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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM
10-Q
☒      QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934.
For the quarterly period ended September 30, 2022
OR
☐       TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934.
Commission file number 1-10447
COTERRA ENERGY INC.
(Exact name of registrant as specified in its charter)
Delaware 04-3072771
(State or other jurisdiction of
incorporation or organization)		 (I.R.S. Employer
Identification Number)
Three Memorial City Plaza
840 Gessner Road, Suite 1400, Houston, Texas 77024
(Address of principal executive offices, including ZIP code)
(281) 589-4600
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title of each classTrading Symbol(s)Name of each exchange on which registered
Common Stock, par value $0.10 per shareCTRANew 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, a 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 ☒
As of November 2, 2022, there were 788,467,351 shares of Common Stock, Par Value $0.10 Per Share, outstanding.

COTERRA ENERGY INC.
INDEX TO FINANCIAL STATEMENTS
  Page
 
   
 
   
   
   
   
   
   
   
   
 
   
   
   
  
2
PART I. FINANCIAL INFORMATION
ITEM 1. Financial Statements
COTERRA ENERGY INC.
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited)
(In millions, except share and per share amounts)September 30,
2022		December 31,
2021
ASSETS  
Current assets  
Cash and cash equivalents$778 $1,036 
Restricted cash10 10 
Accounts receivable, net1,419 1,037 
Income taxes receivable70 — 
Inventories 57 39 
Derivative instruments8 7 
Other current assets8 7 
Total current assets 2,350 2,136 
Properties and equipment, net (Successful efforts method) 17,429 17,375 
Other assets 526 389 
$20,305 $19,900 
LIABILITIES, REDEEMABLE PREFERRED STOCK AND STOCKHOLDERS' EQUITY  
Current liabilities  
Accounts payable $1,010 $747 
Current portion of long-term debt44 — 
Accrued liabilities 294 260 
Income taxes payable— 29 
Interest payable15 25 
Derivative instruments52 159 
Total current liabilities 1,415 1,220 
Long-term debt, net2,188 3,125 
Deferred income taxes 3,229 3,101 
Asset retirement obligations270 259 
Other liabilities 533 407 
Total liabilities7,635 8,112 
Commitments and contingencies
Cimarex redeemable preferred stock1150
Stockholders' equity
Common stock:  
Authorized — 1,800,000,000 shares of $0.10 par value in 2022 and 2021, respectively
  
Issued — 895,539,411 shares and 892,612,010 shares in 2022 and 2021, respectively
9089
Additional paid-in capital 10,992 10,911 
Retained earnings 4,137 2,563 
Accumulated other comprehensive income6 1 
Less treasury stock, at cost:  
107,074,560 shares and 79,082,385 shares in 2022 and 2021, respectively
(2,566)(1,826)
Total stockholders' equity 12,659 11,738 
 $20,305 $19,900 
The accompanying notes are an integral part of these condensed consolidated financial statements.
3
COTERRA ENERGY INC.
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited)
 Three Months Ended 
September 30,		Nine Months Ended 
September 30,
(In millions, except per share amounts)2022202120222021
OPERATING REVENUES    
Natural gas $1,644 $641 $4,223 $1,526 
Oil755 — 2,330 — 
NGL259 — 784 — 
Loss on derivative instruments(156)(201)(613)(302)
Other 18 — 47 — 
 2,520 440 6,771 1,224 
OPERATING EXPENSES    
Direct operations118 21 334 54 
Transportation, processing and gathering255 149 726 419 
Taxes other than income 102 8 276 17 
Exploration 10 4 23 9 
Depreciation, depletion and amortization 422 97 1,196 283 
General and administrative 107 64 301 116 
 1,014 343 2,856 898 
Loss on sale of assets — — (1)— 
INCOME FROM OPERATIONS 1,506 97 3,914 326 
Interest expense, net17 13 59 38 
Gain on debt extinguishment(26)— (26)— 
Income before income taxes 1,515 84 3,881 288 
Income tax expense319 20 848 68 
NET INCOME$1,196 $64 $3,033 $220 
Earnings per share    
Basic $1.51 $0.16 $3.78 $0.55 
Diluted$1.50 $0.16 $3.77 $0.55 
Weighted-average common shares outstanding     
Basic792 400 801 399 
Diluted 797 403 805 402 
The accompanying notes are an integral part of these condensed consolidated financial statements.
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COTERRA ENERGY INC.
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited)
 Nine Months Ended 
September 30,
(In millions)20222021
CASH FLOWS FROM OPERATING ACTIVITIES  
  Net income $3,033 $220 
  Adjustments to reconcile net income to cash provided by operating activities:  
Depreciation, depletion and amortization1,196 283 
Deferred income tax expense128 17 
Loss on sale of assets1 — 
Loss on derivative instruments613 302 
Net cash paid in settlement of derivative instruments(723)(61)
Amortization of premium and debt issuance costs(35)2 
Gain on debt extinguishment(26)— 
Stock-based compensation and other62 24 
  Changes in assets and liabilities:
Accounts receivable, net(382)(70)
Income taxes(99)(49)
Inventories(26)2 
Other current assets(4)(2)
Accounts payable and accrued liabilities194 64 
Interest payable(10)(13)
Other assets and liabilities50 (3)
Net cash provided by operating activities3,972 716 
CASH FLOWS FROM INVESTING ACTIVITIES  
Capital expenditures(1,205)(459)
Proceeds from sale of assets22 — 
Net cash used in investing activities(1,183)(459)
CASH FLOWS FROM FINANCING ACTIVITIES  
Borrowings from debt— 100 
Repayments of debt(830)(288)
Repayments of finance leases(4)— 
Treasury stock repurchases(740)— 
Dividends paid(1,459)(128)
Cash received for stock option exercises11 — 
Cash paid for conversion of redeemable preferred stock(10)— 
Tax withholdings on vesting of stock awards(15)(6)
Net cash used in financing activities(3,047)(322)
Net decrease in cash, cash equivalents and restricted cash(258)(65)
Cash, cash equivalents and restricted cash, beginning of period1,046 152 
Cash, cash equivalents and restricted cash, end of period$788 $87 
The accompanying notes are an integral part of these condensed consolidated financial statements.
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COTERRA ENERGY INC.

CONDENSED CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY (Unaudited)
(In millions, except per share amounts)Common SharesCommon Stock ParTreasury SharesTreasury StockPaid-In CapitalAccumulated Other Comprehensive IncomeRetained EarningsTotal
Balance at December 31, 2021893 $89 79 $(1,826)$10,911 $1 $2,563 $11,738 
Net income— — — — — — 608 608 
Exercise of stock options— — — — 6 — — 6 
Stock amortization and vesting— — — — 10 — — 10 
Treasury stock repurchases— — 8 (192)— — — (192)
Cash dividends:
Common stock at $0.56 per share
— — — — — — (455)(455)
Preferred stock at $20.3125 per share
— — — — — — (1)(1)
Other comprehensive income— — — — — 4 — 4 
Balance at March 31, 2022893 $89 87 $(2,018)$10,927 $5 $2,715 $11,718 
Net income— — — — — — 1,229 1,229 
Exercise of stock options— — — — 3 — — 3 
Stock amortization and vesting— — — — 18 — — 18 
Conversion of Cimarex redeemable preferred stock1 — — — 28 — — 28 
Purchase of treasury stock— — 12 (321)— — — (321)
Cash dividends:
Common stock at $0.60 per share
— — — — — — (484)(484)
Balance at June 30, 2022894 $89 99 $(2,339)$10,976 $5 $3,460 $12,191 
Net income— — — — — — 1,196 1,196 
Exercise of stock options— — — — 2 — — 2 
Stock amortization and vesting1 1 — — 14 — — 15 
Purchase of treasury stock— — 8 (227)— — — (227)
Cash dividends:
Common stock at $0.65 per share
— — — — — — (519)(519)
Other comprehensive income— — — — — 1 — 1 
Balance at September 30, 2022895 $90 107 $(2,566)$10,992 $6 $4,137 $12,659 

(In millions, except per share amounts)Common SharesCommon Stock ParTreasury SharesTreasury StockPaid-In CapitalAccumulated Other Comprehensive IncomeRetained EarningsTotal
Balance at December 31, 2020478 $48 79 $(1,823)$1,804 $2 $2,185 $2,216 
Net income— — — — — — 126 126 
Stock amortization and vesting— — — — 4 — — 4 
Cash dividends at $0.10 per share
— — — — — — (40)(40)
Balance at March 31, 2021478 $48 79 $(1,823)$1,808 $2 $2,271 $2,306 
Net income— — — — — — 30 30 
Stock amortization and vesting— — — — 8 — — 8 
Cash dividends at $0.11 per share
— — — — — — (44)(44)
Balance at June 30, 2021478 $48 79 $(1,823)$1,816 $2 $2,257 $2,300 
Net income— — — — — — 64 64 
Stock amortization and vesting— — — — 7 — — 7 
Cash dividends at $0.11 per share
— — — — — — (44)(44)
Balance at September 30, 2021478 $48 79 $(1,823)$1,823 $2 $2,277 $2,327 

