 Significant Unobservable Inputs					Total Fair Value				Netting (1)				Carrying Amount
Risk Management Assets
Commodity Derivatives:
Current assets		$	-			$	116			$	-			$	116			$	(6	)		$	110
Foreign Currency Derivatives:
Current assets			-				-				-				-				(2	)			(2	)
Risk Management Liabilities
Commodity Derivatives:
Current liabilities		$	-			$	26			$	-			$	26			$	(6	)		$	20
Long-term liabilities			-				21				-				21				-				21
Foreign Currency Derivatives:
Current liabilities			-				89				-				89				(2	)			87

(1)Netting to offset derivative assets and liabilities where the legal right and intention to offset exists, or where counterparty master netting arrangements contain provisions for net settlement.

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The Company’s Level 1 and Level 2 risk management assets and liabilities include contracts with terms to 2028, consisting of commodity fixed price contracts, WTI three-way options, NYMEX three-way options, basis swaps, a physical forward contract receiving a percentage of the Japan Korea Marker (“JKM”) index price and foreign currency swaps. The Company uses discounted cash flow and option-pricing models for fair valuing commodity derivatives. The fair value models use inputs such as contracted notional volumes, market future prices, maturities, credit adjusted risk free rates, and market-based implied volatility factors. The fair values of these contracts are estimated using inputs which are either directly or indirectly observable from active markets, such as exchange and other published prices, broker quotes and observable trading activity throughout the term of the instruments.

During the third quarter of 2024, the Company transferred its WTI three-way options from Level 3 into Level 2 as a result of the availability of more observable inputs, such as volatility and comparable contract terms, from independent active markets.

The three-way options are a combination of a sold call, a bought put and a sold put. These contracts allow the Company to participate in the upside of commodity prices to the ceiling of the call option and provide the Company with partial downside price protection through the put options.

Level 3 Fair Value Measurements

During the three months ended June 30, 2025, Ovintiv entered into a ten-year physical forward contract, with terms to 2037, to deliver 100 MMcf/d of natural gas volumes with a delivery point in Alberta and will receive the Chicago city-gates (“Chicago”) index price, less deducts. Delivery of natural gas volumes is expected to commence November 1, 2027. This contract is a derivative and is required to be measured at fair value each reporting period with changes in the fair value recorded in net earnings. The fair value of this contract is based on the discounted cash flow model using observable and unobservable inputs such as forward prices less deducts. The data used to develop the unobservable inputs are obtained from third parties whenever possible and reviewed by the Company for reasonableness.

A summary of changes in Level 3 fair value measurements for risk management positions is presented below:

		Six Months Ended
		June 30,
		2025				2024
Balance, Beginning of Year		$	-			$	16
Total Gains (Losses)			(2	)			(42	)
Purchases, Sales, Issuances and Settlements:
Purchases, sales and issuances			-				-
Settlements			-				9
Transfers Out of Level 3			-				-
Balance, End of Period		$	(2	)		$	(17	)
Change in Unrealized Gains (Losses) During the
Period Included in Net Earnings (Loss)		$	(2	)		$	(33	)

Quantitative information about unobservable inputs used in Level 3 fair value measurements is presented below as at June 30, 2025:

		Valuation Technique		Unobservable Inputs		Range		Weighted Average
Risk Management - Physical Forward Contract		Discounted Cash Flow Model		Forward Prices (1)		$0.64/Mcf - $2.45/Mcf		$1.12/Mcf

(1)Forward prices refers to the differential between Chicago and AECO forward prices.

A 10 percent increase or decrease in forward price differentials between Chicago and AECO for the physical forward contract would cause an approximate corresponding $22 million (nil as at December 31, 2024) increase or decrease to net risk management assets and liabilities.

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19. Financial Instruments and Risk Management

A) Financial Instruments

Ovintiv’s financial assets and liabilities are recognized in cash and cash equivalents, accounts receivable and accrued revenues, other assets, accounts payable and accrued liabilities, risk management assets and liabilities, long-term debt, and other liabilities and provisions.

B) Risk Management Activities

Ovintiv uses derivative financial instruments to manage its exposure to fluctuating commodity prices and foreign currency exchange rates. The Company does not apply hedge accounting to any of its derivative financial instruments. As a result, gains and losses from changes in the fair value are recognized in net earnings (loss).

Commodity Price Risk

Commodity price risk arises from the effect that fluctuations in future commodity prices may have on revenues from production. To partially mitigate exposure to commodity price risk, the Company has entered into various derivative financial instruments. The use of these derivative instruments is governed under formal policies and is subject to limits established by the Board of Directors.

Oil and NGLs - To partially mitigate oil and NGL commodity price risk, the Company uses WTI- and NGL-based contracts such as fixed price contracts and options.

Natural Gas - To partially mitigate natural gas commodity price risk, the Company uses NYMEX- and AECO- based contracts such as fixed price contracts and options. Ovintiv has also entered into forward contracts to partially manage against widening price differentials between various production areas and benchmark price points.

Foreign Exchange Risk

Foreign exchange risk arises from changes in foreign currency exchange rates that may affect the fair value or future cash flows from the Company’s financial assets or liabilities. To partially mitigate the effect of foreign exchange fluctuations on future commodity revenues and expenses, the Company may enter into foreign currency derivative contracts from time to time. As at June 30, 2025, the Company does not have any notional U.S. dollar denominated currency swaps.

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Risk Management Positions as at June 30, 2025

		Notional Volumes		Term		Average Price		Fair Value
Oil and NGL Contracts						US$/bbl
Fixed Price Contracts
Propane Fixed Price		10.0 Mbbls/d		2025		31.83		$	1
WTI Three-Way Options
Sold call / bought put / sold put		50.0 Mbbls/d		2025		78.58 / 65.00 / 50.00			28
Sold call / bought put / sold put		17.3 Mbbls/d		2026		71.73 / 62.15 / 51.79			10
Oil and NGLs Fair Value Position									39
Natural Gas Contracts						US$/Mcf
Fixed Price Contracts
AECO Fixed Price		50 MMcf/d		2026		2.35			-
NYMEX Three-Way Options
Sold call / bought put / sold put		500 MMcf/d		2025		4.47 / 3.00 / 2.25			(12	)
Sold call / bought put / sold put		462 MMcf/d		2026		6.46 / 3.33 / 2.61			(13	)
Basis Contracts (1)				2025					66
				2027					2
				2028					1
Physical Forward Contracts (2)				2026 - 2037					(6	)
Natural Gas Fair Value Position									38
Total Fair Value Position								$	77

(1)Ovintiv has entered into natural gas basis swaps associated with AECO and NYMEX.

(2)Ovintiv has entered into natural gas physical forward contracts associated with JKM (50 MMcf/d) and Chicago (100 MMcf/d), as described in Note 18.

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Earnings Impact of Realized and Unrealized Gains (Losses) on Risk Management Positions

		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2025				2024				2025				2024
Realized Gains (Losses) on Risk Management
Commodity and Other Derivatives:
Revenues (1)		$	33			$	69			$	63			$	115
Foreign Currency Derivatives:
Foreign exchange (2)			-				(1	)			(98	)			(1	)
		$	33			$	68			$	(35	)		$	114
Unrealized Gains (Losses) on Risk Management
Commodity and Other Derivatives:
Revenues (3)		$	54			$	8			$	8			$	(92	)
Foreign Currency Derivatives:
Foreign exchange			2				(2	)			89				(10	)
		$	56			$	6			$	97			$	(102	)
Total Realized and Unrealized Gains (Losses) on Risk Management, net
Commodity and Other Derivatives:
Revenues (1) (3)		$	87			$	77			$	71			$	23
Foreign Currency Derivatives:
Foreign exchange (2)			2				(3	)			(9	)			(11	)
		$	89			$	74			$	62			$	12

(1)There were no realized gains or losses related to other derivative contracts for the three and six months ended June 30, 2025 (2024 - gain of $4 million, respectively).

(2)Includes a realized foreign exchange loss of $97 million for the six months ended June 30, 2025, related to notional U.S. dollar denominated currency swaps as discussed in Note 6.

(3)There were no unrealized gains or losses related to other derivative contracts for the three and six months ended June 30, 2025 or 2024.

Reconciliation of Unrealized Risk Management Positions from January 1 to June 30

				2025								2024
				Fair Value				Total Unrealized Gain (Loss)				Total Unrealized Gain (Loss)
Fair Value of Contracts, Beginning of Year				$	(20	)
Change in Fair Value of Contracts in Place at Beginning of Year
and Contracts Entered into During the Period					62			$	62			$	12
Fair Value of Contracts Realized During the Period					35				35				(114	)
Fair Value of Contracts, End of Period				$	77			$	97			$	(102	)

Risk management assets and liabilities arise from the use of derivative financial instruments and are measured at fair value. See Note 18 for a discussion of fair value measurements.

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Unrealized Risk Management Positions

		As at				As at
		June 30,				December 31,
		2025				2024
Risk Management Assets
Current		$	98			$	108
Long-term			2				-
			100				108
Risk Management Liabilities
Current			7				107
Long-term			16				21
			23				128
Net Risk Management Assets (Liabilities)		$	77			$	(20	)

C) Credit Risk

Credit risk arises from the potential that the Company may incur a loss if a counterparty to a financial instrument fails to meet its obligation in accordance with agreed terms. While exchange-traded contracts are subject to nominal credit risk due to the financial safeguards established by the exchanges and clearing agencies, over-the-counter traded contracts expose Ovintiv to counterparty credit risk. Counterparties to the Company’s derivative financial instruments consist primarily of major financial institutions and companies within the energy industry. This credit risk exposure is mitigated through the use of credit policies approved by the Board of Directors governing the Company’s credit portfolio including credit practices that limit transactions according to counterparties’ credit quality. Mitigation strategies may include master netting arrangements, requesting collateral, purchasing credit insurance and/or transacting credit derivatives. The Company executes commodity derivative financial instruments under master agreements that have netting provisions that provide for offsetting payables against receivables. Ovintiv actively evaluates the creditworthiness of its counterparties, assigns appropriate credit limits and monitors credit exposures against those assigned limits. As at June 30, 2025, Ovintiv’s maximum exposure of loss due to credit risk from derivative financial instrument assets on a gross and net fair value basis was $110 million and $100 million, respectively, as disclosed in Note 18. The Company had no significant credit derivatives in place and held no collateral at June 30, 2025.

Any cash equivalents include high-grade, short-term securities, placed primarily with financial institutions with investment grade ratings. Any foreign currency agreements entered into are with major financial institutions that have investment grade credit ratings.

A substantial portion of the Company’s accounts receivable are with customers and working interest owners in the oil and gas industry and are subject to normal industry credit risks. As at June 30, 2025, approximately 94 percent (94 percent as at December 31, 2024) of Ovintiv’s accounts receivable and financial derivative credit exposures were with investment grade counterparties.

