Coterra Energy Inc. (NYSE:CTRA) ("Coterra" or the "Company") today reported second-quarter 2023 financial and operating results. Thomas E. Jorden, Chairman, Chief Executive Officer and President, commented, "Coterra continues to demonstrate outstanding operational execution, with a notable production beat this quarter driven primarily by strong well performance. As such we are increasing our 2023 BOE and natural gas production guidance by 2% and our oil guidance by 3%, at the mid-point. Coterra remains committed to maximizing shareholder value through consistent, profitable growth."

Second-Quarter 2023 Highlights

Net Income (GAAP) totaled $209 million, or $0.28 per share. Adjusted Net Income (non-GAAP) was $291 million, or $0.39 per share.
Cash Flow From Operating Activities (GAAP) totaled $646 million. Discretionary Cash Flow (non-GAAP) totaled $705 million.
Cash capital expenditures for drilling, completion and other fixed asset additions (GAAP) totaled $592 million. Accrued capital expenditures from drilling, completion and other fixed asset additions (non-GAAP) totaled $537 million, within our guidance range of $510 - $570 million.
Free Cash Flow (non-GAAP) totaled $113 million.
Unit operating cost totaled $8.27 per BOE (barrel of oil equivalent), within our annual guidance range of $7.30-$9.40 per BOE.
Total equivalent production of 665 MBoepd (thousand barrels of oil equivalent per day), exceeded the high-end of guidance (650 MBoepd), driven by strong well performance and improved cycle times in all three of our regions.
- Oil production averaged 95.8 MBopd (thousand barrels of oil per day), exceeding the high-end of guidance (91.5 MBopd).
- Natural gas production averaged 2,904 MMcfpd (million cubic feet per day), exceeding the high-end of guidance (2,850 MMcfpd).
- Natural Gas Liquids (NGLs) production averaged 85.0 MBoepd.
Realized average prices:
- Oil: $71.88 per Bbl (barrel), excluding the effect of commodity derivatives, and $72.17 per Bbl, including the effect of commodity derivatives
- Natural Gas: $1.65 per Mcf (thousand cubic feet), excluding the effect of commodity derivatives, and $1.95 per Mcf, including the effect of commodity derivatives
- Natural Gas Liquids (NGLs): $16.67 per BOE (barrel of oil equivalent)

Shareholder Return Highlights

Jorden noted, "Given that commodity prices were down more than 30% quarter-over-quarter, Coterra will return 184% of 2Q23 Free Cash Flow to shareholders, which is significantly above our minimum 50% return commitment, as our cash position has afforded us the luxury to transact counter-cyclically on share repurchases."

Common Dividend: On August 7, 2023, Coterra's Board of Directors (the "Board") approved a quarterly base dividend of $0.20 per share, which will be paid on August 31, 2023 to holders of record on August 17, 2023.
Share Repurchases: During the quarter, the Company repurchased 2.4 million shares for $57 million at an average price of $23.55 per share, leaving $1.7 billion remaining on the $2.0 billion share repurchase authorization as of June 30, 2023.
Total Shareholder Return: During the quarter, total shareholder return amounted to $208 million, comprised of $151 million of declared dividends and $57 million of share repurchases, representing 184% of Free Cash Flow. Year-to-date, total shareholder return amounted to $628 million, comprised of $303 million of declared dividends and $325 million of share repurchases, representing 94% of Free Cash Flow.
Reiterate Shareholder Return Strategy: Coterra remains committed to returning 50%+ of Free Cash Flow to shareholders through its $0.80/share annual dividend and share repurchases. Based on the share repurchases executed to date and expected declared dividends for the year, Coterra is on track to return at least 75% of currently forecasted Free Cash Flow.

Guidance Update and Activity Outlook:

Increasing full-year 2023 production guidance to the following:
- Total production volumes of 630-655 MBoepd; mid-point +2% from prior guidance
- Oil production of 91.0-94.0 MBopd; mid-point +3% from prior guidance
- Natural gas production of 2,750-2,900 MMcfpd; mid-point +2% from prior guidance
2023 capital budget (accrual basis) remains unchanged at $2.0 - $2.2 billion
Estimate 2023 Discretionary Cash Flow of approximately $3.4 billion, at recent strip prices
Estimate 2023 Free Cash Flow of approximately $1.2 billion, at recent strip prices

Third-quarter 2023 production and capital guidance:

Total production volumes of 625-655 MBoepd
Oil production of 88.0-91.0 MBopd
Natural gas production of 2,775-2,875 MMcfpd
Expect capital expenditures (accrual basis) of $540 – $610 million

Coterra is currently running six rigs and three completion crews in the Permian Basin, one rig and one completion crew in the Anadarko Basin, and two rigs and one completion crew in the Marcellus.