The accompanying notes are an integral part of these condensed consolidated financial statements.
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COTERRA ENERGY INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
1. Financial Statement Presentation
During interim periods, Coterra Energy Inc. (the “Company”) follows the same accounting policies disclosed in its Annual Report on Form 10-K for the year ended December 31, 2021 (the “Form 10-K”) filed with the Securities and Exchange Commission (“SEC”), except for any new accounting pronouncements adopted during the period. The interim condensed consolidated financial statements are unaudited and should be read in conjunction with the notes to the consolidated financial statements and information presented in the Form 10-K. In management’s opinion, the accompanying interim condensed consolidated financial statements contain all material adjustments, consisting only of normal recurring adjustments, necessary for a fair statement. The results for any interim period are not necessarily indicative of the results that may be expected for the entire year.
Certain reclassifications have been made to prior year statements to conform with the current year presentation. These reclassifications have no impact on previously reported stockholders’ equity, net income or cash flows.
2. Acquisitions
Cimarex Energy Co.
On October 1, 2021, the Company completed a merger transaction (the “Merger”) with Cimarex Energy Co. (“Cimarex”). Cimarex is an oil and gas exploration and production company with operations in Texas, New Mexico and Oklahoma.
Purchase Price Allocation
The transaction was accounted for using the acquisition method of accounting. Under the acquisition method of accounting, the assets, liabilities and mezzanine equity of Cimarex and its subsidiaries were recorded at their respective fair values as of the effective date of the Merger. The purchase price allocation was based on preliminary estimates and assumptions, which are subject to change for up to one year after October 1, 2021, the effective date of the Merger, as the Company finalizes the valuations of the assets acquired, liabilities assumed and the related tax balances as of the effective date of the Merger. Determining the fair value of the assets and liabilities of Cimarex requires judgment and certain assumptions to be made. The most significant fair value estimates related to the valuation of Cimarex's oil and gas properties and certain other fixed assets, long-term debt and derivative instruments. Oil and gas properties and certain fixed assets were valued using an income and market approach utilizing Level 3 inputs including internally generated production and development data and estimated price and cost estimates. Long-term debt was valued using a market approach utilizing Level 1 inputs including observable market prices on the underlying debt instruments. Derivative liabilities were based on Level 3 inputs consistent with the Company’s other commodity derivative instruments. There were no adjustments to the purchase price allocation during the nine months ended September 30, 2022.
Unaudited Pro Forma Financial Information
The results of Cimarex’s operations have been included in the Company’s consolidated financial statements since October 1, 2021, the effective date of the Merger. The following supplemental pro forma information for the nine months ended September 30, 2021 has been prepared to give effect to the Merger as if it had occurred on January 1, 2021. The information below reflects pro forma adjustments based on available information and certain assumptions that management believes are factual and supportable. The pro forma results of operations do not include any cost savings or other synergies that may result from the acquisition or any estimated costs that have been or will be incurred by Coterra to integrate the Cimarex assets.
The pro forma information is not necessarily indicative of the results that might have occurred had the transaction actually taken place on January 1, 2021 and is not intended to be a projection of future results. Future results may vary significantly
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from the results reflected in the following pro forma information because of normal production declines, changes in commodity prices, future acquisitions and divestitures, future development and exploration activities and other factors.
(In millions, except per share amounts)Nine Months Ended 
September 30, 2021
Pro forma revenue$3,011 
Pro forma net income219 
Pro forma basic earnings per share$0.27 
Pro forma diluted earnings per share$0.27 
3. Properties and Equipment, Net
Properties and equipment, net are comprised of the following:
(In millions)September 30,
2022		December 31,
2021
Proved oil and gas properties$16,505 $15,340 
Unproved oil and gas properties 5,288 5,316 
Gathering and pipeline systems436 395 
Land, buildings and other equipment 175 140 
Finance lease right-of-use asset24 20 
22,428 21,211 
Accumulated depreciation, depletion and amortization(4,999)(3,836)
 $17,429 $17,375 
Capitalized Exploratory Well Costs
As of September 30, 2022, the Company did not have any projects with exploratory well costs capitalized for a period of greater than one year after drilling.
4. Debt and Credit Agreements
The Company’s debt and credit agreements consisted of the following:
(In millions)September 30,
2022		December 31,
2021
6.51% weighted-average private placement senior notes
$— $37 
5.58% weighted-average private placement senior notes
— 87 
3.65% weighted-average private placement senior notes
825 825 
4.375% senior notes due June 1, 2024 (1)
44 750 
3.90% senior notes due May 15, 2027
750 750 
4.375% senior notes due March 15, 2029
500 500 
Net premium (discount)119 185 
Unamortized debt issuance costs(6)(9)
$2,232 $3,125 
________________________________________________________
(1) Includes $44 million of current portion of long-term debt at September 30, 2022 that was called for redemption in October 2022.
At September 30, 2022, the Company was in compliance with all financial and other covenants for both its revolving credit facility and senior notes.
In September 2022, the Company redeemed $706 million principal amount of its 4.375% senior notes for approximately $706 million, exclusive of interest. In August 2022, the Company repurchased $37 million principal amount of its 6.51% weighted-average senior notes for approximately $38 million and $87 million principal amount of its 5.58% weighted-average
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senior notes for approximately $92 million. In connection with these transactions, the Company recognized a net gain on debt extinguishment of $26 million during the nine months ended September 30, 2022, primarily due to the write off of related debt premiums and debt issuance costs.
Subsequent Event. In October 2022, the Company redeemed the remaining $44 million of its Cimarex 4.375% senior notes for approximately $44 million, exclusive of interest.
Revolving Credit Agreement
At September 30, 2022, the Company had no borrowings outstanding under its revolving credit facility and unused commitments of $1.5 billion.
5. Derivative Instruments
As of September 30, 2022, the Company had the following outstanding financial commodity derivatives:
 20222023
Natural GasFourth QuarterFirst QuarterSecond QuarterThird QuarterFourth Quarter
Waha swaps (1)
     Volume (MMBtu)1,550,000 — — — — 
     Weighted average price$4.77 $— $— $— $— 
Waha gas collars (1)
     Volume (MMBtu)1,840,000 8,100,000 8,190,000 8,280,000 8,280,000 
     Weighted average floor$2.50 $3.03 $3.03 $3.03 $3.03 
     Weighted average ceiling$3.12 $5.39 $5.39 $5.39 $5.39 
NYMEX collars
     Volume (MMBtu)63,770,000 40,500,000 4,550,000 4,600,000 1,550,000 
     Weighted average floor$4.47 $5.14 $4.50 $4.50 $4.50 
     Weighted average ceiling$7.20 $9.41 $8.39 $8.39 $8.39 
El Paso Permian gas collars (2)
     Volume (MMBtu)1,840,000 — — — — 
     Weighted average floor$2.50 $— $— $— $— 
     Weighted average ceiling$3.15 $— $— $— $— 
PEPL gas collars (3)
     Volume (MMBtu)1,840,000 — — — — 
     Weighted average floor$2.60 $— $— $— $— 
     Weighted average ceiling$3.27 $— $— $— $— 
Leidy basis swaps (4)
     Volume (MMBtu)1,550,000 — — — — 
     Weighted average price$(1.50)$— $— $— $— 
________________________________________________________
(1)The index price is Waha West Texas Natural Gas Index (“Waha”) as quoted in Platt’s Inside FERC.
(2)The index price is El Paso Natural Gas Company, Permian Basin Index (“Perm EP”) as quoted in Platt’s Inside FERC.
(3)The index price is Panhandle Eastern Pipe Line, Tex/OK Mid-Continent Index (“PEPL”) as quoted in Platt’s Inside FERC.
(4)The index price is Transco, Leidy Line receipts (“Leidy”) as quoted in Platt’s Inside FERC.
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20222023
OilFourth QuarterFirst QuarterSecond Quarter
WTI oil collars
     Volume (Mbbl)2,116 1,350 1,365 
     Weighted average floor$67.65 $70.00 $70.00 
     Weighted average ceiling$112.50 $116.03 $116.03 
WTI Midland oil basis swaps (1)
     Volume (Mbbl)2,116 1,350 1,365 
     Weighted average differential$0.46 $0.63 $0.63 
________________________________________________________
(1)The index price is WTI Midland as quoted by Argus Americas Crude.
Effect of Derivative Instruments on the Condensed Consolidated Balance Sheet
Fair Values of Derivative Instruments
  Derivative AssetsDerivative Liabilities
(In millions)Balance Sheet LocationSeptember 30,
2022		December 31,
2021		September 30,
2022		December 31,
2021
Commodity contractsDerivative instruments (current)$8 $7 $52 $159 
Commodity contractsOther assets (non-current)2 — — — 
$10 $7 $52 $159 
Offsetting of Derivative Assets and Liabilities in the Condensed Consolidated Balance Sheet
(In millions)September 30,
2022		December 31,
2021
Derivative assets  
Gross amounts of recognized assets$70 $27 
Gross amounts offset in the condensed consolidated balance sheet(60)(20)
Net amounts of assets presented in the condensed consolidated balance sheet10 7 
Gross amounts of financial instruments not offset in the condensed consolidated balance sheet— — 
Net amount$10 $7 
Derivative liabilities   
Gross amounts of recognized liabilities$112 $179 
Gross amounts offset in the condensed consolidated balance sheet(60)(20)
Net amounts of liabilities presented in the condensed consolidated balance sheet52 159 
Gross amounts of financial instruments not offset in the condensed consolidated balance sheet13 35 
Net amount$65 $194 
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Effect of Derivative Instruments on the Condensed Consolidated Statement of Operations
 Three Months Ended 
September 30,		Nine Months Ended 
September 30,
(In millions)2022202120222021
Cash paid on settlement of derivative instruments    
Gas contracts$(202)$(64)$(405)$(61)
Oil contracts(57)— (318)— 
Non-cash gain (loss) on derivative instruments    
Gas Contracts2 (137)(47)(241)
Oil Contracts101 — 157 — 
 $(156)$(201)$(613)$(302)
6. Fair Value Measurements
The Company follows the authoritative guidance for measuring fair value of assets and liabilities in its financial statements. For further information regarding the fair value hierarchy, refer to Note 1 of the Notes to the Consolidated Financial Statements in the Form 10-K.
Financial Assets and Liabilities
The following fair value hierarchy table presents information about the Company’s financial assets and liabilities measured at fair value on a recurring basis:
(In millions)Quoted Prices in
Active Markets for
Identical Assets
(Level 1)		Significant Other
Observable Inputs
(Level 2)		Significant
Unobservable Inputs
(Level 3)		Balance at  
September 30, 2022
Assets    
Deferred compensation plan$40 $— $— $40 
Derivative instruments— 2 68 70 
$40 $2 $68 $110 
Liabilities   
Deferred compensation plan$53 $— $— $53 
Derivative instruments— — 112 112 
$53 $— $112 $165 
(In millions)Quoted Prices in
Active Markets for
Identical Assets
(Level 1)		Significant Other
Observable Inputs
(Level 2)		Significant
Unobservable Inputs
(Level 3)		Balance at  
December 31, 2021
Assets    
Deferred compensation plan$47 $— $— $47 
Derivative instruments— — 27 27 
$47 $— $27 $74 
Liabilities   
Deferred compensation plan$56 $— $— $56 
Derivative instruments— — 179 179 
$56 $— $179 $235 
The Company’s investments associated with its deferred compensation plans consist of mutual funds and deferred shares of the Company’s common stock that are publicly traded and for which market prices are readily available.
The derivative instruments were measured based on quotes from the Company’s counterparties or internal models. Such quotes and models have been derived using an income approach that considers various inputs, including current market and contractual prices for the underlying instruments, quoted forward commodity prices, basis differentials, volatility factors and interest rates for a similar length of time as the derivative contract term as applicable. Estimates are derived from or verified using relevant NYMEX futures contracts and/or are compared to multiple quotes obtained from counterparties. The
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determination of the fair values presented above also incorporates a credit adjustment for non-performance risk. The Company measured the non-performance risk of its counterparties by reviewing credit default swap spreads for the various financial institutions with which it has derivative transactions while non-performance risk of the Company is evaluated using market credit spreads provided by several of the Company’s banks. The Company has not incurred any losses related to non-performance risk of its counterparties and does not anticipate any material impact on its financial results due to non-performance by third parties.
The most significant unobservable inputs relative to the Company’s Level 3 derivative contracts are basis differentials and volatility factors. An increase (decrease) in these unobservable inputs would result in an increase (decrease) in fair value, respectively. The Company does not have access to the specific assumptions used in its counterparties’ valuation models. Consequently, additional disclosures regarding significant Level 3 unobservable inputs were not provided.
The following table sets forth a reconciliation of changes in the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy:
Nine Months Ended 
September 30,
(In millions)20222021
Balance at beginning of period$(152)$24 
Total gain (loss) included in earnings(596)(222)
Settlement (gain) loss704 43 
Transfers in and/or out of Level 3— — 
Balance at end of period$(44)$(155)
Change in unrealized gains (losses) relating to assets and liabilities still held at the end of the period$(11)$(157)
Non-Financial Assets and Liabilities
The Company discloses or recognizes its non-financial assets and liabilities, such as impairments or acquisitions, at fair value on a nonrecurring basis. As none of the Company’s other non-financial assets and liabilities were measured at fair value as of September 30, 2022, additional disclosures were not required.
The estimated fair value of the Company’s asset retirement obligations at inception is determined by utilizing the income approach by applying a credit-adjusted risk-free rate, which takes into account the Company’s credit risk, the time value of money, and the current economic state to the undiscounted expected abandonment cash flows. Given the unobservable nature of the inputs, the measurement of the asset retirement obligations was classified as Level 3 in the fair value hierarchy.
Fair Value of Other Financial Instruments
The estimated fair value of other financial instruments is the amount at which the instruments could be exchanged currently between willing parties. The carrying amounts reported in the Condensed Consolidated Balance Sheet for cash and cash equivalents and restricted cash approximate fair value, due to the short-term maturities of these instruments. Cash and cash equivalents and restricted cash are classified as Level 1 in the fair value hierarchy and the remaining financial instruments are classified as Level 2.
The fair value of the Company’s 4.375% senior notes due June 1, 2024, 3.90% senior notes due May 15, 2027 and 4.375% senior notes due March 15, 2029 is based on quoted market prices, which is classified as Level 1 in the fair value hierarchy. The Company uses available market data and valuation methodologies to estimate the fair value of its private placement senior notes. The fair value of the private placement senior notes is the estimated amount the Company would have to pay a third party to assume the debt, including a credit spread for the difference between the issue rate and the period end market rate. The credit spread is the Company’s default or repayment risk. The credit spread (premium or discount) is determined by comparing the Company’s senior notes and revolving credit facility to new issuances (secured and unsecured) and secondary trades of similar size and credit statistics for both public and private debt. The fair value of the private placement senior notes is based on interest rates currently available to the Company. The Company’s private placement senior notes are valued using an income approach and are classified as Level 3 in the fair value hierarchy.
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The carrying amount and estimated fair value of debt is as follows:
 September 30, 2022December 31, 2021
(In millions)Carrying
Amount		Estimated Fair
Value		Carrying
Amount		Estimated Fair
Value
Long-term debt$2,232 $1,984 $3,125 $3,163 
Current maturities(44)(44)— — 
Long-term debt, excluding current maturities$2,188 $1,940 $3,125 $3,163 
7. Asset Retirement Obligations
Activity related to the Company’s asset retirement obligations is as follows:
(In millions)Nine Months Ended 
September 30, 2022
Balance at beginning of period$263 
Liabilities incurred9 
Liabilities settled (1)
Liabilities divested(3)
Accretion expense7 
Balance at end of period275 
Less: current asset retirement obligations(5)
Noncurrent asset retirement obligations$270 
8. Commitments and Contingencies
Contractual Obligations
The Company has various contractual obligations in the normal course of its operations. There have been no material changes to the Company’s contractual obligations described under “Transportation, Processing and Gathering Agreements” and “Lease Commitments” as disclosed in Note 8 of the Notes to Consolidated Financial Statements in the Form 10-K, except as discussed below.
Lease Commitments
On July 7, 2022, the Company commenced a lease for an electric hydraulic fracturing fleet. The Company recognized an operating lease liability and right-of-use asset of approximately $148 million during the third quarter of 2022 related to this lease.
Legal Matters
Pennsylvania Office of Attorney General Matter
On June 16, 2020, the Office of Attorney General of the Commonwealth of Pennsylvania informed the Company that it will pursue certain misdemeanor and felony charges in a Susquehanna County Magisterial District Court against the Company related to alleged violations of the Pennsylvania Clean Streams Law, which prohibits discharge of industrial wastes. The Company is vigorously defending itself against such charges; however, the proceedings could result in fines or penalties against the Company. At this time, it is not possible to estimate the amount of any fines or penalties, or the range of such fines or penalties, that are reasonably possible in this case.
Securities Litigation
In October 2020, a class action lawsuit styled Delaware County Emp. Ret. Sys. v. Cabot Oil and Gas Corp., et. al. (U.S. District Court, Middle District of Pennsylvania), was filed against the Company, Dan O. Dinges, its then Chief Executive Officer, and Scott C. Schroeder, its Chief Financial Officer, alleging that the Company made misleading statements in its periodic filings with the SEC in violation of Section 10(b) and Section 20 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). The plaintiffs allege misstatements in the Company’s public filings and disclosures over a number of years relating to its potential liability for alleged environmental violations in Pennsylvania. The plaintiffs allege that such misstatements caused a decline in the price of the Company’s common stock when it disclosed in its Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2019 two notices of violations from the Pennsylvania Department of
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Environmental Protection and an additional decline when it disclosed on June 15, 2020 the criminal charges brought by the Office of the Attorney General of the Commonwealth of Pennsylvania related to alleged violations of the Pennsylvania Clean Streams Law, which prohibits discharge of industrial wastes. The court appointed Delaware County Employees Retirement System to represent the purported class on February 3, 2021. In April 2021, the complaint was amended to include Phillip L. Stalnaker, the Company’s then Senior Vice President of Operations, as a defendant. The plaintiffs seek monetary damages, interest and attorney’s fees.
Also in October 2020, a stockholder derivative action styled Ezell v. Dinges, et. al. (U.S. District Court, Middle District of Pennsylvania) was filed against the Company, Messrs. Dinges and Schroeder and the Board of Directors of the Company serving at that time, for alleged securities violations under Section 10(b) and Section 21D of the Exchange Act arising from the same alleged misleading statements that form the basis of the class action lawsuit described above. In addition to the Exchange Act claims, the derivative actions also allege claims based on breaches of fiduciary duty and statutory contribution theories. In December 2020, the Ezell case was consolidated with a second derivative case filed in the U.S. District Court, Middle District of Pennsylvania with similar allegations. In January 2021, a third derivative case was filed in the U.S. District Court, Middle District of Pennsylvania with substantially similar allegations and it too was consolidated with the Ezell case in February 2021.
On February 25, 2021, the Company filed a motion to transfer the class action lawsuit to the U.S. District Court for the Southern District of Texas, in Houston, Texas, where its headquarters are located. On June 11, 2021, the Company filed a motion to dismiss the class action lawsuit on the basis that the plaintiffs’ allegations do not meet the requirements for pleading a claim under Section 10(b) or Section 20 of the Exchange Act. On June 22, 2021, the motion to transfer the class action lawsuit to the Southern District of Texas was granted. Pursuant to the prior agreement of the parties, the consolidated derivative case discussed in the preceding paragraph was also transferred to the Southern District of Texas on July 12, 2021. Subsequently, an additional stockholder derivative action styled Treppel Family Trust U/A 08/18/18 Lawrence A. Treppel and Geri D. Treppel for the benefit of Geri D. Treppel and Larry A. Treppel v. Dinges, et al. (U.S. District Court, Southern District of Texas, Houston Division), asserting substantially similar Delaware common law claims as in the existing derivative cases, was filed in the Southern District of Texas and consolidated with the existing consolidated derivative cases. On January 12, 2022, the U.S. District Court for the Southern District of Texas granted the Company’s motion to dismiss the class action lawsuit but allowed the plaintiffs to file an amended complaint. The class action plaintiffs filed their amended complaint on February 11, 2022. The Company filed a motion to dismiss the amended class action complaint on March 10, 2022. On August 10, 2022, the U.S. District Court for the Southern District of Texas granted in part and denied in part the Company’s motion to dismiss the amended class action complaint, dismissing certain claims with prejudice but allowing certain claims to proceed. The Company filed its answer to the amended class action complaint on September 14, 2022. With respect to the consolidated derivative cases, on April 1, 2022, the U.S. District Court for the Southern District of Texas granted the Company’s motion to dismiss such consolidated derivative cases but allowed the plaintiffs to file an amended complaint. The derivative plaintiffs filed their third amended complaint on May 16, 2022. The Company filed its motion to dismiss such amended complaint on June 24, 2022, and filed its reply in support of such motion to dismiss on September 4, 2022. The Company’s motion to dismiss the consolidated derivative cases is fully briefed and is pending for decision. The Company intends to vigorously defend the class action and derivative lawsuits.
In November 2020, the Company received a stockholder demand for inspection of books and records under Section 220 of the General Corporation Law of the State of Delaware (“Section 220 Demand”). The Section 220 Demand seeks broad categories of documents reviewed by the Board of Directors and minutes of meetings of the Board of Directors pertaining to alleged environmental violations in Pennsylvania, as well as documents relating to any board of directors conflicts of interest, dating from January 1, 2015 to the present. The Company also received three other similar requests from other stockholders in February and June 2021. On May 17, 2021, the Company was served with a complaint filed in the Court of Chancery of the State of Delaware by the stockholder making the February 2021 Section 220 Demand to compel the production of books and records requested. After making an agreed books and records production, the Section 220 complaint was voluntarily dismissed effective September 21, 2021. The Company also provided substantially the same books and records production in response to the other three Section 220 requests described above. It is possible that one or more additional stockholder suits could be filed pertaining to the subject matter of the Section 220 Demands and the class and derivative actions described above.
Other Legal Matters
The Company is a defendant in various other legal proceedings arising in the normal course of business. All known liabilities are accrued when management determines they are probable based on its best estimate of the potential loss. While the outcome and impact of these legal proceedings on the Company cannot be predicted with certainty, management believes that the resolution of these proceedings will not have a material effect on the Company’s financial position, results of operations or cash flows.
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Contingency Reserves
When deemed necessary, the Company establishes reserves for certain legal proceedings. The establishment of a reserve is based on an estimation process that includes the advice of legal counsel and subjective judgment of management. While management believes these reserves to be adequate, it is reasonably possible that the Company could incur additional losses with respect to those matters for which reserves have been established. The Company believes that any such amount above the amounts accrued would not be material to the Condensed Consolidated Financial Statements. Future changes in facts and circumstances not currently known or foreseeable could result in the actual liability exceeding the estimated ranges of loss and amounts accrued.
9. Revenue Recognition
Disaggregation of Revenue
The following table presents revenues from contracts with customers disaggregated by product:
Three Months Ended September 30,Nine Months Ended September 30,
(In millions)2022202120222021
Natural gas$1,644 $641 $4,223 $1,526 
Oil755 — 2,330 — 
NGL259 — 784 — 
Other18 — 47 — 
$2,676 $641 $7,384 $1,526 
All of the Company’s revenues from contracts with customers represent products transferred at a point in time as control is transferred to the customer and generated in the United States of America.
Transaction Price Allocated to Remaining Performance Obligations
A significant number of the Company’s product sales contracts are short-term in nature, with a contract term of one year or less. For those contracts, the Company has utilized the practical expedient exempting the Company from disclosure of the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of one year or less.
As of September 30, 2022, the Company had $7.3 billion of unsatisfied performance obligations related to natural gas sales that have a fixed pricing component and a contract term greater than one year. The Company expects to recognize these obligations over periods ranging from two to 16 years.
Contract Balances
Receivables from contracts with customers are recorded when the right to consideration becomes unconditional, which is generally when control of the product has been transferred to the customer. Receivables from contracts with customers were $1.3 billion and $922 million as of September 30, 2022 and December 31, 2021, respectively, and are reported in accounts receivable, net on the Condensed Consolidated Balance Sheet. As of September 30, 2022, the Company has no assets or liabilities related to its revenue contracts, including no upfront payments or rights to deficiency payments.
10. Income Taxes
On August 16, 2022, the Inflation Reduction Act (the “IRA”) was signed into law pursuant to the budget reconciliation process. The IRA introduced a new 15 percent corporate alternative minimum tax, effective for tax years beginning after December 31, 2022, on the adjusted financial statement income (“AFSI”) of corporations with average AFSI exceeding $1 billion over a three-year testing period. The IRA also introduced an excise tax of one percent on the fair market value of certain public company stock repurchases made after December 31, 2022. The Company is continuing to evaluate the IRA and its requirements, as well as the impact to the Company’s business.
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11. Capital Stock
Dividends
Common Stock
In February 2022, the Company’s Board of Directors approved an increase in the quarterly base dividend on the Company’s common stock from $0.125 to $0.15 per share.
The following table summarizes the dividends the Company has paid on its common stock during the nine months ended September 30, 2022 and 2021:
Rate per share
FixedVariableTotalTotal Dividends Paid
(In millions)
2022:
First quarter$0.15 $0.41 $0.56 $455 
Second quarter0.15 0.45 0.60 484 
Third quarter0.15 0.50 0.65 519 
Total year-to-date$0.45 $1.36 $1.81 $1,458 
2021:
First quarter$0.10 $— $0.10 $40 
Second quarter0.11 — 0.1144 
Third quarter0.11 — 0.1144 
Total year-to-date$0.32 $— $0.32 $128 
Subsequent Event. In November 2022, the Company’s Board of Directors approved the quarterly base dividend of $0.15 per share and a variable dividend of $0.53 per share, resulting in a base-plus-variable dividend of $0.68 per share on the Company’s common stock.
Treasury Stock
In February 2022, the Company’s Board of Directors terminated the previously authorized share repurchase program and authorized a new share repurchase program. This new share repurchase program authorizes the Company to purchase up to $1.25 billion of the Company’s common stock in the open market or in negotiated transactions.
During the nine months ended September 30, 2022, the Company repurchased 28 million shares for $740 million under the new share repurchase program. As of September 30, 2022, 107 million shares were held as treasury stock, with $510 million remaining under the Company’s current share repurchase program.
Cimarex Redeemable Preferred Stock
In May 2022, the holders of 21,900 shares of Cimarex redeemable preferred stock elected to convert their Cimarex redeemable preferred stock into Coterra common stock and cash. As a result of the conversion, the holders received 809,846 shares of Coterra common stock and $10 million in cash according to the terms of the Certificate of Designations for the Cimarex redeemable preferred stock. The book value of the converted shares was $39 million, and upon conversion the excess of carrying value over cash paid was credited to additional paid-in capital. There was no gain or loss recognized on the transaction because it was completed in accordance with the original terms of the Certificate of Designations for the Cimarex redeemable preferred stock. At September 30, 2022, there were 6,125 shares of Cimarex redeemable preferred stock outstanding with a carrying value of $11 million.