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20. Supplementary Information

Supplemental disclosures to the Condensed Consolidated Statement of Cash Flows are presented below:

A)Net Change in Non-Cash Working Capital

		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2025				2024				2025				2024
Operating Activities
Accounts receivable and accrued revenues		$	130			$	63			$	72			$	235
Accounts payable and accrued liabilities			(24	)			(9	)			(125	)			(301	)
Current portion of operating lease liabilities			6				6				26				(3	)
Income tax receivable and payable			(1	)			(23	)			18				(258	)
		$	111			$	37			$	(9	)		$	(327	)

B)Non-Cash Activities

		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2025				2024				2025				2024
Non-Cash Operating Activities
ROU operating lease assets and liabilities		$	(16	)		$	(25	)		$	(424	)		$	(33	)
Non-Cash Investing Activities
Property, plant and equipment accruals		$	(42	)		$	(17	)		$	27			$	(2	)
Capitalized long-term incentives			-				-				(4	)			(7	)
Property additions/dispositions, including swaps			6				14				33				31

21. Commitments and Contingencies

Commitments

The following table outlines the Company’s commitments as at June 30, 2025:

		Expected Future Payments
(undiscounted)		2025				2026				2027				2028				2029				Thereafter				Total
Transportation and Processing		$	399			$	798			$	679			$	529			$	447			$	1,916			$	4,768
Drilling and Field Services			141				65				2				-				-				-				208
Building Leases & Other Commitments			6				7				6				6				4				11				40
Total		$	546			$	870			$	687			$	535			$	451			$	1,927			$	5,016

Operating leases with terms greater than one year are not included in the commitments table above. The table above includes short-term leases with contract terms less than 12 months, such as drilling rigs and field office leases, as well as non-lease operating cost components associated with building leases.

Included within transportation and processing in the table above are certain commitments associated with midstream service agreements with VMLP as described in Note 15. Divestiture transactions can reduce certain commitments disclosed above.

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Contingencies

Ovintiv is involved in various legal claims and actions arising in the normal course of the Company’s operations. Although the outcome of these claims cannot be predicted with certainty, the Company does not expect these matters to have a material adverse effect on Ovintiv’s financial position, cash flows or results of operations. Management’s assessment of these matters may change in the future as these matters are subject to a number of uncertainties. For any material matters that the Company believes an unfavorable outcome is reasonably possible, the Company discloses the nature and a range of potential exposures, if reasonably estimable. If an unfavorable outcome were to occur, there exists the possibility of a material impact on the Company’s consolidated net earnings or loss for the period in which the effect becomes reasonably estimable. The Company accrues for such items when a liability is both probable and the amount can be reasonably estimated. Such accruals are based on the Company’s information known about the matters, estimates of the outcomes of such matters and experience in handling similar matters.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The MD&A is intended to provide a narrative description of the Company’s business from management’s perspective, which includes an overview of Ovintiv’s condensed consolidated results for the three and six months ended June 30, 2025, and period-over-period comparison. This MD&A should be read in conjunction with the unaudited interim Condensed Consolidated Financial Statements and accompanying notes for the period ended June 30, 2025 (“Consolidated Financial Statements”), which are included in Part I, Item 1 of this Quarterly Report on Form 10-Q and the audited Consolidated Financial Statements and accompanying notes and MD&A for the year ended December 31, 2024, which are included in Items 8 and 7, respectively, of the 2024 Annual Report on Form 10‑K.

Common industry terms and abbreviations are used throughout this MD&A and are defined in the Definitions, Conversions and Conventions sections of this Quarterly Report on Form 10-Q. This MD&A includes the following sections:

•Executive Overview

•Results of Operations

•Liquidity and Capital Resources

•Non-GAAP Measures

Executive Overview

Strategy

Ovintiv aims to be a leading North American energy producer and is focused on developing its high-quality multi-basin portfolio of oil and natural gas producing plays. Ovintiv is committed to delivering quality returns from its capital investment, generating significant cash flows and providing durable cash returns to its shareholders through the commodity price cycle. The Company aims to achieve its strategic priorities through execution excellence, disciplined capital allocation, and commercial acumen and risk management. In addition, the Company is dedicated to driving progress in areas of environmental, social, and governance, aligning with its commitment to corporate responsibility.

In support of the Company’s commitment to enhancing shareholder value, Ovintiv utilizes its capital allocation framework to provide competitive returns to shareholders while strengthening its balance sheet.

Ovintiv continually monitors and evaluates changing market conditions to maximize cash flows, mitigate risks and renew its premium well inventory. The Company’s high-quality assets, located in the United States and Canada, form a multi-basin, multi-product portfolio which enables flexible and efficient investment of capital that supports the Company’s strategy.

Ovintiv seeks to deliver results in a socially and environmentally responsible manner. Best practices are deployed across its assets, allowing the Company to capitalize on operational efficiencies and decrease emissions intensity. The Company’s sustainability reporting, which outlines its key metrics, targets and relative progress achieved, can be found in the Company Outlook section of this MD&A and on the Company’s sustainability website.

Underpinning Ovintiv’s strategy are core values of one, agile, innovative and driven, which guide the organization to be collaborative, responsive, flexible and determined. The Company is committed to excellence with a passion to drive corporate financial performance and shareholder value.

For additional information on Ovintiv’s strategy, its reporting segments and the plays in which the Company operates, refer to Items 1 and 2 of the 2024 Annual Report on Form 10-K.

In evaluating its operations and assessing its leverage, Ovintiv reviews performance-based measures such as Non‑GAAP Cash Flow and debt-based metrics such as Debt to Adjusted Capitalization, Debt to EBITDA and Debt to Adjusted EBITDA, which are non-GAAP measures and do not have any standardized meaning under U.S. GAAP. These measures may not be similar to measures presented by other issuers and should not be viewed as a substitute for measures reported under U.S. GAAP. Additional information regarding these measures, including reconciliations to the closest GAAP measure, can be found in the Non-GAAP Measures section of this MD&A.

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Highlights

During the first six months of 2025, the Company focused on executing its 2025 capital investment plan aimed at maximizing profitability through operational and capital efficiencies, and delivering cash from operating activities. In conjunction with closing the Montney Acquisition, as discussed below, the Company was also focused on integrating the new assets into its existing operations.

Lower upstream product revenues in the first six months of 2025 compared to 2024, primarily resulted from lower oil production volumes and lower realized oil and plant condensate prices, excluding the impact of risk management activities, partially offset by higher average realized natural gas prices, excluding the impact of risk management activities, and higher plant condensate production volumes. Oil production volumes decreased primarily as a result of the sale of the Company’s Uinta assets in the first quarter of 2025. Average realized oil and plant condensate prices decreased 12 percent and 10 percent, respectively, primarily due to lower benchmark prices. Higher realized average natural gas prices of 49 percent were primarily due to higher benchmark prices and exposure to other downstream benchmark prices. Plant condensate production volumes increased due to the Montney Acquisition in the first quarter of 2025. Ovintiv continues to focus on optimizing realized prices from the diversification of the Company’s downstream markets.

Significant Developments

•On January 31, 2025, the Company closed its previously announced acquisition of certain Montney assets from Paramount Resources Ltd. (“Paramount”), in an all-cash transaction of approximately $2.308 billion (C$3.328 billion), after preliminary closing adjustments (“Montney Acquisition”). The acquisition added approximately 109,000 net acres in the core of the liquids-rich Alberta Montney. The transaction had an effective date of October 1, 2024.

•On January 22, 2025, the Company closed its previously announced divestiture of substantially all of its Uinta assets, comprising approximately 126,000 net acres in the Uinta Basin of Utah, to FourPoint Resources, LLC, for approximately $1.9 billion, after preliminary closing and other adjustments. The transaction had an effective date of October 1, 2024.

Financial Results

Three months ended June 30, 2025

•Reported net earnings of $307 million, or $1.18 per share diluted, including net gains on risk management in revenues of $87 million, before tax.

•Generated cash from operating activities of $1,013 million and Non-GAAP Cash Flow of $913 million.

•Purchased for cancellation, approximately 4.1 million shares of common stock for total consideration of approximately $147 million.

•Paid dividends of $0.30 per share of common stock totaling $77 million.

Six months ended June 30, 2025

•Reported net earnings of $148 million, or $0.57 per share diluted, including a non-cash ceiling test impairment of $557 million, after tax, or $2.13 per share diluted.

•Recognized net gains on risk management in revenues of $71 million, before tax.

•Generated cash from operating activities of $1,886 million and Non-GAAP Cash Flow of $1,917 million.

•Purchased for cancellation, approximately 4.1 million shares of common stock for total consideration of approximately $147 million.

•Paid dividends of $0.60 per share of common stock totaling $155 million.

•Had approximately $3.2 billion in total liquidity as at June 30, 2025, which included available credit facilities of $3,350 million, available uncommitted demand lines of $132 million, and cash and cash equivalents of $20 million, net of outstanding commercial paper of $331 million.

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•Reported Debt to EBITDA of 1.6 times and Non-GAAP Debt to Adjusted EBITDA of 1.2 times.

Capital Investment

During the six months ended June 30, 2025

•Executed the Company’s 2025 capital plan with expenditures totaling $1,138 million.

•Focused on highly efficient capital activity to benefit from short-cycle high margin and/or low-cost projects which provide flexibility to respond to fluctuations in commodity prices, as discussed in the Company Outlook section of this MD&A.

Production

During the six months ended June 30, 2025

•Produced average liquids volumes of 300.6 Mbbls/d, which accounted for 50 percent of total production volumes. Average oil and plant condensate volumes of 208.5 Mbbls/d, represented 69 percent of total liquids production volumes.

•Produced average natural gas volumes of 1,807 MMcf/d, which accounted for 50 percent of total production volumes.

•Produced average total volumes of 601.9 MBOE/d.

Operating Expenses

During the six months ended June 30, 2025

•Incurred upstream transportation and processing expenses of $817 million or $7.50 per BOE, an increase of $53 million compared to 2024, primarily due to increased production volumes related to the Montney Acquisition in the first quarter of 2025.

•Incurred upstream operating expenses of $420 million or $3.86 per BOE, a decrease of $47 million compared to 2024, primarily due to the sale of the Company’s Uinta assets in the first quarter of 2025, partially offset by increased activity related to the Montney Acquisition in the first quarter of 2025.

•Incurred production, mineral and other taxes of $160 million, which represents approximately 4.3 percent of upstream product revenues. Total production, mineral and other taxes decreased by $12 million compared to 2024, primarily due to lower oil commodity prices and the sale of the Company’s Uinta assets in the first quarter of 2025.

Additional information on the items above and other expenses can be found in the Results of Operations section of this MD&A.

In 2024, Ovintiv reassessed its reportable segments and reclassified its Market Optimization segment to present the Company’s market optimization activities in their respective USA and Canadian operating segments, which they support (“Segment Reclassification”). Additional information on the Segment Reclassification can be found in Note 3 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

2025 Outlook

Industry Outlook

Oil and Natural Gas Markets

The oil and gas industry is cyclical and commodity prices are inherently volatile. Oil prices reflect global supply and demand dynamics as well as the geopolitical and macroeconomic environment.

Oil prices for the remainder of 2025 are expected to be impacted by the interplay between the pace of global economic growth and demand for oil, OPEC+ and non-OPEC+ production levels, and continued price volatility resulting from geopolitical events and macroeconomic uncertainties. Supply and the accumulation of global oil inventories are expected to be impacted by changes in geopolitical volatility, OPEC+ and non-OPEC+ production levels, and consumer demand behavior.

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Natural gas prices are primarily impacted by structural changes in supply and demand, deviations from seasonally normal weather, as well as volatility in regional markets.

Natural gas prices for the remainder of 2025 are expected to be impacted by the interplay between natural gas production and associated natural gas from oil production, changes in demand from the power generation sector, changes in export levels of U.S. and Canadian liquefied natural gas, impacts from seasonal weather, as well as supply chain constraints or other disruptions resulting from geopolitical events.

Political developments, including trade disputes and policy changes, continue to elevate global uncertainty and financial market volatility. U.S. sanctions and tariffs on select products may disrupt global supply and demand, leading to commodity price volatility. These actions can provoke retaliatory measures from other countries, further increasing economic volatility and the risk of a global recession.

