Coterra Energy Reports Fourth-Quarter and Full-Year 2022 Results, Provides 2023 Outlook and Updates Shareholder Return Strategy

HOUSTON–(BUSINESS WIRE)–Coterra Energy Inc. (NYSE: CTRA) (“Coterra” or the “Company”) today reported fourth-quarter and full-year 2022 financial and operating results. On October 1, 2021, Coterra announced that the merger involving the Company, which was formerly named Cabot Oil & Gas Corporation (“Cabot”), and Cimarex Energy Co. (“Cimarex”) was completed (the “Merger”). Fourth-quarter 2021 results discussed within this release represent Coterra. Full-year 2021 results include nine months of legacy Cabot results from January 1 to September 30, plus three months of Coterra beginning October 1, unless noted otherwise.

Thomas E. Jorden, Chairman, Chief Executive Officer and President, commented, “Coterra delivered a strong 2022. Outstanding execution led to value creation, outsized shareholder returns and further improvement of our industry-leading balance sheet. Combining our track record of execution with our deep inventory of high-quality assets, Coterra is positioned to succeed through commodity cycles.”

Fourth-Quarter 2022 Summary

• Net income for fourth quarter 2022 totaled $1,032 million, or $1.32 per share. Adjusted net income (non-GAAP) for fourth-quarter 2022, excluding non-recurring items, was $905 million, or $1.16 per share.
• Generated cash flow from operating activities of $1,484 million.
• Discretionary cash flow totaled $1,393 million (non-GAAP).
• Accrued capital expenditures totaled $483 million.
• Generated Free Cash Flow of $892 million (non-GAAP).
• Delivered total equivalent production of 632 MBoepd (thousand barrels equivalent per day).
  • Oil production averaged 90.7 MBbls/d (thousand barrels per day), above the high-end of guidance.
  • Natural gas production averaged 2,780 Mmcf/d (million cubic feet per day), above the high-end of guidance.

Coterra’s average realized prices for oil, natural gas and natural gas liquids (NGLs) for fourth-quarter 2022, excluding the effect of commodity derivatives, were $82.26 per barrel (Bbl), $4.87 per thousand cubic feet (Mcf), and $25.02 per Bbl, respectively. Including the effect of commodity derivatives, average realized prices for oil and natural gas for fourth-quarter 2022 were $81.57 per Bbl and $4.74 per Mcf, respectively.

2023 Outlook

“Guided by principles focused on full-cycle value creation and disciplined capital allocation, Coterra expects to invest approximately 50 percent of its cash flow, at recent strip prices”, commented Jorden. “This is expected to result in a 2023 production profile that will be relatively flat year-over-year before returning to modest growth in 2024 and 2025. Coterra’s dynamic organization, top-tier assets and industry-leading balance sheet are poised to generate long-term consistent profitable growth.”

• Estimated cash flow from operating activities of approximately $4.0 billion, at recent commodity strip prices
• Expected capital investment of $2.0 billion to $2.2 billion
  • $1,825 to $2,025 million is allocated to drilling and completion activities.
  • Approximately 49 percent of drilling and completion capital will be invested in the Permian Basin, 44 percent in the Marcellus Shale and the balance in the Anadarko Basin.
  • Represents approximately 50 percent of projected cash flow from operating activities at recent commodity strip prices.
  • Capital increase driven by inflation (10% y/y) and a modest activity increase.
• Expect annual average production of 610 – 650 MBoe/d, in line with 2022.
  • Expect annual average oil production of 86-92 MBbls/d, up 2% y/y.
  • Expect annual average natural gas production of 2,700 – 2,850 MMcf/d, down modestly y/y as Upper Marcellus delineation increases in 2023 (~40% of 2023 Marcellus activity). The 40% Upper Marcellus weighting is expected to be the high-end over the next few years.
  • Expect to turn-in-line 150 to 175 total net wells.
• Estimate free cash flow (non-GAAP) of approximately $1.9 billion, at recent commodity strip prices.

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.