Strong Financial Position

Coterra maintains a strong financial position with an investment-grade credit rating and approximately $2.3 billion of liquidity. As of June 30, 2023, Coterra had total long-term debt of $2.2 billion with a principal amount of $2.1 billion. The company exited the quarter with a cash balance of $841 million, no debt outstanding under its $1.5 billion five-year revolving credit facility, and no near-term debt maturities. Coterra's net debt to trailing twelve months Adjusted EBITDAX ratio (non-GAAP) at June 30, 2023 was 0.2x.

Year-to-date 2023 Summary Highlights
Net Income (GAAP) totaled $886 million, or $1.16 per share. Adjusted Net Income (non-GAAP) totaled $953 million, or $1.25 per share.
Cash Flow From Operating Activities of $2,140 million. Discretionary Cash Flow (non-GAAP) totaled $1,744 million.
Cash capital expenditures for drilling, completion and other fixed asset additions (GAAP) totaled $1,075 million. Accrued capital expenditures for drilling, completion and other fixed asset additions (non-GAAP) totaled $1,105 million.
Free Cash Flow equaled $669 million (non-GAAP).

See "Supplemental non-GAAP Financial Measures" below for descriptions of the above non-GAAP measures as well as reconciliations of these measures to the associated GAAP measures.

Committed to Sustainability and ESG Leadership

Coterra is committed to environmental stewardship, sustainable practices, and strong corporate governance. The Company's sustainability report can be found under "A Sustainable Future" on www.coterra.com. Coterra plans to publish its 2023 Sustainability Report in the fourth quarter of 2023.

Second-Quarter 2023 Conference Call

Coterra will host a conference call tomorrow, Tuesday, August 8, 2023, at 9:00 AM CT (10:00 AM ET), to discuss second-quarter 2023 financial and operating results.

Conference Call Information

Date: August 8, 2023

Time: 10:00 AM ET / 9:00 AM CT

Dial-in (for callers in the U.S. and Canada): (888) 550-5424

International dial-in: (646) 960-0819

Conference ID: 3813676

The live audio webcast and related earnings presentation can be accessed on the "Events & Presentations" page under the "Investors" section of the Company's website at www.coterra.com. The webcast will be archived and available at the same location after the conclusion of the live event.

About Coterra Energy

Coterra is a premier exploration and production company based in Houston, Texas with focused operations in the Permian Basin, Marcellus Shale, and Anadarko Basin. We strive to be a leading energy producer, delivering sustainable returns through the efficient and responsible development of our diversified asset base. Learn more about us at www.coterra.com.