12. Stock-Based Compensation
General
The Company grants certain stock-based compensation awards, including restricted stock awards, restricted stock units, performance share awards and stock options. Stock-based compensation expense associated with these awards was $26 million and $10 million in the third quarter of 2022 and 2021, respectively, and $70 million and $26 million for the nine months ended
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September 30, 2022 and 2021, respectively. Stock-based compensation expense is included in general and administrative expense in the Condensed Consolidated Statement of Operations.
Refer to Note 13 of the Notes to the Consolidated Financial Statements in the Form 10-K for further description of the various types of stock-based compensation awards and the applicable award terms.
Restricted Stock Units - Employees
During the nine months ended September 30, 2022, the Company granted 2,244,405 restricted stock units to employees of the Company with a weighted average grant date value of $24.80 per unit. The fair value of restricted stock unit grants is based on the closing stock price on the grant date. Restricted stock units generally vest either at the end of a three-year service period or on a graded or graduated vesting basis at each anniversary date over a three-year service period. The Company used an annual forfeiture rate assumption of zero to five percent for purposes of recognizing stock-based compensation expense for its restricted stock units.
Restricted Stock Units - Non-Employees Directors
In June 2022, the Company granted 45,472 restricted stock units, with a weighted-average grant date value of $35.19 per unit, to the Company’s non-employee directors. The fair value of these units is measured based on the closing stock price on grant date. These units will vest in April 2023 and the Company will recognize compensation expense ratably over the vesting period.
Performance Share Awards
The Company has two outstanding types of performance share awards: one based on performance conditions measured against the Company’s internal performance metrics (“Employee Performance Share Awards”) and one based on market conditions (“TSR Performance Share Awards”). The Company used an annual forfeiture rate assumption of zero to five percent for purposes of recognizing stock-based compensation expense for its performance share awards.
Performance Share Awards Based on Internal Performance Metrics
The fair value of the Employee Performance Share Awards is based on the closing stock price on the grant date. Each performance share award represents the right to receive up to 100 percent of the award in shares of the Company’s common stock.
Employee Performance Share Awards. During 2022, the compensation committee of the Board of Directors of the Company certified that the performance conditions for certain of the Employee Performance Share Awards that were granted in 2020 and 2021 had been met. In July 2022, 1,775,790 shares with a grant date fair value of $22 million were issued and fully vested.
Performance Share Awards Based on Market Conditions
These awards have both an equity and liability component, with the right to receive up to the first 100 percent of the award in shares of common stock and the right to receive up to an additional 100 percent of the value of the award in excess of the equity component in cash. The equity portion of these awards is valued on the grant date and is not marked to market, while the liability portion of the awards is valued as of the end of each reporting period on a mark-to-market basis. The Company calculates the fair value of the equity and liability portions of the awards using a Monte Carlo simulation model.
TSR Performance Share Awards. During the nine months ended September 30, 2022, the Company granted 1,161,599 TSR Performance Share Awards, which are earned, or not earned, based on the comparative performance of the Company’s common stock measured against a predetermined group of companies in the Company’s peer group and certain industry-related indices over a three-year performance period, which commenced on February 1, 2022 and ends on January 31, 2025. The 2022 TSR Performance Share Awards include a feature that will reduce the potential cash component of the award if the actual performance is negative over the three-year period and the base calculation indicates an above-target payout.
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The following assumptions were used to determine the grant date fair value of the equity component on February 28, 2022 and the period-end fair value of the liability component of the TSR Performance Share Awards:
 Grant DateSeptember 30,
2022
Fair value per performance share award $17.89 $12.47 
Assumptions:   
     Stock price volatility42.3 %42.3 %
     Risk-free rate of return1.60 %4.19 %
13. Earnings per Common Share
Basic earnings per share (“EPS”) is computed by dividing net income by the weighted-average number of common shares outstanding for the period. Diluted EPS is similarly calculated, except that the common shares outstanding for the period is increased using the treasury stock method to reflect the potential dilution that could occur if outstanding stock awards were vested at the end of the applicable period. Anti-dilutive shares represent potentially dilutive securities that are excluded from the computation of diluted income or loss per share as their impact would be anti-dilutive.
The following is a calculation of basic and diluted earnings per share:
Three Months Ended 
September 30,		Nine Months Ended 
September 30,
(In millions, except per share amounts)2022202120222021
Income (Numerator)
Net income$1,196 $64 $3,033 $220 
Less: dividends attributable to participating securities(2)— (5)— 
Less: Cimarex redeemable preferred stock dividends— — (1)— 
Net income available to common stockholders$1,194 $64 $3,027 $220 
Shares (Denominator)
Weighted-average shares - Basic792 400 801 399 
Dilution effect of stock awards at end of period5 3 4 3 
Weighted-average shares - Diluted797 403 805 402 
Earnings per share:
Basic$1.51 $0.16 $3.78 $0.55 
Diluted$1.50 $0.16 $3.77 $0.55 
The following is a calculation of weighted-average shares excluded from diluted EPS due to anti-dilutive effect:
Three Months Ended 
September 30,		Nine Months Ended 
September 30,
(In millions)2022202120222021
Weighted-average stock awards excluded from diluted EPS due to the anti-dilutive effect calculated using the treasury stock method1 — 1 1 
14. Restructuring Costs
In connection with the Merger, the Company incurred certain merger-related restructuring costs that are primarily related to workforce reductions and the associated employee severance benefits that were triggered by the Merger. The Company recognized $44 million of restructuring expenses during 2022 related to the accrual of employee-related severance and termination benefits associated with the expected termination of certain Cimarex employees.
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The following table summarizes the Company’s restructuring liabilities:
(In millions)Nine Months Ended September 30, 2022
Balance at beginning of period$43 
Additions to merger-related restructuring costs44
Payments of merger-related restructuring costs(13)
Balance at end of period$74 
15. Additional Balance Sheet Information
Certain balance sheet amounts are comprised of the following:
(In millions)September 30,
2022		December 31,
2021
Accounts receivable, net  
Trade accounts $1,273 $922 
Joint interest accounts 125 83 
Other accounts 24 34 
 1,422 1,039 
Allowance for credit losses (3)(2)
 $1,419 $1,037 
Other assets  
Deferred compensation plan $40 $47 
Debt issuance costs3 5 
Operating lease right-of-use assets435 317 
Derivative instruments2 — 
Other accounts46 20 
 $526 $389 
Accounts payable
Trade accounts $76 $94 
Royalty and other owners 531 315 
Accrued transportation95 96 
Accrued capital costs 149 88 
Taxes other than income 81 60 
Accrued lease operating costs31 29 
Other accounts47 65 
 $1,010 $747 
Accrued liabilities
Employee benefits $67 $81 
Taxes other than income 35 13 
Restructuring liability35 43 
Operating lease liabilities116 69 
Financing lease liabilities6 14 
Other accounts 35 40 
 $294 $260 
Other liabilities
Deferred compensation plan $53 $56 
Postretirement benefits29 33 
Operating lease liabilities 319 248 
Financing lease liabilities13 7 
Restructuring liability39 — 
Other accounts80 63 
 $533 $407 
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16. Interest Expense, net
Interest expense is comprised of the following:
Three Months Ended September 30,Nine Months Ended September 30,
(In millions)2022202120222021
Interest Expense, net
Interest expense$29 $10 $90 31 
Debt premium amortization(11)— (32)— 
Debt issuance cost amortization1 1 3 2 
Other(2)2 (2)5 
$17 $13 $59 $38 
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ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following review of operations of Coterra Energy Inc. (“Coterra,” “our,” “we” and “us”) for the three and nine month periods ended September 30, 2022 and 2021 should be read in conjunction with our Condensed Consolidated Financial Statements and the Notes included in this Quarterly Report on Form 10-Q (this “Form 10-Q”) and with the Consolidated Financial Statements, Notes and Management’s Discussion and Analysis included in our Annual Report on Form 10-K for the year ended December 31, 2021 (our “Form 10-K”).
OVERVIEW
Cimarex Merger
On October 1, 2021, we completed a merger transaction (the “Merger”) with Cimarex Energy Co. (“Cimarex”). Cimarex is an oil and gas exploration and production company with operations in Texas, New Mexico and Oklahoma.
In connection with the Merger, we have continued to evaluate and refine our process for assessing the estimated proved reserves of our legacy Cimarex and Cabot operations. Based on the analysis to date, as of September 30, 2022, we anticipate our total company proved reserves will decrease by approximately 15 to 20 percent year over year at December 31, 2022. This decrease in proved reserves is driven by a downward revision to prior estimates of approximately 32 to 36 percent for our Marcellus Shale properties, partially offset by an upward revision of approximately 8 to 12 percent for our Permian and Anadarko properties. Approximately a quarter of the estimated total revision volume in the Marcellus Shale is related to the SEC 5-year rule for PUDs due to the timing of capital investments, changes around well spacing, and location optimization within the Marcellus region. Factors that may impact the size of the total adjustment include commodity prices, well performance, operating expenses and the completion of the annual PUD reserves process, which will be incorporated as of year-end 2022. The expected net downward revision of prior estimates did not have a material impact on our Condensed Consolidated Financial Statements as of and for the period ended September 30, 2022 and is not expected to have a material impact on our 2022 and go-forward Consolidated Financial Statements.
Financial and operational information set forth herein does not include the activity of Cimarex for periods prior to the closing of the Merger.
Financial and Operating Overview
Financial and operating results for the nine months ended September 30, 2022 compared to the nine months ended September 30, 2021 reflect the following:
•Equivalent production increased 69.2 MMboe from 104.0 MMboe, or 380.9 MBoepd, in 2021 to 173.2 MMboe, or 634.4 MBoepd in 2022. The increase was attributable to production during the first nine months of 2022 from properties acquired in the Merger, which significantly expanded our operations.
•Natural gas production increased 144.6 Bcf from 623.9 Bcf, or 2,285.1 Mmcf per day, in the 2021 period to 768.5 Bcf, or 2,815.2 Mmcf per day, in the 2022 period. The increase was primarily attributable to production during the first nine months of 2022 from properties acquired in the Merger, which significantly expanded our operations.
•Oil production increased 24 Mmbbl from prior year. The increase was attributable to production from properties acquired in the Merger.
•NGL production increased 22 Mmbbl from prior year. The increase was attributable to production from properties acquired in the Merger.
•Average realized natural gas price was $4.97 per Mcf, $2.62 higher than the $2.35 per Mcf realized in the corresponding period of the prior year.
•Average realized oil and NGL prices for the nine months ended September 30, 2022 were $85.31 and $36.44 per Bbl, respectively.
•Total capital expenditures were $1,254 million compared to $461 million in the corresponding period of the prior year. The increase in capital expenditures was attributable to our expanded operations after the Merger.
•Drilled 206 gross wells (133.8 net) with a success rate of 100 percent compared to 73 gross wells (70.1 net) with a success rate of 100 percent for the corresponding period of the prior year. Wells drilled represents wells drilled to total depth during the period.
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•Completed 168 gross wells (104.1 net) in 2022 compared to 71 gross wells (67.1 net) in the corresponding period of 2021. Wells completed includes wells completed during the period, regardless of when they were drilled.
•Average rig count during 2022 was approximately 6.2, 2.9 and 1.1 rigs in the Permian Basin, Marcellus Shale and Anadarko Basin, respectively, compared to an average rig count of approximately 2.7 rigs in the Marcellus Shale during the corresponding period of 2021.
•Increased our dividends from $0.32 per share for regular quarterly dividends in 2021 to $1.81 per share during 2022, including $0.45 and $1.36 per share for base and variable dividends, respectively, as part of the Company’s returns-focused strategy.
• Implemented our new share repurchase program and repurchased 28 million shares for $740 million. There were no share repurchases during the nine months ended September 30, 2021.
•Redeemed $706 million principal amount of our 4.375% senior notes and repurchased $37 million principal amount of our 6.51% weighted-average senior notes and $87 million principal amount of our 5.58% weighted-average senior notes during the nine months ended September 30, 2022, as part of our efforts to strengthen our balance sheet. Repaid $188 million of senior notes which matured during the nine months ended September 30, 2021.