Company Outlook

The Company will continue to exercise discretion and discipline, and intends to optimize capital allocation through the remainder of 2025 as the commodity price environment evolves. Ovintiv pursues innovative ways to maximize cash flows and reduce operating and administrative expenses.

Markets for oil and natural gas are exposed to different price risks and are inherently volatile. The Company enters into derivative financial instruments to mitigate price volatility and provide more certainty around cash flows. As at June 30, 2025, the Company has hedged approximately 50.0 Mbbls/d of expected oil and condensate production and 500 MMcf/d of expected natural gas production for the remainder of the year. In addition, Ovintiv proactively utilizes commodity derivatives and transportation contracts to diversify the Company’s sales markets, thereby reducing significant exposure to any given market and regional pricing.

Additional information on Ovintiv’s hedging program can be found in Note 19 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

Capital Investment

The Company continues to execute its 2025 capital investment program, focusing on maximizing returns from high-margin oil and condensate, and generating cash flows in excess of capital expenditures.

During the second quarter of 2025, the Company invested $521 million, which was lower than its second quarter guidance of $550 million to $600 million, primarily due to timing of projects. In July 2025, the Company reduced its full year 2025 capital investment guidance range to $2,125 million to $2,175 million.

Ovintiv continually strives to improve well performance and lower costs through innovative techniques. Ovintiv’s large-scale cube development model utilizes multi-well pads and advanced completion designs to maximize returns and resource recovery from its reservoirs. Ovintiv’s disciplined capital program and continuous innovation create flexibility to allocate capital in changing commodity markets to maximize cash flows while preserving the long-term value of the Company’s multi-basin portfolio.

Production

During the second quarter of 2025, total average production volumes were 615.3 MBOE/d, which exceeded the second quarter guidance range of 585.0 MBOE/d to 605.0 MBOE/d. Average oil and plant condensate production volumes were 211.2 Mbbls/d, average other NGL production volumes were 95.5 Mbbls/d and average natural gas production volumes were 1,851 MMcf/d, which exceeded second quarter guidance ranges of 202.0 Mbbls/d to 208.0 Mbbls/d, 87.0 Mbbls/d to 92.0 Mbbls/d and 1,775 MMcf/d to 1,825 MMcf/d, respectively.

In July 2025, the Company updated its full year 2025 total production guidance ranges to reflect strong well performance and the successful integration of the newly acquired Montney assets. The Company expects to meet its updated full year 2025 production guidance range of 600.0 MBOE/d to 620.0 MBOE/d, including oil and plant condensate production volumes of approximately 205.0 Mbbls/d to 209.0 Mbbls/d, other NGLs production volumes of approximately 93.0 Mbbls/d to 96.0 Mbbls/d and natural gas production volumes of approximately 1,825 MMcf/d to 1,875 MMcf/d.

36

Operating Expenses

Ovintiv promotes a collaborative culture that values knowledge exchange, open communication, continuous improvement and learning. This culture stimulates innovation and fosters the creation of best practices resulting in efficiency improvements and enhanced operational performance for the Company.

In July 2025, the Company updated its upstream operating expense guidance range to approximately $3.75 per BOE to $4.00 per BOE for the remainder of the year. The Company is on track to maintain full year upstream transportation and processing costs of approximately $7.50 per BOE to $8.00 per BOE and total production, mineral and other taxes of approximately 3.75 to 4.50 percent of upstream revenues.

Additional information on Ovintiv’s third quarter and full year 2025 Corporate Guidance can be accessed on the Company’s website at www.ovintiv.com.

Environmental, Social and Governance

Ovintiv recognizes the importance of implementing and maintaining sustainable practices to reduce its environmental footprint. The Company voluntarily participates in emission reduction programs and has adopted a range of strategies to help reduce emissions from its operations. These strategies include incorporating new and proven technologies, optimizing processes in its operations and working closely with third-party providers to develop best practices. The Company continues to look for innovative techniques and efficiencies in support of its commitment to emission reductions.

In May 2025, Ovintiv published its 2024 Sustainability Report. The report highlights the Company’s 2024 environmental, social and governance results, and its progress in emissions intensity reductions with the goal to meet its Scope 1&2 GHG emissions target by 2030. As at the end of 2024, the Company had achieved a greater than 45 percent reduction in the Scope 1&2 GHG emissions intensity from 2019 levels and expects to meet its emissions intensity reduction target of 50 percent by 2030 measured against the 2019 baseline. Ovintiv remains committed to its GHG emissions reduction target and has tied the target to the Company’s annual compensation program for all employees. In addition, Ovintiv continues to work towards eliminating routine flaring in its operations.

In conjunction with the Company’s strategy, Ovintiv may acquire assets to strengthen its multi-basin portfolio. Acquisitions are thoroughly assessed and evaluated for environmental impacts and alignment with the Company’s GHG emissions target. Ovintiv continues to work to integrate sustainable practices within the acquired operations to support company-wide sustainability objectives.

The Company’s social commitment framework, which is rooted in the Company’s foundational values of integrity, safety, sustainability, trust and respect, reflects Ovintiv’s positive contributions to the communities where it operates and highlights the Company’s approach to enabling an inclusive culture.

Ovintiv remains committed to protecting the health and safety of its workforce. Safety is a foundational value at Ovintiv and plays a critical role in the Company’s belief that a safe workplace is a strong indicator of a well-managed business. This safety-oriented mindset enables the Company to quickly respond to emergencies and minimize any impacts to employees and business continuity. Safety performance goals are incorporated into the Company’s annual compensation program. Additional information on talent management and employee safety can be found in the Human Capital section of Items 1 and 2 of the 2024 Annual Report on Form 10-K.

Additional information on Ovintiv’s sustainable business practices are included in its most recent Sustainability Report on the Company’s sustainability website at sustainability.ovintiv.com.

37

Results of Operations

Selected Financial Information

	Three months ended June 30,										Six months ended June 30,
($ millions)		2025				2024						2025				2024
Product and Service Revenues
Upstream product revenues (1)		$	1,755			$	1,848					$	3,717			$	3,784
Service revenues (2)			9				1						12				3
Total Product and Service Revenues			1,764				1,849						3,729				3,787
Sales of Purchased Product (1)			450				344						860				793
Gains (Losses) on Risk Management, Net			87				77						71				23
Sublease Revenues			17				18						35				37
Total Revenues			2,318				2,288						4,695				4,640
Total Operating Expenses (3)			1,807				1,732						4,273				3,590
Operating Income (Loss)			511				556						422				1,050
Total Other (Income) Expenses			112				90						216				156
Net Earnings (Loss) Before Income Tax			399				466						206				894
Income Tax Expense (Recovery)			92				126						58				216
Net Earnings (Loss)		$	307			$	340					$	148			$	678

(1)In conjunction with the Segment Reclassification as discussed in the Highlights section of this MD&A, prior period results have been reclassified for comparative purposes.

(2)Service revenues comprise third-party gathering and processing fees.

(3)Total Operating Expenses include non-cash items such as DD&A, impairments, accretion of asset retirement obligations and long-term incentive costs. The three and six months ended June 30, 2025, include non-cash ceiling test impairments of nil and $730 million, respectively (2024 - nil, respectively).

Revenues

Ovintiv’s revenues are substantially derived from sales of oil, NGLs and natural gas production. Increases or decreases in Ovintiv’s revenue, profitability and future production are highly dependent on the commodity prices the Company receives. Prices are market driven and fluctuate due to factors beyond the Company’s control, such as supply and demand, seasonality and geopolitical and economic factors. The Company’s realized prices generally reflect WTI, NYMEX, Edmonton Condensate and AECO benchmark prices, as well as other downstream benchmarks, including Houston and Dawn. The Company proactively mitigates price risk and optimizes margins by entering into firm transportation contracts to diversify market access to different sales points. Realized prices, excluding the impact of risk management activities, may differ from the benchmarks for many reasons, including quality, location, or production being sold at different market hubs.

Benchmark prices relevant to the Company are shown in the table below.

Benchmark Prices

		Three months ended June 30,										Six months ended June 30,
(average for the period)		2025				2024						2025				2024
Oil & NGLs
WTI ($/bbl)		$	63.74			$	80.57					$	67.58			$	78.77
Houston ($/bbl)			64.91				82.21						68.80				80.53
Edmonton Condensate (C$/bbl)			88.21				105.72						94.39				102.32
Natural Gas
NYMEX ($/MMBtu)		$	3.44			$	1.89					$	3.55			$	2.07
AECO (C$/Mcf)			2.07				1.44						2.05				1.74
Dawn (C$/MMBtu)			3.97				2.29						4.82				2.84

38

Production Volumes and Realized Prices

	Three months ended June 30,																	Six months ended June 30,
	Production Volumes (1)									Realized Prices (2)								Production Volumes (1)									Realized Prices (2)
	2025				2024					2025				2024				2025				2024					2025				2024
Oil (Mbbls/d, $/bbl)
USA Operations		141.6				166.8				$	64.50			$	78.20				146.0				168.5				$	68.24			$	77.18
Canadian Operations		0.4				0.5					63.42				74.86				0.3				0.3					66.40				74.07
Total		142.0				167.3					64.50				78.19				146.3				168.8					68.24				77.17
NGLs - Plant Condensate (Mbbls/d, $/bbl)
USA Operations		11.4				10.9					50.76				59.43				10.8				10.7					54.34				58.71
Canadian Operations		57.8				33.7					62.76				75.61				51.4				31.8					65.05				73.77
Total		69.2				44.6					60.79				71.66				62.2				42.5					63.18				69.96
NGLs - Other (Mbbls/d, $/bbl)
USA Operations		76.8				75.7					17.52				16.84				73.6				75.1					19.52				18.09
Canadian Operations		18.7				16.3					21.44				25.36				18.5				15.0					25.12				27.54
Total		95.5				92.0					18.28				18.35				92.1				90.1					20.64				19.67
Total Oil & NGLs (Mbbls/d, $/bbl)
USA Operations		229.8				253.4					48.11				59.09				230.4				254.3					52.03				58.94
Canadian Operations		76.9				50.5					52.73				59.35				70.2				47.1					54.54				59.03
Total		306.7				303.9					49.27				59.13				300.6				301.4					52.62				58.95
Natural Gas (MMcf/d, $/Mcf)
USA Operations		508				531					2.26				1.16				509				528					2.70				1.59
Canadian Operations		1,343				1,209					2.24				1.36				1,298				1,165					2.56				1.81
Total		1,851				1,740					2.24				1.30				1,807				1,693					2.60				1.74
Total Production (MBOE/d, $/BOE)
USA Operations		314.7				341.9					38.81				45.61				315.3				342.5					42.40				46.23
Canadian Operations		300.6				251.9					23.47				18.40				286.6				241.3					24.95				20.27
Total		615.3				593.8					31.32				34.08				601.9				583.8					34.10				35.49
Production Mix (%)
Oil & Plant Condensate		34				36													35				36
NGLs - Other		16				15													15				16
Total Oil & NGLs		50				51													50				52
Natural Gas		50				49													50				48
Production Change
Period Over Period (%) (3)
Total Oil & NGLs		1				7													-				13
Natural Gas		6				-													7				3
Total Production		4				4													3				8

(1)Average daily.

(2)Average per-unit prices, excluding the impact of risk management activities.

(3)Includes production impacts of acquisitions and divestitures.