Cautionary Statement Regarding Forward-Looking Information

This press release contains certain forward-looking statements within the meaning of federal securities laws. Forward-looking statements are not statements of historical fact and reflect Coterra's current views about future events. Such forward-looking statements include, but are not limited to, statements about returns to shareholders, enhanced shareholder value, reserves estimates, future financial and operating performance and goals and commitment to sustainability and ESG leadership, strategic pursuits and goals, including with respect to the publication of Coterra's first Sustainability Report, and other statements that are not historical facts contained in this press release. The words "expect," "project," "estimate," "believe," "anticipate," "intend," "budget," "plan," "predict," "potential," "possible," "may," "should," "could," "would," "will," "strategy," "outlook" and similar expressions are also intended to identify forward-looking statements. We can provide no assurance that the forward-looking statements contained in this press release will occur as projected and actual results may differ materially from those projected. Forward-looking statements are based on current expectations, estimates and assumptions that involve a number of risks and uncertainties that could cause actual results to differ materially from those projected. These risks and uncertainties include, without limitation, the risk that the combined businesses will not be integrated successfully; the risk that the cost savings and any other synergies from the Merger may not be fully realized or may take longer to realize than expected; the volatility in commodity prices for crude oil and natural gas; cost increases; supply chain disruptions; the effect of future regulatory or legislative actions, including the risk of new restrictions with respect to well spacing, hydraulic fracturing, natural gas flaring, seismicity, produced water disposal, or other oil and natural gas development activities; disruption from the Merger making it more difficult to maintain relationships with customers, employees or suppliers; the diversion of management time on integration-related issues; the potential effects of further developments to the long-term impact of the COVID-19 pandemic and variants thereof on Coterra's business, financial condition and results of operations; actions by, or disputes among or between, the Organization of Petroleum Exporting Countries and other producer countries; market factors; market prices (including geographic basis differentials) of oil and natural gas; impacts of inflation; labor shortages and economic disruption (including as a result of the pandemic or geopolitical disruptions such as the war in Ukraine); determination of reserves estimates, adjustments or revisions, including factors impacting such determination such as commodity prices, well performance, operating expenses and completion of Coterra's annual PUD reserves process, as well as the impact on our financial statements resulting therefrom; the presence or recoverability of estimated reserves; the ability to replace reserves; environmental risks; drilling and operating risks; exploration and development risks; competition; the ability of management to execute its plans to meet its goals; and other risks inherent in Coterra's businesses. In addition, the declaration and payment of any future dividends, whether regular base quarterly dividends, variable dividends or special dividends, will depend on Coterra's financial results, cash requirements, future prospects and other factors deemed relevant by Coterra's Board. While the list of factors presented here is considered representative, no such list should be considered to be a complete statement of all potential risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. For additional information about other factors that could cause actual results to differ materially from those described in the forward-looking statements, please refer to Coterra's annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and other filings with the SEC, which are available on Coterra's website at www.coterra.com.

Forward-looking statements are based on the estimates and opinions of management at the time the statements are made. Except to the extent required by applicable law, Coterra does not undertake any obligation to publicly update or revise any forward-looking statement, whether as a result of new information, future events or otherwise. Readers are cautioned not to place undue reliance on these forward-looking statements that speak only as of the date hereof.

Operational Data
The tables below provide a summary of production volumes, price realizations and operational activity by region and units costs for the Company for the periods indicated:

	Quarter Ended June 30,				Six Months Ended June 30,
		2023		2022		2023		2022
PRODUCTION VOLUMES
Marcellus Shale
Natural gas (Bcf)		211.4		199.8		403.5		403.7
Equivalent production (MMBoe)		35.2		33.3		67.2		67.3
Daily equivalent production (MBoepd)		387.1		366.0		371.5		371.7

Permian Basin
Natural gas (Bcf)		37.0		38.9		75.5		76.4
Oil (MMBbl)		8.1		7.5		15.7		14.4
NGL (MMBbl)		5.9		5.6		11.7		10.4
Equivalent production (MMBoe)		20.2		19.6		40.0		37.5
Daily equivalent production (MBoepd)		222.9		215.0		221.2		207.4

Anadarko Basin
Natural gas (Bcf)		15.8		15.0		33.3		30.0
Oil (MMBbl)		0.6		0.5		1.3		1.1
NGL (MMBbl)		1.8		1.6		3.5		3.2
Equivalent production (MMBoe)		4.9		4.6		10.3		9.3
Daily equivalent production (MBoepd)		54.7		50.4		57.1		51.2

Total Company
Natural gas (Bcf)		264.3		253.9		512.4		510.3
Oil (MMBbl)		8.7		8.0		17.0		15.5
NGL (MMBbl)		7.7		7.2		15.2		13.6
Equivalent production (MMBoe)		60.5		57.5		117.7		114.2
Daily equivalent production (MBoepd)		664.9		631.7		650.1		630.8

AVERAGE SALES PRICE (excluding hedges)
Marcellus Shale
Natural gas ($/Mcf)	$	1.78	$	5.54	$	2.70	$	4.90

Permian Basin
Natural gas ($/Mcf)	$	0.92	$	6.51	$	1.16	$	5.51
Oil ($/Bbl)	$	71.71	$	109.25	$	72.80	$	101.67
NGL ($/Bbl)	$	15.36	$	38.23	$	18.85	$	37.70

Anadarko Basin
Natural gas ($/Mcf)	$	1.57	$	7.09	$	2.40	$	5.98
Oil ($/Bbl)	$	74.32	$	108.74	$	74.56	$	100.90
NGL ($/Bbl)	$	21.02	$	42.47	$	24.27	$	41.32