Impact of the COVID-19 Pandemic
The ongoing coronavirus (“COVID-19”) pandemic has caused widespread illness and significant loss of life, leading governments across the world to impose severely stringent limitations on movement and human interaction. Our efforts to respond to the challenges presented by the ongoing pandemic, as well as certain operational decisions we previously implemented, such as our maintenance capital program and safety and preventative measures developed to minimize unnecessary risk of exposure and prevent infection among our employees and the communities in which we operate, have helped to minimize the impact, and any resulting disruptions, of the pandemic to our business and operations.
The long-term impact that the COVID-19 pandemic will have on our business, cash flows, liquidity, financial condition and results of operations will depend on future developments, including, among others, the duration, ultimate geographic spread and severity of the virus and its variants, the global availability and efficacy of treatments, vaccines and boosters, vaccination and immunization rates, any significant resurgence in virus transmission and infection in regions that have experienced improvements, the extent and duration of governmental and other measures implemented to try to slow the spread of the virus (including through the re-imposition of prior measures) and other actions by governmental authorities, customers, suppliers and other third parties.
Market Conditions and Commodity Prices
Our financial results depend on many factors, particularly commodity prices and our ability to find, develop and market our production on economically attractive terms. Commodity prices are affected by many factors outside of our control, including changes in market supply and demand, which are impacted by pipeline capacity constraints, inventory storage levels, basis differentials, weather conditions and other factors.
The ongoing conflict between Russia and Ukraine has driven oil and natural gas prices up significantly, in part because of sanctions by the European Union, the United Kingdom and the U.S. on imports of oil and gas from Russia, and may have further global economic consequences, including disruptions of the global energy markets and the amplification of inflation and supply chain constraints. Recent Russian actions have further contributed to global uncertainties for the future, causing even higher oil and natural gas prices. The ultimate impact of the war in Ukraine will depend on future developments and the timing and extent to which normal economic and operating conditions resume.
In addition, the issue of, and increasing political and social attention on, climate change has resulted in both existing and pending national, regional and local legislation and regulatory measures, such as mandates for renewable energy and emissions reductions, targeted at limiting or reducing emissions of greenhouse gases.
Changes in these laws or regulations may result in delays or restrictions in permitting and the development of projects, may result in increased costs and may impair our ability to move forward with our construction, completions, drilling, water management, waste handling, storage, transport and remediation activities, any of which could have an adverse effect on our financial results.
Our revenues, operating results, financial condition and ability to borrow funds or obtain additional capital depend substantially on prevailing commodity prices, particularly oil and natural gas prices. Material declines in commodity prices
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could have a material adverse effect on our operating results, financial condition, liquidity and ability to obtain financing. Lower commodity prices also may reduce the amount of oil, natural gas, and NGLs that we can produce economically, and we may curtail our production during such low commodity price environments. Commodity prices have been and remain volatile, with prices sometimes fluctuating widely. Because of this volatility, we cannot accurately predict future commodity prices or, in turn determine with any degree of certainty what effect increases or decreases in these prices could have on our capital program, production volumes or revenues.
Our long-term success also depends on finding and developing sufficient amounts of oil and natural gas reserves at economical costs. Certain of our capital expenditures and expenses are affected by general inflation, which has risen throughout 2022. We expect to see inflation impact our cost structure for the remainder of 2022, albeit it at a more moderate pace compared to earlier in the year.
Our realized prices are also further impacted by our hedging activities. We account for our derivative instruments on a mark-to-market basis, with changes in fair value recognized in operating revenues in the Condensed Consolidated Statement of Operations. As a result of these mark-to-market adjustments associated with our derivative instruments, we will experience volatility in our earnings due to commodity price volatility. Refer to “Results of Operations” below and Note 5 of the Notes to the Condensed Consolidated Financial Statements for more information.
NYMEX oil and natural gas futures prices have strengthened since the reduction of pandemic-related restrictions and OPEC+ cooperation. Improving oil and natural gas futures prices in part reflect market expectations of limited U.S. supply growth from publicly traded companies as a result of capital investment discipline and a focus on delivering free cash flow returns to stockholders. In addition, natural gas prices have benefited from strong worldwide liquefied natural gas (“LNG”) demand, which is, in part, a result of buyers shifting from Russian gas due to the Ukraine invasion, sustained higher U.S. exports, lower associated gas growth from oil drilling and improved U.S. economic activity. Oil price futures have improved (although such future prices are still lower than current spot prices) coinciding with recovering global economic activity, lower supply from major oil producing countries, OPEC+ cooperation and moderating inventory levels.
Although the current outlook on oil and natural gas prices is generally favorable and our operations have not been significantly impacted in the short-term, in the event further disruptions occur and continue for an extended period of time, our operations could be adversely impacted, commodity prices could decline and our costs may continue to increase. Although we are unable to predict future commodity prices, at current oil, natural gas and NGL price levels, we do not believe that an impairment of our oil and gas properties is reasonably likely to occur in the near future; however, in the event that commodity prices significantly decline or costs increase significantly from current levels, our management would evaluate the recoverability of the carrying value of our oil and gas properties.
For information about the impact of realized commodity prices on our revenues, refer to “Results of Operations” below.
Recent U.S. Tax Legislation
On August 16, 2022, the Inflation Reduction Act of 2022 (the “IRA”) was signed into law pursuant to the budget reconciliation process. The IRA introduced a new 15 percent corporate alternative minimum tax, effective for tax years beginning after December 31, 2022, on the adjusted financial statement income (“AFSI”) of corporations with average AFSI exceeding $1 billion over a three-year testing period. The IRA also introduced an excise tax of one percent on the fair market value of certain public company stock repurchases made after December 31, 2022. We are continuing to evaluate the IRA and its requirements, as well as the impact to our business.

