v3.20.4
Cover Page - USD ($)
 12 Months Ended
Dec. 31, 2020
Jan. 20, 2021
Jun. 30, 2020
Document Information [Line Items]      
Document Type 10-K    
Document Annual Report true    
Document Period End Date Dec. 31, 2020    
Document Transition Report false    
Entity File Number 001-14901    
Entity Registrant Name CNX Resources Corporation    
Entity Incorporation, State or Country Code DE    
Entity Tax Identification Number 51-0337383    
Entity Address, Address Line One CNX Center    
Entity Address, Address Line Two 1000 CONSOL Energy Drive Suite 400    
Entity Address, City or Town Canonsburg    
Entity Address, State or Province PA    
Entity Address, Postal Zip Code 15317-6506    
City Area Code 724    
Local Phone Number 485-4000    
Entity Well-known Seasoned Issuer Yes    
Entity Voluntary Filers No    
Entity Current Reporting Status Yes    
Entity Interactive Data Current Yes    
Entity Filer Category Large Accelerated Filer    
Entity Small Business false    
Entity Emerging Growth Company false    
ICFR Auditor Attestation Flag true    
Entity Shell Company false    
Entity Public Float     $ 1,111,264,635
Entity Common Stock, Shares Outstanding   219,707,417  
Documents Incorporated by Reference Portions of CNX's Proxy Statement for the Annual Meeting of Shareholders to be held on May 6, 2021, are incorporated by reference in Items 10, 11, 12, 13 and 14 of Part III.    
Amendment Flag false    
Document Fiscal Year Focus 2020    
Document Fiscal Period Focus FY    
Entity Central Index Key 0001070412    
Current Fiscal Year End Date --12-31    
Common Stock      
Document Information [Line Items]      
Title of 12(b) Security Common Stock ($.01 par value)    
Trading Symbol CNX    
Security Exchange Name NYSE    
Preferred Share Purchase Rights      
Document Information [Line Items]      
Title of 12(b) Security Preferred Share Purchase Rights    
No Trading Symbol Flag true    
Security Exchange Name NYSE    
v3.20.4
Consolidated Statements of Income - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Gain (Loss) on Commodity Derivative Instruments $ 172,982 $ 376,105 $ (30,212)
Other Revenue and Operating Income 82,459 87,992 116,723
Total Revenue and Other Operating Income 1,257,978 1,922,449 1,730,434
Operating Expense      
Lease Operating Expense 40,407 65,443 95,139
Production, Ad Valorem and Other Fees 24,196 27,461 32,750
Depreciation, Depletion and Amortization 501,821 508,463 493,423
Purchased Gas Costs 100,902 90,553 64,817
Impairment of Exploration and Production Properties 61,849 327,400 0
Impairment of Goodwill 473,045 0 0
Impairment of Unproved Properties and Expirations 0 119,429 0
Impairment of Other Intangible Assets 0 0 18,650
Selling, General and Administrative Costs 109,375 143,550 134,806
Other Operating Expense 85,472 79,255 72,412
Total Operating Expense 1,697,744 1,736,473 1,226,963
Other Expense (Income)      
Other Expense (Income) 23,584 2,862 (14,571)
Gain on Asset Sales and Abandonments, net (21,224) (35,563) (157,015)
Gain on Previously Held Equity Interest 0 0 (623,663)
(Gain) Loss on Debt Extinguishment (10,101) 7,614 54,118
Interest Expense 170,806 151,379 145,934
Total Other Expense (Income) 163,065 126,292 (595,197)
Total Costs and Expenses 1,860,809 1,862,765 631,766
(Loss) Earnings Before Income Tax (602,831) 59,684 1,098,668
Income Tax (Benefit) Expense (174,087) 27,736 215,557
Net (Loss) Income (428,744) 31,948 883,111
Less: Net Income Attributable to Non-Controlling Interest 55,031 112,678 86,578
Net (Loss) Income Attributable to CNX Resources Shareholders $ (483,775) $ (80,730) $ 796,533
Earnings Per Share [Abstract]      
Basic (in usd per share) $ (2.43) $ (0.42) $ 3.75
Diluted (in usd per share) (2.43) (0.42) 3.71
Dividends Declared Per Share (in usd per share) $ 0 $ 0 $ 0
Natural Gas, NGLs and Oil Revenue      
Revenue $ 896,745 $ 1,364,325 $ 1,577,937
Purchased Gas Revenue      
Revenue 105,792 94,027 65,986
Transportation, Gathering and Compression      
Operating Expense      
Cost of Goods and Services Sold 285,683 330,539 302,933
Exploration and Production Related Other Costs      
Operating Expense      
Cost of Goods and Services Sold $ 14,994 $ 44,380 $ 12,033
v3.20.4
Consolidated Statement of Comprehensive Income - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Statement of Comprehensive Income [Abstract]      
Net (Loss) Income $ (428,744) $ 31,948 $ 883,111
Other Comprehensive (Loss) Income:      
Actuarially Determined Long-Term Liability Adjustments (Net of tax: $914, $1,664, $(792)) (2,579) (4,701) 1,672
Comprehensive (Loss) Income (431,323) 27,247 884,783
Less: Comprehensive Income Attributable to Noncontrolling Interests 55,031 112,678 86,578
Comprehensive (Loss) Income Attributable to CNX Resources Shareholders $ (486,354) $ (85,431) $ 798,205
v3.20.4
Consolidated Statement of Comprehensive Income (Parentheticals) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Adjustment For Actuarially Determined Liabilities      
Other comprehensive income, tax expense $ 914 $ 1,664 $ (792)
v3.20.4
Consolidated Balance Sheets - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Current Assets:    
Cash and Cash Equivalents $ 15,617 $ 16,283
Restricted Cash 735 0
Accounts and Notes Receivable:    
Trade (Note 17) 145,929 133,480
Other Receivables 4,238 13,679
Supplies Inventories 9,657 6,984
Recoverable Income Taxes (Note 6) 88 62,425
Derivative Instruments (Note 19) 84,657 247,794
Prepaid Expenses 12,411 17,456
Total Current Assets 273,332 498,101
Property, Plant and Equipment [Abstract]    
Property, Plant and Equipment 10,963,996 10,572,006
Less—Accumulated Depreciation, Depletion and Amortization 3,938,451 3,435,431
Total Property, Plant and Equipment—Net 7,025,545 7,136,575
Other Assets:    
Operating Lease Right-of-Use Assets (Note 13) 108,683 187,097
Investment in Affiliates 16,022 16,710
Derivative Instruments (Note 19) 188,237 314,096
Goodwill (Note 9) 323,314 796,359
Other Intangible Assets (Note 9) 90,095 96,647
Restricted Cash 5,247 0
Other 11,289 15,221
Total Other Assets 742,887 1,426,130
TOTAL ASSETS 8,041,764 9,060,806
Current Liabilities:    
Accounts Payable 118,185 202,553
Derivative Instruments (Note 19) 42,329 41,466
Current Portion of Finance Lease Obligations (Note 13) 6,876 7,164
Current Portion of Long-Term Debt (Note 12) 22,574 0
Current Portion of Operating Lease Obligations (Note 13) 52,575 61,670
Other Accrued Liabilities (Note 11) 198,773 216,086
Total Current Liabilities 441,312 528,939
Non-Current Liabilities:    
Long-Term Debt (Note 12) 2,401,427 2,754,443
Finance Lease Obligations (Note 13) 1,057 7,706
Operating Lease Obligations (Note 13) 53,235 110,466
Derivative Instruments (Note 19) 127,290 115,862
Deferred Income Taxes (Note 6) 466,253 476,108
Asset Retirement Obligations (Note 7) 84,712 63,377
Other 44,041 41,596
Total Non-Current Liabilities 3,178,015 3,569,558
TOTAL LIABILITIES 3,619,327 4,098,497
Stockholders’ Equity:    
Common Stock, $0.01 Par Value; 500,000,000 Shares Authorized, 220,440,993 Issued and Outstanding at December 31, 2020; 186,642,962 Issued and Outstanding at December 31, 2019 2,208 1,870
Capital in Excess of Par Value 2,959,357 2,199,605
Preferred Stock, 15,000,000 Shares Authorized, None Issued and Outstanding 0 0
Retained Earnings 1,476,056 1,971,676
Accumulated Other Comprehensive Loss (15,184) (12,605)
Total CNX Resources Stockholders’ Equity 4,422,437 4,160,546
Noncontrolling Interest 0 801,763
TOTAL STOCKHOLDERS' EQUITY 4,422,437 4,962,309
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY $ 8,041,764 $ 9,060,806
v3.20.4
Consolidated Balance Sheets (Parentheticals) - $ / shares
Dec. 31, 2020
Dec. 31, 2019
Statement of Financial Position [Abstract]    
Common Stock, Par Value (in usd per share) $ 0.01 $ 0.01
Common Stock, Shares Authorized (in shares) 500,000,000 500,000,000
Common Stock, Issued (in shares) 220,440,993 186,642,962
Common Stock, Outstanding (in shares) 220,440,993 186,642,962
Preferred Stock, Authorized (in shares) 15,000,000 15,000,000
Preferred Stock, Issued (in shares) 0 0
Preferred Stock, Outstanding (in shares) 0 0
v3.20.4
Consolidated Statements of Stockholders' Equity - USD ($)
$ in Thousands
Total
Total CNX Resources Stockholders’ Equity
Common Stock
Capital in Excess of Par Value
Retained Earnings (Deficit)
Accumulated Other Comprehensive Income (Loss)
Non- Controlling Interest
Balance, Beginning of Period at Dec. 31, 2017 $ 3,899,899 $ 3,899,899 $ 2,241 $ 2,450,323 $ 1,455,811 $ (8,476) $ 0
Increase (Decrease) in Stockholders' Equity [Roll Forward]              
Net (Loss) Income 883,111 796,533     796,533   86,578
Issuance of Common Stock 1,713 1,713 8 1,705      
Purchase and Retirement of Common Stock (383,752) (383,752) (259) (206,895) (176,598)    
Shares Withheld for Taxes (5,385) (5,037)     (5,037)   (348)
Amortization of Stock-Based Compensation Awards 21,341 18,930   18,930     2,411
Other Comprehensive Income (Loss) 1,672 1,672       1,672  
ASU 2018-02 Reclassification $ 0       1,100 (1,100)  
Accounting Standards Update [Extensible List] us-gaap:AccountingStandardsUpdate201802Member            
Distributions to CNXM Noncontrolling Interest Holders $ (55,433)           (55,433)
Acquisition of CNX Gathering, LLC 718,577           718,577
Balance, End of Period at Dec. 31, 2018 5,081,743 4,329,958 1,990 2,264,063 2,071,809 (7,904) 751,785
Increase (Decrease) in Stockholders' Equity [Roll Forward]              
Net (Loss) Income 31,948 (80,730)     (80,730)   112,678
Issuance of Common Stock 565 565 9 556      
Purchase and Retirement of Common Stock (115,477) (115,477) (129) (101,559) (13,789)    
Shares Withheld for Taxes (6,310) (5,614)     (5,614)   (696)
Amortization of Stock-Based Compensation Awards 38,425 36,545   36,545     1,880
Other Comprehensive Income (Loss) (4,701) (4,701)       (4,701)  
Distributions to CNXM Noncontrolling Interest Holders (63,884)           (63,884)
Balance, End of Period at Dec. 31, 2019 4,962,309 4,160,546 1,870 2,199,605 1,971,676 (12,605) 801,763
Increase (Decrease) in Stockholders' Equity [Roll Forward]              
Net (Loss) Income (428,744) (483,775)     (483,775)   55,031
Issuance of Common Stock 2,057 2,057 8 2,049      
Purchase and Retirement of Common Stock (43,247) (43,247) (41) (33,067) (10,139)    
Shares Withheld for Taxes (2,015) (1,706)     (1,706)   (309)
Amortization of Stock-Based Compensation Awards 14,382 12,897   12,897     1,485
Equity Component of Convertible Senior Notes, net of Issuance Costs 78,317 78,317   78,317      
Purchase of Capped Call (26,351)     (26,351)      
Other Comprehensive Income (Loss) (2,579) (2,579)       (2,579)  
Distributions to CNXM Noncontrolling Interest Holders (41,987)           (41,987)
CNXM Merger (89,705) 726,278 371 725,907     (815,983)
Balance, End of Period at Dec. 31, 2020 $ 4,422,437 $ 4,422,437 $ 2,208 $ 2,959,357 $ 1,476,056 $ (15,184) $ 0
v3.20.4
Consolidated Statements of Cash Flows - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Cash Flows from Operating Activities:      
Net (Loss) Income $ (428,744) $ 31,948 $ 883,111
Adjustments to Reconcile Net (Loss) Income to Net Cash Provided by Continuing Operating Activities:      
Depreciation, Depletion and Amortization 501,821 508,463 493,423
Amortization of Deferred Financing Costs 21,202 7,747 8,361
Impairment of Exploration and Production Properties 61,849 327,400 0
Impairment of Unproved Properties and Expirations 0 119,429 0
Impairment of Goodwill 473,045 0 0
Impairment of Other Intangible Assets 0 0 18,650
Stock-Based Compensation 14,382 38,425 21,341
Gain on Asset Sales and Abandonments, net (21,224) (35,563) (157,015)
Gain on Previously Held Equity Interest 0 0 (623,663)
(Gain) Loss on Debt Extinguishment (10,101) 7,614 54,118
(Gain) Loss on Commodity Derivative Instruments (172,982) (376,105) 30,212
Loss on Other Derivative Instruments 13,051 0 0
Net Cash Received (Paid) in Settlement of Commodity Derivative Instruments 461,217 69,780 (69,720)
Deferred Income Taxes (118,300) 79,092 345,560
Equity in Loss (Earnings) of Affiliates 688 (2,103) (5,363)
Return on Equity Investment 0 4,056 0
Changes in Operating Assets:      
Accounts and Notes Receivable (4,895) 118,622 (57,734)
Supplies Inventories (2,673) 2,731 1,027
Recoverable Income Taxes 62,336 87,050 (118,498)
Prepaid Expenses 4,923 3,115 (1,391)
Changes in Other Assets (39) 1,000 4,904
Changes in Operating Liabilities:      
Accounts Payable (48,485) (6,405) 12,760
Accrued Interest (4,314) 4,529 (5,839)
Other Operating Liabilities (6,453) 13,242 53,135
Changes in Other Liabilities (1,233) (23,507) (1,556)
Net Cash Provided by Operating Activities 795,071 980,560 885,823
Cash Flows from Investing Activities:      
Capital Expenditures (487,291) (1,192,599) (1,116,397)
CNX Gathering LLC Acquisition, Net of Cash Acquired 0 0 (299,272)
Proceeds from Asset Sales 48,322 45,160 511,767
Net Distributions from Equity Affiliates 0 0 9,250
Net Cash Used in Investing Activities (438,969) (1,147,439) (894,652)
Cash Flows from Financing Activities:      
Net (Payments on) Proceeds from CNX Revolving Credit Facility (500,200)    
Net (Payments on) Proceeds from CNX Revolving Credit Facility   49,000 612,000
Payments on Miscellaneous Borrowings (7,155) (7,149) (7,165)
Payments on Long-Term Notes (882,213) (405,876) (955,019)
Net Proceeds from CSG Non-Revolving Credit Facilities 158,794 0 0
Proceeds from Issuance of Convertible Senior Notes 334,650 0 0
Purchase of Capped Call Related to Convertible Senior Notes (35,673) 0 0
Net (Payments on) Proceeds from CNXM Revolving Credit Facility (20,750) 227,750 (65,500)
Distributions to CNXM Noncontrolling Interest Holders (41,987) (63,884) (55,433)
Proceeds from Issuance of Common Stock 2,057 565 1,713
Shares Withheld for Taxes (2,015) (6,310) (5,385)
Purchases of Common Stock (37,247) (117,477) (381,752)
Debt Issuance and Financing Fees (26,047) (10,655) (20,599)
Net Cash (Used in) Provided by Financing Activities (350,786) 165,964 (483,140)
Net Increase (Decrease) in Cash, Cash Equivalents, and Restricted Cash 5,316 (915) (491,969)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period 16,283 17,198 509,167
Cash, Cash Equivalents, and Restricted Cash at End of Period 21,599 16,283 17,198
CNX Senior Notes      
Cash Flows from Financing Activities:      
Proceeds from Issuance of Senior Notes 707,000 500,000 0
CNXM Senior Notes      
Cash Flows from Financing Activities:      
Proceeds from Issuance of Senior Notes $ 0 $ 0 $ 394,000
v3.20.4
Significant Accounting Policies
 12 Months Ended
Dec. 31, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]  
Significant Accounting Policies SIGNIFICANT ACCOUNTING POLICIES:
A summary of the significant accounting policies of CNX Resources Corporation and subsidiaries ("CNX" or "the Company") is presented below. These, together with the other notes that follow, are an integral part of the Consolidated Financial Statements.

Basis of Consolidation:

The Consolidated Financial Statements include the accounts of CNX Resources Corporation, its wholly-owned subsidiaries, and its majority-owned and/or controlled subsidiaries. Investments in business entities in which CNX does not have control but has the ability to exercise significant influence over the operating and financial policies, are accounted for under the equity method. All significant intercompany transactions and accounts have been eliminated in consolidation. Investments in oil and natural gas producing entities are accounted for under the proportionate consolidation method.
Prior to the Merger on September 28, 2020, see Note 4 - Acquisitions and Dispositions, certain variable interest entities were required to be consolidated pursuant to the Consolidation topic of the Financial Accounting Standards Board (FASB) Accounting Standards Codification. The portion of these entities that was not owned by the Company was presented as non-controlling interest.
Use of Estimates:
The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, as well as various disclosures. Actual results could differ from those estimates. The most significant estimates included in, but not limited to, the preparation of the consolidated financial statements are related to long-lived assets (including intangible assets and goodwill), accounts receivable credit losses, the values of natural gas, NGLs, condensate and oil (collectively "natural gas") reserves, asset retirement obligations, deferred income tax assets and liabilities, contingencies, fair value of derivative instruments, the fair value of the liability and equity components of the convertible senior notes, stock-based compensation and salary retirement benefits.
Cash, Cash Equivalents, and Restricted Cash
Cash and cash equivalents include cash on hand and on deposit at banking institutions as well as all highly liquid short-term securities with original maturities of three months or less.
Restricted cash consists of cash that the Company is contractually obligated to maintain in accordance with the terms of the Cardinal States Gathering LLC and CSG Holdings II LLC Credit Agreements, each dated March 13, 2020 (See Note 12 - Long-Term Debt for more information).
The following table provides a reconciliation of cash, cash equivalents, and restricted cash to amounts shown in the statement of cash flows:
December 31,
202020192018
Cash and Cash Equivalents$15,617 $16,283 $17,198 
Restricted Cash, Current Portion735 — — 
Restricted Cash, Less Current Portion 5,247 — — 
Total Cash, Cash Equivalents and Restricted Cash$21,599 $16,283 $17,198 
Trade Accounts Receivable and Allowance for Credit Losses:
Trade accounts receivable are recorded at the invoiced amount and do not bear interest.
On January 1, 2020, CNX adopted Accounting Standards Update (ASU) 2016-13 Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, which replaces the incurred loss impairment methodology with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. The measurement of expected credit losses is based on relevant information about past events, including historical experience, current conditions, and reasonable and supportable forecasts that affect the collectability of the reported amount. CNX adopted Topic 326 using the prospective transition method.

Prior to adopting Topic 326, CNX reserved for specific accounts receivable when it was probable that all or a part of an outstanding balance would not be collected, such as customer bankruptcies. Collectability was determined based on terms of sale, credit status of customers and various other circumstances. CNX regularly reviewed collectability and established or adjusted the allowance as necessary using the specific identification method. Account balances were charged off against the allowance after all means of collection had been exhausted and the potential for recovery was considered remote. Reserves for uncollectible amounts were not material in the periods presented.
Under Topic 326, management records an allowance for credit losses related to the collectability of third-party customers' receivables using the historical aging of the customer receivable balance. The collectability is determined based on past events, including historical experience, customer credit rating, as well as current market conditions. CNX monitors customer ratings and collectability on an on-going basis. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote.

There were no material financing receivables with a contractual maturity greater than one year at December 31, 2020 or 2019.

As of December 31, 2020 and 2019, Accounts Receivable - Trade were $145,929 and $133,480, respectively, and Other Receivables were $4,238 and $13,679, respectively.

The following represents the roll forward of the allowance for credit losses for the years ended:
December 31,
20202019
Allowance for Credit Losses - Trade, Beginning of Year$— $— 
Provision for Expected Credit Losses84 — 
Allowance for Credit Losses - Trade, End of Period$84 $— 
Allowance for Credit Losses - Other Receivables, Beginning of Year$2,463 $2,038 
Provision for Expected Credit Losses2,760 595 
Write-off of Uncollectible Accounts(1,975)(170)
Allowance for Credit Losses - Other Receivables, End of Period$3,248 $2,463 

Inventories:

Inventories are stated at the lower of cost or net realizable value. The cost of supplies inventory is determined by the average cost method and includes operating and maintenance supplies to be used in the Company's operations.