Total Company
Natural gas ($/Mcf)	$	1.65	$	5.78	$	2.46	$	5.05
Oil ($/Bbl)	$	71.88	$	109.23	$	72.93	$	101.62
NGL ($/Bbl)	$	16.67	$	39.17	$	20.11	$	38.55

	Quarter Ended June 30,				Six Months Ended June 30,
		2023		2022		2023		2022
AVERAGE SALES PRICE (including hedges)
Total Company
Natural gas ($/Mcf)	$	1.95	$	5.15	$	2.81	$	4.66
Oil ($/Bbl)	$	72.17	$	92.78	$	73.11	$	84.76
NGL ($/Bbl)	$	16.67	$	39.17	$	20.11	$	38.55

	Quarter Ended June 30,				Six Months Ended June 30,
		2023		2022		2023		2022
WELLS DRILLED⁽¹⁾
Gross wells
Marcellus Shale		16		20		36		42
Permian Basin		33		43		72		72
Anadarko Basin		11		10		17		13
		60		73		125		127

Net wells
Marcellus Shale		16.0		20.0		36.0		42.0
Permian Basin		21.3		21.8		37.9		39.8
Anadarko Basin		5.1		5.1		8.4		6.5
		42.4		46.9		82.3		88.3

TURN IN LINES
Gross wells
Marcellus Shale		20		18		45		30
Permian Basin		34		36		79		67
Anadarko Basin		3		1		7		8
		57		55		131		105

Net wells
Marcellus Shale		20.0		18.0		45.0		27.1
Permian Basin		19.1		13.9		42.2		29.8
Anadarko Basin		—		0.1		0.1		0.1
		39.1		32.0		87.3		57.0

	Quarter Ended June 30,				Six Months Ended June 30,
		2023		2022		2023		2022
AVERAGE UNIT COSTS ($/Boe)⁽²⁾
Direct operations	$	2.16	$	2.03	$	2.24	$	1.90
Transportation, processing and gathering		4.27		4.13		4.20		4.12
Taxes other than income		1.05		1.72		1.27		1.53
General and administrative (excluding stock-based compensation, severance expense and merger-related expense)		0.79		0.92		0.85		0.92
Unit Operating Cost	$	8.27	$	8.80	$	8.56	$	8.47
Depreciation, depletion and amortization		6.54		7.21		6.50		6.78
Exploration		0.09		0.12		0.08		0.11
Stock-based compensation		0.11		0.36		0.19		0.39
Merger-related expense		—		—		—		0.06
Severance expense		0.05		0.24		0.09		0.34
Interest expense		0.09		0.36		0.09		0.37
	$	15.15	$	17.09	$	15.51	$	16.52

_______________________________________________________________________________

(1)		Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled.
(2)		Total unit costs may differ from the sum of the individual costs due to rounding.

Derivatives Information
As of June 30, 2023, the Company had the following outstanding financial commodity derivatives:

	2023
Natural Gas	Third Quarter		Fourth Quarter
Waha gas collars
Volume (MMBtu)		8,280,000		8,280,000
Weighted average floor ($/MMBtu)	$	3.03	$	3.03
Weighted average ceiling ($/MMBtu)	$	5.39	$	5.39

NYMEX collars
Volume (MMBtu)		32,200,000		29,150,000
Weighted average floor ($/MMBtu)	$	4.07	$	4.03
Weighted average ceiling ($/MMBtu)	$	6.78	$	6.61

	2023
Oil	Third Quarter		Fourth Quarter
WTI oil collars
Volume (MBbl)		920		920
Weighted average floor ($/Bbl)	$	65.00	$	65.00
Weighted average ceiling ($/Bbl)	$	89.66	$	89.66

WTI Midland oil basis swaps
Volume (MBbl)		920		920
Weighted average differential ($/Bbl)	$	1.01	$	1.01

CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited)