39

Upstream Product Revenues, Excluding Realized Gains (Losses) on Risk Management

	Three months ended June 30,
($ millions)	Oil				NGLs - Plant Condensate				NGLs - Other				Natural Gas				Total
2024 Upstream Product Revenues (1)	$	1,196			$	293			$	154			$	205			$	1,848
Increase (decrease) due to:
Sales prices		(182	)			(80	)			(1	)			158				(105	)
Production volumes		(181	)			171				7				15				12
2025 Upstream Product Revenues	$	833			$	384			$	160			$	378			$	1,755
	Six months ended June 30,
($ millions)	Oil				NGLs - Plant Condensate				NGLs - Other				Natural Gas				Total
2024 Upstream Product Revenues (1)	$	2,378			$	545			$	324			$	537			$	3,784
Increase (decrease) due to:
Sales prices		(238	)			(95	)			10				277				(46	)
Production volumes		(330	)			262				11				36				(21	)
2025 Upstream Product Revenues	$	1,810			$	712			$	345			$	850			$	3,717

(1)In conjunction with the Segment Reclassification as discussed in the Highlights section of this MD&A, prior period results have been reclassified for comparative purposes.

Oil Revenues

Three months ended June 30, 2025 versus June 30, 2024

Oil revenues were lower by $363 million compared to the second quarter of 2024 primarily due to:

•A decrease of $13.69 per bbl, or 18 percent, in the average realized oil prices which decreased revenues by $182 million. The decrease reflected lower WTI and Houston benchmark prices which were both down 21 percent, partially offset by higher regional pricing relative to the benchmark prices; and

•Lower average oil production volumes of 25.3 Mbbls/d decreased revenues by $181 million. Lower production volumes were primarily due to the sale of the Uinta assets during the first quarter of 2025 (27.9 Mbbls/d), partially offset by successful drilling in Anadarko and Permian (3.9 Mbbls/d).

Six months ended June 30, 2025 versus June 30, 2024

Oil revenues were lower by $568 million compared to the first six months of 2024 primarily due to:

•Lower average oil production volumes of 22.5 Mbbls/d decreased revenues by $330 million. Lower production volumes were primarily due to the sale of the Uinta assets during the first quarter of 2025 (21.1 Mbbls/d); and

•A decrease of $8.93 per bbl, or 12 percent, in the average realized oil prices which decreased revenues by $238 million. The decrease reflected lower Houston and WTI benchmark prices which were down 15 percent and 14 percent, respectively, partially offset by higher regional pricing relative to the benchmark prices.

NGL Revenues

Three months ended June 30, 2025 versus June 30, 2024

NGL revenues were higher by $97 million compared to the second quarter of 2024 primarily due to:

•Higher average plant condensate production volumes of 24.6 Mbbls/d increased revenues by $171 million. Higher production volumes were primarily due to the Montney Acquisition in the first quarter of 2025 (22.0 Mbbls/d) and successful drilling in Montney (5.7 Mbbls/d), partially offset by lower production volumes in Montney related to increased third-party plant downtime (4.4 Mbbls/d); and

40

•A decrease of $10.87 per bbl, or 15 percent, in the average realized plant condensate prices which decreased revenues by $80 million. The decrease primarily reflected the lower Edmonton Condensate benchmark price which was down 17 percent.

Six months ended June 30, 2025 versus June 30, 2024

NGL revenues were higher by $188 million compared to the first six months of 2024 primarily due to:

•Higher average plant condensate production volumes of 19.7 Mbbls/d increased revenues by $262 million. Higher production volumes were primarily due to the Montney Acquisition in the first quarter of 2025 (18.4 Mbbls/d) and successful drilling in Montney (3.0 Mbbls/d), partially offset by lower production volumes in Montney related to increased third-party plant downtime (1.7 Mbbls/d); and

•A decrease of $6.78 per bbl, or 10 percent, in the average realized plant condensate prices which decreased revenues by $95 million. The decrease primarily reflected the lower Edmonton Condensate benchmark price which was down eight percent.

Natural Gas Revenues

Three months ended June 30, 2025 versus June 30, 2024

Natural gas revenues were higher by $173 million compared to the second quarter of 2024 primarily due to:

•An increase of $0.94 per Mcf, or 72 percent, in the average realized natural gas prices which increased revenues by $158 million. The increase reflected the higher NYMEX and AECO benchmark prices which were up 82 percent and 44 percent, respectively, and exposure to other downstream benchmark prices relating to the Company’s diversified markets in the Canadian Operations, partially offset by lower regional pricing relative to benchmark prices in the USA Operations; and

•Higher average natural gas production volumes of 111 MMcf/d increased revenues by $15 million. Higher production volumes were primarily due to the Montney Acquisition in the first quarter of 2025 (207 MMcf/d) and successful drilling in Montney and Permian (137 MMcf/d). The higher production volumes were partially offset by lower production volumes in Montney primarily related to pipeline restrictions and increased third-party plant downtime (102 MMcf/d), higher effective royalty rates in Montney (67 MMcf/d), the sale of the Uinta and Horn River assets in the first quarter of 2025 (31 MMcf/d), and natural declines in Anadarko (24 MMcf/d).

Six months ended June 30, 2025 versus June 30, 2024

Natural gas revenues were higher by $313 million compared to the first six months of 2024 primarily due to:

•An increase of $0.86 per Mcf, or 49 percent, in the average realized natural gas prices which increased revenues by $277 million. The increase reflected the higher NYMEX and AECO benchmark prices which were up 71 percent and 18 percent, respectively, and exposure to other downstream benchmark prices relating to the Company’s diversified markets in the Canadian Operations, partially offset by lower regional pricing relative to benchmark prices in the USA Operations; and

•Higher average natural gas production volumes of 114 MMcf/d increased revenues by $36 million. Higher production volumes were primarily due to the Montney Acquisition in the first quarter of 2025 (173 MMcf/d), and successful drilling in Montney and Permian (93 MMcf/d). The higher production volumes were partially offset by lower production volumes in Montney primarily related to pipeline restrictions and increased third-party plant downtime (69 MMcf/d), the sale of the Uinta and Horn River assets in the first quarter of 2025 (42 MMcf/d), natural declines in Anadarko (22 MMcf/d), and higher effective royalty rates in Montney (18 MMcf/d).

41

Sales of Purchased Product

Revenues from the sale of purchased product relate to activities that provide operational flexibility and cost mitigation for transportation commitments, product type, delivery points and customer diversification within the USA and Canadian Operations segments.

		Three months ended June 30,										Six months ended June 30,
($ millions)		2025				2024 (1)						2025				2024 (1)
Sales of Purchased Product		$	450			$	344					$	860			$	793

(1)In conjunction with the Segment Reclassification as discussed in the Highlights section of this MD&A, prior period results have been reclassified for comparative purposes.

Three months ended June 30, 2025 versus June 30, 2024

Sales of purchased product revenues increased $106 million compared to the second quarter of 2024 primarily due to:

•Higher sales of third-party purchased liquids volumes in the USA Operations ($280 million) and higher realized third-party natural gas pricing ($16 million);

partially offset by:

•Lower realized third-party liquids pricing ($189 million).

Six months ended June 30, 2025 versus June 30, 2024

Sales of purchased product revenues increased $67 million compared to the first six months of 2024 primarily due to:

•Higher sales of third-party purchased liquids volumes in the USA Operations ($319 million) and higher realized third-party natural gas pricing ($10 million);

partially offset by:

•Lower realized third-party liquids pricing ($258 million).

42

Gains (Losses) on Risk Management, Net

As a means of managing commodity price volatility, Ovintiv enters into commodity derivative financial instruments on a portion of its expected oil, NGLs and natural gas production volumes. Additional information on the Company’s commodity price positions as at June 30, 2025, can be found in Note 19 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

The following tables provide the effects of the Company’s risk management activities on revenues.

		Three months ended June 30,										Six months ended June 30,
($ millions)		2025				2024						2025				2024
Realized Gains (Losses) on Risk Management
Commodity Price
Oil		$	9			$	(25	)				$	9			$	(33	)
NGLs - Other			-				1						-				2
Natural Gas			24				89						54				142
Other (1)			-				4						-				4
Total			33				69						63				115
Unrealized Gains (Losses) on Risk Management			54				8						8				(92	)
Total Gains (Losses) on Risk Management, Net		$	87			$	77					$	71			$	23
		Three months ended June 30,										Six months ended June 30,
(Per-unit)		2025				2024						2025				2024
Realized Gains (Losses) on Risk Management
Commodity Price
Oil ($/bbl)		$	0.73			$	(1.61	)				$	0.35			$	(1.06	)
NGLs - Other ($/bbl)		$	-			$	0.12					$	-			$	0.12
Natural Gas ($/Mcf)		$	0.14			$	0.56					$	0.16			$	0.46
Total ($/BOE)		$	0.59			$	1.21					$	0.57			$	1.05

(1)Other primarily includes realized gains from other derivative contracts with no associated production volumes.

Ovintiv recognizes fair value changes from its risk management activities each reporting period. The changes in fair value result from new positions and settlements that occur during each period, as well as the relationship between contract prices and the associated forward curves. Realized gains or losses on risk management activities related to commodity price mitigation are included in the USA and Canadian Operations’ revenues as the contracts are cash settled. Unrealized gains or losses on fair value changes of unsettled contracts are included in the Corporate and Other segment.

During the second quarter of 2025, the Company entered into physical forward contracts to further mitigate a portion of its exposure to AECO benchmark prices. The Company’s ongoing market diversification strategy shifts a portion of its commodity price exposure to alternative pricing hubs including Japan Korea Marker and Chicago city-gates, commencing in 2026 and 2027, respectively.

Additional information on fair value changes and risk management contracts can be found in Notes 18 and 19, respectively, to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

Sublease Revenues

Sublease revenues primarily include amounts related to the sublease of office space in The Bow office building recorded in the Corporate and Other segment. Additional information on office sublease income can be found in Note 10 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

43

Operating Expenses

Production, Mineral and Other Taxes

Production, mineral and other taxes include production and property taxes. Production taxes are generally assessed as a percentage of oil, NGLs and natural gas production revenues. Property taxes are generally assessed based on the value of the underlying assets.

		Three months ended June 30,										Six months ended June 30,
($ millions)		2025				2024						2025				2024
USA Operations		$	67			$	85					$	150			$	165
Canadian Operations			6				4						10				7
Total		$	73			$	89					$	160			$	172
		Three months ended June 30,										Six months ended June 30,
($/BOE)		2025				2024						2025				2024
USA Operations		$	2.36			$	2.74					$	2.64			$	2.65
Canadian Operations		$	0.21			$	0.17					$	0.19			$	0.17
Production, Mineral and Other Taxes		$	1.31			$	1.65					$	1.47			$	1.62

Three months ended June 30, 2025 versus June 30, 2024

Production, mineral and other taxes decreased $16 million compared to the second quarter of 2024 primarily due to:

•The Uinta assets sold in the first quarter of 2025 ($11 million) and lower oil commodity prices ($10 million);

partially offset by:

•Higher property taxes due to the Montney Acquisition in the first quarter of 2025 ($2 million).

Six months ended June 30, 2025 versus June 30, 2024

Production, mineral and other taxes decreased $12 million compared to the first six months of 2024 primarily due to:

•Lower oil commodity prices ($14 million) and the Uinta assets sold in the first quarter of 2025 ($11 million);

partially offset by:

•Higher effective production tax rates ($4 million), higher property taxes primarily due to the Montney Acquisition in the first quarter of 2025 ($4 million) and production tax recoveries in Anadarko in 2024 ($4 million).

44

Transportation and Processing

Transportation and processing expense includes transportation costs incurred to move product from production points to sales points including gathering, compression, pipeline tariffs, trucking and storage costs. Ovintiv also incurs costs related to processing provided by third parties or through ownership interests in processing facilities.