Property, Plant and Equipment:

CNX uses the successful efforts method of accounting for natural gas producing activities. Costs of property acquisitions, successful exploratory, development wells and related support equipment and facilities are capitalized. Periodic valuation provisions for impairment of capitalized costs of unproved mineral interests are expensed. Costs of unsuccessful exploratory wells are expensed when such wells are determined to be non-productive, or if the determination cannot be made after finding sufficient quantities of reserves to continue evaluating the viability of the project. The costs of producing properties and mineral
interests are amortized using the units-of-production method. Depreciation, depletion and amortization expense is calculated based on the actual produced sales volumes multiplied by the applicable rate per unit, which is derived by dividing the net capitalized costs by the number of units expected to be produced over the life of the reserves. Wells and related equipment and intangible drilling costs are also amortized on a units-of-production method. Proved developed reserves, as estimated by petroleum engineers, are used to calculate amortization of wells and related equipment and facilities and amortization of intangible drilling costs. Total proved reserves, also estimated by petroleum engineers, are used to calculate depletion on property acquisitions. Proved oil and natural gas reserve estimates are based on geological and engineering evaluations of in-place hydrocarbon volumes. Units-of-production amortization rates are revised at least once per year, or more frequently if events and circumstances indicate an adjustment is necessary. Such revisions are accounted for prospectively as changes in accounting estimates. The Company recorded depreciation, depletion and amortization expense related to proved gas properties using the units-of-production method of $400,758, $423,488, and $412,588 for the years ended December 31, 2020, 2019, and 2018, respectively.

Property, plant and equipment is recorded at cost upon acquisition. Expenditures which extend the useful lives of existing plant and equipment are capitalized. Interest costs applicable to major asset additions are capitalized during the construction period. Planned major maintenance costs which do not extend the useful lives of existing plant and equipment are expensed as incurred.

Depreciation of plant and equipment is calculated on the straight-line method over their estimated useful lives or lease terms, generally as follows:
Years
Buildings and Improvements
10 to 45
Machinery and Equipment
3 to 25
Gathering and Transmission
30 to 40
Leasehold ImprovementsLife of Lease

Costs for purchased software are capitalized and amortized using the straight-line method over the estimated useful life which does not exceed seven years.

Impairment of Long-Lived Assets:

Impairment of long-lived assets is recorded when indicators of impairment are present and the undiscounted cash flows estimated to be generated by those assets are less than the assets' carrying value. The carrying value of the assets is then reduced to its estimated fair value which is usually measured based on an estimate of future discounted cash flows. Impairment of equity investments is recorded when indicators of impairment are present, and the estimated fair value of the investment is less than the assets' carrying value.

Impairment of Proved Properties:

CNX performs a quantitative impairment test whenever events or changes in circumstances indicate that an asset group's carrying amount may not be recoverable, over proved properties using the published NYMEX forward prices, timing, methods and other assumptions consistent with historical periods. When indicators of impairment are present, tests require that the Company first compare expected future undiscounted cash flows by asset group to their respective carrying values. If the carrying amount exceeds the estimated undiscounted future cash flows, a reduction of the carrying amount of the natural gas properties to their estimated fair values is required, which is determined based on discounted cash flow techniques using significant assumptions including projected revenues, future commodity prices and a market-specific weighted average cost of capital which are affected by expectations about future market and economic conditions. 

During the year ended December 31, 2020, CNX recognized certain indicators of impairments specific to our Southwest Pennsylvania Coalbed Methane asset group and determined that the carrying value of that asset group was not recoverable. The fair value of the asset group was estimated by using level 3 inputs which consisted of discounting the estimated future cash flows using discount rates and other assumptions that market participants would use in their estimates of fair value. As a result, an impairment of $61,849 was recognized and is included in Impairment of Exploration and Production Properties in the Consolidated Statements of Income. The impairment was related to an economic decision to temporarily idle certain wells and the related processing facility during the first quarter.
During the fourth quarter of 2019, CNX identified certain indicators of impairment specific to our Central Pennsylvania Marcellus asset group and determined that the carrying value of that asset group was not recoverable. The fair value of the asset group was estimated by using level 3 inputs which consisted of discounting the estimated future cash flows using discount rates and other assumptions that market participants would use in their estimates of fair value. As a result, an impairment of $327,400 was included in Impairment of Exploration and Production Properties in the Consolidated Statements of Income. This impairment was related to 56 operated wells and approximately 51,000 acres within our Central Pennsylvania Marcellus proved properties in Armstrong, Indiana, Jefferson and Westmoreland counties. The majority of these properties were developed prior to 2013 and the last of these properties were developed in 2015.
Impairment of Unproved Properties:
Capitalized costs of unproved oil and gas properties are evaluated at least annually for recoverability on a prospective basis. Indicators of potential impairment include, but are not limited to, changes brought about by economic factors, commodity price outlooks, our geologists’ evaluation of the property, favorable or unfavorable activity on the property being evaluated and/or adjacent properties, potential shifts in business strategy employed by management and historical experience. The likelihood of an impairment of unproved oil and gas properties increases as the expiration of a lease term approaches if drilling activity has not commenced. If it is determined that the Company does not intend to drill on the property prior to expiration or does not have the intent and ability to extend, renew, trade, or sell the lease prior to expiration, an impairment expense is recorded. Expense for lease expirations that were not previously impaired are recorded as the leases expire.

For the year ended December 31, 2019, CNX recorded an impairment related to unproved properties of $119,429 that was included in Impairment of Unproved Properties and Expirations in the Consolidated Statements of Income. These unproved properties are within CNX's Central Pennsylvania operating region and east of the acreage associated with the proved property impairment described above.

Exploration expense, which is associated primarily with lease expirations, was $14,994, $44,380 and $12,033 for the years ended December 31, 2020, 2019 and 2018, respectively, and is included in Exploration and Production Related Other Costs in the Consolidated Statements of Income.

Impairment of Goodwill:

In connection with the Midstream Acquisition (See Note 4 - Acquisitions and Dispositions for more information), CNX recorded $796,359 of goodwill through the application of purchase accounting. The goodwill recorded was allocated in its entirety to the Midstream reporting unit within the Shale segment.

Goodwill is the cost of an acquisition less the fair value of the identifiable net assets of the acquired business. Goodwill is not amortized, but rather it is evaluated for impairment annually during the fourth quarter, or more frequently if recent events or prevailing conditions indicate it is more likely than not that the fair value of a reporting unit is less than its carrying value. These indicators include, but are not limited to, overall financial performance, industry and market considerations, anticipated future cash flows and discount rates, changes in the stock price with regards to CNX, regulatory and legal developments, and other relevant factors.

In connection with the annual evaluation of goodwill for impairment or earlier if an impairment indicator is identified, CNX may first consider qualitative factors to assess whether there are indicators that it is more likely than not that the fair value of a reporting unit may not exceed its carrying amount. If after assessing such factors or circumstances, CNX determines it is more likely than not that the fair value of a reporting unit is greater than its carrying amount, then a quantitative assessment is not required. If CNX chooses to bypass the qualitative assessment, or if it chooses to perform a qualitative assessment but is unable to qualitatively conclude that no impairment has occurred, then CNX will perform a quantitative assessment. In the case of a quantitative assessment, CNX estimates the fair value of the reporting unit with which the goodwill is associated using level 3 inputs and compares it to the carrying value. If the estimated fair value of a reporting unit is less than its carrying value, an impairment charge is recognized for the excess of the reporting unit's carrying value over its fair value. The Company uses a combination of the income approach (generally a discounted cash flow method) and market approach (which may include the guideline public company method and/or the guideline transaction method) to estimate the fair value of a reporting unit.

The income approach is used to estimate value based on the present value of future economic benefits that are expected to be produced by an asset or business entity. This approach generally involves two general steps:

(i) The first step involves establishing a forecast of the estimated future net cash flows expected to accrue directly or indirectly to the owner of the asset over its remaining useful life or to the owner of the business entity (including a
reporting unit).
(ii) The second step involves discounting these estimated future net cash flows to their present value using a market rate of return.

CNX determined the fair value based on estimated future revenues and earnings before deducting net interest expense (interest expense less interest income) and income taxes (EBITDA - a non-GAAP financial measure), and also included estimates for capital expenditures, discounted to present value using an industry rate adjusted for company-specific risk, which management feels reflects the overall level of inherent risk of the reporting unit. These assumptions are affected by expectations about future market, industry and economic conditions. Cash flow projections were derived from board approved budgeted amounts, a seven-year operating forecast and an estimate of future cash flows. Subsequent cash flows were developed using growth or contraction rates that management believes are reasonably likely to occur.

The estimates of future cash flows and EBITDA are subjective in nature and are subject to impacts from business risks as described in Item 1A. Risk Factors of this Form 10-K. The fair value estimation process requires considerable judgment and determining the fair value is sensitive to changes in assumptions impacting management’s estimates of future financial results. Although CNX believes the estimates and assumptions used in estimating the fair value are reasonable and appropriate, different assumptions and estimates could materially impact the estimated fair value. Future results could differ from our current estimates and assumptions.

In connection with CNX's assessment of goodwill in the first quarter of 2020 in relation to the deteriorating macroeconomic conditions, and the decline in the observable market value of CNXM securities both in relation to the COVID-19 pandemic and the overall decline in the master limited partnership (MLP) market space, an impairment indicator was identified. CNX bypassed the qualitative assessment and performed a quantitative test that utilized a combination of the income and market approaches to estimate the fair value of the Midstream reporting unit. As a result of this assessment, CNX concluded that the carrying value exceed its estimated fair value, and as a result, an impairment of $473,045 was included in Impairment of Goodwill in the Consolidated Statements of Income.

In connection with our annual assessment of goodwill in the fourth quarter of 2020, we bypassed the qualitative assessment and performed a quantitative test that utilized a combination of the income and market approaches to estimate the fair value of the Midstream reporting unit. As a result of this assessment, we concluded that the estimated fair value exceeded carrying value, and accordingly no adjustment to goodwill was necessary. However, the margin by which the fair value of the Midstream reporting unit exceeded its carrying value was less than 10%. As a result, this reporting unit is susceptible to impairment risk from further adverse macroeconomic conditions or other adverse factors such as future gathering volumes being less than those currently estimated. Any such adverse changes in the future could reduce the underlying cash flows used to estimate fair values and could result in a decline in fair value that could trigger future impairment charges relating to the Midstream reporting unit.

Impairment of Definite-Lived Intangible Assets:

Definite-lived intangible assets are amortized on a straight-line basis over their estimated economic lives and they are reviewed for impairment when indicators of impairment are present.

In connection with the Midstream Acquisition (See Note 4 - Acquisitions and Dispositions for more information), CNX recorded $128,781 of other intangible assets, which are comprised of customer relationships, through the application of purchase accounting.

In May 2018, CNX determined that the carrying value of a portion of the customer relationship intangible assets that were acquired in connection with the Midstream acquisition exceeded their fair value in conjunction with the Asset Exchange Agreement with HG Energy II Appalachia, LLC (See Note 4 - Acquisitions and Dispositions for more information). CNX recognized an impairment on this intangible asset of $18,650, which is included in Impairment of Other Intangible Assets in the Consolidated Statements of Income.

The customer relationships intangible asset is amortized on a straight-line basis over approximately 17 years.
Income Taxes:
Deferred tax assets and liabilities are recognized for the expected future tax consequences of events that have been recognized in the Company's financial statements or tax returns. The provision for income taxes represents income taxes paid or
payable for the current year and the change in deferred taxes, excluding the effects of acquisitions during the year. Deferred taxes result from differences between the financial and tax bases of the Company's assets and liabilities and are adjusted for changes in tax rates and tax laws when changes are enacted. Valuation allowances are recorded to reduce deferred tax assets when it is more likely than not that a deferred tax benefit will not be realized.
CNX evaluates all tax positions taken on the state and federal tax filings to determine if the position is more likely than not to be sustained upon examination. For positions that do not meet the more likely than not to be sustained criteria, the Company determines, on a cumulative probability basis, the largest amount of benefit that is more likely than not to be realized upon ultimate settlement. A previously recognized tax position is reversed when it is subsequently determined that a tax position no longer meets the more likely than not threshold to be sustained. The evaluation of the sustainability of a tax position and the probable amount that is more likely than not is based on judgment, historical experience and on various other assumptions that the Company believes are reasonable under the circumstances. The results of these estimates, that are not readily apparent from other sources, form the basis for recognizing an uncertain tax position liability. Actual results could differ from those estimates upon subsequent resolution of identified matters.

Asset Retirement Obligations:

CNX accrues for dismantling and removing costs of gas-related facilities and related surface reclamation using the accounting treatment prescribed by the Asset Retirement and Environmental Obligations Topic of the FASB Accounting Standards Codification. This topic requires the fair value of an asset retirement obligation be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. Estimates are regularly reviewed by management and are revised for changes in future estimated costs and regulatory requirements. The present value of the estimated asset retirement costs is capitalized as part of the carrying amount of the long-lived asset. Amortization of the capitalized asset retirement cost is generally determined on a units-of-production basis. Accretion of the asset retirement obligation is recognized over time and generally will escalate over the life of the producing asset, typically as production declines. Accretion is included in Depreciation, Depletion and Amortization in the Consolidated Statements of Income.

Investment Plan:

CNX has an investment plan that is available to most employees. Throughout the years ended December 31, 2020, 2019 and 2018, the Company's matching contribution was 6% of eligible compensation contributed by eligible employees. The Company may also make discretionary contributions to the Plan ranging from 1% to 6% of eligible compensation for eligible employees (as defined by the Plan). There were no such discretionary contributions made by CNX for the years ended December 31, 2020, 2019 and 2018. Total matching contribution payments and costs were $2,976, $3,460 and $3,205 for the years ended December 31, 2020, 2019 and 2018, respectively.

Revenue Recognition:

Revenues are recognized when the recognition criteria of ASC 606 are met, which generally occurs at the point in which title passes to the customers. For natural gas, NGL and oil revenue, this occurs at the contractual point of delivery. For revenues generated from natural gas gathering services provided to third-parties, this occurs when obligations under the terms of the contract with the shipper are satisfied.
CNX sells natural gas to accommodate the delivery points of its customers. In general, this gas is purchased at market price and re-sold on the same day at market price less a small transaction fee. These matching buy/sell transactions include a legal right of offset of obligations and have been simultaneously entered into with the counterparty. These transactions qualify for netting under the Nonmonetary Transactions Topic of the FASB Accounting Standards Codification and are, therefore, recorded net within the Consolidated Statements of Income in the Purchased Gas Revenue line.
CNX purchases natural gas produced by third-parties at market prices less a fee. The gas purchased from third-parties is then resold to end users or gas marketers at current market prices. These revenues and expenses are recorded gross as Purchased Gas Revenue and Purchase Gas Costs, respectively, in the Consolidated Statements of Income. Purchased gas revenue is recognized when title passes to the customer. Purchased gas costs are recognized when title passes to CNX from the third-party.

Contingencies:

From time to time, CNX, or its subsidiaries, are subject to various lawsuits and claims with respect to such matters as personal injury, wrongful death, damage to property, exposure to hazardous substances, governmental regulations (including environmental remediation), employment and contract disputes and other claims and actions, arising out of the normal course of
business. Liabilities are recorded when it is probable that obligations have been incurred and the amounts can be reasonably estimated. Estimates are developed through consultation with legal counsel involved in the defense of these matters and are based upon the nature of the lawsuit, progress of the case in court, view of legal counsel, prior experience in similar matters and management's intended response. Environmental liabilities are not discounted or reduced by possible recoveries from third-parties. Legal fees associated with defending these various lawsuits and claims are expensed when incurred.
Stock-Based Compensation:
Stock-based compensation expense for all stock-based compensation awards is based on the grant date fair value estimated in accordance with the provisions of the Stock Compensation Topic of the FASB Accounting Standards Codification. CNX recognizes these compensation costs on a straight-line basis over the requisite service period of the award, which is generally the award's vesting term. See Note 15 - Stock-Based Compensation for more information.

Derivative Instruments:

CNX enters into interest rate swap agreements to manage its exposure to interest rate volatility. These swaps change the variable-rate cash flow exposure on the debt obligations to fixed cash flows. The change in fair value of the interest rate swap agreements are accounted for on a mark-to-market basis with the changes in fair value recorded in current period earnings.
CNX enters into financial derivative instruments to manage its exposure to commodity price volatility. Natural gas commodity hedges are accounted for on a mark-to-market basis with changes in fair value recorded in current period earnings.
None of the Company's counterparty master agreements currently require CNX to post collateral for any of its positions. However, as stated in the counterparty master agreements, if CNX's obligations with any of its counterparties cease to be secured on the same basis as similar obligations with the other lenders under the credit facility, CNX would be required to post collateral for instruments in a liability position in excess of defined thresholds. All of the Company's derivative instruments are subject to master netting arrangements with the counterparties. CNX recognizes all financial derivative instruments as either assets or liabilities at fair value in the Consolidated Balance Sheets on a gross basis, generally measured based upon Level 2 inputs, which is further described in Note 18 - Fair Value of Financial Instruments.
Each of the Company's counterparty master agreements allows, in the event of default, the ability to elect early termination of outstanding contracts. If early termination is elected, CNX and the applicable counterparty would net settle all open hedge positions.
CNX is exposed to credit risk in the event of non-performance by counterparties, whose creditworthiness is subject to continuing review. Historically, CNX has not experienced any issues of non-performance by derivative counterparties.
Recent Accounting Pronouncements:

In August 2020, the FASB issued Accounting Standards Update (ASU) 2020-06 - Accounting for Convertible Instruments and Contracts in an Entity's Own Equity. This ASU simplifies an entity's accounting for convertible instruments by eliminating two of the three models in ASC 470-20 that require separate accounting for embedded conversion features, simplifies the settlement assessment that entities are required to perform to determine whether a contract qualifies for equity classification, requires entities to use the if-converted method for all convertible instruments in the diluted EPS calculation and include the effect of potential share settlement (if the effect is more dilutive) for instruments that may be settled in cash or shares, except for certain liability-classified share-based payment awards, requires new disclosures about events that occur during the reporting period and cause conversion contingencies to be met and about the fair value of an entity's convertible debt at the instrument level, among other things. The amendments in this ASU are effective for public entities for fiscal years beginning after December 15, 2021, including interim periods within those fiscal years, and can be adopted through either a modified retrospective method of transition or a fully retrospective method of transition. Early adoption is permitted, but no earlier than fiscal years beginning after December 15, 2020, including interim periods within those fiscal years. The Company is still evaluating the effect of adopting this guidance.

In March 2020, the FASB issued ASU 2020-04 - Reference Rate Reform - Facilitation of the Effects of Reference Rate Reform on Financial Reporting (Topic 848). This ASU provides optional expedient and exceptions for applying generally accepted accounting principles to contracts, hedging relationships, and other transactions affected by reference rate reform if certain criteria are met. In response to the concerns about structural risks of interbank offered rates (IBORs) and, particularly, the risk of cessation of the London Interbank Offered Rate (LIBOR), regulators in several jurisdictions around the world have undertaken reference rate reform initiatives to identify alternative reference rates that are more observable or transaction based
and less susceptible to manipulation. The ASU provides companies with optional guidance to ease the potential accounting burden associated with transitioning away from reference rates that are expected to be discontinued. In January 2021, the FASB issued ASU 2021-01, which clarifies that certain provisions in Topic 848, if elected by an entity, apply to derivative instruments that use an interest rate for margining, discounting, or contract price alignment that is modified as a result of reference rate reform. The amendments in these ASUs are effective for all entities as of March 12, 2020 through December 31, 2022. The Company is still evaluating the effect of adopting this guidance.

In March 2020, the FASB issued ASU 2020-03 - Codification Improvements to Financial Instruments. This ASU improves and clarifies various financial instruments topics, including the CECL standard. The ASU includes seven different issues that describe the areas of improvement and the related amendments to GAAP, intended to make the standards easier to understand and apply by eliminating inconsistencies and providing clarifications. The amendments in this ASU have different effective dates. The adoption of this guidance is not expected to have a material impact on the Company's financial statements.

Reclassifications:
Certain amounts in prior periods have been reclassified to conform with the report classifications of the year ended December 31, 2020, with no effect on previously reported net income, stockholders' equity, or statement of cash flows.

Subsequent Events:

The Company has evaluated all subsequent events through the date the financial statements were issued. No material recognized or non-recognizable subsequent events were identified.
v3.20.4
Earnings Per Share
 12 Months Ended
Dec. 31, 2020
Earnings Per Share [Abstract]  
Earnings Per Share EARNINGS PER SHARE:
Basic earnings per share is computed by dividing net income attributable to CNX shareholders by the weighted average shares outstanding during the reporting period. Diluted earnings per share is computed similarly to basic earnings per share, except that the weighted average shares outstanding are increased to include, if dilutive, additional shares from stock options, performance stock options, restricted stock units, performance share units and shares issuable upon conversion of CNX's outstanding Convertible Notes (See Note 12 - Long-Term Debt). The number of additional shares is calculated by assuming that outstanding stock options and performance share options were exercised, that outstanding restricted stock units and performance share units were released, and that the proceeds from such activities were used to acquire shares of common stock at the average market price during the reporting period.

Pursuant to the Merger (See Note 4 - Acquisitions and Dispositions for more information), all outstanding phantom units previously granted under the CNXM long-term incentive plan were converted into the right to receive 0.88 shares of common stock of CNX. As such, all outstanding phantom units were converted, effective as of the closing of the Merger, into CNX restricted stock units. Each CNX restricted stock unit will be subject to the same vesting, forfeiture and other terms and conditions applicable to the converted CNXM phantom units. Under Accounting Standards Codification Topic 718, Compensation - Stock Compensation, it was determined that there was no additional compensation cost to record as the conversion of awards did not result in incremental fair value. CNXM's dilutive units did not have a material impact on the Company's earnings per share calculations for the period from January 1, 2020 through September 30, 2020, the year ended December 31, 2019, or the period from January 3, 2018 through December 31, 2018.