	Quarter Ended June 30,						Six Months Ended June 30,
(In millions, except per share amounts)		2023			2022			2023			2022
OPERATING REVENUES
Natural gas	$	436		$	1,468		$	1,258		$	2,579
Oil		626			876			1,241			1,575
NGL		129			280			306			525
Gain (loss) on derivative instruments		(12	)		(66	)		126			(457	)
Other		6			14			31			29
		1,185			2,572			2,962			4,251
OPERATING EXPENSES
Direct operations		130			116			264			216
Transportation, processing and gathering		258			238			494			471
Taxes other than income		63			98			149			174
Exploration		5			7			9			13
Depreciation, depletion and amortization		395			414			764			774
General and administrative (excluding stock-based compensation, severance expense and merger-related expense)		48			52			100			104
Stock-based compensation⁽¹⁾		7			21			23			44
Merger-related expense		—			—			—			7
Severance expense		3			14			11			39
		909			960			1,814			1,842
Gain (loss) on sale of assets		—			(3	)		5			(1	)
INCOME FROM OPERATIONS		276			1,609			1,153			2,408
Interest expense		16			22			33			43
Interest income		(10	)		(1	)		(22	)		(1	)
Income before income taxes		270			1,588			1,142			2,366
Income tax expense		61			359			256			529
NET INCOME	$	209		$	1,229		$	886		$	1,837
Earnings per share - Basic	$	0.28		$	1.53		$	1.16		$	2.28
Weighted-average common shares outstanding		755			803			760			806

_______________________________________________________________________________

(1)

Includes the impact of our performance share awards and restricted stock.

CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited)

(In millions)	June 30, 2023		December 31, 2022
ASSETS
Current assets	$	1,640	$	2,211
Properties and equipment, net (successful efforts method)		17,801		17,479
Other assets		438		464
	$	19,879	$	20,154

LIABILITIES, REDEEMABLE PREFERRED STOCK AND STOCKHOLDERS' EQUITY
Current liabilities	$	941	$	1,193
Long-term debt, net (excluding current maturities)		2,171		2,181
Deferred income taxes		3,367		3,339
Other long term liabilities		733		771
Cimarex redeemable preferred stock		8		11
Stockholders' equity		12,659		12,659
	$	19,879	$	20,154

CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited)

	Quarter Ended June 30,						Six Months Ended June 30,
(In millions)		2023			2022			2023			2022
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	209		$	1,229		$	886		$	1,837
Depreciation, depletion and amortization		395			414			764			774
Deferred income tax expense		4			65			27			101
(Gain) loss on sale of assets		—			3			(5	)		1
(Gain) loss on derivative instruments		12			66			(126	)		457
Net cash received (paid) in settlement of derivative instruments		84			(293	)		184			(464	)
Stock-based compensation and other		7			18			24			38
Income charges not requiring cash		(6	)		(9	)		(10	)		(19	)
Changes in assets and liabilities		(59	)		(614	)		396			(524	)
Net cash provided by operating activities		646			879			2,140			2,201

CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures for drilling, completion and other fixed asset additions		(592	)		(471	)		(1,075	)		(741	)
Capital expenditures for leasehold and property acquisitions		(5	)		(3	)		(6	)		(4	)
Proceeds from sale of assets		28			2			33			4
Net cash used in investing activities		(569	)		(472	)		(1,048	)		(741	)

CASH FLOWS FROM FINANCING ACTIVITIES
Repayment of finance leases		(1	)		(1	)		(3	)		(3	)
Common stock repurchases		(57	)		(303	)		(325	)		(487	)
Dividends paid		(152	)		(484	)		(588	)		(940	)
Tax withholding on vesting of stock awards		—			(1	)		(1	)		(7	)
Capitalized debt issuance costs		—			—			(7	)		—
Cash received for stock option exercises		—			4			—			10
Cash paid for conversion of redeemable preferred stock		—			(10	)		(1	)		(10	)
Net cash used in financing activities		(210	)		(795	)		(925	)		(1,437	)
Net increase (decrease) in cash, cash equivalents and restricted cash	$	(133	)	$	(388	)	$	167		$	23

Supplemental Non-GAAP Financial Measures (Unaudited)

We report our financial results in accordance with accounting principles generally accepted in the United States (GAAP). However, we believe certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results and results of prior periods. In addition, we believe these measures are used by analysts and others in the valuation, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. See the reconciliations below that compare GAAP financial measures to non-GAAP financial measures for the periods indicated.

We have also included herein certain forward-looking non-GAAP financial measures. Due to the forward-looking nature of these non-GAAP financial measures, we cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in capital. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking non-GAAP financial measures to their most directly comparable forward-looking GAAP financial measures. Reconciling items in future periods could be significant.