Increasing Base Dividend, Announcing New Share Repurchase Authorization, Updating Return Strategy

• Coterra’s Board of Directors (the “Board”) approved a 33 percent increase to the annual base dividend to $0.80 per share from $0.60 per share.
• After completing its buyback authorization ($1.25 billion) during calendar 2022, the Board approved a new $2.0 billion authorization, representing approximately 11% of the Company’s market capitalization as of market close on February 21, 2023. The timing and volume of share repurchases under this authorization will be determined by management, at its discretion. The $2 billion share repurchase program takes effect in February 2023 and does not have a fixed expiration.
• Coterra’s 2022 return strategy targeted 50%+ of Free Cash Flow (non-GAAP) paid via cash dividends (base + variable). The company’s updated 2023 strategy maintains its 50%+ Free Cash Flow return target but now assumes this can be accomplished through a combination of base dividends, share repurchases and/or variable dividends.

Jorden commented, “We are pleased to increase the base dividend, which underscores the confidence in our long-term outlook and financial strength through all cycles. Additionally, we established a new buyback authorization totaling $2.0 billion, which will accelerate returns to shareholders and allow the company to take advantage of value dislocations. We remain committed to returning 50%+ of our Free Cash Flow to shareholders. Due to market conditions and the value proposition of our shares, in 2023 we are realigning our strategy to focus on buybacks ahead of variable dividends. Our 2023 capital return priorities include paying our increased base dividend first, share repurchases second, and variable dividends third. With 2023 estimated Free Cash Flow approaching $2 billion, based on recent strip prices, we are projected to generate sufficient cash flow to fund the base dividend and make meaningful progress on the new buyback authorization.”

Full-Year 2022 and Fourth Quarter 2022 Shareholder Return Highlights

• Driven by relatively high commodity prices and strong execution during 2022, the company returned $3.25 billion to shareholders through our base dividend ($480 million), variable dividend ($1.51 billion) and share repurchases ($1.25 billion). The total 2022 return was 85% of Free Cash Flow and the total dividend (base + variable) was 50% of Free Cash Flow.
• On February 22, 2023, in addition to its base dividend ($0.20 per share), the Board approved a $0.37 per share variable dividend payment based on fourth-quarter 2022 free cash flow (non-GAAP) generation.
  • The approved total quarterly dividend (base plus variable) equals $0.57 per share ($0.20 base, $0.37 variable), and will be paid on March 30, 2023 to holders of record on March 16, 2023.
• During the quarter, the Company repurchased 20 million shares for $510 million, averaging $25.60 per share, to fully execute on its $1.25 billion share repurchase authorization during calendar 2022.

2022 Highlights

• Net Income of $4.1 billion, or $5.09 per share.
• Operating Cash Flow of $5.5 billion, Discretionary Cash Flow of $5.6 billion, Free Cash Flow of $3.9 billion.
• Dividends paid of $2.0 billion, complemented by $1.25 billion of share repurchases.
• Retired $0.9 billion of long-term notes.
• Exceeded initial 2022 production targets as well as emissions reduction targets.

Full-Year 2022 Summary

Full-year 2022 total equivalent production averaged 633.8 MBoepd. Oil production averaged 87.5 MBbls/d and natural gas production averaged 2,806 MMcf/d.

Coterra’s average realized prices for oil, natural gas and NGLs for 2022, excluding the effect of commodity derivatives, were $94.47 per Bbl, $5.34 per Mcf, and $33.58 per Bbl, respectively. Including the effect of commodity derivatives, average realized prices for oil and natural gas for 2022 were $84.33 per Bbl and $4.91 per Mcf, respectively.

Net income for full-year 2022 totaled $4,065 million or $5.09 per share. Adjusted net income (non-GAAP) for full-year 2022, excluding non-recurring items, was $3,932 million, or $4.94 per share.

Coterra reported cash flow from operating activities of $5,456 million for full-year 2022. Full-year 2022 discretionary cash flow (non-GAAP) was $5,642 million and free cash flow (non-GAAP) totaled $3,942 million, both of which are inclusive of merger-related costs.

Coterra incurred a total of $1,737 million of capital expenditures in full-year 2022, including $1,617 million of drilling and completion capital.

The company achieved zero routine high-pressure flaring across Coterra’s three core operating regions during 2022. Additionally, the company beat its 2022 environmental goals and laid out ambitious 2023 goals.