The table below sets forth the share-based awards that have been excluded from the computation of diluted earnings per share because their effect would be antidilutive:
For the Years Ended December 31,
 202020192018
Anti-Dilutive Options4,200,509 4,696,264 2,285,775 
Anti-Dilutive Restricted Stock Units2,160,727 1,282,582 — 
Anti-Dilutive Performance Share Units721,244 752,899 145,217 
Anti-Dilutive Performance Share Options— 927,268 927,268 
7,082,480 7,659,013 3,358,260 

The Company expects to settle the principal amount of the Convertible Notes in cash. As a result, only the amount by which the conversion value exceeds the aggregated principal amount of the Convertible Notes is included in the diluted
earnings per share computation under the treasury stock method. The conversion spread has a dilutive impact on diluted earnings per share when the average market price of the Company’s common stock for a given period exceeds the initial conversion price of $12.84 per share for the Convertible Notes. As of December 31, 2020, the if-converted value of the Convertible Notes did not exceed the outstanding principal amount. In connection with the Convertible Notes’ issuance, the Company entered into privately negotiated capped call transactions with certain counterparties, (the “Capped Calls” and “Capped Call Transactions”), which were not included in calculating the number of diluted shares outstanding, as their effect would have been anti-dilutive.

The computations for basic and diluted (loss) earnings per share are as follows:
For the Years Ended December 31,
 202020192018
Net (Loss) Income$(428,744)$31,948 $883,111 
Less: Net Income Attributable to Non-Controlling Interest55,031 112,678 86,578 
Net (Loss) Income Attributable to CNX Resources Shareholders$(483,775)$(80,730)$796,533 
Weighted-Average Shares of Common Stock Outstanding199,225,441 190,727,122 212,348,581 
Effect of Diluted Shares*— — 2,280,384 
Weighted-Average Diluted Shares of Common Stock Outstanding199,225,441 190,727,122 214,628,965 
(Loss) Earnings Per Share:
Basic$(2.43)$(0.42)$3.75 
Diluted$(2.43)$(0.42)$3.71 
*During periods in which the Company incurs a net loss, diluted weighted average shares outstanding are equal to basic weighted average shares outstanding because the effect of all equity awards is antidilutive.

Shares of common stock outstanding were as follows:
For the Years Ended December 31,
 202020192018
Balance, Beginning of Year186,642,962 198,663,342 223,743,322 
Issuance Related to Stock-Based Compensation (1)882,335 909,107 814,344 
Retirement of Common Stock (2)(4,138,527)(12,929,487)(25,894,324)
Issuance Related to CNXM Merger37,054,223 — — 
Balance, End of Year220,440,993 186,642,962 198,663,342 
(1) See Note 15 - Stock-Based Compensation for additional information.
(2) See Note 5 - Stock Repurchase for additional information.
v3.20.4
Revenue From Contracts With Customers
 12 Months Ended
Dec. 31, 2020
Revenue from Contract with Customer [Abstract]  
Revenue From Contracts With Customers REVENUE FROM CONTRACTS WITH CUSTOMERS:
Revenues are recognized when control of the promised goods or services is transferred to the Company’s customers, in an amount that reflects the consideration the Company expects to be entitled to in exchange for those goods or services. The Company has elected to exclude all taxes from the measurement of transaction price.

For natural gas, NGL and oil, and purchased gas revenue, the Company generally considers the delivery of each unit (MMBtu or Bbl) to be a separate performance obligation that is satisfied upon delivery. Payment terms for these contracts typically require payment within 25 days of the end of the calendar month in which the hydrocarbons are delivered. A significant number of these contracts contain variable consideration because the payment terms refer to market prices at future delivery dates. In these situations, the Company has not identified a standalone selling price because the terms of the variable payments relate specifically to the Company’s efforts to satisfy the performance obligations. A portion of the contracts contain fixed consideration (i.e. fixed price contracts or contracts with a fixed differential to NYMEX or index prices). The fixed consideration is allocated to each performance obligation on a relative standalone selling price basis, which requires judgment from management. For these contracts, the Company generally concludes that the fixed price or fixed differentials in the contracts are representative of the standalone selling price. Revenue associated with natural gas, NGL and oil as presented on the accompanying Consolidated Statements of Income represent the Company’s share of revenues net of royalties and
excluding revenue interests owned by others. When selling natural gas, NGL and oil on behalf of royalty owners or working interest owners, the Company is acting as an agent and thus reports the revenue on a net basis.

Included in Other Revenue and Operating Income in the Consolidated Statements of Income and in the below table are revenues generated from natural gas gathering services provided to third-parties. The gas gathering services are interruptible in nature and include charges for the volume of gas actually gathered and do not guarantee access to the system. Volumetric based fees are based on actual volumes gathered. The Company generally considers the interruptible gathering of each unit (MMBtu) of natural gas as a separate performance obligation. Payment terms for these contracts typically require payment within 25 days of the end of the calendar month in which the hydrocarbons are gathered.

Disaggregation of Revenue

The following table is a disaggregation of revenue by major source:
For the Years Ended December 31,
202020192018
Revenue from Contracts with Customers:
Natural Gas Revenue$823,132 $1,251,013 $1,391,459 
NGL Revenue64,138 104,139 165,883 
Oil/Condensate Revenue9,475 9,173 20,595 
Total Natural Gas, NGL and Oil Revenue896,745 1,364,325 1,577,937 
Purchased Gas Revenue105,792 94,027 65,986 
Other Sources of Revenue and Other Operating Income:
Gain (Loss) on Commodity Derivative Instruments 172,982 376,105 (30,212)
Other Revenue and Operating Income82,459 87,992 116,723 
Total Revenue and Other Operating Income$1,257,978 $1,922,449 $1,730,434 

The disaggregated revenue information corresponds with the Company’s segment reporting found in Note 21 - Segment Information.

Contract Balances

CNX invoices its customers once a performance obligation has been satisfied, at which point payment is unconditional. Accordingly, CNX's contracts with customers do not give rise to contract assets or liabilities under ASC 606. The Company has no contract assets recognized from the costs to obtain or fulfill a contract with a customer. The opening and closing balances of the Company’s receivables related to contracts with customers were $133,480 and $145,929, respectively, as of December 31, 2020.

Transaction Price Allocated to Remaining Performance Obligations

ASC 606 requires that the Company disclose the aggregate amount of transaction price that is allocated to performance obligations that have not yet been satisfied. However, the guidance provides certain practical expedients that limit this requirement, including when variable consideration is allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied promise to transfer a distinct good or service that forms part of a series.

A significant portion of CNX's natural gas, NGL and oil and purchased gas revenue is short-term in nature with a contract term of one year or less. For those contracts, CNX has utilized the practical expedient in ASC 606-10-50-14 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.

For revenue associated with contract terms greater than one year, a significant portion of the consideration in those contracts is variable in nature and the Company allocates the variable consideration in its contract entirely to each specific performance obligation to which it relates. Therefore, any remaining variable consideration in the transaction price is allocated
entirely to wholly unsatisfied performance obligations. As such, the Company has not disclosed the value of unsatisfied performance obligations pursuant to the practical expedient.

For revenue associated with contract terms greater than one year with a fixed price component, the aggregate amount of the transaction price allocated to remaining performance obligations was $120,275 as of December 31, 2020. The Company expects to recognize net revenue of $55,500 in the next 12 months and $37,151 over the following 12 months, with the remainder recognized thereafter.

For revenue associated with CNX's midstream contracts, which also have terms greater than one year, the interruptible gathering of each unit of natural gas represents a separate performance obligation; therefore, future volumes are wholly unsatisfied, and disclosure of the transaction price allocated to remaining performance obligations is not required.

Prior-Period Performance Obligations
CNX records revenue in the month production is delivered to the purchaser. However, settlement statements for certain natural gas, NGL and oil revenue may not be received for 30 to 90 days after the date production is delivered, and as a result, the Company is required to estimate the amount of production delivered to the purchaser and the price that will be received for the sale of the product. CNX records the differences between the estimate and the actual amounts received in the month that payment is received from the purchaser. The Company has existing internal controls for its revenue estimation process and the related accruals, and any identified differences between its revenue estimates and actual revenue received historically have not been significant. For each of the years ended December 31, 2020, 2019, and 2018, revenue recognized in the current reporting period related to performance obligations satisfied in prior a reporting period was not material.
v3.20.4
Acquisitions and Dispositions
 12 Months Ended
Dec. 31, 2020
Business Combinations [Abstract]  
Acquisitions And Dispositions ACQUISITIONS AND DISPOSITIONS:
On July 26, 2020, CNX entered into an Agreement and Plan of Merger (the “Merger Agreement”) with CNXM, CNX Midstream GP LLC (the “General Partner”) and CNX Resources Holding LLC., a wholly owned subsidiary of CNX (“Merger Sub”), pursuant to which Merger Sub merged with and into CNXM with CNXM surviving as an indirect wholly owned subsidiary of CNX (the “Merger”). On September 28, 2020, the Merger was completed and CNX issued 37,054,223 shares of common stock to acquire the 42,107,071 common units of CNXM not owned by CNX prior to the Merger at a fixed exchange ratio of 0.88 shares of CNX common stock for each CNXM common unit, for total implied consideration of $384,623. As a result of the Merger, CNXM’s common units are no longer publicly traded.

Except for the Class B units of CNXM, which were automatically canceled immediately prior to the effective time of the Merger for no consideration in accordance with CNXM’s partnership agreement, the interests in CNXM owned by CNX and its subsidiaries remain outstanding as limited partner interests in the surviving entity. The General Partner will continue to own the non-economic general partner interest in the surviving entity.

Because CNX controlled CNXM prior to the Merger and continues to control CNXM after the Merger, CNX accounted for the change in its ownership interest in CNXM as an equity transaction which was reflected as a reduction of noncontrolling interest with corresponding increases to common stock and capital in excess of par value. No gain or loss was recognized in its condensed consolidated statements of operations as a result of the Merger.

The tax effects of the Merger were reported as adjustments to deferred income taxes and capital in excess of par value.

Prior to the effective time of the Merger on September 28, 2020, public unitholders held a 46.9% equity interest in CNXM and CNX owned the remaining 53.1% equity interest. The earnings of CNXM that were attributed to its common units held by the public prior to the Merger are reflected in Net Income Attributable to Noncontrolling Interest in the Consolidated Statements of Income. There were no changes in CNX's ownership interest in CNXM during the year ended December 31, 2019. See discussion of Midstream Acquisition below for change in ownership interest during the year ended December 31, 2018.

CNXM’s revolving credit facility (See Note 10 - Revolving Credit Facilities) and the CNXM Senior Notes (See Note 12 - Long-Term Debt) were not impacted by the Merger.

The Company incurred $11,271 of transaction costs directly attributable to the Merger during the year ended December 31, 2020, including financial advisory, legal service and other professional fees, which were recorded to Other Expense (Income) in the Consolidated Statements of Income.
On August 31, 2018, CNX closed on the sale of substantially all of its Ohio Utica Joint Venture Assets in the wet gas Utica Shale areas of Belmont, Guernsey, Harrison, and Noble Counties, which included approximately 26,000 net undeveloped acres. The net cash proceeds of $381,124 are included in Proceeds from Asset Sales in the Consolidated Statements of Cash Flows and the net gain on the transaction of $130,710 is included in Gain on Asset Sales and Abandonments, net in the Consolidated Statements of Income.

On May 2, 2018, CNX closed on an Asset Exchange Agreement (the “AEA”) with HG Energy II Appalachia, LLC (“HG Energy”), pursuant to which, among other things, HG Energy (i) paid to CNX approximately $7,000 and (ii) assigned to CNX certain undeveloped Marcellus and Utica acreage in Southwest Pennsylvania, in exchange for CNX (x) assigning its interest in certain non-core midstream assets and surface acreage to HG Energy and (y) releasing certain HG Energy oil and gas acreage from dedication under a gathering agreement that is partially held, indirectly, by CNX. In connection with the transaction, CNX also agreed to certain transactions with CNXM, including the amendment of the existing gas gathering agreement between CNX and CNXM to increase the existing well commitment by an additional forty wells. The net gain on the sale was $286 and is included in Gain on Asset Sales and Abandonments, net in the Consolidated Statements of Income.

As a result of the AEA, CNX determined that the carrying value of a portion of the customer relationship intangible assets that were acquired in connection with the Midstream Acquisition discussed below (see also Note 9 - Goodwill and Other Intangible Assets) exceeded their fair value, and recognized an impairment of approximately $18,650, which is included in Impairment of Other Intangible Assets in the Consolidated Statements of Income.
On March 30, 2018, CNX Gas completed the sale of substantially all of its shallow oil and gas assets and certain Coalbed Methane (CBM) assets in Pennsylvania and West Virginia for $89,921 in cash consideration. In connection with the sale, the buyer assumed approximately $196,514 of asset retirement obligations. The net gain on the sale was $4,227 and is included in Gain on Asset Sales and Abandonments, net in the Consolidated Statements of Income.

On December 14, 2017, CNX Gas entered into a purchase agreement with Noble, pursuant to which CNX Gas acquired Noble’s 50% membership interest in CNX Gathering for a cash purchase price of $305,000 (the "Midstream Acquisition"). Prior to the Midstream Acquisition, the Company accounted for its 50% interest in CNX Gathering as an equity method investment as the Company had the ability to exercise significant influence, but not control, over the operating and financial policies of the midstream operations. In conjunction with the Midstream Acquisition, the Company obtained a controlling interest in CNX Gathering and, through CNX Gathering's ownership of the general partner, control over the Partnership. Accordingly, the Midstream Acquisition has been accounted for as a business combination using the acquisition method of accounting pursuant to ASC Topic 805, Business Combinations, or ASC 805. ASC 805 requires that, in circumstances where a business combination is achieved in stages (or step acquisition), previously held equity interests are remeasured at fair value and any difference between the fair value and the carrying value of the equity interest held be recognized as a gain or loss on the statement of income.

The fair value assigned to the previously held equity interest in CNX Gathering and CNXM for purposes of calculating the gain or loss was $799,033 and was determined using the income approach, based on a discounted cash flow methodology. The resulting gain on remeasurement to fair value of the previously held equity interest in CNX Gathering and CNXM of $623,663 is included in Gain on Previously Held Equity Interest in the Consolidated Statements of Income.

The fair value of the previously held equity interests was based on inputs that are not observable in the market and therefore represent Level 3 inputs (See Note 18 - Fair Value of Financial Instruments). The fair value was measured using valuation techniques that convert future cash flows into a single discounted amount. Significant inputs to the valuation included estimates of: (i) gathering volumes; (ii) future operating costs; and (iii) a market-based weighted average cost of capital. These inputs required significant judgments and estimates by management.

The fair value of midstream facilities and equipment, generally consisting of pipeline systems and compression stations, were estimated using the cost approach. Significant unobservable inputs in the valuation include management's assumptions about the replacement costs for similar assets, the relative age of the acquired assets and any potential economic or functional obsolescence associated with the acquired assets. As a result, the fair value estimates of the midstream facilities and equipment represents a Level 3 fair value measurement.

As part of the purchase price allocation, the Company identified intangible assets for customer relationships with third-party customers. The fair value of the identified intangible assets was determined using the income approach, which requires a forecast of the expected future cash flows generated and an estimated market-based weighted average cost of capital. Significant unobservable inputs in the valuation include future revenue estimates, future cost assumptions, and estimated
customer retention rates. As a result, the fair value estimate of the identified intangible assets represents a Level 3 fair value measurement.

The noncontrolling interest in the acquired business is comprised of the limited partner units in CNXM, which were not acquired by the Company. At the time of the Midstream Acquisition, the CNXM limited partner units were actively traded on the New York Stock Exchange and were valued based on observable market prices as of the transaction date and therefore represent a Level 1 fair value measurement.

Allocation of Purchase Price (Midstream Acquisition)

The following table summarizes the purchase price and the amounts of identified assets acquired and liabilities assumed based on the fair value as of January 3, 2018, with any excess of the purchase price over the fair value of the identified net assets acquired recorded as goodwill. The purchase price allocation was finalized as of December 31, 2018.

Fair Value of Consideration Transferred:
Amount
Cash Consideration$305,000 
CNX Gathering Cash on Hand at January 3, 2018 Distributed to Noble2,620 
Fair Value of Previously Held Equity Interest799,033 
Total Estimated Fair Value of Consideration Transferred$1,106,653 

The following is a summary of the fair values of the net assets acquired:
Amount
Fair Value of Assets Acquired:
Cash and Cash Equivalents$8,348 
Accounts and Notes Receivable21,199 
Prepaid Expense2,006 
Other Current Assets163 
Property, Plant and Equipment, net1,043,340 
Intangible Assets128,781 
Other593 
Total Assets Acquired1,204,430 
Fair Value of Liabilities Assumed:
Accounts Payable26,059 
CNXM Revolving Credit Facility149,500 
Total Liabilities Assumed175,559 
Total Identifiable Net Assets1,028,871 
Fair Value of Noncontrolling Interest in CNXM(718,577)
Goodwill796,359 
Net Assets Acquired$1,106,653 

Post-Acquisition Operating Results (Midstream Acquisition)

The Midstream Acquisition contributed the following to the Midstream reporting unit within the Shale segment:
For the Years Ended December 31,
202020192018
Other Revenue and Operating Income$64,710 $74,314 $89,781 
Earnings Before Income Tax$156,818 $166,654 $133,811 
v3.20.4
Stock Repurchase
 12 Months Ended
Dec. 31, 2020
Equity [Abstract]  
Stock Repurchase STOCK REPURCHASE:
As of December 31, 2020, CNX's Board of Directors had approved $750,000 in stock repurchases since the October 30, 2017 inception of the current stock repurchase program. On January 26, 2021, the Company’s Board of Directors approved an increase in the aggregate amount of the current stock repurchase program plan, to $900,000. This increases the amount available under the current stock repurchase program to $245,000, not subject to an expiration date. The repurchases may be affected from time-to-time through open market purchases, privately negotiated transactions, Rule 10b5-1 plans, accelerated stock repurchases, block trades, derivative contracts or otherwise in compliance with Rule 10b-18. The timing of any repurchases will be based on a number of factors, including available liquidity, the Company's stock price, the Company's financial outlook, and alternative investment options. The stock repurchase program does not obligate the Company to repurchase any dollar amount or number of shares and the Board may modify, suspend, or discontinue its authorization of the program at any time. The Board of Directors will continue to evaluate the size of the stock repurchase program based on CNX's free cash flow position, leverage ratio, and capital plans.

During the year ended December 31, 2020, 4,138,527 shares were repurchased and retired at an average price of $10.43 per share for a total cost of $43,247. During the year ended December 31, 2019, 12,929,487 shares were repurchased and retired at an average price of $8.91 per share for a total cost of $115,477. During the year ended December 31, 2018, 25,894,324 shares were repurchased and retired at an average price of $14.80 per share for a total cost of $383,752.
v3.20.4
Income Taxes
 12 Months Ended
Dec. 31, 2020
Income Tax Disclosure [Abstract]  
Income Taxes INCOME TAXES:
Income tax (benefit) expense provided on earnings consisted of:
For the Years Ended December 31,
202020192018
Current:
U.S. Federal
$(55,799)$(51,243)$(130,003)
U.S. State
12 (113)— 
(55,787)(51,356)(130,003)
Deferred:
U.S. Federal
(83,080)47,717 319,813 
U.S. State
(35,220)31,375 25,747 
(118,300)79,092 345,560 
Total Income Tax (Benefit) Expense$(174,087)$27,736 $215,557 
The components of the net deferred taxes are as follows:
December 31,
20202019
Deferred Tax Assets:
Net Operating Loss- Federal
$215,936 $202,913 
Net Operating Loss - State
129,641 130,430 
Foreign Tax Credit43,194 43,194 
Operating Lease Right-of-Use Assets28,085 47,849 
Gas Well Closing24,251 17,888 
Salary Retirement11,478 9,236 
Equity Compensation6,639 9,308 
Alternative Minimum Tax— 51,241 
Interest Limitation— 25,734 
Other
9,416 10,030 
Total Deferred Tax Assets
468,640 547,823 
Valuation Allowance
(123,098)(125,054)
Net Deferred Tax Assets
345,542 422,769 
Deferred Tax Liabilities:
Property, Plant and Equipment
(649,917)(593,401)
Investment in Partnership
(85,882)(145,424)
Gas Derivatives
(26,882)(105,721)
   Operating Lease Liabilities (28,287)(46,640)
   Discount on Convertible Notes(18,097)— 
Advance Gas Royalties
(2,519)(3,337)
Other
(211)(4,354)
Total Deferred Tax Liabilities
(811,795)(898,877)
Net Deferred Tax Liability
$(466,253)$(476,108)

Deferred taxes are recorded for certain tax benefits, including net operating losses and tax credit carry-forwards, if management assesses the utilization of those assets to be more likely than not. A valuation allowance is required when it is not more likely than not that all or a portion of a deferred tax asset will be realized. All available evidence, both positive and negative, must be considered in determining the need for a valuation allowance. Positive evidence considered included financial earnings generated over the past three years for certain subsidiaries, reversals of financial to tax temporary differences and the implementation of and/or ability to employ various tax planning strategies. Negative evidence includes financial and tax losses generated in prior periods and the inability to achieve forecasted results for those periods.

As of December 31, 2020, the Company has a deferred tax asset related to federal net operating losses of $215,936, which expire at various times between 2034 and 2039. However, because of the Tax Cuts and Jobs Act (the "TCJA Act") enacted on December 22, 2017 and the Coronavirus Aid, Relief, and Economic Security Act (the "CARES Act") enacted on March 27, 2020, the anticipated federal net operating losses generated in 2018 - 2020 do not expire but may only offset 80% of taxable income in any tax years beginning after 2020.