		Three months ended June 30,										Six months ended June 30,
($ millions)		2025				2024						2025				2024
Upstream
USA Operations		$	114			$	126					$	226			$	253
Canadian Operations			312				260						591				511
Upstream Transportation and Processing			426				386						817				764
Other (1)			9				27						16				68
Total		$	435			$	413					$	833			$	832
		Three months ended June 30,										Six months ended June 30,
($/BOE)		2025				2024						2025				2024
USA Operations		$	4.01			$	4.05					$	3.96			$	4.06
Canadian Operations		$	11.40			$	11.37					$	11.38			$	11.65
Upstream Transportation and Processing		$	7.62			$	7.15					$	7.50			$	7.20

(1)The second quarter and first six months of 2025 include pipeline transportation fees associated with previously divested assets in the USA Operations of $1 million, respectively (2024 ‑ $17 million and $50 million, respectively) and other third-party transportation and processing fees with no associated volumes in the Canadian Operations of approximately $8 million and $15 million, respectively (2024 ‑ $10 million and $18 million, respectively).

Three months ended June 30, 2025 versus June 30, 2024

Transportation and processing expense increased $22 million compared to the second quarter of 2024 primarily due to:

•Higher production volumes due to the Montney Acquisition during the first quarter of 2025 ($71 million) and higher natural gas production volumes in Permian ($5 million);

partially offset by:

•An expired pipeline transportation contract ($17 million), the Uinta and Horn River assets sold in the first quarter of 2025 ($15 million), a third-party plant turnaround in Montney in 2024 ($8 million), lower midstream transportation costs in Montney ($6 million) and lower natural gas production volumes in Anadarko ($4 million).

Six months ended June 30, 2025 versus June 30, 2024

Transportation and processing expense increased $1 million compared to the first six months of 2024 primarily due to:

•Higher production volumes due to the Montney Acquisition during the first quarter of 2025 ($121 million) and higher natural gas production volumes in Permian ($10 million);

partially offset by:

•An expired pipeline transportation contract ($50 million), the Uinta and Horn River assets sold in the first quarter of 2025 ($32 million), a higher U.S./Canadian dollar exchange rate ($18 million), lower midstream transportation costs in Montney ($15 million), a third-party plant turnaround in Montney in 2024 ($8 million), and lower production volumes in Anadarko ($8 million).

45

Operating

Operating expense includes costs paid by the Company, net of amounts capitalized, on oil and natural gas properties in which Ovintiv has a working interest. These costs primarily include labor, service contract fees, chemicals, fuel, water hauling, electricity and workovers.

		Three months ended June 30,										Six months ended June 30,
($ millions)		2025				2024						2025				2024
Upstream
USA Operations		$	173			$	205					$	342			$	416
Canadian Operations			42				26						78				51
Upstream Operating Expense			215				231						420				467
Other			4				6						4				13
Total		$	219			$	237					$	424			$	480
		Three months ended June 30,										Six months ended June 30,
($/BOE)		2025				2024						2025				2024
USA Operations		$	6.03			$	6.58					$	5.99			$	6.67
Canadian Operations		$	1.56			$	1.18					$	1.52			$	1.19
Upstream Operating Expense		$	3.84			$	4.29					$	3.86			$	4.40

Three months ended June 30, 2025 versus June 30, 2024

Operating expense decreased $18 million compared to the second quarter of 2024 primarily due to:

•The sale of the Uinta assets in the first quarter of 2025 ($25 million), and decreased workover activity in Anadarko and Permian ($5 million);

partially offset by:

•Higher activity due to the Montney Acquisition in the first quarter of 2025 ($11 million).

Six months ended June 30, 2025 versus June 30, 2024

Operating expense decreased $56 million compared to the first six months of 2024 primarily due to:

•The sale of the Uinta assets in the first quarter of 2025 ($47 million), increased operational efficiencies in Permian ($12 million), decreased workover activity in Anadarko and Permian ($10 million), and lower salaries and benefits resulting from the corporate reorganization which commenced in 2024 ($8 million);

partially offset by:

•Higher activity due to the Montney Acquisition in the first quarter of 2025 ($17 million).

Purchased Product

Purchased product expense includes purchases of oil, NGLs and natural gas from third parties that are used to provide operational flexibility and cost mitigation for transportation commitments, product type, delivery points and customer diversification within the USA and Canadian Operations segments.

	Three months ended June 30,											Six months ended June 30,
($ millions)		2025				2024						2025				2024
Purchased Product		$	440			$	333					$	842			$	773

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Three months ended June 30, 2025 versus June 30, 2024

Purchased product expense increased $107 million compared to the second quarter of 2024 primarily due to:

•Higher third-party purchased liquids volumes in the USA Operations ($280 million) and higher third-party natural gas purchase prices ($17 million);

partially offset by:

•Lower third-party liquids purchase prices ($190 million).

Six months ended June 30, 2025 versus June 30, 2024

Purchased product expense increased $69 million compared to the first six months of 2024 primarily due to:

•Higher third-party purchased liquids volumes in the USA Operations ($319 million) and higher third-party natural gas purchase prices ($13 million);

partially offset by:

•Lower third-party liquids purchase prices ($260 million).

Depreciation, Depletion & Amortization

Proved properties within each country cost center are depleted using the unit-of-production method based on proved reserves as discussed in Note 1 to the Consolidated Financial Statements included in Item 8 of the 2024 Annual Report on Form 10-K. Depletion rates are impacted by impairments, acquisitions, divestitures and foreign exchange rates, as well as fluctuations in 12-month average trailing prices which affect proved reserves volumes. Corporate assets are carried at cost and depreciated on a straight-line basis over the estimated service lives of the assets.

Additional information can be found under Upstream Assets and Reserve Estimates in the Critical Accounting Estimates section of the MD&A included in Item 7 of the 2024 Annual Report on Form 10-K.

		Three months ended June 30,										Six months ended June 30,
($ millions)		2025				2024						2025				2024
Upstream
USA Operations		$	370			$	498					$	745			$	987
Canadian Operations			180				76						345				148
Upstream DD&A			550				574						1,090				1,135
Corporate & Other			6				6						11				11
Total		$	556			$	580					$	1,101			$	1,146
		Three months ended June 30,										Six months ended June 30,
($/BOE)		2025				2024						2025				2024
USA Operations		$	12.91			$	15.99					$	13.04			$	15.84
Canadian Operations		$	6.56			$	3.34					$	6.64			$	3.38
Upstream DD&A		$	9.81			$	10.62					$	10.00			$	10.69

Three months ended June 30, 2025 versus June 30, 2024

DD&A decreased $24 million compared to the second quarter of 2024 primarily due to:

•Lower depletion rates and production volumes in the USA Operations primarily due to the sale of the Uinta assets in the first quarter of 2025 ($88 million and $40 million, respectively);

partially offset by:

•Higher depletion rates and production volumes in the Canadian Operations primarily due to the Montney Acquisition in the first quarter of 2025 ($89 million and $15 million, respectively).

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The upstream depletion rate in the USA Operations decreased $3.08 per BOE primarily due to a lower depletable base resulting from the sale of the Uinta assets in the first quarter of 2025. The upstream depletion rate in the Canadian Operations increased $3.22 per BOE primarily due to a higher depletable base resulting from the Montney Acquisition in the first quarter of 2025, partially offset by the ceiling test impairments recognized in the fourth quarter of 2024 and first quarter of 2025.

Six months ended June 30, 2025 versus June 30, 2024

DD&A decreased $45 million compared to the first six months of 2024 primarily due to:

•Lower depletion rates and production volumes in the USA Operations primarily due to the sale of the Uinta assets in the first quarter of 2025 ($160 million and $82 million, respectively);

partially offset by:

•Higher depletion rates and production volumes in the Canadian Operations primarily due to the Montney Acquisition in the first quarter of 2025 ($175 million and $26 million, respectively).

The upstream depletion rate in the USA Operations decreased $2.80 per BOE primarily due to a lower depletable base resulting from the sale of the Uinta assets in the first quarter of 2025. The upstream depletion rate in the Canadian Operations increased $3.26 per BOE primarily due to a higher depletable base resulting from the Montney Acquisition in the first quarter of 2025, partially offset by the ceiling test impairments recognized in the fourth quarter of 2024 and first quarter of 2025.

Ceiling Test Impairment

Under full cost accounting, the carrying amount of Ovintiv’s oil and natural gas properties within each country cost center is subject to a ceiling test performed quarterly. Ceiling test impairments are recognized when the capitalized costs, net of accumulated depletion and the related deferred income taxes, exceed the sum of the estimated after-tax future net cash flows from proved reserves as calculated under SEC requirements using the 12-month average trailing prices and discounted at 10 percent. The 12‑month average trailing price is calculated as the average of the price on the first day of each month within the trailing 12‑month period.

In the second quarter and first six months of 2025, the Company recognized before-tax non-cash ceiling test impairments of nil and $730 million, respectively, in the Canadian Operations. The non-cash impairment recognized in the first quarter of 2025 primarily resulted from the 12-month average trailing prices used in the ceiling test at March 31, 2025, which were lower than the market prices used for the Montney Acquisition on January 31, 2025.

The 12-month average trailing prices used in the ceiling test calculations were based on the benchmark prices below. The benchmark prices were adjusted for basis differentials to determine local reference prices, transportation costs and tariffs, heat content and quality.

		Oil & NGLs								Natural Gas
		WTI ($/bbl)				Edmonton Condensate (C$/bbl)				Henry Hub ($/MMBtu)				AECO (C$/MMBtu)
12-Month Average Trailing Reserves Pricing (1)
June 30, 2025		$	70.48			$	97.10			$	2.86			$	1.48
December 31, 2024			75.48				99.60				2.13				1.26
June 30, 2024			79.00				102.56				2.32				2.11

(1)All prices were held constant in all future years when estimating net revenues and reserves.

Future declines in the 12‑month average trailing commodity prices could reduce proved reserves values and result in the recognition of future ceiling test impairments. Future ceiling test impairments can also result from changes to reserves estimates, future development costs, capitalized costs and unproved property costs. Proceeds received from oil and natural gas divestitures are typically deducted from the Company’s capitalized costs and can reduce the risk of ceiling test impairments.

The Company believes that the discounted after-tax future net cash flows from proved reserves required to be used in the ceiling test calculation are not indicative of the fair market value of Ovintiv’s oil and natural gas properties or the future net cash flows expected to be generated from such properties. The discounted after-tax future net cash flows do not consider the fair market

48

value of unamortized unproved properties, or probable or possible liquids and natural gas reserves. In addition, there is no consideration given to the effect of future changes in commodity prices. Ovintiv manages its business using estimates of reserves and resources based on forecast prices and costs. Additional information on the ceiling test calculation can be found in Note 9 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10‑Q.

Administrative

Administrative expense represents costs associated with corporate functions provided by Ovintiv staff. These expenses primarily include salaries and benefits, operating leases, office, information technology, restructuring and long-term incentive costs.

		Three months ended June 30,										Six months ended June 30,
($ millions)		2025				2024						2025				2024
Administrative, excluding Long-Term Incentive Costs,
Restructuring Costs, and Legal Costs (1)		$	67			$	69					$	139			$	144
Long-term incentive costs			8				8						18				23
Restructuring costs			1				-						11				-
Legal costs			-				(1	)					1				11
Total Administrative		$	76			$	76					$	169			$	178
		Three months ended June 30,										Six months ended June 30,
($/BOE)		2025				2024						2025				2024
Administrative, excluding Long-Term Incentive Costs,
Restructuring Costs, and Legal Costs (1)		$	1.19			$	1.28					$	1.28			$	1.34
Long-term incentive costs			0.15				0.14						0.17				0.22
Restructuring costs			0.03				-						0.10				-
Legal costs			-				(0.01	)					0.01				0.11
Total Administrative		$	1.37			$	1.41					$	1.56			$	1.67

(1)The second quarter and first six months of 2025 include costs related to The Bow office lease of $26 million and $54 million, respectively (2024 - $29 million and $58 million, respectively), half of which is recovered from sublease revenues.