Present Value Index (PVI10) is often used by management as a return-on-investment metric and defined as the estimated net present value (using a 10% discount rate) of the future net cash flows from such reserves (for which we utilize certain assumptions regarding future commodity prices and operating costs), adding back our direct net costs incurred in drilling and adding back our completing, constructing facilities, and flowing back such wells, and then dividing that sum by our direct net costs incurred in drilling, completing, constructing facilities, and flowing back such wells.

Reconciliation of Net Income to Adjusted Net Income and Adjusted Earnings Per Share

Adjusted Net Income and Adjusted Earnings per Share are presented based on our management's belief that these non-GAAP measures enable a user of financial information to understand the impact of identified adjustments on reported results. Adjusted Net Income is defined as net income plus gain and loss on sale of assets, non-cash gain and loss on derivative instruments, stock-based compensation expense, severance expense, merger-related expenses and tax effect on selected items. Adjusted Earnings per Share is defined as Adjusted Net Income divided by weighted-average common shares outstanding. Additionally, we believe these measures provide beneficial comparisons to similarly adjusted measurements of prior periods and use these measures for that purpose. Adjusted Net Income and Adjusted Earnings per Share are not measures of financial performance under GAAP and should not be considered as alternatives to net income and earnings per share, as defined by GAAP.

	Quarter Ended June 30,						Six Months Ended June 30,
(In millions, except per share amounts)		2023			2022			2023			2022
As reported - net income	$	209		$	1,229		$	886		$	1,837
Reversal of selected items:
(Gain) loss on sale of assets		—			3			(5	)		1
(Gain) loss on derivative instruments⁽¹⁾		96			(227	)		58			(7	)
Stock-based compensation expense		7			21			23			44
Merger-related expense		—			—			—			7
Severance expense		3			14			11			39
Tax effect on selected items		(24	)		43			(20	)		(19	)
Adjusted net income	$	291		$	1,083		$	953		$	1,902
As reported - earnings per share	$	0.28		$	1.53		$	1.16		$	2.28
Per share impact of selected items		0.11			(0.18	)		0.09			0.08
Adjusted earnings per share	$	0.39		$	1.35		$	1.25		$	2.36
Weighted-average common shares outstanding		755			803			760			806

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(1)

This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in Gain (loss) on derivative instruments in the Condensed Consolidated Statement of Operations.

Reconciliation of Discretionary Cash Flow and Free Cash Flow

Discretionary Cash Flow is defined as cash flow from operating activities excluding changes in assets and liabilities. Discretionary Cash Flow is widely accepted as a financial indicator of an oil and gas company's ability to generate available cash to internally fund exploration and development activities, return capital to shareholders through dividends and share repurchases, and service debt and is used by our management for that purpose. Discretionary Cash Flow is presented based on our management's belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies that use the full cost method of accounting for oil and gas producing activities or have different financing and capital structures or tax rates. Discretionary Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.

Free Cash Flow is defined as Discretionary Cash Flow less cash paid for capital expenditures. Free Cash Flow is an indicator of a company's ability to generate cash flow after spending the money required to maintain or expand its asset base, and is used by our management for that purpose. Free Cash Flow is presented based on our management's belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies. Free Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.

	Quarter Ended June 30,						Six Months Ended June 30,
(In millions)		2023			2022			2023			2022
Cash flow from operating activities	$	646		$	879		$	2,140		$	2,201
Changes in assets and liabilities		59			614			(396	)		524
Discretionary cash flow		705			1,493			1,744			2,725
Cash paid for capital expenditures for drilling, completion and other fixed asset additions		(592	)		(471	)		(1,075	)		(741	)
Free cash flow	$	113		$	1,022		$	669		$	1,984

Capital Expenditures

	Quarter Ended June 30,						Six Months Ended June 30,
(In millions)		2023			2022			2023		2022
Cash paid for capital expenditures for drilling, completion and other fixed asset additions	$	592		$	471		$	1,075	$	741
Change in accrued capital costs		(55	)		(2	)		30		53
Capital expenditures for drilling, completion and other fixed asset additions	$	537		$	469		$	1,105	$	794

Reconciliation of Adjusted EBITDAX

Adjusted EBITDAX is defined as net income plus interest expense, other expense, income tax expense, depreciation, depletion, and amortization (including impairments), exploration expense, gain and loss on sale of assets, non-cash gain and loss on derivative instruments, stock-based compensation expense, severance expense and merger-related expense. Adjusted EBITDAX is presented on our management's belief that this non-GAAP measure is useful information to investors when evaluating our ability to internally fund exploration and development activities and to service or incur debt without regard to financial or capital structure. Our management uses Adjusted EBITDAX for that purpose. Adjusted EBITDAX is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.