The CARES Act, which, among other things; increased the adjusted taxable income limitation for the disallowance of interest expense from 30% to 50% and provided for refunds of any remaining alternative minimum tax (AMT) credits in 2020. The impact of other tax implications of the Act on the financial statements and related disclosures are immaterial.

The TCJA Act repealed the corporate AMT for tax years beginning January 1, 2018 and provides that AMT credits can be utilized to offset current federal taxes owed in tax years 2018 through 2020. In addition, 50% of any unused AMT credits are refundable during these years with any remaining AMT credit carryforward being fully refunded in 2021, which was revised under the CARES Act to 2020. The Company has no deferred tax asset relating to federal AMT credits as of December 31,
2020 compared to $51,241 as of December 31, 2019, a decrease of $51,241 from the prior year that resulted from the refunds received of all remaining outstanding AMT credits.

A valuation allowance on foreign tax credits of $43,194 has also been recorded at December 31, 2020 and 2019. The foreign tax credits expire at various times between 2021 and 2023.

CNX has, on an after federal tax basis, a deferred tax asset related to state operating losses of $129,641 with a related valuation allowance of $79,197 at December 31, 2020. The deferred tax asset related to state operating losses, on an after-tax adjusted basis, was $130,430 with a related valuation allowance of $81,202 at December 31, 2019. A review of positive and negative evidence regarding these state tax benefits concluded that the valuation allowances for various CNX subsidiaries was warranted. These net operating losses (NOLs) expire at various times between 2021 and 2040.

Management will continue to assess the potential for realized deferred tax assets based upon income forecast data and the feasibility of future tax planning strategies and may record adjustments to valuation allowances against deferred tax assets in future periods, as appropriate, that could materially impact net income.

The following is a reconciliation, stated as a percentage of pretax income, of the United States statutory federal income tax rate to CNX's effective tax rate:
 For the Years Ended December 31,
 202020192018
 AmountPercentAmountPercentAmountPercent
Statutory U.S. Federal Income Tax Rate$(126,595)21.0 %$12,534 21.0 %$230,721 21.0 %
Net Effect of State Income Taxes(32,336)5.5 1,333 2.2 60,814 5.6 
Non-Controlling Interest(11,556)1.9 (23,662)(39.6)(18,181)(1.7)
Uncertain Tax Positions375 (0.1)— — (4,265)(0.4)
Accrual to Tax Return Reconciliation
13 — 603 1.0 3,028 0.3 
Effect of Equity Compensation4,311 (0.7)8,771 14.7 — — 
Effect of Change in State Valuation Allowance(2,004)0.3 33,238 55.6 (22,684)(2.1)
Effect of Change in Federal Valuation Allowance48 — (2,640)(4.4)(18,110)(1.7)
Other Deferred Adjustments1,166 (0.2)(1,691)(2.8)5,957 0.6 
Effect of Federal and State Rate Reductions(1,450)0.2 (3,842)(6.4)(27,429)(2.5)
Effect of Federal Tax Credits(6,284)1.0 2,881 4.8 1,208 0.1 
Other225 — 211 0.4 4,498 0.4 
Income Tax (Benefit) Expense / Effective Rate$(174,087)28.9 %$27,736 46.5 %$215,557 19.6 %

The effective tax rate for the year ended December 31, 2020 was higher than the U.S. federal statutory rate primarily due to state taxes, equity compensation, and the decrease in certain state valuation allowances as a result of the Merger transaction with CNXM partially offset by the benefit from non-controlling interest.

The effective tax rate for the year ended December 31, 2019 was higher than the U.S. federal statutory rate primarily due to state taxes, equity compensation, and the increase in certain state valuation allowances as a result of the higher than projected net operating loss generated in 2018 partially offset by the benefit from non-controlling interest.

As a result of the Midstream Acquisition on January 3, 2018 as discussed in Note 4 - Acquisitions and Dispositions, the Company obtained a controlling interest in CNX Gathering LLC and, through CNX Gathering's ownership of the general partner, control over CNXM. The financial results for 2018 through 2020 reflect full consolidation of CNXM’s assets and liabilities. The effective tax rates for the years ended December 31, 2019 and 2018 reflect a $23,662 and $18,181 reduction in income tax expense, respectively, due to the non-controlling interest in CNXM’s earnings.

The effective tax rate for the year ended December 31, 2018 was lower than the U.S. federal statutory rate primarily due to the effect of the filing of a Federal NOL carryback for 2017 and 2016 resulting in a financial statement benefit of $23,483 through the realization of the Federal NOLs at a 35% tax rate as a carryback versus the current 21% tax rate as a carryforward, the reversal of the AMT credit sequestration valuation allowance, and the release of certain state valuation allowances as a result of a corporate reorganization during the year. The federal NOL carryback claims for 2016 and 2017 were subject to a review by the IRS and the Joint Committee on Taxation which has since been completed.
The TCJA Act, which, among other things, lowered the U.S. Federal corporate income tax rate from 35% to 21%, repealed the corporate AMT for tax years beginning January 1, 2018, and provided for a refund of previously accrued AMT credits. The Company's effective tax rate for 2018 reflects the release of previously recorded valuation allowances against AMT credit carry-forwards of $12,413, as those credits were able to be monetized under the TCJA Act.

In December 2019, the FASB issued ASU 2019-12 - Income Taxes - Simplifying the Accounting for Income Taxes (Topic 740), which simplifies the accounting for income taxes by removing certain exceptions to the general principles in Topic 740. This ASU removes the following exceptions: (1) exception to the incremental approach for intraperiod tax allocation when there is a loss from continuing operations and income or a gain from other items; (2) exception to the requirement to recognize a deferred tax liability for equity method investments when a foreign subsidiary becomes an equity method investment; (3) exception to the ability not to recognize a deferred tax liability for a foreign subsidiary when a foreign equity method investment becomes a subsidiary; and (4) exception to the general methodology for calculating income taxes in an interim period when a year-to-date loss exceeds the anticipated loss for the year. The amendments in this ASU also improve consistency and simplify other areas of Topic 740 by clarifying and amending existing guidance. The amendments in this ASU were applied using different approaches depending on what the specific amendment relates to and, for public entities, are effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2020. The Company early adopted ASU 2019-12 as of January 1, 2020.

A reconciliation of the beginning and ending gross amounts of unrecognized tax benefits is as follows:
For the Years Ended
December 31,
20202019
Balance at Beginning of Period$31,516 $31,516 
Increase in Unrecognized Tax Benefits Resulting from Tax Positions Taken During Prior Periods
1,726 — 
Reduction in Unrecognized Tax Benefits Because of the Lapse of the Applicable Statute of Limitations(1,351)— 
Balance at End of Period$31,891 $31,516 

If these unrecognized tax benefits were recognized, $31,891 and $31,516 would affect CNX's effective income tax rate for 2020 and 2019, respectively.

In 2020, CNX recognized an increase in unrecognized tax benefits of $1,726 for tax benefits resulting from a tax position taken on our 2019 federal tax return for additional tax credits. CNX recognized a reduction to unrecognized tax benefits of $1,351 due to the expiration of the statute of limitations from a position taken on a previously filed federal income tax return.

CNX recognizes accrued interest related to unrecognized tax benefits in its interest expense. As of December 31, 2020 and 2019, the Company reported no accrued liability relating to uncertain tax positions in Other Liabilities in the Consolidated Balance Sheets. During the years ended December 31, 2020 and 2019, CNX paid no interest related to income tax deficiencies.

CNX recognizes penalties accrued related to uncertain tax positions in its income tax expense. CNX had no accrued liabilities for tax penalties as of December 31, 2020 and 2019.
CNX and its subsidiaries file federal income tax returns with the United States and income tax returns within various states. With few exceptions, the Company is no longer subject to United States federal, state, local or non-U.S. income tax examinations by tax authorities for the years before 2018.
v3.20.4
Asset Retirement Obligations
 12 Months Ended
Dec. 31, 2020
Asset Retirement Obligation [Abstract]  
Asset Retirement Obligations ASSET RETIREMENT OBLIGATIONS:
The reconciliation of changes in asset retirement obligations is as follows:
December 31,
20202019
Balance, Beginning of Year$68,454 $38,554 
Obligations Divested(703)— 
Accretion Expense11,067 9,458 
Obligations Incurred2,806 2,933 
Obligations Settled(7,905)(4,231)
Revisions in Estimated Cash Flows19,449 21,740 
Balance, End of Year$93,168 $68,454 
v3.20.4
Property, Plant and Equipment
 12 Months Ended
Dec. 31, 2020
Property, Plant and Equipment [Abstract]  
Property, Plant and Equipment PROPERTY, PLANT AND EQUIPMENT:
December 31,
Property, Plant and Equipment20202019
Intangible Drilling Cost$4,965,252 $4,688,497 
Gas Gathering Equipment2,510,917 2,463,866 
Proved Gas Properties1,253,094 1,208,046 
Gas Wells and Related Equipment1,120,061 1,042,000 
Unproved Gas Properties725,705 755,590 
Surface Land and Other Equipment199,322 226,285 
Other 189,645 187,722 
Total Property, Plant and Equipment10,963,996 10,572,006 
Less: Accumulated Depreciation, Depletion and Amortization3,938,451 3,435,431 
Total Property, Plant and Equipment - Net$7,025,545 $7,136,575 

During the years ended December 31, 2020 and 2019, the Company capitalized $1,328 and $5,482, respectively, of interest on Gas Gathering Equipment under construction.

Amounts below reflect properties where drilling operations have not yet commenced and therefore, were not being amortized for the years ended December 31, 2020 and 2019, respectively. These assets will be amortized using the units-of-production method and reclassified to proved gas properties when placed in service.
December 31,
20202019
Unproved Gas Properties$725,705 $755,590 
Advance Royalties9,676 12,770 
     Total$735,381 $768,360 
v3.20.4
Goodwill and Other Intangible Assets
 12 Months Ended
Dec. 31, 2020
Goodwill and Intangible Assets Disclosure [Abstract]  
Goodwill and Other Intangible Assets GOODWILL AND OTHER INTANGIBLE ASSETS:
In connection with the Midstream Acquisition that closed on January 3, 2018 (see Note 4 - Acquisitions and Dispositions for more information), CNX recorded $796,359 of goodwill and $128,781 of other intangible assets which are comprised of customer relationships.

Impairment of Goodwill

All goodwill is attributed to the Midstream reporting unit within the Shale segment. Goodwill is evaluated for impairment at least annually and whenever events or changes in circumstance indicate that the fair value of a reporting unit is less than its carrying amount. In connection with the evaluation of goodwill for impairment, CNX may first consider qualitative factors to assess whether there are indicators that it is more likely than not that the fair value of a reporting unit may not exceed its
carrying amount. If after assessing such factors or circumstances, CNX determines it is more likely than not that the fair value of a reporting unit is greater than its carrying amount, then a quantitative assessment is not required. If CNX chooses to bypass the qualitative assessment, or if it chooses to perform a qualitative assessment but is unable to qualitatively conclude that no impairment has occurred, then CNX will perform a quantitative assessment. If the estimated fair value of a reporting unit is less than its carrying value, an impairment charge is recognized for the excess of the reporting unit's carrying value over its fair value. The Company uses a combination of the income approach (generally a discounted cash flow method) and market approach (which may include the guideline public company method and/or the guideline transaction method) to estimate the fair value of a reporting unit.

In estimating the fair value of the Midstream reporting unit, the Company used the income approach’s discounted cash flow method, which applies significant inputs not observable in the public market (Level 3), including estimates and assumptions related to the use of an appropriate discount rate, future throughput volumes, operating costs and capital spending, discounted to present value using an industry rate adjusted for company-specific risk, which management feels reflects the overall level of inherent risk of the reporting unit. These assumptions are affected by expectations about future market, industry and economic conditions. Cash flow projections were derived from board approved budgeted amounts, a seven-year operating forecast and an estimate of future cash flows. Subsequent cash flows were developed using growth or contraction rates that management believes are reasonably likely to occur. The Company used the market approach’s comparable company method. The comparable company method evaluates the value of a company using metrics of other businesses of similar size and industry.

During the first quarter of 2020, the Company identified indicators of impairment in the form of deteriorating macroeconomic conditions, and the decline in the observable market value of CNXM securities both in relation to the COVID-19 pandemic and the overall decline in the MLP market space. Management concluded that these factors presented indications that the fair value of the Midstream reporting unit was more likely than not below the reporting unit’s carrying value. CNX bypassed the qualitative assessment and performed a quantitative test that utilized a combination of the income and market approaches as described above to estimate the fair value of the Midstream reporting unit. As a result of this assessment, CNX concluded that the carrying value exceeded its estimated fair value, and a corresponding impairment of $473,045 was recorded, which was included in Impairment of Goodwill in the accompanying Consolidated Statements of Income.

In connection with our annual assessment of goodwill in the fourth quarter of 2020, we bypassed the qualitative assessment and performed a quantitative test that utilized a combination of the income and market approaches to estimate the fair value of the Midstream reporting unit. As a result of this assessment, we concluded that the estimated fair value exceeded carrying value, and accordingly no adjustment to goodwill was necessary. However, the margin by which the fair value of the Midstream reporting unit exceeded its carrying value was less than 10%. As a result, this reporting unit is susceptible to impairment risk from further adverse macroeconomic conditions or other adverse factors such as future gathering volumes being less than those currently estimated. Any additional adverse changes in the future could reduce the underlying cash flows used to estimate fair values and could result in a decline in fair value that could trigger future impairment charges.

The estimates of future cash flows are subjective in nature and are subject to impacts from business risks as described in “Item 1A. Risk Factors”. The fair value estimation process requires considerable judgment and determining the fair value is sensitive to changes in assumptions impacting management’s estimates of future financial results. Although CNX believes the estimates and assumptions used in estimating the fair value are reasonable and appropriate, different assumptions and estimates could materially impact the estimated fair value. Future results could differ from our current estimates and assumptions.

Changes in the carrying amount of goodwill consist of the following activity:
Amount
December 31, 2019$796,359 
Impairment473,045 
December 31, 2020$323,314 
Other Intangible Assets

The carrying amount and accumulated amortization of other intangible assets consist of the following:
December 31,
20202019
Other Intangible Assets:
Gross Amortizable Asset - Customer Relationships$109,752 $109,752 
Less: Accumulated Amortization - Customer Relationships19,657 13,105 
Total Other Intangible Assets, net$90,095 $96,647 

During the year ended December 31, 2018, CNX determined that the carrying value of a portion of the customer relationship intangible assets exceeded their fair value as a result of the AEA with HG Energy. Accordingly, CNX recognized an impairment on this intangible asset of $18,650. There were no such impairments during the years ended December 31, 2020 and 2019.
The customer relationship intangible asset is being amortized on a straight-line basis over approximately 17 years. Amortization expense related to other intangible assets was $6,552 for each of the years ended December 31, 2020 and 2019, and $6,931 for the year ended December 31, 2018. The estimated annual amortization expense is expected to approximate $6,552 per year for each of the next five years.
v3.20.4
Revolving Credit Facilities
 12 Months Ended
Dec. 31, 2020
Short-term Debt, Other Disclosures [Abstract]  
Revolving Credit Facilities REVOLVING CREDIT FACILITIES:
CNX
In April 2019, CNX amended its senior revolving credit facility ("Credit Facility") and extended its maturity to April 2024. The lenders' commitments remained unchanged at $2,100,000, with an accordion feature that allows the Company to increase commitments to $3,000,000. In addition, the cumulative credit basket for dividends and distributions was replaced with a basket for dividends and distributions subject to a pro forma net leverage ratio of at least 3.00 to 1.00 and availability under the Credit Facility of at least 15% of the aggregate commitments. In April 2020, as part of the semi-annual borrowing base redetermination, both the lenders' commitments and borrowing base decreased to $1,900,000, and the $650,000 letters of credit aggregate sub-limit remained unchanged. The amount of cash on hand that CNX may have is also limited to $150,000 when loans under the credit agreement are outstanding, subject to certain exceptions. In October 2020, as part of the semi-annual borrowing base redetermination, the lenders reaffirmed CNX's $1,900,000 borrowing base. In November 2020, as part of the issuance of the $500,000 of 6.00% Senior Notes due January 2029 (See Note 12 - Long-Term Debt), both the lenders' commitments and borrowing base decreased to $1,775,000.

The CNX Credit Facility is secured by substantially all of the assets of CNX and certain of its subsidiaries (excluding the certain excluded subsidiaries, which includes Cardinal States Gathering LLC, CNX Midstream GP LLC and CNXM, and their respective subsidiaries).

Under the terms of the agreement, borrowings under the revolving credit facility will bear interest at CNX's option at either:
•the base rate, which is the highest of (i) the federal funds open rate plus 0.50%, (ii) PNC Bank, N.A.’s prime rate, or (iii) the one-month LIBOR rate plus 1.0%, in each case, plus a margin ranging from 0.75% to 1.75%; or
•the LIBOR rate, which is the LIBOR rate plus a margin ranging from 1.75% to 2.75%.

The CNX Credit Facility contains a number of affirmative and negative covenants including those that, except in certain circumstances, limit the Company and the subsidiary guarantors' ability to create, incur, assume or suffer to exist indebtedness, create or permit to exist liens on properties, dispose of assets, make investments, purchase or redeem CNX common stock, pay dividends, merge with another corporation and amend the senior unsecured notes. The Company must also mortgage 85% of the value of its proved reserves and 85% of the value of its proved developed producing reserves, in each case, which are included in the borrowing base, maintain applicable deposit, securities and commodities accounts with the lenders or affiliates thereof, and enter into control agreements with respect to such applicable accounts.

The CNX Credit Facility contains customary events of default, including, but not limited to, a cross-default to certain other debt, breaches of representations and warranties, change of control events and breaches of covenants.
The CNX Credit Facility also requires that CNX maintain a maximum net leverage ratio of no greater than 4.00 to 1.00, which is calculated as the ratio of debt less cash on hand to consolidated EBITDA, measured quarterly. CNX must also maintain a minimum current ratio of no less than 1.00 to 1.00, which is calculated as the ratio of current assets, plus revolver availability, to current liabilities, excluding borrowings under the revolver, measured quarterly. The calculation of all of the ratios exclude CNXM. CNX was in compliance with all financial covenants as of December 31, 2020.

At December 31, 2020, the CNX Credit Facility had $160,800 of borrowings outstanding and $185,272 of letters of credit outstanding, leaving $1,428,928 of unused capacity. At December 31, 2019, the CNX Credit Facility had $661,000 of borrowings outstanding and $204,726 of letters of credit outstanding, leaving $1,234,274 of unused capacity.

CNX Midstream Partners LP (CNXM)
CNXM's revolving credit facility was not impacted by the Merger (See Note 4 - Acquisitions and Dispositions).

In April 2019, CNXM amended its senior secured revolving credit facility (the “CNXM Credit Facility”) and extended its maturity to April 2024. The lenders' commitments remained unchanged at $600,000, with an accordion feature that allows CNXM to increase the available borrowings by up to an additional $250,000 under certain terms and conditions. The CNXM Credit Facility includes the ability to issue letters of credit up to $100,000 in the aggregate.

Under the terms of the amended agreement, borrowings under the CNXM Credit Facility will bear interest at CNXM's option at either:
•the base rate, which is the highest of (i) the federal funds open rate plus 0.50%, (ii) PNC Bank, N.A.’s prime rate, or (iii) the one-month LIBOR rate plus 1.0%, in each case, plus a margin ranging from 0.50% to 1.50%; or
•the LIBOR rate, plus a margin ranging from 1.50% to 2.50%.
Fees and interest rate spreads under the CNXM Credit Facility are based on the total leverage ratio, measured quarterly.

The CNXM Credit Facility requires CNXM to comply with a number of affirmative and negative covenants. In addition, CNXM is obligated to maintain at the end of each fiscal quarter (w) for so long as at least $150,000 of the CNXM 6.50% Senior Notes due March 2026 (CNXM Senior Notes) are outstanding, a maximum total leverage ratio of no greater than 5.25 to 1.00 (which increases to no greater than 5.50 to 1.00 during qualifying acquisition periods); (x) if less than $150,000 of the CNXM Senior Notes are outstanding, a maximum total leverage ratio of no greater than 4.75 to 1.00 (which increases to no greater than 5.25 to 1.00 during qualifying acquisition periods); (y) a maximum secured leverage ratio of no greater than 3.50 to 1.00 and (z) a minimum interest coverage ratio of no less than 2.50 to1.00. CNXM was in compliance with all financial covenants as of December 31, 2020.