Six months ended June 30, 2025 versus June 30, 2024

Administrative expense decreased $9 million compared to the first six months of 2024 primarily due to:

•Lower legal costs ($10 million) and lower long-term incentive costs ($5 million);

partially offset by:

•Restructuring costs incurred primarily related to the corporate reorganization which commenced in 2024 ($11 million).

In 2024, Ovintiv undertook a plan to reduce its workforce by approximately 10 percent as part of a corporate reorganization. Additional information on restructuring charges and long-term incentive costs can be found in Notes 16 and 17 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

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Other (Income) Expenses

		Three months ended June 30,										Six months ended June 30,
($ millions)		2025				2024						2025				2024
Interest		$	95			$	105					$	192			$	203
Foreign Exchange (Gain) Loss, Net			22				(10	)					32				(38	)
Other (Gains) Losses, Net			(5	)			(5	)					(8	)			(9	)
Total Other (Income) Expenses		$	112			$	90					$	216			$	156

Interest

Interest expense primarily includes interest on Ovintiv’s short-term and long-term debt. Additional information on changes in interest and long-term debt can be found in Notes 5 and 11, respectively, to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

Three months ended June 30, 2025 versus June 30, 2024

Interest expense decreased $10 million compared to the second quarter of 2024 primarily due to:

•Lower interest expense on short-term borrowings ($4 million) and lower interest expense resulting from the repayment of the Company’s $600 million senior note in the second quarter of 2025 ($4 million).

Six months ended June 30, 2025 versus June 30, 2024

Interest expense decreased $11 million compared to the first six months of 2024 primarily due to:

•Lower interest expense on short-term borrowings ($8 million) and lower interest expense resulting from the repayment of the Company’s $600 million senior note in the second quarter of 2025 ($4 million);

partially offset by:

•Financing fees incurred related to the termination of two term facilities following the closing of the Uinta divestiture and Montney Acquisition in the first quarter of 2025 ($5 million).

Foreign Exchange (Gain) Loss, Net

Foreign exchange gains and losses primarily result from the impact of fluctuations in the Canadian to U.S. dollar exchange rate. Additional information on changes in foreign exchange gains or losses can be found in Note 6 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q. Additional information on foreign exchange rates and the effects of foreign exchange rate changes can be found in Part I, Item 3 of this Quarterly Report on Form 10-Q.

Three months ended June 30, 2025 versus June 30, 2024

Net foreign exchange loss of $22 million compared to a gain of $10 million during the second quarter of 2024 primarily due to:

•Losses on other monetary revaluations compared to gains in 2024 ($20 million), realized foreign exchange losses on the settlement of intercompany notes compared to gains in 2024 ($7 million) and unrealized foreign exchange gains on the translation of intercompany notes in 2024 ($6 million).

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Six months ended June 30, 2025 versus June 30, 2024

Net foreign exchange loss of $32 million compared to a gain of $38 million during the first six months of 2024 primarily due to:

•Higher realized foreign exchange losses on the settlement of U.S. dollar risk management contracts issued from Canada ($97 million), unrealized foreign exchange losses on the translation of intercompany notes compared to gains in 2024 ($77 million) and losses on other monetary revaluations compared to gains in 2024 ($22 million);

partially offset by:

•Unrealized foreign exchange gains on the translation of U.S. dollar risk management contracts issued from Canada compared to losses in 2024 ($92 million) and higher realized foreign exchange gains on the settlement of intercompany notes ($33 million).

Other (Gains) Losses, Net

Other (gains) losses, net, primarily includes other non-recurring revenues or expenses and may also include items such as interest income, reclamation charges related to decommissioned assets, and adjustments related to other assets.

Other gains in the second quarter and first six months of 2025 includes interest income of $3 million and $8 million, respectively, primarily generated from short-term investments (2024 - $1 million and $3 million, respectively).

Income Tax

During the first six months of 2025, current income tax expense of $69 million was higher than the comparative period in 2024 primarily due to the resolution of prior period items in Canada in 2025.

During the second quarter of 2025, the deferred income tax expense of $66 million was lower than the comparative period in 2024 primarily due to lower earnings in 2025. During the first six months of 2025, the deferred income tax recovery was $11 million compared to an expense of $161 million in 2024 primarily due to the impact of the non-cash ceiling test impairment recognized in Canada in the first quarter of 2025.

The determination of income and other tax liabilities of the Company and its subsidiaries requires interpretation of complex domestic and foreign tax laws and regulations, that are subject to change. The Company’s interpretation of tax laws may differ from the interpretation of the tax authorities. As a result, there are tax matters under review for which the timing of resolution is uncertain. The Company believes that the provision for income taxes is adequate.

On July 4, 2025, the One Big Beautiful Bill Act (H.R.1) was signed into law, introducing reforms to U.S. tax policy, energy infrastructure, and environmental regulation. Ovintiv continues to assess the impact of this legislative change. The Company does not anticipate a significant impact in 2025, however it does anticipate additional tax benefits for 2026 and beyond.

Additional information on income taxes can be found in Note 7 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

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Liquidity and Capital Resources

Sources of Liquidity

The Company has the flexibility to access cash equivalents and a range of funding alternatives at competitive rates through committed revolving credit facilities as well as debt and equity capital markets. Ovintiv closely monitors the accessibility of cost-effective credit and ensures that sufficient liquidity is in place to fund capital expenditures and dividend payments. In addition, the Company may use cash and cash equivalents, cash from operating activities, or proceeds from asset divestitures to fund its operations and capital allocation framework or to manage its capital structure as discussed below. As at June 30, 2025, $16 million in cash and cash equivalents was held by Canadian subsidiaries. The cash held by Canadian subsidiaries is accessible and may be subject to additional U.S. income taxes and Canadian withholding taxes if repatriated.

The Company’s capital structure consists of total shareholders’ equity plus long-term debt, including any current portion. The Company’s objectives when managing its capital structure are to maintain financial flexibility to preserve Ovintiv’s access to capital markets and its ability to meet financial obligations and finance internally generated growth, as well as potential acquisitions. Ovintiv has a practice of maintaining capital discipline and strategically managing its capital structure by adjusting capital spending, adjusting dividends paid to shareholders, issuing new shares of common stock, purchasing shares of common stock for cancellation or return to treasury, issuing new debt and repaying or repurchasing existing debt.

		As at June 30,
($ millions, except as indicated)		2025				2024
Cash and Cash Equivalents		$	20			$	8
Available Credit Facilities			3,350				3,250
Available Uncommitted Demand Lines (1)			132				211
Issuance of U.S. Commercial Paper			(331	)			(384	)
Total Liquidity		$	3,171			$	3,085
Long-Term Debt, including current portion		$	5,333			$	6,087
Total Shareholders’ Equity		$	10,377			$	10,328
Debt to Capitalization (%) (2)			34				37
Debt to Adjusted Capitalization (%) (2)			23				25

(1)Includes three uncommitted demand lines totaling $312 million, net of $180 million in related undrawn letters of credit (2024 - $283 million and $72 million, respectively).

(2)These measures are defined in the Non-GAAP Measures section of this MD&A.

The Company has full access to two committed revolving U.S. dollar denominated credit facilities totaling $3.5 billion, which include a $2.2 billion revolving credit facility for Ovintiv Inc. and a $1.3 billion revolving credit facility for a Canadian subsidiary (collectively, the “Credit Facilities”). The Credit Facilities, which mature in December 2029, provide financial flexibility and allow the Company to fund its operations or capital investment program. As at June 30, 2025, $150 million was outstanding under the revolving Credit Facilities.

Depending on the Company’s credit rating and market demand, the Company may issue from its two U.S. Commercial Paper (“CP”) programs, which include a $1.5 billion program for Ovintiv Inc. and a $1.0 billion program for a Canadian subsidiary. As at June 30, 2025, the Company had $331 million of commercial paper outstanding under its U.S. CP program maturing at various dates with a weighted average interest rate of approximately 5.03 percent, which is supported by the Company’s Credit Facilities. All of Ovintiv’s credit ratings are investment grade as at June 30, 2025.

The available Credit Facilities, uncommitted demand lines, and cash and cash equivalents, net of outstanding commercial paper, provide Ovintiv with total liquidity of approximately $3.2 billion as at June 30, 2025. As at June 30, 2025, Ovintiv also had approximately $180 million in undrawn letters of credit issued in the normal course of business as collateral security.

Ovintiv has a U.S. shelf registration statement under which the Company may issue from time to time, debt securities, common stock, preferred stock, warrants, units, share purchase contracts and share purchase units in the U.S. The U.S. shelf registration statement expires in March 2026.

The obligations under the Company’s existing debt securities are fully and unconditionally guaranteed on a senior unsecured basis by Ovintiv Canada ULC, an indirect wholly-owned subsidiary of the Company. Additional information on the Company’s Canadian Operations segment and the Bow office lease can be found in the Results of Operations section in this MD&A and

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in the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q, and the MD&A and audited Consolidated Financial Statements and accompanying notes for the year ended December 31, 2024, which are included in Items 7 and 8, respectively, of the 2024 Annual Report on Form 10-K.

Ovintiv is currently in compliance with all financial covenants under the Credit Facilities. Management monitors Debt to Adjusted Capitalization, which is a non-GAAP measure defined in the Non-GAAP Measures section of this MD&A, as a proxy for Ovintiv’s financial covenant under the Credit Facilities, which requires Debt to Adjusted Capitalization to be less than 60 percent. As at June 30, 2025, the Company’s Debt to Adjusted Capitalization was 23 percent. The definitions used in the covenant under the Credit Facilities adjust capitalization for cumulative historical ceiling test impairments recorded in conjunction with the Company’s January 1, 2012 adoption of U.S. GAAP. Additional information on financial covenants can be found in Note 15 to the Consolidated Financial Statements included in Item 8 of the 2024 Annual Report on Form 10‑K.

Sources and Uses of Cash

The following table summarizes the sources and uses of the Company’s cash and cash equivalents.

				Three months ended June 30,										Six months ended June 30,
($ millions)	Activity Type			2025				2024						2025				2024
Sources of Cash and Cash Equivalents
Cash from operating activities	Operating			$	1,013			$	1,020					$	1,886			$	1,679
Proceeds from divestitures	Investing				12				2						1,896				4
Corporate acquisition	Investing				-				-						-				12
Net issuance of revolving debt	Financing				396				-						481				350
Other	Investing				-				-						102				-
					1,421				1,022						4,365				2,045
Uses of Cash and Cash Equivalents
Capital expenditures	Investing				521				622						1,138				1,213
Acquisitions	Investing				3				5						2,313				195
Net repayment of revolving debt	Financing				-				111						-				-
Repayment of long-term debt	Financing				600				-						600				-
Purchase of shares of common stock	Financing				147				184						147				434
Dividends on shares of common stock	Financing				77				80						155				160
Other	Investing/Financing				48				17						21				40
					1,396				1,019						4,374				2,042
Foreign Exchange Gain (Loss) on Cash, Cash Equivalents     and Restricted Cash Held in Foreign Currency					(13	)			-						(13	)			2
Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash				$	12			$	3					$	(22	)		$	5

Operating Activities

Net cash from operating activities in the second quarter and first six months of 2025 was $1,013 million and $1,886 million, respectively, and was primarily a reflection of the impacts from production volumes, average realized commodity prices, realized gains/losses on risk management and changes in non‑cash working capital.