Other Issues and Contingencies
Climate-related regulations and climate-related business trends may impact our business, financial conditions and results of our operations, and we may experience the following:
•decreased demand for goods or services that produce significant greenhouse gas emissions or are related to carbon-based energy sources;
•increased demand for goods that result in lower emissions than competing products;
•increased competition to develop innovative new products that result in lower emissions;
•increased demand for generation and transmission of energy from alternative energy sources; and
•reputational risks resulting from our operations or oil, natural gas and NGLs that we sell to the extent they are perceived to produce material greenhouse gas emissions.

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Outlook
Our 2022 capital program is expected to be approximately $1.6 billion to $1.7 billion, which includes $1.45 billion to $1.55 billion for drilling and completion activities. We expect to fund these capital expenditures with our operating cash flow and, if required, cash on hand.
In 2021, we drilled 114 gross wells (99.9 net) and completed 132 gross wells (108.3 net), of which 14 gross wells (13.0 net) were drilled but uncompleted in prior years. For the nine months ended September 30, 2022, our capital program focused on the Permian Basin, Marcellus Shale and Anadarko Basin, where we drilled 133.8 net wells and completed 104.1 net wells. Our capital program for the remainder of 2022 will focus on execution of our 2022 plan, which remains in line with the updated full-year guidance released in August. We allocate our planned program for capital expenditures based on market conditions, return on capital and free cash flow expectations and availability of services and human resources. We will continue to assess the oil and natural gas price environment and may adjust our capital expenditures accordingly.
FINANCIAL CONDITION
Liquidity and Capital Resources
We strive to maintain an adequate liquidity level to address commodity price volatility and risk. Our primary sources of liquidity are (1) net cash provided by operating activities, (2) cash on hand and (3) available borrowing capacity under our revolving credit facility.
Our liquidity requirements consist primarily of (1) capital expenditures, (2) payment of contractual obligations, including debt and interest payments, (3) working capital requirements, (4) dividend payments and (5) share repurchases. See below for additional discussion and analysis of our cash flows. We believe that, with operating cash flow, cash on hand and availability under our revolving credit facility, we have the ability to finance our spending plans over the next twelve months and, based on current expectations, for the long term.
As of September 30, 2022, we had no borrowings outstanding under our revolving credit facility, our unused commitments were $1.5 billion and we had unrestricted cash on hand of $778 million.
Our revolving credit facility includes a covenant limiting our borrowing capacity based on our leverage ratio. Refer to Note 4 of the Notes to the Consolidated Financial Statements, “Debt and Credit Agreements,” in our Form 10-K for further details regarding our leverage ratio.
Our debt is currently rated as investment grade by the three leading rating agencies. In determining our credit ratings, the agencies consider a number of qualitative and quantitative items including, but not limited to, current commodity prices, our liquidity position, our leverage ratios, our financial results, our asset quality and reserve mix, debt levels and cost structure. Credit ratings are not recommendations to buy, sell, or hold securities and may be subject to revision or withdrawal at any time by the assigning rating agency. There are no “rating triggers” in any of our debt agreements that would accelerate the scheduled maturities should our credit rating fall below a certain level. However, a change in our credit rating could impact our interest rate on any borrowings under our revolving credit facility, and our ability to economically access debt markets in the future and could trigger the requirement to post credit support under various agreements, which could reduce the borrowing capacity under our revolving credit facility.
Our investments are generally funded with cash flow provided by operating activities together with cash on hand, bank borrowings, sales of non-strategic assets, and, from time to time, private or public financing based on our monitoring of capital markets and our balance sheet. We also may use a combination of these sources of funds to refinance or retire our outstanding debt through privately negotiated transactions, open market repurchases, redemptions, exchanges, tender offers or otherwise, but we have no obligation to do so.
At September 30, 2022, we were in compliance with all financial and other covenants applicable to our revolving credit facility and senior notes. Refer to our Form 10-K for further discussion of our restrictive financial covenants.
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Cash Flows
Our cash flows from operating activities, investing activities and financing activities were as follows:
Nine Months Ended 
September 30,
(In millions)20222021
Cash flows provided by operating activities $3,972 $716 
Cash flows used in investing activities (1,183)(459)
Cash flows used in financing activities (3,047)(322)
Net decrease in cash, cash equivalents and restricted cash$(258)$(65)
Operating Activities. Operating cash flow fluctuations are substantially driven by changes in commodity prices, production volumes and operating expenses. Commodity prices have historically been volatile, primarily as a result of supply and demand for oil and natural gas, pipeline infrastructure constraints, basis differentials, inventory storage levels, seasonal influences and geopolitical, economic and other factors. In addition, fluctuations in cash flow may result in an increase or decrease in our capital expenditures.
On October 1, 2021, we and Cimarex completed the Merger. Although we expect to achieve certain general and administrative expense synergies over the long-term through cost savings, in the near-term we will continue to incur certain merger-related costs, which in total are expected to range from $100 million to $110 million. These payments will primarily relate to workforce reductions and the associated employee severance benefits. As of September 30, 2022, we have incurred approximately $87 million of employee severance benefits.
Our working capital is substantially influenced by the variables discussed above and fluctuates based on the timing and amount of borrowings and repayments under our revolving credit facility, repayments of debt, the timing of cash collections and payments on our trade accounts receivable and payable, respectively, payment of dividends, repurchases of our securities and changes in the fair value of our commodity derivative activity. From time to time, our working capital will reflect a deficit, while at other times it will reflect a surplus. This fluctuation is not unusual. At September 30, 2022 and December 31, 2021, we had a working capital surplus of $935 million and $916 million, respectively. We believe we have adequate liquidity and availability under our revolving credit facility to meet our working capital requirements over the next 12 months.
Net cash provided by operating activities for the nine months ended September 30, 2022 increased by $3.3 billion compared to the same period in 2021. This increase was primarily due to higher natural gas, oil and NGL revenue, partially offset by higher operating expenses, higher cash paid on derivative settlements and a larger decrease in working capital and other assets and liabilities. The increase in natural gas, oil and NGL revenue was primarily due to our expanded operations after the Merger and an increase in realized natural gas prices from the nine months ended September 30, 2021 to the nine months ended September 30, 2022.
Refer to “Results of Operations” below for additional information relative to commodity prices, production and operating expense fluctuations. We are unable to predict future commodity prices and, as a result, cannot provide any assurance about future levels of net cash provided by operating activities.
Investing Activities. Cash flows used in investing activities increased by $724 million for the nine months ended September 30, 2022 compared to the nine months ended September 30, 2021. The increase was primarily due to $746 million of higher capital expenditures as a result of our expanded operations after the Merger.
Financing Activities. Cash flows used in financing activities increased by $2.7 billion for the nine months ended September 30, 2022 compared to the nine months ended September 30, 2021. This increase was primarily due to higher dividend payments of $1.3 billion as a result of the increase in our base dividend rate from $0.10 per share in April 2021 to $0.15 per share in February 2022, resulting in a base dividend of $0.45 per share for the nine months ended September 30, 2022 compared to $0.32 per share for the nine months ended September 30, 2021, and the payment of variable dividends of $1.36 per share during the nine months ended September 30, 2022. Dividend payments also increased due to the additional shares issued in October 2021 as consideration in the Merger. The increase in cash flows used in financing activities was also due to share repurchases of $740 million during the nine months ended September 30, 2022 and $642 million of higher debt repayments, net of borrowings during the nine months ended September 30, 2022.
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Capitalization
Information about our capitalization is as follows:
(In millions)September 30,
2022		December 31,
2021
Debt (1)
$2,232 $3,125 
Stockholders' equity 12,659 11,738 
Total capitalization $14,891 $14,863 
Debt to total capitalization 15 %21 %
Cash and cash equivalents $778 $1,036 
________________________________________________________
(1)Includes $44 million of current portion of long-term debt at September 30, 2022 that was called for redemption in October 2022. There were no borrowings outstanding under our revolving credit facility as of September 30, 2022 and December 31, 2021.
Share repurchases. Under our authorized share repurchase program approved in February 2022, we repurchased 28 million shares of our common stock for $740 million during the nine months ended September 30, 2022. We did not repurchase any shares of our common stock during the nine months ended September 30, 2021.
Dividends. During the nine months ended September 30, 2022, we paid dividends of $1.5 billion on our common stock and Cimarex’s redeemable preferred stock, which included regular quarterly dividends on our common stock of $0.45 per share and variable dividends of $1.36 per share, and a dividend of $23.125 per share on Cimarex’s redeemable preferred stock in each of the first three quarters of 2022. During the nine months ended September 30, 2021, we paid dividends of $128 million ($0.32 per share) on our common stock.
In November 2022, our Board of Directors approved a quarterly base dividend of $0.15 per share and a variable dividend of $0.53 per share, resulting in a total base-plus-variable dividend of $0.68 per share on our common stock.
Capital and Exploration Expenditures
On an annual basis, we generally fund most of our capital expenditures, excluding any significant property acquisitions, with cash generated from operations, and, if required, cash on hand and borrowings under our revolving credit facility. We budget these expenditures based on our projected cash flows for the year.
The following table presents major components of our capital and exploration expenditures:
Nine Months Ended 
September 30,
(In millions)20222021
Capital expenditures:  
Drilling and facilities$1,164 $448 
Leasehold acquisitions6 4 
Pipeline and gathering41 — 
Other43 9 
 1,254 461 
Exploration expenditures(1)
23 9 
$1,277 $470 
________________________________________________________
(1)There were no exploratory dry hole costs for the nine months ended September 30, 2022 and 2021.
For the nine months ended September 30, 2022, our capital program was focused on the Permian Basin, Marcellus Shale and Anadarko Basin, where we drilled 133.8 net wells and completed 104.1 net wells. We expect our 2022 capital program to be approximately $1.6 billion to $1.7 billion and will focus on the Permian Basin, where we are currently running six rigs and two completion crews, and the Marcellus Shale, where we are currently running three rigs and one completion crew. In August we increased our full-year expected 2022 capital program due to inflation and a modest increase in activity planned for the remaining second half of 2022. Refer to “Outlook” for additional information regarding the current year drilling program. We will continue to assess the commodity price environment and may adjust our capital expenditures accordingly. 
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Contractual Obligations
We have various contractual obligations in the normal course of our operations. There have been no material changes to our contractual obligations described under “Transportation, Processing and Gathering Agreements” and “Lease Commitments” as disclosed in Note 8 of the Notes to the Consolidated Financial Statements and the obligations described under “Contractual Obligations” in Item 7 “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in our Form 10-K, except as described under “Lease Commitments” as disclosed in Note 8 of the Notes to the Condensed Consolidated Financial Statements included in this Form 10-Q.
Critical Accounting Policies and Estimates
Our discussion and analysis of our financial condition and results of operations are based on our Condensed Consolidated Financial Statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The preparation of these financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses. Refer to our Form 10-K for further discussion of our critical accounting policies.
RESULTS OF OPERATIONS
Third Quarters of 2022 and 2021 Compared
Operating Revenues
Three Months Ended September 30,Variance
(In millions)20222021AmountPercent
Operating Revenues
Natural gas $1,644 $641 $1,003 156 %
Oil755 — 755 100 %
NGL259 — 259 100 %
Loss on derivative instruments(156)(201)45 22 %
Other 18 — 18 100 %
 $2,520 $440 $2,080 473 %
Production Revenues
Our production revenues are derived from the sale of our oil, natural gas and NGL production. Our 2022 production revenues were substantially higher due to the Merger, which significantly expanded our operations to include the Permian and Anadarko Basins, and increased commodity prices. Increases and decreases in our revenues, profitability and future production growth are highly dependent on the commodity prices we receive, which we expect to continue to fluctuate due to supply and demand factors, the availability of transportation, seasonality and geopolitical, economic and other factors.
Natural Gas Revenues
 Three Months Ended September 30,VarianceIncrease
(Decrease)
(In millions)
 20222021AmountPercent
Price variance ($/Mcf)$6.37 $2.95 $3.42 116 %$884 
Volume variance (Bcf)258.2217.4 40.819 %119 
    $1,003 
Natural gas revenues increased $1.0 billion primarily due to significantly higher natural gas prices and higher production. The increase in production was primarily related to properties acquired in the Merger, which significantly expanded our operations.
Oil Revenues
Oil revenues increased $755 million due to our expanded operations after the Merger and increased oil prices.
NGL Revenues
NGL revenues increased $259 million due to our expanded operations after the Merger and increased NGL prices.
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Loss on Derivative Instruments
Net gains and losses on our derivative instruments are a function of fluctuations in the underlying commodity index prices as compared to the contracted prices and the monthly cash settlements (if any) of the instruments. We have elected not to designate our derivatives as hedging instruments for accounting purposes and, therefore, we do not apply hedge accounting treatment to our derivative instruments. Consequently, changes in the fair value of our derivative instruments and cash settlements on the instruments are included as a component of operating revenues as either a net gain or loss on derivative instruments. Cash settlements of our contracts are included in cash flows from operating activities in our statements of cash flows. The following table presents the components of “Loss on derivative instruments” for the periods indicated:
 Three Months Ended 
September 30,
(In millions)20222021
Cash paid on settlement of derivative instruments
Gas contracts$(202)$(64)
Oil contracts(57)— 
Non-cash gain (loss) on derivative instruments
Gas contracts2 (137)
Oil contracts101 — 
$(156)$(201)
Operating Costs and Expenses
Costs associated with producing oil and natural gas are substantial. Among other factors, some of these costs vary with commodity prices, some trend with the volume and commodity mix of production, some are a function of the number of wells we own, some depend on the prices charged by service companies and some fluctuate based on a combination of the foregoing. Our operating costs and expenses in 2022 were substantially increased due to the Merger, which significantly expanded our operations to include the Permian and Anadarko Basins. In addition, our costs for services, labor and supplies have recently increased due to higher demand for those items, inflation and supply chain disruptions.
The following table reflects our operating costs and expenses for the periods indicated and a discussion of the operating costs and expenses follows.
 Three Months Ended September 30,VariancePer BOE
(In millions, except per BOE)20222021AmountPercent20222021
Operating Expenses    
Direct operations$118 $21 $97 462 %$1.99 $0.59 
Transportation, processing and gathering255 149 106 71 %4.33 4.10 
Taxes other than income 102 8 94 1,175 %1.72 0.23 
Exploration 10 4 6 150 %0.17 0.11 
Depreciation, depletion and amortization 422 97 325 335 %7.16 2.68 
General and administrative 107 64 43 67 %1.80 1.80 
$1,014 $343 $671 196 %
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Direct Operations
Direct operations expense generally consists of costs for labor, equipment, maintenance, saltwater disposal, compression, power, treating and miscellaneous other costs (collectively, “lease operating expense”). Direct operations expense also includes well workover activity necessary to maintain production from existing wells. Direct operations expense consisted of lease operating expense and workover expense as follows:
Three Months Ended September 30,Per BOE
(In millions, except per BOE)20222021Variance20222021
Direct Operating Expense
Lease operating expense$93 $17 $76 $1.57 $0.48 
Workover expense25 4 21 0.42 0.11 
$118 $21 $97 $1.99 $0.59 
Lease operating and workover expense increased primarily due to our expanded operations after the Merger.
Transportation, Processing and Gathering
Transportation, processing and gathering costs principally consist of expenditures to prepare and transport production downstream from the wellhead, including gathering, fuel, and compression, and processing costs, which are incurred to extract NGLs from the raw natural gas stream. Gathering costs also include costs associated with operating our gas gathering infrastructure, including operating and maintenance expenses. Costs vary by operating area and will fluctuate with increases or decreases in production volumes, contractual fees, and changes in fuel and compression costs.
Transportation, processing and gathering costs increased $106 million primarily due to our expanded operations after the Merger, along with a slight increase in gathering charges in the Marcellus Shale.
Taxes Other Than Income
Taxes other than income consist of production (or severance) taxes, drilling impact fees, ad valorem taxes and other taxes. State and local taxing authorities assess these taxes, with production taxes being based on the volume or value of production, drilling impact fees being based on drilling activities and prevailing natural gas prices and ad valorem taxes being based on the value of properties. The following table presents taxes other than income for the periods indicated:
Three Months Ended September 30,
(In millions)20222021Variance
Taxes Other than Income
Production$78 $— $78 
Drilling impact fees8 7 1 
Ad valorem15 — 15 
Other1 1 — 
$102 $8 $94 
Taxes other than income as a percentage of production revenue3.8 %1.2 %
Taxes other than income increased $94 million. Production taxes represented the majority of our taxes other than income, which increased primarily due to higher production related to properties acquired in the Merger and higher commodity prices. Ad valorem taxes increased primarily due to our expanded operations after the Merger and higher property valuations.
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Depreciation, Depletion and Amortization
Depreciation, depletion and amortization (“DD&A”) expense consisted of the following for the periods indicated:
Three Months Ended September 30,Per BOE
(In millions, except per BOE)20222021Variance20222021
DD&A Expense
Depletion$391 $94 $297 $6.63 $2.60 
Depreciation18 1 17 0.31 0.02 
Amortization of unproved properties11 1 10 0.19 0.03 
Accretion of ARO2 1 1 0.03 0.03 
$422 $97 $325 $7.16 $2.68 