The CNXM Credit Facility also contains customary events of default, including, but not limited to, a cross-default to certain other debt, breaches of representations and warranties, change of control events and breaches of covenants. The obligations under the revolving credit facility are secured by substantially all of the assets of CNXM and its wholly-owned subsidiaries. CNX is not a guarantor under the CNXM Credit Facility.
At December 31, 2020, the CNXM Credit Facility had $291,000 of borrowings outstanding and $30 of letters of credit outstanding, leaving $308,970 of unused capacity. At December 31, 2019, the CNXM Credit Facility had $311,750 of borrowings outstanding, leaving $288,250 of unused capacity.
v3.20.4
Other Accrued Liabilities
 12 Months Ended
Dec. 31, 2020
Other Liabilities Disclosure [Abstract]  
Other Accrued Liabilities OTHER ACCRUED LIABILITIES:
December 31,
20202019
Royalties$72,401 $74,061 
Accrued Interest26,549 30,862 
Short-Term Incentive Compensation20,340 21,030 
Transportation Charges15,969 16,533 
Deferred Revenue10,986 13,964 
Accrued Other Taxes10,580 9,115 
Accrued Payroll & Benefits5,009 6,248 
Other26,697 37,610 
Current Portion of Long-Term Liabilities:
Asset Retirement Obligations8,455 5,076 
Salary Retirement
1,787 1,587 
Total Other Accrued Liabilities$198,773 $216,086 
v3.20.4
Long-Term Debt
 12 Months Ended
Dec. 31, 2020
Long-term Debt, Other Disclosures [Abstract]  
Long-term Debt LONG-TERM DEBT:
December 31,
20202019
Senior Notes due March 2027 at 7.25% (Principal of $700,000 and $500,000, respectively, plus Unamortized Premium of $6,686 at December 31, 2020)
$706,686 $500,000 
Senior Notes due January 2029 at 6.00%, Issued at Par Value
500,000 — 
CNX Midstream Partners LP Senior Notes due March 2026 at 6.50% (Principal of $400,000 less Unamortized Discount of $3,875 and $4,625, respectively)*
396,125 395,375 
CNX Midstream Partners LP Revolving Credit Facility* 291,000 311,750 
Convertible Senior Notes due May 2026 at 2.25% (Principal of $345,000 less Unamortized Discount and Issuance Costs of $107,735)
237,265 — 
CNX Revolving Credit Facility160,800 661,000 
Cardinal States Gathering Company Credit Facility maturing in March 2028 (Principal of $114,985 less Unamortized Discount of $1,126)
113,859 — 
CSG Holdings II LLC Credit Facility maturing in March 2027 (Principal of $45,559 less Unamortized Discount of $441)
45,118 — 
Senior Notes due April 2022 at 5.875% (Principal of $894,307 plus Unamortized Premium of $1,001 at December 31, 2019)
— 895,308 
Less: Unamortized Debt Issuance Costs26,852 8,990 
2,424,001 2,754,443 
Less: Amounts Due in One Year22,574 — 
Long-Term Debt$2,401,427 $2,754,443 
*CNX is not a guarantor of CNXM's 6.50% Senior Notes due March 2026 or CNXM's Credit Facility.

CNXM's Credit Facility and the CNXM Senior Notes were not impacted by the Merger (See Note 4 - Acquisitions and Dispositions).
At December 31, 2020, annual undiscounted maturities of CNX and CNXM long-term debt during the next five years and thereafter are as follows:
Year ended December 31,Amount
2021$22,574 
202223,712 
202324,469 
2024474,366 
202523,057 
Thereafter1,989,166 
      Total Long-Term Debt Maturities$2,557,344 

During the year ended December 31, 2020, CNX purchased and retired the remaining $894,307 of its outstanding 5.875% Senior Notes due April 2022. As part of this transaction, a gain of $10,101 was included in (Gain) Loss on Debt Extinguishment in the Consolidated Statements of Income.

In November 2020, CNX completed a private offering of $500,000 aggregate principal amount of 6.00% Senior Notes due January 2029 (the “Senior Notes due January 2029”). The notes, along with the related guarantees, were issued pursuant to an indenture, dated November 30, 2020, among the Company, the subsidiary guarantors party thereto and UMB Bank, N.A., as trustee. The notes accrue interest from November 30, 2020 at a rate of 6.00% per year. Interest is payable semi-annually in arrears on January 15 and July 15 of each year, beginning July 15, 2021. The Senior Notes due January 2029 mature on January 15, 2029, subject to adjustment upon the occurrence of specified events. The notes rank equally in right of payment with all of the Company’s existing and future senior indebtedness and senior to any subordinated indebtedness that the Company may incur. The notes are guaranteed by most of CNX's subsidiaries but does not include CNXM (or its subsidiaries or general partner) or CSG Holdings III LLC.

In September 2020, CNX completed a private offering of $200,000 aggregate principal amount of 7.25% Senior Notes due March 2027 (the “Senior Notes due March 2027s”) plus $7,000 of unamortized bond premium at a price of 103.5% of par with an effective yield of 6.34%. The notes, along with the related guarantees, were issued pursuant to an indenture, dated March 14, 2019. The notes accrue interest from September 14, 2020 at a rate of 7.25% per year. Interest is payable semi-annually in arrears on March 14 and September 14 of each year, beginning March 14, 2021. The notes mature on March 14, 2027. The Senior Notes due March 2027 rank equally in right of payment with all of the Company’s existing and future senior indebtedness and senior to any subordinated indebtedness that the Company may incur. The notes are guaranteed by most of CNX's subsidiaries but does not include CNXM (or its subsidiaries or general partner) or CSG Holdings III LLC.

In April 2020, CNX issued $345,000 in aggregate principal amount of 2.25% convertible senior notes due May 2026 (the "Convertible Notes") in a private offering to qualified institutional buyers pursuant to Rule 144A under the Securities Act of 1933, as amended, including $45,000 aggregate principal amount of Convertible Notes issued pursuant to the exercise in full of the initial purchasers’ option to purchase additional Convertible Notes. The Convertible Notes were issued pursuant to an indenture and are senior, unsecured obligations of the Company. The Convertible Notes bear interest at a fixed rate of 2.25% per annum, payable semi-annually in arrears on May 1 and November 1 of each year, commencing on November 1, 2020. Proceeds from the issuance of the Convertible Notes totaled $334,650, net of initial purchaser discounts and issuance costs. The notes are guaranteed by most of CNX's subsidiaries but does not include CNXM (or its subsidiaries or general partner) or CSG Holdings III LLC.

The initial conversion rate is 77.8816 shares of CNX's common stock per $1,000 principal amount of Convertible Notes, which represents an initial conversion price of approximately $12.84 per share, subject to adjustment upon the occurrence of specified events. The Convertible Notes will mature on May 1, 2026, unless earlier repurchased, redeemed or converted. Before February 1, 2026, note holders will have the right to convert their Convertible Notes only upon the occurrence of the following events:

•during any calendar quarter (and only during such calendar quarter) commencing after the calendar quarter ending on June 30, 2020, if the Last Reported Sale Price per share of Common Stock exceeds one hundred and thirty percent (130%) of the Conversion Price for each of at least twenty (20) Trading Days (whether or not consecutive) during the thirty (30) consecutive Trading Days ending on, and including, the last Trading Day of the immediately preceding calendar quarter.
•during the five (5) consecutive Business Days immediately after any ten (10) consecutive trading day period (such ten (10) consecutive Trading Day period, the “Measurement Period”) if the trading Price per $1,000 principal amount of
Notes, as determined following a request by a Holder in accordance with the procedures set forth below, for each trading day of the Measurement Period was less than ninety eight percent (98%) of the product of the last reported sale price per share of common stock on such trading day and the conversion rate on such trading day.
•if we call any or all of the Convertible Notes for redemption, at any time prior to the close of business on the scheduled trading day immediately preceding the redemption date; or
•upon the occurrence of certain specified corporate events as set forth in the indenture governing the Convertible Notes.

From and after February 1, 2026, note holders may convert their Convertible Notes at any time at their election until the close of business on the second scheduled trading day immediately before the maturity date.

Upon conversion, the Company may satisfy its conversion obligation by paying and/or delivering, as the case may be, cash, shares of the Company’s common stock or a combination of cash and shares of the Company’s common stock, at the Company’s election, in the manner and subject to the terms and conditions provided in the indenture governing the Convertible Notes. The conversion rate is subject to adjustment under certain circumstances in accordance with the terms of the indenture governing the Convertible Notes. In addition, following certain corporate events, as described in the indenture governing the Convertible Notes, that occur prior to the maturity date, the Company will increase the conversion rate, in certain circumstances, for a holder who elects to convert its Convertible Notes in connection with such a corporate event.

The Company will settle conversions by paying or delivering, as applicable, cash, shares of its common stock or a combination of cash and shares of its common stock, at the Company’s election. The Company’s current intent is to settle the principal amount of the Convertible Notes in cash upon conversion.

If certain corporate events that constitute a “Fundamental Change” (as defined in the indenture governing the Convertible Notes) occur, then noteholders may require the Company to repurchase their Notes at a cash repurchase price equal to the principal amount of the Notes to be repurchased, plus accrued and unpaid interest, if any, to, but excluding, the fundamental change repurchase date. The definition of Fundamental Change includes certain business combination transactions involving the Company and certain de-listing events with respect to the Company’s common stock. During the year ended December 31, 2020, the conditions allowing holders of the Convertible Notes to exercise their conversion right were not met and as of December 31, 2020, the notes were not convertible. The Convertible Notes are therefore classified as long-term debt at December 31, 2020.

In accounting for the transaction, the Convertible Notes were separated into liability and equity components. The carrying amount of the liability component was calculated by measuring the fair value of a similar debt instrument that does not have an associated conversion feature. The fair value was based on market data available for publicly traded, senior, unsecured corporate bonds with similar maturity, which represent Level 2 observable inputs. The carrying amount of the equity component, representing the conversion option, was determined by deducting the fair value of the liability component from the principal value of the Convertible Notes and was recorded in Capital in Excess of Par Value in the Consolidated Statement of Stockholders Equity and is not remeasured as long as it continues to meet the conditions for equity classification. The excess of the principal amount of the Convertible Notes over the liability component and the debt issuance costs are amortized to interest expense over the contractual term of the Convertible Notes using the effective interest method.

In accounting for the debt issuance costs of $10,350 related to the Convertible Notes, the Company allocated the total amount incurred to the liability and equity components using the same proportions as the proceeds of the Convertible Notes. Issuance costs attributable to the liability component were $7,024 and will be amortized to interest expense using the effective interest method over the contractual term of the Convertible Notes. Issuance costs attributable to the equity component were $3,326 and were netted with the equity component in Capital in Excess of Par Value in the Consolidated Statement of Stockholders Equity and are not subject to amortization.

The net carrying amount of the liability and equity components of the Convertible Notes was as follows:
December 31, 2020
Liability Component:
Principal$345,000 
Unamortized Discount(101,367)
Unamortized Issuance Costs(6,368)
Net Carrying Amount$237,265 
Equity Component, net of Purchase Discounts and Issuance Costs78,317 
Interest expense related to the Convertible Notes is as follows:
For the Year Ended
December 31, 2020
Contractual Interest Expense $5,175 
Amortization of Debt Discount9,516 
Amortization of Issuance Costs655 
Total Interest Expense $15,346 

In connection with the offering of the Convertible Notes, the Company entered into privately negotiated capped call transactions with certain counterparties, (the “Capped Calls”). The Capped Calls each have an initial strike price of $12.84 per share, subject to certain adjustments, which correspond to the initial conversion price of the Convertible Notes. The Capped Calls have an initial cap price of $18.19 per share, subject to certain adjustments. The Capped Calls cover, subject to anti-dilution adjustments, the aggregate number of shares of the Company’s common stock that initially underlie the Convertible Notes, and are expected generally to reduce potential dilution to the Company’s common stock upon any conversion of Convertible Notes and/or offset any cash payments the Company is required to make in excess of the principal amount of converted Convertible Notes, as the case may be, with such reduction and/or offset subject to a cap, based on the cap price of the Capped Call Transactions. The conditions that cause adjustments to the initial strike price of the Capped Calls mirror the conditions that result in corresponding adjustments for the Convertible Notes. For accounting purposes, the Capped Calls are separate transactions, and not part of the terms of the Convertible Notes. As these transactions meet certain accounting criteria, the Capped Calls are recorded in stockholders’ equity and are not accounted for as derivatives. The cost of $35,673 incurred in connection with the Capped Calls was recorded as a reduction to Capital in Excess of Par Value. The impact of the Capped Calls related to stockholders’ equity has been included in Capital in Excess of Par Value in the Consolidated Statement of Stockholders Equity and includes taxes in the amount of $9,322, for a net impact of $26,351.

During the year ended December 31, 2020, CNX's wholly-owned subsidiary Cardinal States Gathering Company LLC (Cardinal States) entered into a $125,000 non-revolving credit facility agreement (the "Cardinal States Facility"). The Cardinal States Facility matures in 2028, has an interest rate of 3-month LIBOR + 450 basis points and includes an excess cash flow sweep in an amount required to achieve a quarterly targeted debt balance. The facility is secured by substantially all of the Cardinal States assets, requires a minimum level of hedging of the variable interest rate exposure and is non-recourse to CNX.

Additionally, during the year ended December 31, 2020, CNX's wholly-owned subsidiary CSG Holdings II LLC (CSG Holdings) entered into a $50,000 non-revolving credit facility agreement (the "CSG Holdings Facility"). The CSG Holdings Facility matures in 2027, has interest rate of 3-month LIBOR + 675 basis points and includes a full excess cash sweep. The facility is secured by substantially all of the CSG Holding assets, requires a minimum level of hedging of the variable interest rate exposure and is non-recourse to CNX.

During the year ended December 31, 2019, CNX completed a private offering of $500,000 of 7.25% Senior Notes due March 2027. The notes are guaranteed by most of CNX's subsidiaries but do not include CNXM (or its subsidiaries or general partner).

During the year ended December 31, 2019, CNX purchased and retired $400,000 of its outstanding 5.875% Senior Notes due April 2022. As part of this transaction, a loss of $7,614 was included in (Gain) Loss on Debt Extinguishment in the Consolidated Statements of Income.

During the year ended December 31, 2018, CNX purchased and retired $411,375 of its outstanding 5.875% Senior Notes due April 2022. As part of this transaction, a loss of $15,320 was included in (Gain) Loss on Debt Extinguishment in the Consolidated Statements of Income.

During the year ended December 31, 2018, CNX called the $500,000 balance on its 8.00% Senior Notes due April 2023. As part of this transaction, a loss of $38,798 was included in (Gain) Loss on Debt Extinguishment in the Consolidated Statements of Income.
v3.20.4
Leases
 12 Months Ended
Dec. 31, 2020
Leases [Abstract]  
Leases LEASES:On January 1, 2019, the Company adopted ASU 2016-02, and all related amendments, using the transition method, which allows for a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption. CNX elected the transition relief package of practical expedients by applying previous accounting conclusions under ASC 840 to all leases that existed prior to the transition date. As a result, CNX did not reassess 1) whether existing or expired contracts contain
leases, 2) lease classification for any existing or expired leases or 3) whether lease origination costs qualified as initial direct costs. Additionally, the Company elected the short-term practical expedient for all asset classes by establishing an accounting policy to exclude leases with a term of 12 months or less. CNX will not separate lease components from non-lease components for any asset class. Lastly, CNX adopted the easement practical expedient, which allows the Company to apply ASC 842 prospectively to land easements after the adoption date. Easements that existed or expired prior to the adoption date that were not previously assessed under ASC 840 will not be reassessed.
CNX's leasing activities primarily consist of operating and finance leases for electric fracturing equipment, natural gas drilling rigs, CNX's corporate headquarters as well as field offices, a natural gas gathering pipeline and commercial vehicles. Some leases include options to renew ranging from a period of 1 to 10 years, which are not recognized as part of the lease right-of-use (ROU) assets or liabilities as they are not reasonably certain to be exercised.
Operating lease ROU assets and liabilities are recognized at commencement date based on the present value of the lease payments over the lease term. As most of CNX's leases do not provide an implicit rate, an incremental borrowing rate is used to determine the present value of lease payments.
The components of lease cost were as follows:
For the Years Ended December 31,
20202019
Operating Lease Cost$74,703 $73,809 
Finance Lease Cost:
Amortization of Right-of-Use Assets
4,959 5,242 
Interest on Lease Liabilities
739 1,241 
Short-term Lease Cost3,252 5,547 
Variable Lease Cost*9,634 17,337 
Total Lease Cost$93,287 $103,176 
*Amounts recognized in the Consolidated Balance Sheets for natural gas drilling rigs are measured using the rates that would be paid if the rigs were idle, as this represents the minimum payment that could be made under the contract. Variable lease cost represents amounts paid for natural gas drilling rigs above this minimum when the rigs are in use. Amounts recognized in the Consolidated Balance Sheets for electric fracturing equipment are measured using minimum pumping hours under the contract; however, pumping hours may exceed the minimum and vary period to period. Any such amounts paid related to pumping hours in excess of the minimum represent variable lease cost.

Rental expense under operating leases prior to the adoption of ASC 842 was $21,441 for the year ended December 31, 2018.
Amounts recognized in the Consolidated Balance Sheets are as follows:
December 31,
20202019
Operating Leases:
Operating Lease Right-of-Use Asset$108,683 $187,097 
Current Portion of Operating Lease Obligations$52,575 $61,670 
Operating Lease Obligations53,235 110,466 
Total Operating Lease Liabilities
$105,810 $172,136 
Finance Leases:
Property, Plant and Equipment$72,653 $72,916 
Less—Accumulated Depreciation, Depletion and Amortization67,508 63,008 
Property, Plant and Equipment—Net
$5,145 $9,908 
Current Portion of Finance Lease Obligations$6,876 $7,164 
Finance Lease Obligations1,057 7,706 
Total Finance Lease Liabilities
$7,933 $14,870 
Supplemental cash flow information related to leases was as follows:
For the Years Ended December 31,
20202019
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating Cash Flows from Operating Leases
$62,610 $66,827 
Operating Cash Flows from Finance Leases
$739 $1,241 
Financing Cash Flows from Finance Leases
$7,155 $7,149 
Right-of-Use Assets Obtained in Exchange for Lease Obligations:
Operating Leases
$4,027 $15,347 
Finance Leases
$257 $1,846 

Maturities of lease liabilities are as follows:
OperatingFinance
LeasesLeases
Year Ended December 31,
2021$56,190 $7,138 
202221,592 446 
20235,453 442 
20245,433 155 
20254,824 38 
Thereafter25,996 40 
Total Lease Payments119,488 8,259 
Less: Interest13,678 326 
Present Value of Lease Liabilities$105,810 $7,933 

Lease terms and discount rates are as follows:
December 31,
20202019
Weighted Average Remaining Lease Term (years):
Operating Leases
4.684.39
Finance Leases
1.372.16
Weighted Average Discount Rate:
Operating Leases
4.40 %4.96 %
Finance Leases
6.33 %6.92 %
Leases LEASES:On January 1, 2019, the Company adopted ASU 2016-02, and all related amendments, using the transition method, which allows for a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption. CNX elected the transition relief package of practical expedients by applying previous accounting conclusions under ASC 840 to all leases that existed prior to the transition date. As a result, CNX did not reassess 1) whether existing or expired contracts contain
leases, 2) lease classification for any existing or expired leases or 3) whether lease origination costs qualified as initial direct costs. Additionally, the Company elected the short-term practical expedient for all asset classes by establishing an accounting policy to exclude leases with a term of 12 months or less. CNX will not separate lease components from non-lease components for any asset class. Lastly, CNX adopted the easement practical expedient, which allows the Company to apply ASC 842 prospectively to land easements after the adoption date. Easements that existed or expired prior to the adoption date that were not previously assessed under ASC 840 will not be reassessed.
CNX's leasing activities primarily consist of operating and finance leases for electric fracturing equipment, natural gas drilling rigs, CNX's corporate headquarters as well as field offices, a natural gas gathering pipeline and commercial vehicles. Some leases include options to renew ranging from a period of 1 to 10 years, which are not recognized as part of the lease right-of-use (ROU) assets or liabilities as they are not reasonably certain to be exercised.
Operating lease ROU assets and liabilities are recognized at commencement date based on the present value of the lease payments over the lease term. As most of CNX's leases do not provide an implicit rate, an incremental borrowing rate is used to determine the present value of lease payments.
The components of lease cost were as follows:
For the Years Ended December 31,
20202019
Operating Lease Cost$74,703 $73,809 
Finance Lease Cost:
Amortization of Right-of-Use Assets
4,959 5,242 
Interest on Lease Liabilities
739 1,241 
Short-term Lease Cost3,252 5,547 
Variable Lease Cost*9,634 17,337 
Total Lease Cost$93,287 $103,176 
*Amounts recognized in the Consolidated Balance Sheets for natural gas drilling rigs are measured using the rates that would be paid if the rigs were idle, as this represents the minimum payment that could be made under the contract. Variable lease cost represents amounts paid for natural gas drilling rigs above this minimum when the rigs are in use. Amounts recognized in the Consolidated Balance Sheets for electric fracturing equipment are measured using minimum pumping hours under the contract; however, pumping hours may exceed the minimum and vary period to period. Any such amounts paid related to pumping hours in excess of the minimum represent variable lease cost.