Additional detail on changes in non-cash working capital can be found in Note 20 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q. Ovintiv expects it will continue to meet the payment terms of its suppliers.

Non-GAAP Cash Flow in the second quarter and first six months of 2025 was $913 million and $1,917 million, respectively, and was primarily impacted by the items affecting cash from operating activities which are discussed below and in the Results of Operations section of this MD&A.

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Three months ended June 30, 2025 versus June 30, 2024

Net cash from operating activities decreased $7 million compared to the second quarter of 2024 primarily due to:

•Lower realized liquids commodity prices ($263 million), lower oil production volumes ($181 million), lower realized gains on risk management in revenues ($36 million) and higher transportation and processing expense ($22 million);

partially offset by:

•Higher NGLs and natural gas production volumes ($193 million), higher realized natural gas commodity prices ($158 million), changes in non-cash working capital ($74 million), lower operating expense, excluding non-cash long-term incentive costs ($19 million), lower production, mineral and other taxes ($16 million), and lower interest expense ($8 million).

Six months ended June 30, 2025 versus June 30, 2024

Net cash from operating activities increased $207 million compared to the first six months of 2024 primarily due to:

•Changes in non-cash working capital ($318 million), higher NGLs and natural gas production volumes ($309 million), higher realized natural gas commodity prices ($277 million), lower operating expense, excluding non-cash long-term incentive costs ($59 million), lower production, mineral and other taxes ($12 million), lower administrative expense, excluding non-cash long-term incentive costs ($11 million) and lower interest expense ($10 million);

partially offset by:

•Lower oil production volumes ($330 million), lower realized liquids commodity prices ($323 million), higher realized foreign exchange losses on the settlement of U.S. dollar risk management contracts issued from Canada ($97 million), lower realized gains on risk management in revenues ($52 million) and an increase in current income tax expense ($14 million).

Investing Activities

Cash used in investing activities in the first six months of 2025 was $1,453 million primarily due to the Montney Acquisition and capital expenditures, partially offset by the sale of the Company’s Uinta assets. Capital expenditures, and acquisition and divestiture activities are summarized in Notes 3 and 8, respectively, to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10‑Q.

Capital expenditures decreased $75 million compared to the first six months of 2024, primarily due to decreased capital activity resulting from the sale of the Uinta assets in the first quarter of 2025, and decreased capital activity and increased efficiencies in Permian, partially offset by increased capital activity in Anadarko and increased capital activity in Montney due to the Montney Acquisition in the first quarter of 2025.

Acquisitions in the first six months of 2025 were $2,313 million, which primarily included the Montney Acquisition. Acquisitions in the first six months of 2024 were $195 million, which primarily included property purchases with oil and liquids-rich potential in the USA Operations.

Divestitures in the first six months of 2025 were $1,896 million, which primarily included the sale of the Uinta assets in Utah.

Additional information regarding the Montney Acquisition and the sale of the Uinta assets can be found in Note 8 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

Financing Activities

Net cash used in financing activities has been impacted by Ovintiv’s strategic objective to return value to shareholders by repaying existing debt, purchasing shares of common stock and paying dividends.

Net cash used in financing activities in the first six months of 2025 increased $168 million compared to 2024. The increase was primarily due to the repayment of the Company’s May 2025 senior notes during the second quarter of 2025 ($600 million), partially offset by decreased purchases of shares of common stock ($287 million) and an increase in the net issuance of revolving debt in 2025 compared to 2024 ($131 million).

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In May 2025, Ovintiv redeemed its $600 million, 5.65 percent senior notes due May 15, 2025, with cash on hand and proceeds from short-term borrowings. The Company’s long-term debt, including the current portion of $940 million, totaled $5,333 million at June 30, 2025. The Company’s long-term debt at December 31, 2024, including the current portion of $600 million, totaled $5,453 million. As at June 30, 2025, the Company has $459 million of fixed rate long-term debt due within the next year.

In support of the Company’s commitment to enhancing shareholder value, Ovintiv utilizes its capital allocation framework to provide competitive returns to shareholders while strengthening its balance sheet. Ovintiv resumed its share buyback program in the second quarter of 2025 following a temporary pause, as discussed below, and expects to continue to deliver shareholder returns through share buybacks.

For additional information on long-term debt, refer to Note 11 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q. Further details on the Company’s debt-based metrics can be found in the Non-GAAP measures section of this MD&A.

Dividends

The Company pays quarterly dividends to common shareholders at the discretion of the Board of Directors.

	Three months ended June 30,											Six months ended June 30,
($ millions, except as indicated)		2025				2024						2025				2024
Dividend Payments		$	77			$	80					$	155			$	160
Dividend Payments ($/share)		$	0.30			$	0.30					$	0.60			$	0.60

On July 24, 2025, the Board of Directors declared a dividend of $0.30 per share of common stock payable on September 29, 2025, to common shareholders of record as of September 15, 2025.

Normal Course Issuer Bid

On September 26, 2024, the Company announced it had received regulatory approval for the renewal of its NCIB program, which enables the Company to purchase, for cancellation or return to treasury, up to approximately 25.9 million shares of common stock over a 12-month period from October 3, 2024 to October 2, 2025. The Company expects to continue to execute the NCIB program in conjunction with its capital allocation framework.

The Company’s share buyback program was temporarily paused in the fourth quarter of 2024 to recover the transaction proceeds differential between the Montney Acquisition and the Uinta divestiture of $377 million. Following the recovery of the transaction proceeds differential, Ovintiv resumed its share buyback program under the NCIB in the second quarter of 2025 and purchased, for cancellation, approximately 4.1 million shares of common stock for total consideration of approximately $147 million. For additional information on the NCIB, refer to Note 13 to the Consolidated Financial Statements included in Part I, Item 1 and Part II, Item 2, “Unregistered Sales of Equity Securities and Use of Proceeds” of this Quarterly Report on Form 10‑Q.

Material Cash Requirements

For information on material cash requirements, refer to the Material Cash Requirements section of the MD&A included in Item 7 of the 2024 Annual Report on Form 10-K.

Commitments and Contingencies

For information on commitments and contingencies, refer to Note 21 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

Critical Accounting Estimates

There have been no significant changes to the Company’s critical accounting policies and use of estimates from the disclosures reported in the Critical Accounting Estimates section of the MD&A included in Item 7 of the 2024 Annual Report on Form 10‑K.

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Non-GAAP Measures

Certain measures in this document do not have any standardized meaning as prescribed by U.S. GAAP and, therefore, are considered non-GAAP measures. These measures may not be comparable to similar measures presented by other issuers and should not be viewed as a substitute for measures reported under U.S. GAAP. These measures are commonly used in the oil and gas industry and by Ovintiv to provide shareholders and potential investors with additional information regarding the Company’s liquidity and its ability to generate funds to finance its operations. Non-GAAP measures include: Non-GAAP Cash Flow, Debt to Adjusted Capitalization, Debt to EBITDA and Debt to Adjusted EBITDA. Management’s use of these measures is discussed further below.

Cash from Operating Activities and Non-GAAP Cash Flow

Non-GAAP Cash Flow is a non-GAAP measure defined as cash from (used in) operating activities excluding net change in other assets and liabilities, and net change in non-cash working capital.

Management believes this measure is useful to the Company and its investors as a measure of operating and financial performance across periods and against other companies in the industry, and is an indication of the Company’s ability to generate cash to finance capital investment programs, to service debt and to meet other financial obligations. This measure is used, along with other measures, in the calculation of certain performance targets for the Company’s management and employees.

		Three months ended June 30,										Six months ended June 30,
($ millions)		2025				2024						2025				2024
Cash From (Used in) Operating Activities		$	1,013			$	1,020					$	1,886			$	1,679
(Add back) deduct:
Net change in other assets and liabilities			(11	)			(42	)					(22	)			(54	)
Net change in non-cash working capital			111				37						(9	)			(327	)
Non-GAAP Cash Flow		$	913			$	1,025					$	1,917			$	2,060

Debt to Capitalization and Debt to Adjusted Capitalization

Debt to Adjusted Capitalization is a non-GAAP measure which adjusts capitalization for historical ceiling test impairments that were recorded as at December 31, 2011. Management monitors Debt to Adjusted Capitalization as a proxy for the Company’s financial covenant under the Credit Facilities which require Debt to Adjusted Capitalization to be less than 60 percent. Adjusted Capitalization includes debt, total shareholders’ equity and an equity adjustment for cumulative historical ceiling test impairments recorded as at December 31, 2011 in conjunction with the Company’s January 1, 2012, adoption of U.S. GAAP.

($ millions, except as indicated)		June 30, 2025				December 31, 2024
Debt (Long-Term Debt, including Current Portion)		$	5,333			$	5,453
Total Shareholders’ Equity			10,377				10,331
Capitalization		$	15,710			$	15,784
Debt to Capitalization		34%				35%
Debt (Long-Term Debt, including Current Portion)		$	5,333			$	5,453
Total Shareholders’ Equity			10,377				10,331
Equity Adjustment for Impairments at December 31, 2011			7,746				7,746
Adjusted Capitalization		$	23,456			$	23,530
Debt to Adjusted Capitalization		23%				23%

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Debt to EBITDA and Debt to Adjusted EBITDA

Debt to EBITDA and Debt to Adjusted EBITDA are non-GAAP measures. EBITDA is defined as trailing 12-month net earnings (loss) before income taxes, depreciation, depletion and amortization, and interest. Adjusted EBITDA is EBITDA adjusted for impairments, accretion of asset retirement obligation, unrealized gains/losses on risk management, foreign exchange gains/losses, gains/losses on divestitures and other gains/losses.

Management believes these measures are useful to the Company and its investors as a measure of financial leverage and the Company’s ability to service its debt and other financial obligations. These measures are used, along with other measures, in the calculation of certain financial performance targets for the Company’s management and employees.

($ millions, except as indicated)		June 30, 2025				December 31, 2024
Debt (Long-Term Debt, including Current Portion)		$	5,333			$	5,453
Net Earnings (Loss)			595				1,125
Add back (deduct):
Depreciation, depletion and amortization			2,245				2,290
Interest			401				412
Income tax expense (recovery)			68				226
EBITDA		$	3,309			$	4,053
Debt to EBITDA (times)			1.6				1.3
Debt (Long-Term Debt, including Current Portion)		$	5,333			$	5,453
Net Earnings (Loss)			595				1,125
Add back (deduct):
Depreciation, depletion and amortization			2,245				2,290
Impairments			1,180				450
Accretion of asset retirement obligation			24				19
Interest			401				412
Unrealized (gains) losses on risk management			36				136
Foreign exchange (gain) loss, net			51				(19	)
Other (gains) losses, net			(164	)			(165	)
Income tax expense (recovery)			68				226
Adjusted EBITDA		$	4,436			$	4,474
Debt to Adjusted EBITDA (times)			1.2				1.2

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Item 3: Quantitative and Qualitative Disclosures About Market Risk

The primary objective of the following information is to provide forward-looking quantitative and qualitative information about Ovintiv’s potential exposure to market risks. The term “market risk” refers to the Company’s risk of loss arising from adverse changes in oil, NGL and natural gas prices, foreign currency exchange rates and interest rates. The following disclosures are not meant to be precise indicators of expected future losses but rather indicators of reasonably possible losses. The forward-looking information provides indicators of how the Company views and manages ongoing market risk exposures.