Depletion of our producing properties is computed on a field basis using the units-of-production method under the successful efforts method of accounting. The economic life of each producing property depends upon the estimated proved reserves for that property, which in turn depend upon the assumed realized sales price for future production. Therefore, fluctuations in oil and gas prices will impact the level of proved developed and proved reserves used in the calculation. Higher prices generally have the effect of increasing reserves, which reduces depletion expense. Conversely, lower prices generally have the effect of decreasing reserves, which increases depletion expense. The cost of replacing production also impacts our depletion expense. In addition, changes in estimates of reserve quantities, estimates of operating and future development costs, reclassifications of properties from unproved to proved and impairments of oil and gas properties will also impact depletion expense. Our depletion expense increased $297 million due to increased production and a higher depletion rate of $6.63 per BOE for the three months ended September 30, 2022, both of which are attributable to the value of the oil and gas properties acquired on the closing date of the Merger, compared to $2.60 per BOE for the three months ended September 30, 2021.
Fixed assets consist primarily of gas gathering facilities, water infrastructure, buildings, vehicles, aircraft, furniture and fixtures and computer equipment and software. These items are recorded at cost and are depreciated on the straight-line method based on expected lives of the individual assets, which range from three to 30 years. Also included in our depreciation expense is the depreciation of the right-of-use asset associated with our finance lease gathering system. The increase in depreciation expense during the three months ended September 30, 2022 as compared to the three months ended September 30, 2021 is primarily due to depreciation on our gathering facilities acquired in the Merger.
Unproved properties are amortized based on our drilling experience and our expectation of converting our unproved leaseholds to proved properties. If development of unproved properties is deemed unsuccessful and the properties are abandoned or surrendered, the capitalized costs are expensed in the period the determination is made. The rate of amortization depends on the timing and success of our exploration and development program. Our amortization of unproved properties increased due to the amortization of our unproved properties acquired in the Merger.
General and Administrative
General and administrative (“G&A”) expense consists primarily of salaries and related benefits, stock-based compensation, office rent, legal and consulting fees, systems costs and other administrative costs incurred. A portion of our G&A expense is reported net of amounts reimbursed to us by working interest owners of the oil and gas properties we operate. The table below reflects our G&A expense for the periods indicated:
Three Months Ended September 30,
(In millions)20222021Variance
G&A Expense
General and administrative expense$68 $14 $54 
Stock-based compensation expense26 10 16 
Merger-related expense13 40 (27)
$107 $64 $43 
G&A expense, excluding stock-based compensation and merger related expenses, increased $54 million primarily due to the Merger, which significantly expanded our headcount and office-related expenses.
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Stock-based compensation expense will fluctuate based on the grant date fair value of awards, the number of awards, the requisite service period of the awards, estimated employee forfeitures, and the timing of the awards. Stock-based compensation expense increased $16 million primarily due to the issuance of additional shares as consideration in the Merger and increased headcount, and the accelerated vesting of employee performance shares as described under “Stock-Based Compensation” as disclosed in Note 12 of the Notes to the Condensed Consolidated Financial Statements included in this Form 10-Q.
Merger-related expenses decreased $27 million primarily due to lower administrative and professional fees associated with the Merger partially offset by $12 million of employee-related severance and termination benefits associated with the expected termination of certain employees, which is being accrued over the expected transition period.
Interest Expense, net
The table below reflects our interest expense, net for the periods indicated:
Three Months Ended September 30,
(In millions)20222021Variance
Interest Expense, net
Interest expense$29 $10 $19 
Debt premium amortization(11)— (11)
Debt issuance cost amortization 1 1 — 
Other(2)2 (4)
$17 $13 $4 
Interest expense, net increased $4 million, primarily due to the incremental interest expense, net of premium amortization associated with the debt assumed in the Merger of $2.2 billion. This increase was partially offset by lower interest expense due to the repayment of $100 million of our 3.65% weighted-average private placement senior notes, which matured in September 2021, and the repayment of $37 million of our 6.51% weighted-average private placement senior notes and $87 million of our 5.58% weighted-average private placement senior notes in August 2022.
Gain on Debt Extinguishment
During the third quarter of 2022, we paid down $830 million of our debt for $836 million and recognized a net gain on debt extinguishment of $26 million primarily due to the write off of related debt premiums and debt issuance costs.
Income Tax Expense
The table below reflects our income tax expense for the periods indicated:
Three Months Ended September 30,
(In millions)20222021Variance
Income Tax Expense
Current tax expense$292 $18 $274 
Deferred tax expense27 2 25
$319 $20 $299 
Combined federal and state effective income tax rate21.1 %24.6 %
Income tax expense increased $299 million due to higher pre-tax income in the third quarter of 2022 compared to the third quarter of 2021, partially offset by a lower effective tax rate. The effective tax rate was lower for the third quarter of 2022 compared to the third quarter of 2021 due to differences in the non-recurring discrete items recorded during the third quarter of 2022 versus the third quarter of 2021.
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First Nine Months of 2022 and 2021 Compared
Operating Revenues
 Nine Months Ended September 30,Variance
(In millions)20222021AmountPercent
Operating Revenues
Natural gas $4,223 $1,526 $2,697 177 %
Oil2,330 — 2,330 100 %
NGL784 — 784 100 %
Loss on derivative instruments(613)(302)(311)(103)%
Other 47 — 47 100 %
 $6,771 $1,224 $5,547 453 %
Production Revenues
Natural Gas Revenues
 Nine Months Ended September 30,VarianceIncrease
(Decrease)
(In millions)
 20222021AmountPercent
Price variance ($/Mcf)$5.49 $2.45 $3.04 124 %$2,342 
Volume variance (Bcf)768.5623.9144.6 23 %355 
    $2,697 
Natural gas revenues increased $2.7 billion primarily due to significantly higher natural gas prices and higher production. The increase in production was primarily related to properties acquired in the Merger, which significantly expanded our operations.
Oil Revenues
Oil revenues increased $2.3 billion due to our expanded operations after the Merger and increased oil prices.
NGL Revenues
NGL revenues increased $784 million due to our expanded operations after the Merger and increased NGL prices.
Loss on Derivative Instruments
The following table presents the components of “Loss on derivative instruments” for the periods indicated:
 Nine Months Ended 
September 30,
(In millions)20222021
Cash (paid) received on settlement of derivative instruments
Gas contracts$(405)$(61)
Oil contracts(318)— 
Non-cash (loss) gain on derivative instruments
Gas contracts(47)(241)
Oil contracts157 — 
$(613)$(302)
Operating Costs and Expenses
Our operating costs and expenses in 2022 were substantially increased due to the Merger, which significantly expanded our operations to include the Permian and Anadarko Basins. In addition, our costs for services, labor and supplies have recently increased due to higher demand for those items, inflation and supply chain disruptions.
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The following table reflects our operating costs and expenses for the periods indicated and a discussion of the operating costs and expenses follows.
 Nine Months Ended September 30,VariancePer BOE
(In millions, except per BOE)20222021AmountPercent20222021
Operating Expenses    
Direct operations$334 $54 $280 519 %$1.93 $0.52 
Transportation, processing and gathering726 419 307 73 %4.19 4.03 
Taxes other than income 276 17 259 1,524 %1.59 0.17 
Exploration 23 9 14 156 %0.13 0.09 
Depreciation, depletion and amortization 1,196 283 913 323 %6.91 2.72 
General and administrative 301 116 185 159 %1.73 1.13 
$2,856 $898 $1,958 218 %
Direct Operations
Direct operations expense consisted of lease operating expense and workover expense as follows:
Nine Months Ended September 30,Per BOE
(In millions, except per BOE)20222021Variance20222021
Direct Operating Expense
Lease operating expense$269 $44 $225 $1.55 $0.42 
Workover expense65 10 55 0.38 0.10 
$334 $54 $280 $1.93 $0.52 
Lease operating and workover expense increased primarily due to our expanded operations after the Merger.
Transportation, Processing and Gathering
Transportation, processing and gathering costs increased $307 million primarily due to our expanded operations after the Merger, along with a slight increase in gathering charges in the Marcellus Shale.
Taxes Other Than Income
The following table presents taxes other than income for the periods indicated:
Nine Months Ended September 30,
(In millions)20222021Variance
Taxes Other than Income
Production$223 $— $223 
Drilling impact fees23 16 7 
Ad valorem29 — 29 
Other1 1 — 
$276 $17 $259 
Taxes other than income as a percentage of production revenue3.8 %1.1 %
Taxes other than income increased $259 million. Production taxes represented the majority of our taxes other than income, which increased primarily due to higher production related to properties acquired in the Merger and higher commodity prices. Drilling impact fees increased primarily due to higher natural gas prices. Ad valorem taxes increased primarily due to our expanded operations after the Merger and higher property valuations.
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Depreciation, Depletion and Amortization
DD&A expense consisted of the following for the periods indicated:
Nine Months Ended September 30,Per BOE
(In millions, except per BOE)20222021Variance20222021
DD&A Expense
Depletion$1,086 $274 $812 $6.27 $2.63 
Depreciation53 5 48 0.31 0.05 
Amortization of unproved properties50 1 49 0.29 0.01 
Accretion of ARO7 3 4 0.04 0.03 
$1,196 $283 $913 $6.91 $2.72 
Depletion expense increased $812 million due to increased production and a higher depletion rate of $6.27 per BOE for the nine months ended September 30, 2022, both of which are attributable to the value of the oil and gas properties acquired on the closing date of the Merger, compared to $2.63 per BOE for the nine months ended September 30, 2021.
Depreciation expense increased $48 million primarily due to depreciation on our gathering facilities acquired in the Merger.
Amortization of unproved properties increased $49 million due to the release of certain leaseholds during the period and the amortization of our unproved properties acquired in the Merger.
General and Administrative
The table below reflects our G&A expense for the periods indicated:
Nine Months Ended September 30,
(In millions)20222021Variance
G&A Expense
General and administrative expense$173 $44 $129 
Stock-based compensation expense70 26 44 
Merger-related expense58 46 12 
$301 $116 $185 
G&A expense, excluding stock-based compensation and merger-related expenses, increased $129 million primarily due to the Merger, which significantly expanded our headcount and office-related expenses.
Stock-based compensation expense will fluctuate based on the grant date fair value of awards, the number of awards, the requisite service period of the awards, estimated employee forfeitures, and the timing of the awards. Stock-based compensation expense increased $44 million primarily due to the issuance of additional shares as consideration in the Merger and increased headcount, and the accelerated vesting of employee performance shares as described under “Stock-Based Compensation” as disclosed in Note 12 of the Notes to the Condensed Consolidated Financial Statements included in this Form 10-Q.
Merger-related expenses increased $12 million primarily due to $51 million of employee-related severance and termination benefits associated with the expected termination of certain employees, which is being accrued over the expected transition period, partially offset by $39 million of lower transaction-related costs associated with the Merger.
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Interest Expense, net
The table below reflects our interest expense, net for the periods indicated:
Nine Months Ended September 30,
(In millions)20222021Variance
Interest Expense, net
Interest expense$90 $31 $59 
Debt premium amortization(32)— (32)
Debt issuance cost amortization3 2 1 
Other(2)5 (7)
$59 $38 $21 
Interest expense, net increased $21 million primarily due to the incremental interest expense, net of premium amortization associated with the debt assumed in the Merger of $2.2 billion. This increase was partially offset by lower interest expense due to the repayment of $100 million of our 3.65% weighted-average private placement senior notes, which matured in September 2021, and the repayment of $37 million of our 6.51% weighted-average private placement senior notes and $87 million of our 5.58% weighted-average private placement senior notes in August 2022.
Gain on Debt Extinguishment
During the third quarter of 2022, we paid down $830 million of our debt for $836 million and recognized a net gain on debt extinguishment of $26 million primarily due to the write off of related debt premiums and debt issuance costs.
Income Tax Expense
Nine Months Ended September 30,
(In millions)20222021Variance
Income Tax Expense
Current tax expense$720 $51 $669 
Deferred tax expense128 17 111 
$848 $68 $780 
Combined federal and state effective income tax rate21.9 %23.7 %
Income tax expense increased $780 million due to higher pre-tax income attributable to higher commodity prices and our expanded operations following the Merger, partially offset by a lower effective tax rate. The effective tax rate was lower for the nine months ended September 30, 2022 compared to the nine months ended September 30, 2021 due to differences in the non-recurring discrete items recorded during the nine months ended September 30, 2022 and 2021.
Forward-Looking Information
The statements regarding future financial and operating performance and results, the anticipated effects of, and certain other matters related to, the Merger involving Cimarex, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in or incorporated by reference into this report, are forward-looking statements. The words “expect”, “project”, “estimate”, “believe”, “anticipate”, “intend”, ‘budget”, “plan”, “forecast”, “target”, “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 report will occur as expected, and actual results may differ materially from those included in this report. Forward-looking statements are based on current expectations and assumptions that involve a number of risks and uncertainties that could cause actual results to differ materially from those included in this report. These risks and uncertainties include, without limitation, the potential effects of further developments related to the long-term impact of the COVID-19 pandemic and variants thereof on our business, financial condition and results of operations and the economy as a whole, the risk that our and Cimarex’s 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 availability of cash on hand and other sources of liquidity to fund our capital expenditures, actions by, or disputes among or between, members of OPEC+, market factors, market prices (including geographic basis differentials) of oil and natural gas, impacts of inflation, labor
35
shortages and economic disruption, including as a result of pandemics and geopolitical disruptions such as the war in Ukraine, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (“SEC”) filings. Refer to “Risk Factors” in Item 1A of Part I of our Form 10-K and in Item 1A of Part II of this Form 10-Q for additional information about these risks and uncertainties. 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, we undertake no obligation to update or revise any forward-looking statement, whether as a result of new information, future events or otherwise. You are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date hereof.
Investors should note that we announce material financial information in SEC filings, press releases and public conference calls. Based on guidance from the SEC, we may use the Investors section of our website (www.coterra.com) to communicate with investors. It is possible that the financial and other information posted there could be deemed to be material information. The information on our website is not part of, and is not incorporated into, this report.
ITEM 3. Quantitative and Qualitative Disclosures about Market Risk
In the normal course of business, we are subject to a variety of risks, including market risks associated with changes in commodity prices and interest rate movements on outstanding debt. The following quantitative and qualitative information is provided about financial instruments to which we were party to as of September 30, 2022 and from which we may incur future gains or losses from changes in commodity prices or interest rates.
Commodity Price Risk
Our most significant market risk exposure is pricing applicable to our oil, natural gas and NGL production. Realized prices are mainly driven by the worldwide price for oil and spot market prices for North American natural gas and NGL production. These prices have been volatile and unpredictable. To mitigate the volatility in commodity prices, we may enter into derivative instruments to hedge a portion of our production.
Derivative Instruments and Risk Management Activities
Our risk management strategy is designed to reduce the risk of commodity price volatility for our production in the oil and natural gas markets through the use of financial commodity derivatives. A committee that consists of members of senior management oversees our risk management activities. Our financial commodity derivatives generally cover a portion of our production and, while protecting us in the event of price declines, limit the benefit to us in the event of price increases. Further, if any of our counterparties defaulted, this protection might be limited as we might not receive the full benefit of our financial commodity derivatives. Please read the discussion below as well as Note 5 of the Notes to the Consolidated Financial Statements in our Form 10-K for a more detailed discussion of our derivatives.
Periodically, we enter into financial commodity derivatives, including collar, swap, roll differential swap and basis swap agreements, to protect against exposure to commodity price declines related to our oil and natural gas production. Our credit agreement restricts our ability to enter into financial commodity derivatives other than to hedge or mitigate risks to which we have actual or projected exposure or as permitted under our risk management policies and that do not subject us to material speculative risks. All of our financial derivatives are used for risk management purposes and are not held for trading purposes. Under the collar agreements, if the index price rises above the ceiling price, we pay the counterparty. If the index price falls below the floor price, the counterparty pays us. Under the swap agreements, we receive a fixed price on a notional quantity of natural gas in exchange for paying a variable price based on a market-based index.
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As of September 30, 2022, we had the following outstanding financial commodity derivatives:
Estimated Value at September 30, 2022
(in millions)
20222023
Natural GasFourth QuarterFirst QuarterSecond QuarterThird QuarterFourth Quarter
Waha swaps (1)
$2 
     Volume (MMBtu)1,550,000 — — — — 
     Weighted average price$4.77 $— $— $— $— 
Waha gas collars (1)
8 
     Volume (MMBtu)1,840,000 8,100,000 8,190,000 8,280,000 8,280,000 
     Weighted average floor$2.50 $3.03 $3.03 $3.03 $3.03 
     Weighted average ceiling$3.12 $5.39 $5.39 $5.39 $5.39 
NYMEX collars(62)
     Volume (MMBtu)63,770,000 40,500,000 4,550,000 4,600,000 1,550,000 
     Weighted average floor$4.47 $5.14 $4.50 $4.50 $4.50 
     Weighted average ceiling$7.20 $9.41 $8.39 $8.39 $8.39 
El Paso Permian gas collars (2)
(2)
     Volume (MMBtu)1,840,000 — — — — 
     Weighted average floor$2.50 $— $— $— $— 
     Weighted average ceiling$3.15 $— $— $— $— 
PEPL gas collars (3)
(4)
     Volume (MMBtu)1,840,000 — — — — 
     Weighted average floor$2.60 $— $— $— $— 
     Weighted average ceiling$3.27 $— $— $— $— 
Leidy Basis swaps (4)
1 
     Volume (MMBtu)1,550,000 — — — — 
     Weighted average price$(1.50)$— $— $— $— 
Total Natural Gas Estimated Value$(57)
________________________________________________________
(1)The index price is Waha West Texas Natural Gas Index (“Waha”) as quoted in Platt’s Inside FERC.
(2)The index price is El Paso Natural Gas Company, Permian Basin Index (“Perm EP”) as quoted in Platt’s Inside FERC.
(3)The index price is Panhandle Eastern Pipe Line, Tex/OK Mid-Continent Index (“PEPL”) as quoted in Platt’s Inside FERC.
(4)The index price is Transco, Leidy Line receipts (“Leidy”) as quoted in Platt’s Inside FERC.