Rental expense under operating leases prior to the adoption of ASC 842 was $21,441 for the year ended December 31, 2018.
Amounts recognized in the Consolidated Balance Sheets are as follows:
December 31,
20202019
Operating Leases:
Operating Lease Right-of-Use Asset$108,683 $187,097 
Current Portion of Operating Lease Obligations$52,575 $61,670 
Operating Lease Obligations53,235 110,466 
Total Operating Lease Liabilities
$105,810 $172,136 
Finance Leases:
Property, Plant and Equipment$72,653 $72,916 
Less—Accumulated Depreciation, Depletion and Amortization67,508 63,008 
Property, Plant and Equipment—Net
$5,145 $9,908 
Current Portion of Finance Lease Obligations$6,876 $7,164 
Finance Lease Obligations1,057 7,706 
Total Finance Lease Liabilities
$7,933 $14,870 
Supplemental cash flow information related to leases was as follows:
For the Years Ended December 31,
20202019
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating Cash Flows from Operating Leases
$62,610 $66,827 
Operating Cash Flows from Finance Leases
$739 $1,241 
Financing Cash Flows from Finance Leases
$7,155 $7,149 
Right-of-Use Assets Obtained in Exchange for Lease Obligations:
Operating Leases
$4,027 $15,347 
Finance Leases
$257 $1,846 

Maturities of lease liabilities are as follows:
OperatingFinance
LeasesLeases
Year Ended December 31,
2021$56,190 $7,138 
202221,592 446 
20235,453 442 
20245,433 155 
20254,824 38 
Thereafter25,996 40 
Total Lease Payments119,488 8,259 
Less: Interest13,678 326 
Present Value of Lease Liabilities$105,810 $7,933 

Lease terms and discount rates are as follows:
December 31,
20202019
Weighted Average Remaining Lease Term (years):
Operating Leases
4.684.39
Finance Leases
1.372.16
Weighted Average Discount Rate:
Operating Leases
4.40 %4.96 %
Finance Leases
6.33 %6.92 %
v3.20.4
Pension
 12 Months Ended
Dec. 31, 2020
Retirement Benefits [Abstract]  
Pension PENSION:
The benefits for the Defined Contribution Restoration Plan were frozen effective July 1, 2018. Employees hired after this date are not eligible for this benefit plan. In addition, current participants receive no further compensation credits after that date, with the last award being 2017. Annual interest credits will continue to be made in accordance with the terms of the plan. The freezing of the plan triggered a curtailment gain of $416 during the year ended December 31, 2018.

The current portion of the pension obligation is included in Other Accrued Liabilities and the noncurrent portion is included in Other Liabilities in the Consolidated Balance Sheets.
The reconciliation of changes in the benefit obligation, plan assets and funded status of the pension benefits is as follows:
December 31,
20202019
Change in Benefit Obligation:
Benefit Obligation at Beginning of Period
$40,196 $33,569 
Service Cost
247 209 
Interest Cost
1,179 1,338 
Actuarial Loss4,098 4,865 
Plan Amendments
— 1,728 
Benefits and Other Payments
(1,644)(1,513)
Benefit Obligation at End of Period$44,076 $40,196 
Change in Plan Assets:
Fair Value of Plan Assets at Beginning of Period
$— $— 
Company Contributions
1,644 1,513 
Benefits and Other Payments
(1,644)(1,513)
Fair Value of Plan Assets at End of Period$— $— 
Funded Status:
Current Liabilities
$(1,787)$(1,587)
Noncurrent Liabilities
(42,289)(38,609)
Net Obligation Recognized$(44,076)$(40,196)
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of:
Net Actuarial Loss
$19,075 $15,361 
Prior Service Cost1,506 1,727 
Total
20,581 17,088 
Less: Tax Benefit
5,397 4,483 
Net Amount Recognized$15,184 $12,605 

The components of the net periodic benefit cost are as follows:
For the Years Ended December 31,
 202020192018
Components of Net Periodic Benefit Cost:
Service Cost
$247 $209 $302 
Interest Cost
1,179 1,338 1,265 
Amortization of Prior Service Cost (Credit)221 (17)(193)
Recognized Net Actuarial Loss
383 242 865 
Curtailment Gain
— — (416)
Net Periodic Benefit Cost$2,030 $1,772 $1,823 

CNX utilizes a corridor approach to amortize actuarial gains and losses that have been accumulated under the pension plan. Cumulative gains and losses that are in excess of 10% of the greater of either the projected benefit obligation (PBO) or the market-related value of plan assets are amortized over the expected remaining future lifetime of all plan participants for the pension plan.
The following table provides information related to the pension plan with an accumulated benefit obligation in excess of plan assets:
As of December 31,
20202019
Projected Benefit Obligation$44,076 $40,196 
Accumulated Benefit Obligation$43,886 $40,196 
Fair Value of Plan Assets$— $— 

Assumptions:

The weighted-average assumptions used to determine benefit obligations are as follows:
As of December 31,
20202019
Discount Rate2.47 %3.36 %
Rate of Compensation Increase— %— %
Interest Credited Rate2.26 %3.01 %

The discount rates are determined using a Company-specific yield curve model (above-mean) developed with the assistance of an external actuary. The Company-specific yield curve models (above-mean) use a subset of the expanded bond universe to determine the Company-specific discount rate. Bonds used in the yield curve are rated AA by Moody's or Standard & Poor's as of the measurement date. The yield curve models parallel the plans' projected cash flows, and the underlying cash flows of the bonds included in the models exceed the cash flows needed to satisfy the Company plans.

The weighted-average assumptions used to determine net periodic benefit cost are as follows:
For the Years ended December 31,
202020192018
Discount Rate3.36 %4.37 %4.28 %
Rate of Compensation Increase— %3.63 %4.05 %
Interest Credited Rate2.47 %3.39 %3.94 %

Cash Flows:
The following benefit payments, which reflect expected future service, are expected to be paid:
Pension
Year ended December 31,Benefits
2021$1,787 
2022$1,846 
2023$1,913 
2024$1,977 
2025$2,049 
Year 2026-2030$11,172 
v3.20.4
Stock-Based Compensation
 12 Months Ended
Dec. 31, 2020
Share-based Payment Arrangement, Noncash Expense [Abstract]  
Stock-Based Compensation STOCK-BASED COMPENSATION:
CNX's Equity Incentive Plan provides for grants of stock-based awards to key employees and to non-employee directors. Amendments to the Equity Incentive Plan have been adopted and approved by the Board of Directors and the Company's shareholders since the commencement of the Equity Incentive Plan. Most recently, in May 2020 the Company's Shareholders adopted and approved a 10,775,000 increase to the total number of shares available for issuance. At December 31, 2020, 14,081,055 shares of common stock remained available for grant under the plan. The Equity Incentive Plan provides that the aggregate number of shares available for issuance will be reduced by one share for each share relating to stock options and by 1.62 for each share relating to Performance Share Units (PSUs) or Restricted Stock Units (RSUs). No award of stock options may be exercised under the Equity Incentive Plan after the tenth anniversary of the grant date of the award.

For those shares expected to vest, CNX recognizes stock-based compensation costs on a straight-line basis over the requisite service period of the award, which is generally the vesting term. Options and RSUs vest over a three-year term. PSUs granted in 2016-2019 vest over a five-year term at 20% per year and PSUs granted in 2020 vest over a three-year term at 33.3% per year subject to performance conditions. If an employee leaves the Company, all unvested shares are forfeited. CNX recognizes forfeitures as they occur. The vesting of all awards will accelerate in the event of death and disability and may accelerate upon a change in control of CNX.

Pursuant to the terms of the change in control severance agreements of certain employees and CNX officers, outstanding equity awards held by such employees vest upon a stockholder (or stockholder group) becoming the beneficial owner of more than 25% of the Company's outstanding common stock. During the year ended December 31, 2019, Southeastern Asset Management, Inc. and its affiliates ("SEAM") acquired shares of CNX's common stock in the open market which resulted in SEAM's aggregate share ownership exceeding more than 25% of CNX's common stock outstanding. This transaction, as such, constituted a change in control event under the severance agreements, resulting in the accelerated vesting of 473,126 restricted stock units and 903,100 performance share units held by the aforementioned employees that were issued prior to 2019. Those affected employees and officers each consented to waive the change in control vesting provision included in the change in control severance agreements with respect to their restricted stock unit and performance share unit awards that were issued during 2019. The accelerated vesting resulted in $19,654 of additional long-term equity-based compensation expense for the year ended December 31, 2019, and is included in Selling, General and Administrative Costs in the Consolidated Statements of Income. The performance share unit awards that vested continue to be subject to the attainment of performance goals as determined by the Compensation Committee of CNX's Board of Directors after the end of the applicable performance period.

The total stock-based compensation expense recognized relating to CNX shares during the years ended December 31, 2020, 2019 and 2018 was $12,897, $36,545 and $18,930, respectively. The related deferred tax benefit totaled $2,134, $3,955, $4,169, respectively.

As of December 31, 2020, CNX has $10,830 of unrecognized compensation cost related to all non-vested stock-based compensation awards, which is expected to be recognized over a weighted-average period of 1.82 years. When stock options are exercised, and restricted and performance stock unit awards become vested, the issuances are made from CNX's common stock shares.

Pursuant to the Merger (See Note 4 - Acquisitions and Dispositions for more information), all outstanding phantom units previously granted under the CNXM long-term incentive plan were converted into the right to receive 0.88 shares of common stock of CNX. As such, all outstanding phantom units were converted, effective as of the closing of the Merger, into CNX restricted stock units. Each CNX restricted stock unit will be subject to the same vesting, forfeiture and other terms and conditions applicable to the converted CNXM phantom units. Under Accounting Standards Codification Topic 718, Compensation - Stock Compensation, it was determined that there was no additional compensation cost to record as the conversion of awards did not result in incremental fair value.
Stock Options:
CNX examined its historical pattern of option exercises in an effort to determine if there were any discernible activity patterns based on certain employee populations. From this analysis, CNX identified two distinct employee populations and used the Black-Scholes option pricing model to value the options for each of the employee populations. The expected term computation presented in the table below is based upon a weighted average of the historical exercise patterns and post-vesting termination behavior of the two populations. The risk-free interest rate was determined for each vesting tranche of an award based upon the calculated yield on U.S. Treasury obligations for the expected term of the award. A combination of historical and implied volatility is used to determine expected volatility and future stock price trends.
The total fair value of options granted during the years ended December 31, 2020, 2019 and 2018 was $1,066, $50, and $143 respectively, based on the following assumptions and weighted average fair values:
December 31,
202020192018
Weighted Average Fair Value of Grants$3.56 $3.48 $6.50 
Risk-free Interest Rate1.61 %2.13 %2.66 %
Expected Dividend Yield— %— %— %
Expected Forfeiture Rate— %— %— %
Expected Volatility55.33 %43.60 %52.68 %
Expected Term in Years5.116.503.71
A summary of the status of stock options granted is presented below:
Weighted
Average
WeightedRemainingAggregate
AverageContractualIntrinsic
ExerciseTerm (inValue (in
SharesPriceyears)thousands)
Outstanding at December 31, 20194,696,264 $18.05 
Granted299,541 $10.46 
Exercised(298,513)$6.87 
Forfeited(3,561)$10.53 
Expired(493,222)$43.53 
Outstanding at December 31, 20204,200,509 $15.32 4.18$9,430 
Exercisable at December 31, 20203,908,444 $15.68 3.81$9,330 
At December 31, 2020, there were 3,710,157 employee stock options outstanding under the Equity Incentive Plan. Non-employee director stock options vest one year after the grant date. There are 490,352 stock options outstanding under these grants.

The aggregate intrinsic value in the table above represents the total pretax intrinsic value (the difference between CNX's closing stock price on the last trading day of the year ended December 31, 2020 and the option's exercise price, multiplied by the number of in-the-money options) that would have been received by the option holders had all option holders exercised their options on December 31, 2020. This amount varies based on the fair market value of CNX's stock. The total intrinsic value of options exercised for the years ended December 31, 2020, 2019 and 2018 was $1,263, $175, and $2,077, respectively.

Cash received from option exercises for the years ended December 31, 2020, 2019 and 2018 was $2,052, $546 and $1,714, respectively. The tax impact from option exercises totaled $328, $46 and $569 for the years ended December 31, 2020, 2019 and 2018, respectively.

Restricted Stock Units:

Under the Equity Incentive Plan, CNX grants certain employees and non-employee directors RSU awards, which entitle the holder to receive shares of common stock as the award vests. Non-employee director RSUs vest at the end of one year. Compensation expense is recognized over the vesting period of the units, described above. The total fair value of RSUs granted during the years ended December 31, 2020, 2019 and 2018 was $10,619, $10,844 and $13,768, respectively. The total fair value of restricted stock units vested during the years ended December 31, 2020, 2019 and 2018 was $4,798, $10,391 and $6,437, respectively.
The following table represents the nonvested restricted stock units and their corresponding fair value (based upon the closing share price) at the date of grant:
Number ofWeighted Average
SharesGrant Date Fair Value
Nonvested at December 31, 20191,033,200 $11.71
Granted1,251,065 $8.49
RSUs granted in conversion, as a result of the CNXM Merger204,619 $18.01
Vested(577,834)$10.95
Forfeited(39,923)$9.65
Nonvested at December 31, 20201,871,127 $10.10
Performance Share Units:
Under the Equity Incentive Plan, CNX grants certain employees performance share unit awards, which entitle the holder to shares of common stock subject to the achievement of certain market and performance goals. Compensation expense is recognized over the performance measurement period of the units in accordance with the provisions of the Stock Compensation Topic of the FASB Accounting Standards Codification for awards with market and performance vesting conditions. The total fair value of performance share units granted during the years ended December 31, 2020, 2019 and 2018 was $3,826, $6,741 and $8,570, respectively. The total fair value of performance share units vested during the years ended December 31, 2020, 2019 and 2018 was $1,926, $4,668 and $7,547, respectively.
The following table represents the nonvested performance share units and their corresponding fair value (based upon the Monte Carlo Methodology) on the date of grant:
Number ofWeighted Average
SharesGrant Date Fair Value
Nonvested at December 31, 20191,400,836 $18.91
Granted660,634 $5.79
PSUs Issued 112,158 $20.39
Vested(274,716)$20.82
Forfeited(131,474)$18.37
Nonvested at December 31, 20201,767,438 $13.85

Performance Options:

Under the Equity Incentive Plan, CNX granted certain employees performance options in 2010, which entitled the holder to shares of common stock subject to the achievement of certain performance goals. Compensation expense was recognized over the vesting period of the options. The Black-Scholes option valuation model was used to value each tranche separately. There have been no performance options granted since 2010. The 927,268 performance options that were outstanding and exercisable at a weighted average exercise price of $39.00 at December 31, 2019 expired as of December 31, 2020.
v3.20.4
Supplemental Cash Flow Information
 12 Months Ended
Dec. 31, 2020
Supplemental Cash Flow Information [Abstract]  
Supplemental Cash Flow Information SUPPLEMENTAL CASH FLOW INFORMATION:
The following are non-cash transactions that impact the investing and financing activities of CNX. For non-cash transactions that relate to the separation, as well as acquisitions and dispositions, see Note 4 - Acquisitions and Dispositions.
As of December 31, 2020, 2019 and 2018, CNX purchased goods and services related to capital projects in the amount of $30,982, $43,982 and $58,246, respectively, which are included in accounts payable.

The following table shows cash paid (received):
For the Years Ended December 31,
202020192018
Interest (Net of Amounts Capitalized)
$141,992 $143,111 $144,756 
Income Taxes
$(118,125)$(138,409)$(11,505)
v3.20.4
Concentrations of Credit Risk and Major Customers
 12 Months Ended
Dec. 31, 2020
Risks and Uncertainties [Abstract]  
Concentration of Credit Risk and Major Customers CONCENTRATION OF CREDIT RISK AND MAJOR CUSTOMERS:
CNX markets natural gas primarily to gas wholesalers in the United States. Concentration of credit risk is summarized below:
December 31,
20202019
Gas Wholesalers$133,253 $115,641 
NGL, Condensate & Processing Facilities
7,008 10,140 
Other5,752 7,699 
Allowance for Credit Losses(84)— 
Total Accounts Receivable Trade
$145,929 $133,480 
As of December 31, 2020, a receivable of $19,995 due from Direct Energy Business Marketing LLC was included in the Gas Wholesalers balance above. As of December 31, 2019, receivables of $23,859 and $15,401 due from Direct Energy Business Marketing LLC and NJR Energy Services Company, respectively, were included. No other customers made up more than 10% of the total balances.
During the year ended December 31, 2020, sales to Direct Energy Business Marketing LLC were $167,390, which comprised over 10% of the Company's revenue from contracts with external customers for the period.
During the year ended December 31, 2019, sales to Direct Energy Business Marketing LLC were $214,980 and sales to NJR Energy Services Company were $147,540, each of which comprised over 10% of the Company's revenue from contracts with external customers for the period.
During the year ended December 31, 2018, sales to NJR Energy Services Company were $219,472 and sales to Direct Energy Business Marketing LLC were $184,668, each of which comprised over 10% of the Company's revenue from contracts with external customers for the period.
v3.20.4
Fair Value of Financial Instruments
 12 Months Ended
Dec. 31, 2020
Fair Value Disclosures [Abstract]  
Fair Value of Financial Instruments FAIR VALUE OF FINANCIAL INSTRUMENTS:
CNX determines the fair value of assets and liabilities based on the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants. The fair values are based on assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and the risks inherent in valuation techniques and the inputs to valuations. The fair value hierarchy is based on whether the inputs to valuation techniques are observable or unobservable. Observable inputs reflect market data obtained from independent sources (including NYMEX forward curves, LIBOR-based discount rates and basis forward curves), while unobservable inputs reflect the Company's own assumptions of what market participants would use.
The fair value hierarchy includes three levels of inputs that may be used to measure fair value as described below:
Level 1 - Quoted prices for identical instruments in active markets.
Level 2 - The fair value of the assets and liabilities included in Level 2 are based on standard industry income approach models that use significant observable inputs, including NYMEX forward curves, LIBOR-based discount rates and basis forward curves.
Level 3 - Unobservable inputs significant to the fair value measurement supported by little or no market activity.
In those cases when the inputs used to measure fair value meet the definition of more than one level of the fair value hierarchy, the lowest level input that is significant to the fair value measurement in its totality determines the applicable level in the fair value hierarchy.
The financial instrument measured at fair value on a recurring basis is summarized below:
 Fair Value Measurements at December 31, 2020Fair Value Measurements at December 31, 2019
DescriptionLevel 1Level 2Level 3Level 1Level 2Level 3
Gas Derivatives$— $117,545 $— $— $405,781 $— 
Interest Rate Swaps$— $(14,270)$— $— $(1,219)$— 
The carrying amounts and fair values of financial instruments for which the fair value option was not elected are as follows:
 December 31, 2020December 31, 2019
 Carrying
Amount		Fair
Value		Carrying
Amount		Fair
Value
Cash and Cash Equivalents$15,617 $15,617 $16,283 $16,283 
Long-Term Debt (Excluding Debt Issuance Costs)$2,450,853 $2,638,251 $2,763,433 $2,619,676 
Cash and cash equivalents represent highly-liquid instruments and constitute Level 1 fair value measurements. Certain of the Company’s debt is actively traded on a public market and, as a result, constitute Level 1 fair value measurements. The portion of the Company’s debt obligations that is not actively traded is valued through reference to the applicable underlying benchmark rate and, as a result, constitute Level 2 fair value measurements.
v3.20.4
Derivative Instruments
 12 Months Ended
Dec. 31, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]  
Derivative Instruments DERIVATIVE INSTRUMENTS:
CNX enters into interest rate swap agreements to manage its exposure to interest rate volatility. These swaps change the variable-rate cash flow exposure on the debt obligations to fixed cash flows. The change in fair value of the interest rate swap agreements are accounted for on a mark-to-market basis with the changes in fair value recorded in current period earnings.

In March 2020, CNX entered into interest rate swaps related to $175,000 of borrowings under the Cardinal States Facility and CSG Holdings Facility (See Note 12 - Long-Term Debt). In order to manage exposure to interest rate volatility, each respective entity entered into an interest rate swap for the full outstanding principal amounts inclusive of a put option at 25 basis points. The underlying notional for each swap and put option reduces over time based upon an expected amortization profile for each respective credit facility. In addition, CSG Holdings entered into a call option commencing March 31, 2023.

In June 2019, CNX entered into an interest rate swap agreement related to $160,000 of borrowings under CNX’s Credit Facility (See Note 10 - Revolving Credit Facilities) which has the economic effect of modifying the variable-interest obligation into a fixed-interest obligation over a three-year period. In March 2020, this swap was terminated and replaced via a new interest rate swap, effective April 3, 2020, into a new four-year interest rate swap inclusive of a put option at zero basis points. Also executed in March 2020 was a new four-year $250,000 interest rate swap inclusive of a put option at zero basis points, effective April 3, 2020. Consistent with the previous interest rate swap agreement, the $250,000 interest rate swap was entered into to manage CNX's exposure to interest rate volatility.

CNX enters into financial derivative instruments (over-the-counter swaps) to manage its exposure to commodity price volatility. Typically, CNX “sells” swaps under which it receives a fixed price from counterparties and pays a floating market price. During the second quarter of 2020, CNX purchased, rather than sold, financial swaps for the period May through November of 2020 under which CNX will pay a fixed price to and receive a floating price from its hedge counterparties. Swaps purchased have the effect of reducing total hedged volumes for the period of the swap. Natural gas commodity hedges are accounted for on a mark-to-market basis with changes in fair value recorded in current period earnings.

CNX is exposed to credit risk in the event of non-performance by counterparties. The creditworthiness of counterparties is subject to continuing review. The Company has not experienced any issues of non-performance by derivative counterparties.

None of the Company's counterparty master agreements currently require CNX to post collateral for any of its positions. However, as stated in the counterparty master agreements, if CNX's obligations with any of its counterparties cease to be secured on the same basis as similar obligations with the other lenders under the credit facility, CNX would have to post collateral for instruments in a liability position in excess of defined thresholds. All of the Company's derivative instruments are subject to master netting arrangements with our counterparties. CNX recognizes all financial derivative instruments as either assets or liabilities at fair value in the Consolidated Balance Sheets on a gross basis.
 
Each of the Company's counterparty master agreements allows, in the event of default, the ability to elect early termination of outstanding contracts. If early termination is elected, CNX and the applicable counterparty would net settle all open hedge positions.