Strong Financial Position

As of December 31, 2022, Coterra had total long-term debt of $2.2 billion with a principal amount of $2.1 billion, with no substantial maturities until 2024. The Company exited the year with a cash balance of $0.7 billion and no debt outstanding under its revolving credit facility. Coterra’s net debt to trailing twelve month EBITDAX ratio (non-GAAP) at December 31, 2022 was 0.2x.

2022 Proved Reserves

At December 31, 2022, Coterra’s proved reserves totaled 2,399 MMBoe, down 17 percent from the Company’s proved reserves of 2,893 MMBoe at December 31, 2021, which is in line with estimates provided in the Company’s third-quarter 2022 earnings press release. At year-end 2022, proved undeveloped reserves accounted for 24 percent of total proved reserves, down from 26 percent at year-end 2021. The Company’s proved reserves are approximately 78 percent natural gas, 10 percent oil and 12 percent NGLs. Proved developed reserves totaled 1,817 MMBoe, or 76 percent of total proved reserves. For a summary of Coterra’s estimated proved reserves at December 31, 2022, see the “Year-End Proved Reserves” table below.

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.

Conference Call

Coterra will host a conference call tomorrow, Thursday, February 23, 2023, at 9:00 AM CT (10:00 AM ET), to discuss fourth-quarter and full-year 2022 financial and operating results and its 2023 outlook.

Conference Call Information

Date: Thursday, February 23, 2023

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

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

Int’l 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 producer, delivering returns with a commitment to sustainability leadership. 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, future financial and operating performance and goals and commitment to sustainability and ESG leadership, strategic pursuits and goals 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 recently combined businesses will not integrate successfully; the risk that the cost savings and any other synergies may not be fully realized or may take longer to realize than expected; the volatility in commodity prices for crude oil and natural gas; 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 transaction making it more difficult to maintain relationships with customers, employees or suppliers; the diversion of management time on integration-related issues; the continuing effects of the COVID-19 pandemic and the impact 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; 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 of directors. 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 and Cimarex’s annual reports 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 and on the SEC’s website at www.sec.gov.

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 December 31,						Twelve Months Ended December 31,
		2022			2021			2022			2021
PRODUCTION VOLUMES
Marcellus Shale
Natural gas (Bcf)		197.2			229.4			804.6			853.0
Equivalent production (MMBoe)		32.9			38.0			134.1			142.0
Daily equivalent production (MBoepd)		357.2			415.5			367.4			389.5
Permian Basin
Natural gas (Bcf)		40.7			41.3			154.9			41.3
Oil (MMBbl)		7.6			7.4			29.6			7.4
NGL (MMBbl)		5.3			5.1			21.7			5.1
Equivalent production (MMBoe)		19.7			19.5			77.2			19.5
Daily equivalent production (MBoepd)		214.3			211.5			211.4			211.5
Anadarko Basin
Natural gas (Bcf)		17.8			16.5			64.3			16.5
Oil (MMBbl)		0.7			0.7			2.3			0.7
NGL (MMBbl)		1.9			2.0			6.9			2.0
Equivalent production (MMBoe)		5.5			5.4			19.9			5.4
Daily equivalent production (MBoepd)		60.2			58.7			54.6			58.7
Total Company(1)
Natural gas (Bcf)		255.8			287.3			1,024.3			911.1
Oil (MMBbl)		8.3			8.1			31.9			8.1
NGL (MMBbl)		7.2			7.1			28.7			7.1
Equivalent production (MMBoe)		58.2			63.1			231.3			167.1
Daily equivalent production (MBoepd)		632.2			686.2			633.8			660.0
AVERAGE SALES PRICE (excluding hedges)
Marcellus Shale
Natural gas ($/Mcf)	$	5.16		$	4.43		$	5.29		$	2.98
Permian Basin
Natural gas ($/Mcf)	$	3.22		$	4.13		$	5.18		$	4.13
Oil ($/Bbl)	$	82.27		$	75.53		$	94.55		$	75.53
NGL ($/Bbl)	$	23.40		$	33.25		$	32.59		$	33.25
Anadarko Basin
Natural gas ($/Mcf)	$	5.44		$	5.19		$	6.29		$	5.19
Oil ($/Bbl)	$	81.94		$	76.49		$	93.34		$	76.49
NGL ($/Bbl)	$	29.60		$	36.61		$	36.66		$	36.61
Total Company
Natural gas ($/Mcf)	$	4.87		$	4.43		$	5.34		$	3.07
Oil ($/Bbl)	$	82.26		$	75.61		$	94.47		$	75.61
NGL ($/Bbl)	$	25.02		$	34.18		$	33.58		$	34.18