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Estimated Value at September 30, 2022
(in millions)
20222023
OilFourth QuarterFirst QuarterSecond Quarter
WTI oil collars$20 
     Volume (Mbbl)2,116 1,350 1,365 
     Weighted average floor$67.65 $70.00 $70.00 
     Weighted average ceiling$112.50 $116.03 $116.03 
WTI oil basis swaps (1)
(5)
     Volume (Mbbl)2,116 1,350 1,365 
     Weighted average differential$0.46 $0.63 $0.63 
Total Oil Estimated Value$15 
___________________________________________________
(1)The index price is WTI Midland as quoted by Argus Americas Crude.
The amounts set forth in the table above represent our total unrealized derivative position at September 30, 2022 and exclude the impact of non-performance risk. Non-performance risk is considered in the fair value of our derivative instruments that are recorded in our Condensed Consolidated Financial Statements and is primarily evaluated by reviewing credit default swap spreads for the various financial institutions with which we have derivative contracts, while our non-performance risk is evaluated using a market credit spread provided by several of our banks.
A significant portion of our expected oil and natural gas production for the remainder of 2022 and beyond is currently unhedged and directly exposed to the volatility in oil and natural gas prices, whether favorable or unfavorable.
During the nine months ended September 30, 2022, oil collars with floor prices ranging from $35.00 to $90.00 per Bbl and ceiling prices ranging from $45.15 to $120.85 per Bbl covered 7.6 Mmbbls, or 32 percent, of oil production at a weighted-average price of $51.49 per Bbl. Oil basis swaps covered 6.6 Mmbbls, or 28 percent, of oil production at a weighted-average price of $0.24 per Bbl. Oil roll differential swaps covered 2.7 Mmbbls, or 11 percent, of oil production at a weighted-average price of $(0.02) per Bbl.
During the nine months ended September 30, 2022, natural gas collars with floor prices ranging from $1.70 to $8.50 per Mmbtu and ceiling prices ranging from $2.10 to $10.63 per Mmbtu covered 178.5 Bcf, or 23 percent of natural gas production at a weighted-average price of $4.71 per Mmbtu. Natural gas swaps covered 11.9 Bcf, or 2 percent of natural gas production at a weighted average price of $2.41 per Mmbtu.
We are exposed to market risk on financial commodity derivative instruments to the extent of changes in market prices of oil and natural gas. However, the market risk exposure on these derivative contracts is generally offset by the gain or loss recognized upon the ultimate sale of the commodity. Although notional contract amounts are used to express the volume of oil and natural gas agreements, the amounts that can be subject to credit risk in the event of non-performance by third parties are substantially smaller. Our counterparties are primarily commercial banks and financial service institutions that our management believes present minimal credit risk and our derivative contracts are with multiple counterparties to minimize our exposure to any individual counterparty. We perform both quantitative and qualitative assessments of these counterparties based on their credit ratings and credit default swap rates where applicable. We have not incurred any losses related to non-performance risk of our counterparties and we do not anticipate any material impact on our financial results due to non-performance by third parties. However, we cannot be certain that we will not experience such losses in the future.
The preceding paragraphs contain forward-looking information concerning future production and projected gains and losses, which may be impacted by both production and changes in the future commodity prices. Refer to “Forward-Looking Information” for further details.
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Interest Rate Risk
At September 30, 2022, we had total debt of $2.2 billion (with a principal amount of $2.1 billion). All of our outstanding debt is based on fixed interest rates and, as a result, we do not have significant exposure to movements in market interest rates with respect to such debt. Our revolving credit facility provides for variable interest rate borrowings; however, we did not have any borrowings outstanding as of September 30, 2022 and, therefore, no related exposure to interest rate risk.
Fair Value of Other Financial Instruments
The estimated fair value of other financial instruments is the amount at which the instrument could be exchanged currently between willing parties. The carrying amounts reported in the Condensed Consolidated Balance Sheet for cash, cash equivalents and restricted cash approximate fair value due to the short-term maturities of these instruments.
The fair value of our senior notes is based on quoted market prices. We use available market data and valuation methodologies to estimate the fair value of our private placement senior notes. The fair value of the private placement senior notes is the estimated amount we would have to pay a third party to assume the debt, including a credit spread for the difference between the issue rate and the period end market rate. The credit spread is our default or repayment risk. The credit spread (premium or discount) is determined by comparing our senior notes and revolving credit facility to new issuances (secured and unsecured) and secondary trades of similar size and credit statistics for both public and private debt. The fair value of the private placement senior notes is based on interest rates currently available to us.
The carrying amount and fair value of debt is as follow:
 September 30, 2022December 31, 2021
(In millions)Carrying
Amount		Estimated Fair
Value		Carrying
Amount		Estimated Fair
Value
Long-term debt$2,232 $1,984 $3,125 $3,163 
Current maturities(44)(44)— — 
Long-term debt, excluding current maturities$2,188 $1,940 $3,125 $3,163 