The total notional amounts of production of CNX's derivative instruments were as follows:
December 31,Forecasted to
20202019Settle Through
Natural Gas Commodity Swaps (Bcf)1,256.9 1,460.6 2025
Natural Gas Basis Swaps (Bcf)1,294.1 1,290.4 2026
Interest Rate Swaps$569,972 $160,000 2028

The gross fair value of CNX's derivative instruments was as follows:
December 31,
20202019
Current Assets:
  Commodity Derivative Instruments:
     Commodity Swaps$53,668 $234,238 
     Basis Only Swaps30,848 13,556 
  Interest Rate Swaps141 — 
Total Current Assets$84,657 $247,794 
Other Non-Current Assets:
  Commodity Derivative Instruments:
     Commodity Swaps$134,661 $288,543 
     Basis Only Swaps52,903 25,553 
  Interest Rate Swaps673 — 
Total Other Non-Current Assets$188,237 $314,096 
Current Liabilities:
  Commodity Derivative Instruments:
     Commodity Swaps$23,506 $345 
     Basis Only Swaps14,491 40,626 
  Interest Rate Swaps4,332 495 
Total Current Liabilities$42,329 $41,466 
Non-Current Liabilities:
  Commodity Derivative Instruments:
     Commodity Swaps$59,388 $9,693 
     Basis Only Swaps57,150 105,445 
  Interest Rate Swaps10,752 724 
Total Non-Current Liabilities$127,290 $115,862 
The effect of derivative instruments on the Company's Consolidated Statements of Income was as follows:
For the Years Ended December 31,
202020192018
Cash Received (Paid) in Settlement of Commodity Derivative Instruments:
  Natural Gas:
   Commodity Swaps$390,547 $82,899 $(41,098)
    Basis Swaps70,670 (13,119)(28,622)
Total Cash Received (Paid) in Settlement of Commodity Derivative Instruments461,217 69,780 (69,720)
Unrealized (Loss) Gain on Commodity Derivative Instruments:
 Natural Gas:
    Commodity Swaps(407,308)406,472 33,026 
    Basis Swaps119,073 (100,147)6,482 
Total Unrealized (Loss) Gain on Commodity Derivative Instruments(288,235)306,325 39,508 
Gain (Loss) on Commodity Derivative Instruments:
  Natural Gas:
    Commodity Swaps(16,761)489,371 (8,072)
    Basis Swaps189,743 (113,266)(22,140)
Total Gain (Loss) on Commodity Derivative Instruments$172,982 $376,105 $(30,212)

The effect of interest rate swaps on Interest Expense in the Company's Consolidated Statements of Income was as follows:
For the Years Ended December 31,
20202019
Cash (Paid) Received in Settlement of Interest Rate Swaps$(3,141)$223 
Unrealized Loss on Interest Rate Swaps(13,051)(1,219)
Loss on Interest Rate Swaps$(16,192)$(996)

Cash Received (Paid) in Settlement of Commodity Derivative Instruments for the year ended December 31, 2020 includes $54,982 related to the monetization of certain NYMEX commodity swaps. The monetization resulted from reducing the contract swap prices of certain 2022, 2023 and 2024 NYMEX natural gas swap contracts. The notional quantities of the contracts were not changed by this monetization. Net proceeds received from the monetization are classified as operating cash flows in the Consolidated Statements of Cash Flows.
    
The Company also enters into fixed price natural gas sales agreements that are satisfied by physical delivery. These physical commodity contracts qualify for the normal purchases and normal sales exception and are not subject to derivative instrument accounting.
v3.20.4
Commitments and Contingent Liabilities
 12 Months Ended
Dec. 31, 2020
Commitments and Contingencies Disclosure [Abstract]  
Commitments and Contingent Liabilities COMMITMENTS AND CONTINGENT LIABILITIES:
CNX and its subsidiaries are subject to various lawsuits and claims with respect to such matters as personal injury, royalty accounting, damage to property, climate change, governmental regulations including environmental violations and remediation, employment and contract disputes and other claims and actions arising out of the normal course of business. CNX accrues the estimated loss for these lawsuits and claims when the loss is probable and can be estimated. The Company's current estimated accruals related to these pending claims, individually and in the aggregate, are immaterial to the financial position, results of operations or cash flows of CNX. It is possible that the aggregate loss in the future with respect to these lawsuits and claims could ultimately be material to the financial position, results of operations or cash flows of CNX; however, such amounts cannot be reasonably estimated.
The 1992 Coal Industry Retiree Health Benefit Act (“Coal Act”), in Section 9711, requires coal companies that were providing health benefits to United Mine Workers of America (“UMWA”) retirees as of February 1993 to continue providing health benefits to such individuals, in substantially the same coverages, for as long as the last signatory operator remains in
business. Section 9711 also requires any “related person” to be joint and severally liable for the provision of these health benefits. On May 1, 2020, the court in the Murray Energy Corporation (“Murray”) bankruptcy proceedings approved a settlement agreement between Murray and the UMWA that transferred to the UMWA 1992 Benefit Plan the Coal Act liabilities for retirees in Murray’s Section 9711 plan. The retirees transferred by Murray to the 1992 Benefit Plan include approximately 2,159 retirees allegedly traced to the December 2013 sale by CONSOL Energy Inc. to Murray Energy of the following possible last signatory operators: Consolidation Coal Company, McElroy Coal Company, Southern Ohio Coal Company, Central Ohio Coal Company, Keystone Coal Mining Corp., and Eight-Four Coal Mining Company (the “Sold Subsidiaries”). On May 2, 2020, the Trustees of the UMWA 1992 Benefit Plan sued CNX and CONSOL Energy Inc. (“CONSOL”) in federal court contending that the Sold Subsidiaries were last signatory operators and that CNX and CONSOL are related persons to the Sold Subsidiaries and, as such, CNX and CONSOL are jointly and severally liable for the Coal Act health benefits allegedly owed to the eligible retirees traced to the Sold Subsidiaries. The 1992 Plan seeks, among other relief, a declaration that CNX and CONSOL are obligated to enroll the eligible retirees attributed to the Sold Subsidiaries in a Section 9711 Plan; that CNX and CONSOL are liable to post the security required by Section 9712; and, that CNX and CONSOL are liable to pay per beneficiary premiums until the eligible retirees are enrolled in a Section 9711 plan, and other fees, costs and disbursements under the Coal Act. We disagree with the suit filed by the UMWA 1992 Plan, have filed a Motion to Dismiss and intend to defend this action. Further, under the Separation and Distribution Agreement that was entered into at the time we spun-out our coal business in 2017, CONSOL agreed to indemnify CNX for all coal-related liabilities, including this lawsuit. With respect to this matter although a loss is possible, it is not probable, and accordingly no accrual has been recognized.

At December 31, 2020, CNX has provided the following financial guarantees, unconditional purchase obligations, and letters of credit to certain third-parties as described by major category in the following tables. These amounts represent the maximum potential of total future payments that the Company could be required to make under these instruments. These amounts have not been reduced for potential recoveries under recourse or collateralization provisions. Generally, recoveries under reclamation bonds would be limited to the extent of the work performed at the time of the default. No amounts related to these unconditional purchase obligations and letters of credit are recorded as liabilities in the financial statements. CNX management believes that the commitments in the following table will expire without being funded, and therefore will not have a material adverse effect on financial condition.

 Amount of Commitment Expiration Per Period
 Total
Amounts
Committed		Less Than
1  Year		1-3 Years3-5 YearsBeyond
5  Years
Letters of Credit:
Firm Transportation$178,352 $178,352 $— $— $— 
Other6,950 6,950 — — — 
Total Letters of Credit185,302 185,302 — — — 
Surety Bonds:
Employee-Related2,600 2,600 — — — 
Environmental12,447 12,187 260 — — 
Financial Guarantees81,670 81,670 — — — 
Other9,183 7,899 1,284 — — 
Total Surety Bonds105,900 104,356 1,544 — — 
Total Commitments$291,202 $289,658 $1,544 $— $— 

Excluded from the above table are commitments and guarantees entered into in conjunction with the spin-off of the Company's coal business in November 2017. Although CONSOL Energy has agreed to indemnify CNX to the extent that CNX would be called upon to pay any of these liabilities, there is no assurance that CONSOL Energy will satisfy its obligations to indemnify CNX in the event that CNX is so called upon (See “Item 1A. Risk Factors” in this Form 10-K).

CNX enters into long-term unconditional purchase obligations to procure major equipment purchases, natural gas firm transportation, gas drilling services and other operating goods and services. These purchase obligations are not recorded in the Consolidated Balance Sheets.
As of December 31, 2020, the purchase obligations for each of the next five years and beyond were as follows:
Obligations DueAmount
Less than 1 year$253,692 
1 - 3 years431,282 
3 - 5 years390,693 
More than 5 years985,201 
Total Purchase Obligations$2,060,868 
v3.20.4
Segment Information
 12 Months Ended
Dec. 31, 2020
Segment Reporting [Abstract]  
Segment Information SEGMENT INFORMATION:
The Company reports segment information based on the “management” approach. The management approach designates the internal reporting used by management for making decisions and assessing performance as the source of the Company’s reportable segments.

The Company evaluates the performance of its reportable segments based on total revenue and other operating income, and operating expenses directly attributable to that segment. Certain expenses are managed outside the reportable segments and therefore are not allocated. These expenses include, but are not limited to, interest expense, impairment of exploration and production properties, impairment of goodwill and other corporate expenses such as selling, general and administrative costs.
CNX's principal activity is to produce pipeline quality natural gas for sale primarily to gas wholesalers and the Company has two reportable segments that conducts those operations: Shale and Coalbed Methane. The Other Segment includes nominal shallow oil and gas production which is not significant to the Company. It also includes the Company's purchased gas activities, unrealized gain or loss on commodity derivative instruments, realized gain on commodity derivative instruments that were monetized prior to their settlement dates, exploration and production related other costs, impairments of exploration and production properties, as well as various other expenses that are managed outside the reportable segments as discussed above. Operating profit for each segment is based on sales less identifiable operating and non-operating expenses.
Prior to the Merger of CNXM that occurred in September 2020 (See Note 4 - Acquisitions and Dispositions), CNX consisted of two principal business divisions: Exploration and Production (E&P) and Midstream. The E&P Division included four reportable segments, Marcellus Shale, Utica Shale, Coalbed Methane and Other Gas. Certain reclassifications of 2019 and 2018 segment information have been made to conform to the 2020 presentation.
Industry segment results for the year ended December 31, 2020 are:
ShaleCoalbed
Methane		OtherConsolidated
Natural Gas, NGLs and Oil Revenue$781,038 $114,366 $1,341 $896,745 (A)
Purchased Gas Revenue— — 105,792 105,792 
Gain (Loss) on Commodity Derivative Instruments337,269 39,884 (204,171)172,982 (B)
Other Operating Income64,710 — 17,749 82,459 (C)
Total Revenue and Other Operating Income$1,183,017 $154,250 $(79,289)$1,257,978   
Total Operating Expense$709,036 $127,845 $860,863 $1,697,744 
Earnings (Loss) Before Income Tax$473,981 $26,405 $(1,103,217)$(602,831)
Segment Assets$6,068,933 $1,095,816 $877,015 $8,041,764 (D)
Depreciation, Depletion and Amortization
$416,441 $69,745 $15,635 $501,821   
Capital Expenditures$474,545 $9,789 $2,957 $487,291   

(A)     Included in Total Natural Gas, NGLs and Oil Revenue are sales of $167,390 to Direct Energy Business Marketing LLC, which comprises over 10% of revenue from contracts with external customers for the period.
(B)    Included in Other is a realized gain on commodity derivative instruments of $83,997 related to the monetization of hedges (see Note 19 - Derivative Instruments for more information).
(C)    Includes midstream revenue of $64,710 and equity in loss of unconsolidated affiliates of $688 for Shale and Other, respectively.
(D)    Includes investments in unconsolidated equity affiliates of $16,022 .
Industry segment results for the year ended December 31, 2019 are:
ShaleCoalbed
Methane		OtherConsolidated
Natural Gas, NGLs and Oil Revenue$1,199,276 $163,893 $1,156 $1,364,325 (E)
Purchased Gas Revenue— — 94,027 94,027 
Gain on Commodity Derivative Instruments
62,418 7,335 306,352 376,105   
Other Revenue and Operating Income74,314 — 13,678 87,992 (F)
Total Revenue and Other Operating Income$1,336,008 $171,228 $415,213 $1,922,449   
Total Operating Expense$787,488 $135,778 $813,207 $1,736,473 
Earnings (Loss) Before Income Tax$548,520 $35,450 $(524,286)$59,684 
Segment Assets$6,527,245 $1,222,005 $1,311,556 $9,060,806 (G)
Depreciation, Depletion and Amortization
$427,219 $73,189 $8,055 $508,463   
Capital Expenditures$1,175,091 $11,333 $6,175 $1,192,599 
(E)     Included in Total Natural Gas, NGLs and Oil Revenue are sales of $214,980 to Direct Energy Business Marketing LLC and $147,540 to NJR Energy Services Company, each of which comprises over 10% of revenue from contracts with external customers for the period.
(F)    Includes midstream revenue of $74,314 and equity in earnings of unconsolidated affiliates of $2,103 for Shale and Other, respectively.
(G)    Includes investments in unconsolidated equity affiliates of $16,710.

Industry segment results for the year ended December 31, 2018 are:
ShaleCoalbed
Methane		OtherConsolidated
Natural Gas, NGLs and Oil Revenue$1,349,196 $212,884 $15,857 $1,577,937 (H)
Purchased Gas Revenue— — 65,986 65,986 
(Loss) Gain on Commodity Derivative Instruments
(60,326)(8,768)38,882 (30,212)  
Other Revenue and Operating Income89,781 — 26,942 116,723 (I)
Total Revenue and Other Operating Income$1,378,651 $204,116 $147,667 $1,730,434   
Total Operating Expense$751,673 $154,121 $321,169 $1,226,963 
Earnings Before Income Tax$626,978 $49,995 $421,695 $1,098,668 
Segment Assets$6,268,113 $1,272,457 $1,051,600 $8,592,170 (J)
Depreciation, Depletion and Amortization
$404,503 $77,004 $11,916 $493,423   
Capital Expenditures$1,094,471 $17,083 $4,843 $1,116,397 
(H)    Included in Total Natural Gas, NGLs and Oil Revenue are sales of $219,472 to NJR Energy Services Company and $184,668 to Direct Energy Business Marketing LLC, each of which comprises over 10% of revenue from contracts with external customers for the period.
(I)    Includes midstream revenue of $89,781 and equity in earnings of unconsolidated affiliates of $5,363 for Shale and Other, respectively.
(J)    Includes investments in unconsolidated equity affiliates of $18,663.
Reconciliation of Segment Information to Consolidated Amounts:

Revenue and Other Operating Income:
For the Years Ended December 31,
202020192018
Total Segment Revenue from Contracts with External Customers$1,067,247 $1,532,666 $1,733,704 
Gain (Loss) on Commodity Derivative Instruments172,982 376,105 (30,212)
Other Operating Income17,749 13,678 26,942 
Total Consolidated Revenue and Other Operating Income
$1,257,978 $1,922,449 $1,730,434 
v3.20.4
Subsequent Event
 12 Months Ended
Dec. 31, 2020
Subsequent Events [Abstract]  
Subsequent Event SUBSEQUENT EVENTTO BE UPDATED IF ANY OCCUR
v3.20.4
Supplemental Gas Data (unaudited)
 12 Months Ended
Dec. 31, 2020
Extractive Industries [Abstract]  
Supplemental Gas Data (unaudited) SUPPLEMENTAL GAS DATA (unaudited):The following information was prepared in accordance with the FASB's Accounting Standards Update No. 2010-03, “Extractive Activities-Oil and Gas (Topic 932).” The supplementary information summarized below presents the results of natural gas and oil activities for the E&P segment in accordance with the successful efforts method of accounting for production activities.
Capitalized Costs:
As of December 31,
20202019
Intangible Drilling Costs$4,965,252 $4,688,497 
Gas Gathering Assets2,510,916 2,463,866 
Proved Gas Properties1,253,094 1,208,046 
Gas Wells and Related Equipment1,120,061 1,042,000 
Unproved Gas Properties725,705 755,590 
Other Gas Assets95,734 73,479 
Total Property, Plant and Equipment10,670,762 10,231,478 
Accumulated Depreciation, Depletion and Amortization(3,852,593)(3,317,442)
Net Capitalized Costs$6,818,169 $6,914,036 

Costs incurred for property acquisition, exploration and development (*):
For the Years Ended December 31,
202020192018
Property Acquisitions:
Proved Properties
$16,622 $36,710 $38,621 
Unproved Properties
8,060 24,760 36,248 
Development**432,438 1,063,945 986,419 
Exploration33,644 79,855 61,604 
Total$490,764 $1,205,270 $1,122,892 
__________
(*)    Includes costs incurred whether capitalized or expensed.
(**)    Includes development costs for midstream of $67 million, $325 million and $142 million for 2020, 2019 and 2018, respectively.

Results of Operations for Producing Activities:
For the Years Ended December 31,
202020192018
Natural Gas, NGLs and Oil Revenue$896,745 $1,364,325 $1,577,937 
Realized Gain (Loss) on Commodity Derivative Instruments 461,217 69,780 (69,720)
Unrealized (Loss) Gain on Commodity Derivative Instruments(288,235)306,325 39,508 
Purchased Gas Revenue105,792 94,027 65,986 
Total Revenue1,175,519 1,834,457 1,613,711 
Lease Operating Expense40,407 65,443 95,139 
Production, Ad Valorem and Other Fees24,196 27,461 32,750 
Transportation, Gathering and Compression285,683 330,539 302,933 
Purchased Gas Costs100,902 90,553 64,817 
Impairment of Exploration and Production Properties61,849 327,400 — 
Impairment of Undeveloped Properties— 119,429 — 
Exploration Costs14,994 44,380 12,033 
Depreciation, Depletion and Amortization501,821 508,463 493,423 
Total Costs1,029,852 1,513,668 1,001,095 
Pre-tax Operating Income145,667 320,789 612,616 
Income Tax Expense42,098 149,167 120,073 
Results of Operations for Producing Activities excluding Corporate and Interest Costs
$103,569 $171,622 $492,543 
The following is production, average sales price and average production costs, excluding ad valorem and severance taxes, per unit of production:
For the Years Ended December 31,
202020192018
Production (MMcfe)511,072 539,149 507,104 
Total Average Sales Price Before Effects of Commodity Derivative Financial Settlements (per Mcfe)$1.75 $2.53 $3.11 
Average Effects of Commodity Derivative Financial Settlements (per Mcfe)$0.74 $0.14 $(0.15)
Total Average Sales Price Including Effects of Commodity Derivative Financial Settlements (per Mcfe)
$2.49 $2.66 $2.97 
Average Lifting Costs, Excluding Ad Valorem and Severance Taxes (per Mcfe)$0.08 $0.12 $0.19 
During the years ended December 31, 2020, 2019 and 2018, the Company drilled 29.0, 75.7, and 83.9 net development wells, respectively. There were no net dry development wells in 2020 and 2018, and 1.0 net dry development well in 2019.
During the years ended December 31, 2020 and 2019, the Company drilled 2.0 and 5.0 net exploratory wells, respectively. During the year ended December 31, 2018, the Company drilled no net exploratory wells. There were no net dry exploratory wells in 2020, 2019 or 2018.
At December 31, 2020, there were 23.0 net development wells and 1.0 exploratory well that are drilled but uncompleted. Additionally, there are 2.0 net exploratory wells that have been completed and are awaiting final tie-in to production.
CNX is committed to provide 492.5 Bcf of gas under existing sales contracts or agreements over the course of the next four years. The Company expects to produce sufficient quantities from existing proved developed reserves to satisfy these commitments.
Most of the Company's development wells and proved acreage are located in Virginia, West Virginia, Ohio and Pennsylvania. Some leases are beyond their primary term, but these leases are extended in accordance with their terms as long as certain drilling commitments or other term commitments are satisfied.
The following table sets forth, at December 31, 2020, the number of producing wells, developed acreage and undeveloped acreage:
Gross(1)Net(2)
Producing Gas Wells (including Gob Wells) - Working Interest4,712 4,401 
Producing Oil Wells - Working Interest— — 
Producing Gas Wells - Royalty Interest1,810 — 
Producing Oil Wells - Royalty Interest152 — 
Acreage Position:
   Proved Developed Acreage351,537 351,537 
   Proved Undeveloped Acreage43,713 43,713 
   Unproved Acreage4,986,196 3,637,982 
Total Acreage5,381,446 4,033,232 
____________
(1)    All of our acreage identified as proved developed and undeveloped is controlled fully by CNX through ownership of a 100% working interest.
(2)    Net acres include acreage attributable to our working interests in the properties. Additional adjustments (either increases or decreases) may be required as we further develop title to and further confirm our rights with respect to our various properties in anticipation of development. We believe that our assumptions and methodology in this regard are reasonable.

Proved Oil and Gas Reserves Quantities:

Annually, the preparation of natural gas reserves estimates is completed in accordance with CNX prescribed internal control procedures, which include verification of input data into a gas reserves forecasting and economic evaluation software, as well as multi-functional management review. As part of the annual review, management reviews and approves changes in the
future development plan and the impact to proved-undeveloped locations to ensure that annual changes are aligned with the overall strategic business plan of the Company. A detailed review is completed to ensure that all proved undeveloped locations will be fully developed within five-years of the reserves booking. As part of the development plan review, management reviews current well production data, acreage position, downstream infrastructure availability, operational leases and other commitments, financial capacity to complete the development and individual project economics in expected future gas pricing scenarios. The input data verification includes reviews of the price and operating, and development cost assumptions as well as tax rates by jurisdiction used in the economic model to determine the reserves. Also, the production volumes are reconciled between the system used to calculate the reserves and other accounting/measurement systems. The technical employee responsible for overseeing the preparation of the reserve estimates is a registered professional engineer in the state of West Virginia with over 16 years of experience in the oil and gas industry. The Company's gas reserves results, which are reported in the Supplemental Gas Data for the year ended December 31, 2020 Form 10-K, were audited by independent petroleum engineers, Netherland, Sewell & Associates, Inc. The technical person primarily responsible for overseeing the audit of the Company's reserves is a registered professional engineer in the state of Texas with over 13 years of experience in the oil and gas industry.