COMMODITY PRICE RISK

Commodity price risk arises from the effect fluctuations in future commodity prices, including oil, NGLs and natural gas, may have on future revenues, expenses and cash flows. Realized pricing is primarily driven by the prevailing worldwide price for oil and spot market prices applicable to the Company’s natural gas production. Pricing for oil, NGLs and natural gas production is volatile and unpredictable as discussed in Part 1, Item 2 of this Quarterly Report on Form 10‑Q in the Executive Overview section in Management’s Discussion and Analysis of Financial Condition and Results of Operations and in Item 1A. “Risk Factors” of the 2024 Annual Report on Form 10‑K. To partially mitigate exposure to commodity price risk, the Company may enter into various derivative financial instruments including futures, forwards, swaps, options and costless collars. The use of these derivative instruments is governed under formal policies and is subject to limits established by the Board of Directors and may vary from time to time. Both exchange traded and over-the-counter traded derivative instruments may be subject to margin-deposit requirements, and the Company may be required from time to time to deposit cash or provide letters of credit with exchange brokers or counterparties to satisfy these margin requirements. For additional information relating to the Company’s derivative and financial instruments, see Notes 18 and 19 to the Condensed Consolidated Financial Statements under Part I, Item 1 of this Quarterly Report on Form 10‑Q.

The table below summarizes the sensitivity of the fair value of the Company’s risk management positions to fluctuations in commodity prices, with all other variables held constant. The Company has used a 10 percent variability to assess the potential impact of commodity price changes. Fluctuations in commodity prices could have resulted in unrealized gains (losses) impacting pre-tax net earnings as follows:

		June 30, 2025
(US$ millions)		10% Price Increase				10% Price Decrease
Oil price		$	(51	)		$	48
NGL price			(6	)			6
Natural gas price			(13	)			9

FOREIGN EXCHANGE RISK

Foreign exchange risk arises from changes in foreign exchange rates that may affect the fair value or future cash flows from the Company’s financial assets or liabilities. As Ovintiv operates primarily in the United States and Canada, fluctuations in the exchange rate between the U.S. and Canadian dollars can have a significant effect on the Company’s reported results.

The table below summarizes selected foreign exchange impacts on Ovintiv’s financial results when compared to the same periods in 2024.

		Three Months Ended June 30,								Six Months Ended June 30,
		$ millions				$/BOE				$ millions				$/BOE
Increase (Decrease) in:
Capital Investment		$	(1	)						$	(9	)
Transportation and Processing Expense (1)			(3	)		$	(0.05	)			(18	)		$	(0.17	)
Operating Expense (1)			-				-				(1	)			(0.02	)
Administrative Expense			(1	)			(0.01	)			(3	)			(0.02	)
Depreciation, Depletion and Amortization (1)			(1	)			(0.02	)			(5	)			(0.05	)

(1)Reflects upstream operations.

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Foreign exchange gains and losses also arise when monetary assets and monetary liabilities denominated in foreign currencies are translated and settled, and primarily include:

•U.S. dollar denominated financing debt issued from Canada

•U.S. dollar denominated risk management assets and liabilities held in Canada

•U.S. dollar denominated cash and short-term investments held in Canada

•Foreign denominated intercompany loans

To partially mitigate the effect of foreign exchange fluctuations on future commodity revenues and expenses, the Company may enter into foreign currency derivative contracts from time to time. As at June 30, 2025, the Company does not have any notional U.S. dollar denominated currency swaps.

As at June 30, 2025, Ovintiv did not have any U.S. dollar denominated financing debt issued from Canada that was subject to foreign exchange exposure.

The table below summarizes the sensitivity to foreign exchange rate fluctuations, with all other variables held constant. The Company has used a 10 percent variability to assess the potential impact from Canadian to U.S. foreign currency exchange rate changes. Fluctuations in foreign currency exchange rates could have resulted in unrealized gains (losses) impacting pre-tax net earnings as follows:

		June 30, 2025
(US$ millions)		10% Rate Increase				10% Rate Decrease
Foreign currency exchange		$	22			$	(27	)

INTEREST RATE RISK

Interest rate risk arises from changes in market interest rates that may affect the fair value or future cash flows from the Company’s financial assets or liabilities. The Company may partially mitigate its exposure to interest rate changes by holding a mix of both fixed and floating rate debt and may also enter into interest rate derivatives to partially mitigate effects of fluctuations in market interest rates.

As at June 30, 2025, Ovintiv had floating rate revolving credit and term loan borrowings of $481 million. Accordingly, on a before-tax basis, the sensitivity for each one percent change in interest rates on floating rate revolving credit and term loan borrowings was $5 million.

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Item 4: Controls and Procedures

DISCLOSURE CONTROLS AND PROCEDURES

Ovintiv’s Chief Executive Officer and Chief Financial Officer performed an evaluation of the effectiveness of the Company’s disclosure controls and procedures as defined in Rules 13a-15(e) and 15d-15(e) of the Exchange Act. The Company’s disclosure controls and procedures are designed to ensure that information required to be disclosed by the Company in reports it files or submits under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the rules and forms of the SEC, and to ensure that the information required to be disclosed by the Company in reports that it files or submits under the Exchange Act, is accumulated and communicated to the Company’s management, including the principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure. Based on this evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that the Company’s disclosure controls and procedures were effective as of June 30, 2025.

CHANGES IN INTERNAL CONTROL OVER FINANCIAL REPORTING

There were no changes in the Company’s internal controls over financial reporting during the second quarter of 2025 that have materially affected, or are reasonably likely to affect, the Company’s internal controls over financial reporting.

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PART II

Item 1. Legal Proceedings

Please refer to Item 3 of the 2024 Annual Report on Form 10‑K and Note 21 to the Condensed Consolidated Financial Statements under Part I, Item 1 of this Quarterly Report on Form 10‑Q.

Item 1A. Risk Factors

There have been no material changes to the risk factors previously disclosed in Item 1A., “Risk Factors” of our Annual Report on Form 10-K for the year ended December 31, 2024.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

Issuer Purchase of Equity Securities

On September 26, 2024, Ovintiv announced it had received regulatory approval to purchase, for cancellation or return to treasury, up to approximately 25.9 million shares of common stock pursuant to a NCIB over a 12-month period from October 3, 2024 and ending October 2, 2025. The number of shares of common stock authorized for purchase represents approximately 10 percent of Ovintiv’s issued and outstanding shares of common stock as at such time.

During the three months ended June 30, 2025, the Company purchased approximately 4.1 million shares of common stock for approximately $146 million, excluding excise tax, at a weighted average price of $35.92. The following table presents the common shares purchased during the three months ended June 30, 2025.

Period	Total Number of Shares Purchased (1)					Average Price Paid per Share (2)				Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs				Maximum Number of Shares That May Yet be Purchased Under the Plans or Programs
April 1 to April 30, 2025			1,234,753			$	32.40				1,234,753				24,685,792
May 1 to May 31, 2025			1,788,932				36.89				1,788,932				22,896,860
June 1 to June 30, 2025			1,041,415				38.41				1,041,415				21,855,445
Total			4,065,100			$	35.92				4,065,100				21,855,445

(1)For the three months ended June 30, 2025, 1,234,753 shares of common stock were repurchased through our broker in accordance with a Rule 10b5-1 compliant plan initially adopted by the Company on September 30, 2021.

(2)Includes commissions but excludes excise taxes.

In the second quarter of 2025, Ovintiv renewed its exemption order (the “NCIB Exemption”) from the Alberta Securities Commission and the Ontario Securities Commission, which permits Ovintiv to make repurchases (the “Proposed Bids”), under its current and any future normal course issuer bids, through the facilities of the NYSE and other U.S.-based trading systems (collectively, “U.S. Markets”), in excess of the maximum allowable purchases under applicable Canadian securities laws. The Company’s initial NCIB Exemption was granted in the first quarter of 2022. The NCIB Exemption applies to any Proposed Bid commenced within 36 months of the date of the exemption order and is subject to several other conditions, including that Ovintiv remain a U.S. and SEC foreign issuer under applicable Canadian securities laws. The purchases of common stock under a Proposed Bid must also be made in compliance with other applicable Canadian securities laws and applicable U.S. rules. Additionally, the NCIB Exemption imposes restrictions on the number of shares of common stock that may be acquired under the exemption, including that: (a) Ovintiv may not acquire common stock in reliance upon the exemption under subsection 4.8(3) of Canadian National Instrument 62-104 – Take-Over Bids and Issuer Bids (“NI 62-104”) from the requirements applicable to issuer bids (the “Other Published Markets Exemption”) if the aggregate number of shares of common stock purchased by Ovintiv, and any person or company acting jointly or in concert with Ovintiv, in reliance on the NCIB Exemption and the Other Published Markets Exemption within any period of 12 months exceeds 5 percent of the outstanding common stock on the first day of such 12-month period; and (b) the aggregate number of shares of common stock purchased pursuant to (i) a Proposed Bid in reliance on the NCIB Exemption; (ii) exempt issuer bid purchases made in the normal course through the facilities of the TSX; and (iii) the Other Published Markets Exemption does not exceed, over the 12-month period of its current NCIB, 10 percent of Ovintiv’s public float. As a result, the NCIB Exemption effectively allows Ovintiv to purchase up to 10 percent of its public float on U.S. Markets under its NCIB. Without the NCIB Exemption this amount would be limited to 5 percent of Ovintiv’s outstanding common stock within a 12-month period under applicable Canadian securities law.

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Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

None.

Item 6. Exhibits

Exhibit No		Description
31.1		Certification of Chief Executive Officer pursuant to Rule 13a-14(a) or 15d-14(a) of the Securities Exchange Act of 1934.
31.2		Certification of Chief Financial Officer pursuant to Rule 13a-14(a) or 15d-14(a) of the Securities Exchange Act of 1934.
32.1*		Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350.
32.2*		Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350.
101.INS		Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.SCH		Inline XBRL Taxonomy Extension Schema With Embedded Linkbases Document.
104		The cover page from the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2025, has been formatted in Inline XBRL.

* The certifications on Exhibits 32.1 and 32.2 hereto are deemed not “filed” for purposes of Section 18 of the Exchange Act or otherwise subject to the liability of that section. Such certifications will not be deemed incorporated by reference to any filings under the Securities Act or the Exchange Act.

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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.

Ovintiv Inc.
By:	/s/ Corey D. Code
	Name:		Corey D. Code
	Title:		Executive Vice-President & Chief Financial Officer

Dated: July 24, 2025

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FAQ

How did Ovintiv's Q2-25 revenue and earnings compare to last year?

Revenue rose slightly to $2.32 bn (+1%), while net income fell to $307 m (-10%), or $1.18 diluted EPS.

What is Ovintiv's current debt level?

At 30 Jun 25, total debt was $5.33 bn (current $940 m; long-term $4.39 bn), down ~$120 m from year-end.

How much free cash flow did OVV generate in Q2-25?

Operating cash flow of $1.01 bn minus capex of $521 m produced roughly $492 m in free cash.

What were the key portfolio changes in 2025?

OVV closed the C$3.3 bn Montney acquisition on 31 Jan 25 and completed the $1.88 bn Uinta Basin divestiture.

How much did Ovintiv return to shareholders in Q2-25?

The company paid $77 m in dividends ($0.30/sh) and repurchased $147 m of stock.

What was the effective tax rate for the quarter?

The Q2-25 effective tax rate was 23.1%, versus 27.0% in Q2-24.