ITEM 4. Controls and Procedures
As of September 30, 2022, the Company carried out an evaluation, under the supervision and with the participation of the Company’s management, including the Company’s Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of the Company’s disclosure controls and procedures pursuant to Rules 13a-15 and 15d-15 of the Securities Exchange Act of 1934 (the Exchange Act). Based upon that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the Company’s disclosure controls and procedures are effective to provide reasonable assurance with respect to the recording, processing, summarizing and reporting, within the time periods specified in the Commission’s rules and forms, of information required to be disclosed by the Company in the reports that it files or submits under the Exchange Act.
During the quarter ended December 31, 2021, the Company completed its Merger with Cimarex. As part of the ongoing integration of the acquired business, the Company is in the process of incorporating the controls and related procedures of Cimarex. Other than incorporating Cimarex’s controls, there were no changes in internal control over financial reporting that occurred during the third quarter of 2022 that have materially affected, or are reasonably likely to have a material effect on, the Company’s internal control over financial reporting.

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PART II. OTHER INFORMATION
ITEM 1. Legal Proceedings
Legal Matters
The information set forth under the heading “Legal Matters” in Note 8 of the Notes to Condensed Consolidated Financial Statements included in this Form 10-Q is incorporated by reference in response to this item.
Environmental Matters
From time to time, we receive notices of violation from governmental and regulatory authorities in areas in which we operate relating to alleged violations of environmental statutes or the rules and regulations promulgated thereunder. Although we cannot predict with certainty whether these notices of violation will result in fines and/or penalties, if fines and/or penalties are imposed, they may result in monetary sanctions, individually or in the aggregate, in excess of $300,000.
ITEM 1A. Risk Factors
The below risk factor updates a risk factor, and should be read in conjunction with the other risk factors, previously discussed in Part I, Item 1A of our Form 10-K. Additional risks and uncertainties, including risks and uncertainties not presently known to us, or that we currently deem immaterial, could also have an adverse effect on our business, financial condition or results of operations.
Commodity prices fluctuate widely, and low prices for an extended period would likely have a material adverse impact on our business.
Our revenues, operating results, financial condition and ability to borrow funds or obtain additional capital depend substantially on prices we receive for the oil, natural gas and NGLs that we sell. Lower commodity prices may reduce the amount of oil, natural gas and NGLs that we can produce economically. Historically, commodity prices have been volatile, with prices fluctuating widely, and they are likely to continue to be volatile. For example, in 2021, the WTI oil prices ranged from a high of $84.65 to a low of $47.62 per Bbl and NYMEX natural gas prices ranged from a high of $23.86 (during Winter Storm Uri) to a low of $2.43 per Mmbtu, while during the nine months ended September 30, 2022, WTI oil prices ranged from a high of $123.70 to a low of $76.08 per Bbl and NYMEX natural gas prices ranged from a high of $9.85 to a low of $3.73 per Mmbtu. Any substantial or extended decline in future commodity prices would have a material adverse effect on our future business, financial condition, results of operations, cash flows, liquidity or ability to finance planned capital expenditures and commitments. Furthermore, substantial, extended decreases in commodity prices may cause us to delay or postpone a significant portion of our exploration and development projects or may render such projects uneconomic, which may result in significant downward adjustments to our estimated proved reserves and could negatively impact our ability to borrow and our cost of capital and our ability to access capital markets, increase our costs under our revolving credit facility and limit our ability to execute aspects of our business plans. Refer to “Future commodity price declines may result in write-downs of the carrying amount of our oil and gas properties, which could materially and adversely affect our results of operations” in our Form 10-K under Part I, Item IA.
Wide fluctuations in commodity prices may result from relatively minor changes in the supply of and demand for oil, natural gas and NGLs, market uncertainty and a variety of additional factors that are beyond our control. These factors include but are not limited to the following:
•the levels and location of oil, natural gas and NGLs supply and demand and expectations regarding supply and demand, including the potential long-term impact of an abundance of natural gas from shale (such as that produced from our Marcellus Shale properties) on the global natural gas supply;
•the level of consumer demand for oil, natural gas and NGLs, which had been significantly impacted by the COVID-19 pandemic, particularly during 2020, and may be impacted in the future depending on the predominance of new variants of COVID-19;
•weather conditions and seasonal trends;
•political, economic or health conditions in oil, natural gas and NGL producing regions, including the Middle East, Africa, South America and the U.S., including for example, the impacts of local or international pandemics and disasters or events such as the global COVID-19 pandemic;
•geopolitical risks and sanctions, including as a result of the war in Ukraine and other actions that may impact demand and supply chains;
•the ability and willingness of the members of OPEC+ to agree to and maintain oil price and production controls;
•the price level and quantities of foreign imports;
40
•actions of governmental authorities;
•the availability, proximity and capacity of gathering, transportation, processing and/or refining facilities in regional or local areas;
•inventory storage levels and the cost and availability of storage and transportation of oil, natural gas and NGLs;
•the nature and extent of domestic and foreign governmental regulations and taxation, including environmental and climate change regulation;
•the price, availability and acceptance of alternative fuels;
•technological advances affecting energy consumption;
•speculation by investors in oil, natural gas and NGLs;
•variations between product prices at sales points and applicable index prices;
•the impact of increased commodity prices and prices in general, on demand for oil, natural gas and NGLs; and
•overall economic conditions, including the value of the U.S. dollar relative to other major currencies.

These factors and the volatile nature of the energy markets make it impossible to predict future commodity prices. If commodity prices decline significantly for a sustained period of time, the lower prices may cause us to reduce our planned drilling program or adversely affect our ability to make planned expenditures, raise additional capital or meet our financial obligations.
ITEM 2. Unregistered Sales of Equity Securities and Use of Proceeds
Issuer Purchases of Equity Securities
Share repurchase activity during the quarter ended September 30, 2022 was as follows:

PeriodTotal Number of Shares Purchased
(In thousands)		Average Price Paid per Share
Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs
(In thousands) (1)
Maximum Approximate Dollar Value of Shares That May Yet Be Purchased Under the Plans or Programs
(In millions) (2)
July 20221,131 $25.91 1,131 $707 
August 2022500 $27.82 500 $693 
September 20226,718 $27.22 6,718 $510 
Total8,349 8,349 
________________________________________________________
(1)In February 2022, our Board of Directors terminated the previously authorized share repurchase program and authorized a new share repurchase program, which was announced on February 24, 2022. This new share repurchase program authorizes us to purchase up to $1.25 billion of our common stock in privately negotiated transactions or in the open market, including under plans complying with Rule 10b5-1 under the Exchange Act. We purchased 8.3 million common shares for $227 million during the quarter ended September 30, 2022.
(2)As of September 30, 2022, we can purchase up to $510 million of shares under the repurchase program.

41
ITEM 6. Exhibits
Index to Exhibits
Exhibit
Number		 Description
 
   
 
   
 
   
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 Document.
   
101.CAL Inline XBRL Taxonomy Extension Calculation Linkbase Document.
   
101.DEF Inline XBRL Taxonomy Extension Definition Linkbase Document.
   
101.LAB Inline XBRL Taxonomy Extension Label Linkbase Document.
   
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Exhibit
Number		 Description
101.PRE Inline XBRL Taxonomy Extension Presentation Linkbase Document.
104Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).
_______________________________________________________________________________.
*Compensatory plan, contract or arrangement.
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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.
 COTERRA ENERGY INC.
 (Registrant)
  
November 4, 2022By:/s/ THOMAS E. JORDEN
  Thomas E. Jorden
  Chief Executive Officer and President
  (Principal Executive Officer)
  
November 4, 2022By:/s/ SCOTT C. SCHROEDER
  Scott C. Schroeder
  Executive Vice President and Chief Financial Officer
  (Principal Financial Officer)
  
November 4, 2022By:/s/ TODD M. ROEMER
  Todd M. Roemer
  Vice President and Chief Accounting Officer
  (Principal Accounting Officer)
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