	Quarter Ended June 30,					Six Months Ended June 30,
(In millions)		2023		2022			2023			2022
Net income	$	209	$	1,229		$	886		$	1,837
Plus (less):
Interest expense, net		6		21			11			42
Income tax expense		61		359			256			529
Depreciation, depletion and amortization		395		414			764			774
Exploration		5		7			9			13
(Gain) loss on sale of assets		—		3			(5	)		1
Non-cash (gain) loss on derivative instruments		96		(227	)		58			(7	)
Merger-related expense		—		—			—			7
Severance expense		3		14			11			39
Stock-based compensation		7		21			23			44
Adjusted EBITDAX	$	782	$	1,841		$	2,013		$	3,279

	Trailing Twelve Months Ended
(In millions)	June 30, 2023			December 31, 2022
Net income	$	3,114		$	4,065
Plus (less):
Interest expense, net		39			70
Loss on debt extinguishment		(28	)		(28	)
Other expense		(2	)		(2	)
Income tax expense		831			1,104
Depreciation, depletion and amortization		1,625			1,635
Exploration		25			29
(Gain) loss on sale of assets		(5	)		1
Non-cash (gain) loss on derivative instruments		(234	)		(299	)
Merger-related expense		1			7
Severance expense		33			62
Stock-based compensation		65			86
Adjusted EBITDAX (trailing twelve months)	$	5,464		$	6,730

Reconciliation of Net Debt

The total debt to total capitalization ratio is calculated by dividing total debt by the sum of total debt and total stockholders' equity. This ratio is a measurement which is presented in our annual and interim filings and our management believes this ratio is useful to investors in assessing our leverage. Net Debt is calculated by subtracting cash and cash equivalents from total debt. The Net Debt to Adjusted Capitalization ratio is calculated by dividing Net Debt by the sum of Net Debt and total stockholders' equity. Net Debt and the Net Debt to Adjusted Capitalization ratio are non-GAAP measures which our management believes are also useful to investors when assessing our leverage since we have the ability to and may decide to use a portion of our cash and cash equivalents to retire debt. Our management uses these measures for that purpose. Additionally, as our planned expenditures are not expected to result in additional debt, our management believes it is appropriate to apply cash and cash equivalents to reduce debt in calculating the Net Debt to Adjusted Capitalization ratio.

(In millions)	June 30, 2023			December 31, 2022
Long-term debt, net		2,171			2,181
Stockholders' equity		12,659			12,659
Total capitalization	$	14,830		$	14,840

Total debt	$	2,171		$	2,181
Less: Cash and cash equivalents		(841	)		(673	)
Net debt	$	1,330		$	1,508

Net debt	$	1,330		$	1,508
Stockholders' equity		12,659			12,659
Total adjusted capitalization	$	13,989		$	14,167

Total debt to total capitalization ratio		14.6	%		14.7	%
Less: Impact of cash and cash equivalents		5.1	%		4.1	%
Net debt to adjusted capitalization ratio		9.5	%		10.6	%

Reconciliation of Net Debt to Adjusted EBITDAX

Total debt to net income is defined as total debt divided by net income. Net debt to Adjusted EBITDAX is defined as net debt divided by trailing twelve month Adjusted EBITDAX. Net debt to Adjusted EBITDAX is a non-GAAP measure which our management believes is useful to investors when assessing our credit position and leverage.

(In millions)	June 30, 2023		December 31, 2022
Total debt	$	2,171	$	2,181
Net income		3,114		4,065
Total debt to net income ratio	0.7 x		0.5 x

Net debt	$	1,330	$	1,508
Adjusted EBITDAX (Trailing twelve months)		5,464		6,730
Net debt to Adjusted EBITDAX	0.2 x		0.2 x

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Coterra Energy Reports Second-Quarter 2023 Results, Announces Quarterly Dividend