	Quarter Ended December 31,						Twelve Months Ended December 31,
		2022			2021			2022			2021
AVERAGE SALES PRICE (including hedges)
Total Company
Natural gas ($/Mcf)	$	4.74		$	3.57		$	4.91		$	2.73
Oil ($/Bbl)	$	81.57		$	60.35		$	84.33		$	60.35
NGL ($/Bbl)	$	25.02		$	34.18		$	33.58		$	34.18

	Quarter Ended December 31,						Twelve Months Ended December 31,
	2022			2021			2022			2021
WELLS DRILLED(2)
Gross wells
Marcellus Shale		27			22			93			95
Permian Basin		43			19			161			19
Anadarko Basin		9			—			31			—
		79			41			285			114
Net wells
Marcellus Shale		27.0			19.1			93.0			89.2
Permian Basin		13.7			10.7			72.7			10.7
Anadarko Basin		0.1			—			8.9			—
		40.8			29.8			174.6			99.9
WELLS COMPLETED(2)
Gross wells
Marcellus Shale		19			21			81			92
Permian Basin		53			36			144			36
Anadarko Basin		11			4			26			4
		83			61			251			132
Net wells
Marcellus Shale		19.0			21.0			78.0			88.1
Permian Basin		22.2			20.2			64.5			20.2
Anadarko Basin		5.9			—			8.7			—
		47.1			41.2			151.2			108.3
TURN IN LINES
Gross wells
Marcellus Shale		26			22			81			92
Permian Basin		39			33			144			33
Anadarko Basin		11			4			26			4
		76			59			251			129
Net wells
Marcellus Shale		26.0			22.0			78.1			88.1
Permian Basin		13.5			18.5			61.3			18.5
Anadarko Basin		5.9			—			8.7			—
		45.4			40.5			148.1			106.6
	Quarter Ended December 31,						Twelve Months Ended December 31,
	2022			2021			2022			2021
AVERAGE UNIT COSTS ($/Boe)(3)
Direct operations	$	2.17		$	1.62		$	1.99		$	0.93
Transportation, processing and gathering		3.94			3.87			4.13			3.97
Taxes other than income		1.55			1.05			1.58			0.50
Exploration		0.11			0.14			0.13			0.11
Depreciation, depletion and amortization		7.54			6.49			7.07			4.15
General and administrative (excluding stock-based compensation and merger-related expense)(4)		1.17			1.52			1.03			0.84
Stock-based compensation		0.28			0.49			0.37			0.34
Merger-related expense		0.18			0.41			0.30			0.43
Interest expense		0.17			0.38			0.30			0.37
	$	17.11		$	15.97		$	16.90		$	11.64

_______________________________________________________________________________

(1)	Production for the twelve months ended December 31, 2021 does not include legacy Cimarex production from January 1, 2021 to September 30, 2021. Combined Coterra and legacy Cimarex full-year 2021 natural gas, oil and NGL production totaled 1,068 Bcf, 28.4 MMBbl, and 25.1 MMBbl, respectively, or total equivalent production of 231.6 MMBoe, or 634 MBoepd.
(2)	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.
(3)	Total unit costs may differ from the sum of the individual costs due to rounding.
(4)	Includes the impact of severance expense related to accrued severance costs as a result of the Merger and the Company’s 2021 Early Retirement Program.

Variable Dividend Calculation
(In millions)		Twelve Months Ended December 31, 2022
Free cash flow(1)		$	3,942
50% payout (Board Discretion: 50% plus)			50	%
Annual return to shareholders			1,971
Annual base dividend ($0.15 per share for the first three quarters and $0.20 per share for the fourth quarter)			512
Variable cash dividend(2)		$	1,459

_______________________________________________________________________________

(1)	See “Supplemental non-GAAP Financial Measures” below for a description of free cash flow as well as reconciliations of this measures to discretionary cash flow and cash flow from operating activities.
(2)	Total cash amounts paid are subject to change based on the number of shares of issued common stock on the dividend record date.

Derivatives Information   As of December 31, 2022, the Company had the following outstanding financial commodity derivatives:
		2023
Natural Gas		First Quarter			Second Quarter			Third Quarter			Fourth Quarter
Waha gas collars
Volume (MMBtu)			8,100,000			8,190,000			8,280,000			8,280,000
Weighted average floor ($/MMBtu)		$	3.03		$	3.03		$	3.03		$	3.03
Weighted average ceiling ($/MMBtu)		$	5.39		$	5.39		$	5.39		$	5.39
NYMEX collars
Volume (MMBtu)			54,000,000			31,850,000			32,200,000			29,150,000
Weighted average floor ($/MMBtu)		$	5.12		$	4.07		$	4.07		$	4.03
Weighted average ceiling ($/MMBtu)		$	9.34		$	6.78		$	6.78		$	6.61

		2023
Oil		First Quarter			Second Quarter
WTI oil collars
Volume (MBbl)			1,350			1,365
Weighted average floor ($/Bbl)		$	70.00		$	70.00
Weighted average ceiling ($/Bbl)		$	116.03		$	116.03
WTI Midland oil basis swaps
Volume (MBbl)			1,350			1,365
Weighted average differential ($/Bbl)		$	0.63		$	0.63

Year-End Proved Reserves   The tables below provide a summary of changes in proved reserves for the year ended December 31, 2022.
	Oil (MBbl)			Natural Gas (Bcf)			NGL (MBbl)			Total (MBOE)
PROVED RESERVES
December 31, 2021	189,429			14,895			220,615			2,892,582
Revision of previous estimates	14,594			(4,299	)		35,162			(666,716	)
Extensions and discoveries	69,118			1,602			69,862			405,972
Purchases of reserves	—			—			—			—
Production	(31,926	)		(1,024	)		(28,697	)		(231,342	)
Sales of reserves	(1,460	)		(1	)		(177	)		(1,830	)
December 31, 2022	239,755			11,173			296,765			2,398,666
PROVED DEVELOPED RESERVES
December 31, 2021	153,010			10,691			193,598			2,128,439
December 31, 2022	168,649			8,543			224,706			1,817,140
PROVED RESERVES BY REGION
Marcellus Shale	8			8,989			—			1,498,181
Permian Basin	221,436			1,505			218,702			691,028
Anadarko Basin	18,051			676			77,834			208,545
Other	261			3			229			912
	239,756			11,173			296,765			2,398,666

CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited)
	Quarter Ended December 31,								Twelve Months Ended December 31,
(In millions, except per share amounts)		2022				2021				2022				2021
OPERATING REVENUES
Natural gas	$	1,246			$	1,272			$	5,469			$	2,798
Oil		686				616				3,016				616
NGL		180				243				964				243
Gain (loss) on derivative instruments		150				81				(463	)			(221	)
Other		18				13				65				13
		2,280				2,225				9,051				3,449
OPERATING EXPENSES
Direct operations		126				102				460				156
Transportation, processing and gathering		229				244				955				663
Taxes other than income		90				66				366				83
Exploration		6				9				29				18
Depreciation, depletion and amortization		439				410				1,635				693
General and administrative (excluding stock-based compensation and merger-related costs)(1)		68				96				241				141
Stock-based compensation(2)		16				31				86				57
Merger-related expense		11				26				69				72
		985				984				3,841				1,883
Loss on sale of assets		—				(2	)			(1	)			(2	)
INCOME FROM OPERATIONS		1,295				1,239				5,209				1,564
Interest expense, net		11				24				70				62
Gain on debt extinguishment		(2	)			—				(28	)			—
Other expense		(2	)			—				(2	)			—
Income before income taxes		1,288				1,215				5,169				1,502
Income tax expense		256				276				1,104				344
NET INCOME	$	1,032			$	939			$	4,065			$	1,158
Earnings per share – Basic	$	1.32			$	1.16			$	5.09			$	2.30
Weighted-average common shares outstanding		781				810				796				503

Contacts

Investor Contact
Daniel Guffey – Vice President of Finance, Planning & Analysis and Investor Relations
281.589.4875

Hannah Stuckey – Investor Relations Manager
281.589.4983

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