The gas reserves estimates are as follows:
CondensateConsolidated
Natural GasNGLs& Crude OilOperations
(MMcf)(Mbbls)(Mbbls)(MMcfe)
Balance December 31, 2017 (a)7,121,758 71,691 4,950 7,581,612 
Revisions (b)313,091 441 865 320,925 
Price Changes28,100 32 4 28,315 
Extensions and Discoveries (c)839,268 16,247 4,010 960,808 
Production(468,228)(6,011)(468)(507,104)
Sales of Reserves In-Place (d)(715,088)(17,252)(1,100)(825,196)
Balance December 31, 2018 (a)7,436,338 65,904 8,261 7,881,335 
Revisions (e)(521,617)5,926 (5,418)(518,570)
Price Changes(40,773)(740)(5)(45,246)
Extensions and Discoveries (c)1,569,813 10,182 2,732 1,647,297 
Production(505,355)(5,428)(204)(539,149)
Balance December 31, 2019 (a)7,938,406 75,844 5,366 8,425,667 
Revisions (f)407,836 51,857 3,525 740,129 
Price Changes(1,019,523)(50,456)(4,946)(1,351,934)
Extensions and Discoveries (c)2,188,773 9,299 400 2,246,968 
Production(481,426)(4,677)(264)(511,072)
Balance December 31, 2020 (a)9,034,066 81,867 4,081 9,549,758 
Proved developed reserves:
December 31, 20184,242,579 40,180 1,870 4,494,878 
December 31, 20194,473,534 59,800 1,087 4,838,858 
December 31, 20204,939,283 42,204 1,207 5,199,748 
Proved undeveloped reserves:
December 31, 20183,193,759 25,724 6,391 3,386,457 
December 31, 20193,464,873 16,044 4,278 3,586,809 
December 31, 20204,094,783 39,664 2,874 4,350,010 
__________
(a)    Proved developed and proved undeveloped gas reserves are defined by SEC Rule 4.10(a) of Regulation S-X. Generally, these reserves would be commercially recovered under current economic conditions, operating methods and government regulations. CNX cautions that there are many inherent uncertainties in estimating proved reserve quantities, projecting future production rates and timing of development expenditures. Proved oil and gas reserves are estimated quantities of natural gas which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years
from known reservoirs under existing economic and operating conditions and government regulations. Proved developed reserves are reserves expected to be recovered through existing wells, with existing equipment and operating methods.
(b)    The upward revision for 2018 of 321 Bcfe is primarily due to a 472 Bcfe upward revision from increased performance through our continued focus on optimization. This is partially offset by a 151 Bcfe downward revision due to plan changes.
(c)    Extensions and Discoveries in 2018, 2019, and 2020 are due to the addition of wells on the Company's Shale acreage more than one offset location away with continued use of reliable technology. The Company uses reliable technologies when assigning reserves to undeveloped locations, including wire line open-hole log data, performance data, geological log cross sections, core data and statistical analysis. The statistical methods use production performance of analog wells and include data from operated and competitor wells. We also use geophysical data that includes data from our wells, published documents, state data-sits and data exchanges to confirm continuity of the formation. Total proved extensions and discoveries are a combination of proved developed and proved undeveloped reserves; and, extensions and discoveries for proven developed reserves are associated with non-operated assets and exploratory wells. In 2020 and 2019, the Company added 70 Bcfe and 77 Bcfe, respectively, related to exploratory and non-operated wells.
(d)    The sales of reserves in-place is related to the divestiture of our Utica JV assets and substantially all of our conventional properties. Refer to Note 4 - Acquisitions and Dispositions for more information.
(e)    The downward revisions in 2019 are due to changes in our five-year development plan due to increased dry gas investment which increased dry gas proved undeveloped reserves and decreased wet gas investment which lowered wet gas proved undeveloped reserves. The investment shift was a result of a significant decrease in forecasted liquids price realizations in the five-year plan. These five-year plan changes resulted in the removal of 872 Bcfe in reserves for wet gas investment. There was additionally a reduction of 304 Bcfe related to removal of proved undeveloped locations removed from our plans due to the SEC five-year development rule. These downward revisions were partially offset by efficiencies in operations investment in dry gas properties which increased reserves by 657 Bcfe.
(f)    Upward revisions in 2020 are due to performance revisions of 579 Bcfe related to production performance and an 853 Bcfe increase in reserves due to a decrease in operating costs in 2020. These upward revisions were partially offset by negative revisions of 677 Bcfe due to changes in our development plan related to the removal of four Utica wells and 23 Marcellus wells from our development plan.
For the Year
Ended
December 31,
2020
Proved Undeveloped Reserves (MMcfe)
Beginning Proved Undeveloped Reserves3,586,809 
Undeveloped Reserves Transferred to Developed (a)(1,152,598)
Price Revisions(380,200)
Revisions Due to Plan Changes (b)(691,054)
Revisions Due to Changes Due to Well Performance (c)810,727 
Extension and Discoveries (d)2,176,326 
Ending Proved Undeveloped Reserves(e)4,350,010 
_________
(a)    During 2020, various exploration and development drilling and evaluations were completed. Approximately, $257,952 of capital was spent in the year ended December 31, 2020 related to undeveloped reserves that were transferred to developed.
(b) The downward revisions for 2020 plan changes is due to the removal of 88 Bcfe of reserves related to 4 Utica wells and 579 Bcfe of reserves related to 23 Marcellus wells which were removed from our development plan.
(c)    The upward revisions due to a 342 Bcfe increase in reserves of liquids rich Marcellus production which requires processing due to a reduction in the Company's operating costs as a result of the CNXM take-in transaction completed in 2020. The remaining portion is due to production performance.
(d)    Extensions and discoveries are due mainly to the addition of 1,465 Bcfe related to 47 net Marcellus wells within our Southwest Pennsylvania and West Virginia dry gas operations and 711 Bcfe of 23 net Utica wells within our Central Pennsylvania and Southwest Pennsylvania operations. The Company uses reliable technologies when assigning reserves to undeveloped locations, including wire line open-hole log data, performance data, geological log cross sections, core data and statistical analysis. The statistical methods use production performance of analog wells and include data from operated and competitor wells. We also use geophysical data that includes data from our wells, published documents, state data-sites and data exchanges to confirm continuity of the formation.
(e)    Included in proved undeveloped reserves at December 31, 2020 are approximately 320,987 MMcfe of reserves that have been reported for more than five years. These reserves are all attributable to acreage within the current operating plan
identified by the life-of-mine timing maps for the Buchanan mine. The annual increase in proved undeveloped gob reserves is a result of a change in planned mining activity, which includes an expanded mining footprint, partially offset by the conversion to proved developed gob reserves. These reserves specifically relate to GOB (a rubble zone formed in the cavity created by the extraction of coal) production due to a complex fracture being generated in the overburden strata above the mined seam. Mining operations take a significant amount of time and our GOB forecasts are consistent with the future plans of the Buchanan Mine that was sold in March 2016 to Coronado IV LLC with the rights to this gas being retained by the Company. Evidence also exists that supports the continual operation of the mine beyond the current plan, unless there was an extreme circumstance resulting from an external factor. These reasons constitute the specific circumstances that exist to continue recognizing these reserves for CNX.
The following table indicates the changes to the Company's suspended exploratory well costs for the three years ended December 31, 2020:
202020192018
Balance, Beginning of Period$8,984 $8,178 $6,388 
Additions to Capitalized Exploratory Well Costs Pending the Determination of Proved Reserves28,336 66,409 49,213 
Reclassifications to Wells, Facilities and Equipment Based on the Determination of Proved Reserves(28,258)(65,603)(46,614)
Capitalized Exploratory Well Costs Charged to Expense— — (809)
Balance, End of Period$9,062 $8,984 $8,178 
At December 31, 2020 there was one well pending the determination of proved reserves. The $9,062 of exploratory well costs capitalized for more than one year is related to one partially constructed well that the Company is currently evaluating to determine the most economic approach to access the natural gas reserves. The company expects to make a determination in 2021 to either finalize the well or to access the natural gas reserves from an alternative location.
CNX proved natural gas reserves are located in the United States.
Standardized Measure of Discounted Future Net Cash Flows:
The following information has been prepared in accordance with the provisions of the Financial Accounting Standards Board's Accounting Standards Update No. 2010-03, “Extractive Activities-Oil and Gas (Topic 932).” This topic requires the standardized measure of discounted future net cash flows to be based on the average, first-day-of-the-month price for the year. Because prices used in the calculation are average prices for that year, the standardized measure could vary significantly from year to year based on the market conditions that occurred.
The projections should not be viewed as realistic estimates of future cash flows, nor should the “standardized measure” be interpreted as representing current value to CNX. Material revisions to estimates of proved reserves may occur in the future; development and production of the reserves may not occur in the periods assumed; actual prices realized are expected to vary significantly from those used; and actual costs may vary. CNX investment and operating decisions are not based on the information presented, but on a wide range of reserve estimates that include probable as well as proved reserves and on different price and cost assumptions.
The standardized measure is intended to provide a better means for comparing the value of CNX proved reserves at a given time with those of other gas producing companies than is provided by a comparison of raw proved reserve quantities.
December 31,
202020192018
Future Cash Flows (a)
Revenues
$16,577,563 $19,489,588 $26,610,100 
Production Costs
(6,071,763)(7,903,120)(7,730,451)
Development Costs (b)(1,957,519)(1,121,073)(1,600,128)
Income Tax Expense
(2,235,205)(2,720,994)(4,147,075)
Future Net Cash Flows6,313,076 7,744,401 13,132,446 
Discounted to Present Value at a 10% Annual Rate(3,677,340)(4,673,932)(8,476,989)
Total Standardized Measure of Discounted Net Cash Flows$2,635,736 $3,070,469 $4,655,457 
_________
(a)    For 2020, the reserves were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2020, adjusted for energy content and a regional price differential. For 2020, this adjusted natural gas price was $1.70 per Mcf, the adjusted oil price was $35.61 per barrel and the adjusted NGL price was $13.18 per barrel. In 2020, as the result of the CNXM take-in transaction (see Note 4 - Acquisitions and Dispositions), there was a change in production costs and development costs. Historically the production costs included contractual CNXM rates but in 2020 this was replaced with actual operating costs of the midstream infrastructure. Additionally, our development costs in 2020 include capital related to connecting undeveloped Shale wells to the midstream gathering systems; in prior years this was captured within the CNXM contractual rate within production costs. These changes resulted in an increase of $932 million to the current year Standardized Measure of Discounted Net Cash Flows.
(b)    Development costs for 2020 include $402,174 of plugging and abandonment costs and $286,724 of Midstream capital on an undiscounted pre-tax basis. On a PV-10 pre-tax discounted basis, these amounts equate to $18,357 and $231,512, respectively. The addition of Midstream capital is the result of the Merger that occurred on September 28, 2020 (See Note 4 - Acquisitions and Dispositions).

    For 2019, the reserves were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2019, adjusted for energy content and a regional price differential. For 2019, this adjusted natural gas price was $2.24 per Mcf, the adjusted oil price was $44.31 per barrel and the adjusted NGL price was $19.10 per barrel.

    For 2018, the reserves were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2018, adjusted for energy content and a regional price differential. For 2018, this adjusted natural gas price was $3.28 per Mcf, the adjusted oil price was $51.68 per barrel and the adjusted NGL price was $27.58 per barrel.
The following are the principal sources of change in the standardized measure of discounted future net cash flows for consolidated operations during:
December 31,
202020192018
Balance at Beginning of Period$3,070,469 $4,655,457 $3,131,398 
Net Changes in Sales Prices and Production Costs(819,247)(2,826,725)1,732,229 
Sales Net of Production Costs(719,441)(1,130,685)(995,630)
Net Change Due to Revisions in Quantity Estimates322,820 (252,796)307,030 
Net Change Due to Extensions, Discoveries and Improved Recovery268,196 654,027 534,052 
Development Costs Incurred During the Period434,273 739,874 844,081 
Difference in Previously Estimated Development Costs Compared to Actual Costs Incurred During the Period
(129,642)(323,922)(434,817)
Purchase of Reserves In-Place— — 209,630 
Sales of Reserves In-Place— — (434,103)
Changes in Estimated Future Development Costs(499,316)(24,469)(49,294)
Net Change in Future Income Taxes138,404 409,797 (507,410)
Timing and Other390,391 586,591 (69,087)
Accretion178,829 583,320 387,378 
     Total Discounted Cash Flow at End of Period$2,635,736 $3,070,469 $4,655,457 
v3.20.4
Supplemental Quarterly Information (unaudited)
 12 Months Ended
Dec. 31, 2020
Quarterly Financial Information Disclosure [Abstract]  
Supplemental Quarterly Information (unaudited)
Supplemental Quarterly Information (unaudited):
(Dollars in thousands, except per share data)
Three Months Ended
March 31,June 30,September 30,December 31,
2020202020202020
Revenue (a)$411,401 $145,088 $61,609 $622,131 
Expenses (b)$149,004 $125,548 $142,327 $134,775 
Net (Loss) Income (c)$(305,222)$(130,487)$(188,793)$195,758 
Net (Loss) Income Attributable to CNX Resources Shareholders$(329,086)$(145,749)$(204,698)$195,758 
(Loss) Earnings Per Share:
Basic (Loss) Earnings Per Share$(1.76)$(0.78)$(1.03)$0.88 
Diluted (Loss) Earnings Per Share$(1.76)$(0.78)$(1.03)$0.87 

Three Months Ended
March 31,June 30,September 30,December 31,
2019201920192019
Revenue (a)$275,234 $602,109 $526,681 $504,747 
Expenses (b)$147,928 $153,835 $153,833 $182,035 
Net (Loss) Income (c)$(64,651)$192,694 $143,960 $(240,055)
Net (Loss) Income Attributable to CNX Resources Shareholders$(87,337)$162,477 $115,538 $(271,408)
(Loss) Earnings Per Share:
Basic (Loss) Earnings Per Share$(0.44)$0.85 $0.62 $(1.45)
Diluted (Loss) Earnings Per Share$(0.44)$0.84 $0.61 $(1.45)
_________
(a) Includes natural gas, NGLs, and oil revenue; gain (loss) on commodity derivative instruments, purchased gas revenue and midstream revenue.
(b) Includes exploration and production costs and other operating expense; excludes depreciation, depletion and amortization, impairment charges, selling, general and administrative, gain (loss) on debt extinguishment, interest expense and other expense.
(c) Includes impairment charges of $61,849 and $473,045 that were recorded during the three months ended March 31, 2020 related to CNX's exploration and production properties and goodwill, respectively, and $327,400 and $119,429 that were recorded during the three months ended December 31, 2019 related to CNX's exploration and production properties and unproved properties, respectively. See Note 1 - Significant Accounting Policies in Item 8 of this Form 10-K for additional information.
v3.20.4
Schedule II - Valuation and Qualifying Accounts
 12 Months Ended
Dec. 31, 2020
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]  
Schedule II - Valuation and Qualifying Accounts
CNX RESOURCES CORPORATION AND SUBSIDIARIES
Valuation and Qualifying Accounts
(Dollars in thousands)

AdditionsDeductions
Balance atRelease ofBalance at
BeginningCharged toValuationCharged toEnd
of PeriodExpenseAllowanceExpenseof Period
Year Ended December 31, 2020
State Operating Loss Carry-Forwards$81,202 $— $(2,004)$— $79,198 
Charitable Contributions658 48 — — 706 
Foreign Tax Credits43,194 — — — 43,194 
            Total$125,054 $48 $(2,004)$— $123,098 
Year Ended December 31, 2019
State Operating Loss Carry-Forwards$47,964 $33,238 $— $— $81,202 
Charitable Contributions3,297 — (2,639)— 658 
Foreign Tax Credits43,194 — — — 43,194 
            Total$94,455 $33,238 $(2,639)$— $125,054 
Year Ended December 31, 2018
State Operating Loss Carry-Forwards$61,560 $— $(13,596)$— $47,964 
Deferred Deductible Temporary Differences9,088 — (9,088)— — 
Charitable Contributions3,156 141 — — 3,297 
162(m) Officers Compensation5,957 — (5,957)— — 
AMT Credit12,413 1,983 (14,396)— — 
Foreign Tax Credits44,402 — (1,208)— 43,194 
            Total$136,576 $2,124 $(44,245)$— $94,455 
v3.20.4
Significant Accounting Policies (Policies)
 12 Months Ended
Dec. 31, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]  
Basis of Consolidation
Basis of Consolidation:

The Consolidated Financial Statements include the accounts of CNX Resources Corporation, its wholly-owned subsidiaries, and its majority-owned and/or controlled subsidiaries. Investments in business entities in which CNX does not have control but has the ability to exercise significant influence over the operating and financial policies, are accounted for under the equity method. All significant intercompany transactions and accounts have been eliminated in consolidation. Investments in oil and natural gas producing entities are accounted for under the proportionate consolidation method.
Prior to the Merger on September 28, 2020, see Note 4 - Acquisitions and Dispositions, certain variable interest entities were required to be consolidated pursuant to the Consolidation topic of the Financial Accounting Standards Board (FASB) Accounting Standards Codification. The portion of these entities that was not owned by the Company was presented as non-controlling interest.
Use of Estimates Use of Estimates: The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, as well as various disclosures. Actual results could differ from those estimates. The most significant estimates included in, but not limited to, the preparation of the consolidated financial statements are related to long-lived assets (including intangible assets and goodwill), accounts receivable credit losses, the values of natural gas, NGLs, condensate and oil (collectively "natural gas") reserves, asset retirement obligations, deferred income tax assets and liabilities, contingencies, fair value of derivative instruments, the fair value of the liability and equity components of the convertible senior notes, stock-based compensation and salary retirement benefits.
Cash, Cash Equivalents, and Restricted Cash
Cash, Cash Equivalents, and Restricted Cash
Cash and cash equivalents include cash on hand and on deposit at banking institutions as well as all highly liquid short-term securities with original maturities of three months or less.
Restricted cash consists of cash that the Company is contractually obligated to maintain in accordance with the terms of the Cardinal States Gathering LLC and CSG Holdings II LLC Credit Agreements, each dated March 13, 2020 (See Note 12 - Long-Term Debt for more information).
Trade Accounts Receivable and Allowance for Credit Losses
Trade Accounts Receivable and Allowance for Credit Losses:
Trade accounts receivable are recorded at the invoiced amount and do not bear interest.
On January 1, 2020, CNX adopted Accounting Standards Update (ASU) 2016-13 Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, which replaces the incurred loss impairment methodology with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. The measurement of expected credit losses is based on relevant information about past events, including historical experience, current conditions, and reasonable and supportable forecasts that affect the collectability of the reported amount. CNX adopted Topic 326 using the prospective transition method.

Prior to adopting Topic 326, CNX reserved for specific accounts receivable when it was probable that all or a part of an outstanding balance would not be collected, such as customer bankruptcies. Collectability was determined based on terms of sale, credit status of customers and various other circumstances. CNX regularly reviewed collectability and established or adjusted the allowance as necessary using the specific identification method. Account balances were charged off against the allowance after all means of collection had been exhausted and the potential for recovery was considered remote. Reserves for uncollectible amounts were not material in the periods presented.
Under Topic 326, management records an allowance for credit losses related to the collectability of third-party customers' receivables using the historical aging of the customer receivable balance. The collectability is determined based on past events, including historical experience, customer credit rating, as well as current market conditions. CNX monitors customer ratings and collectability on an on-going basis. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote.
There were no material financing receivables with a contractual maturity greater than one year at December 31, 2020 or 2019.
Inventories Inventories: Inventories are stated at the lower of cost or net realizable value. The cost of supplies inventory is determined by the average cost method and includes operating and maintenance supplies to be used in the Company's operations.
Property, Plant and Equipment
Property, Plant and Equipment:

CNX uses the successful efforts method of accounting for natural gas producing activities. Costs of property acquisitions, successful exploratory, development wells and related support equipment and facilities are capitalized. Periodic valuation provisions for impairment of capitalized costs of unproved mineral interests are expensed. Costs of unsuccessful exploratory wells are expensed when such wells are determined to be non-productive, or if the determination cannot be made after finding sufficient quantities of reserves to continue evaluating the viability of the project. The costs of producing properties and mineral
interests are amortized using the units-of-production method. Depreciation, depletion and amortization expense is calculated based on the actual produced sales volumes multiplied by the applicable rate per unit, which is derived by dividing the net capitalized costs by the number of units expected to be produced over the life of the reserves. Wells and related equipment and intangible drilling costs are also amortized on a units-of-production method. Proved developed reserves, as estimated by petroleum engineers, are used to calculate amortization of wells and related equipment and facilities and amortization of intangible drilling costs. Total proved reserves, also estimated by petroleum engineers, are used to calculate depletion on property acquisitions. Proved oil and natural gas reserve estimates are based on geological and engineering evaluations of in-place hydrocarbon volumes. Units-of-production amortization rates are revised at least once per year, or more frequently if events and circumstances indicate an adjustment is necessary. Such revisions are accounted for prospectively as changes in accounting estimates. The Company recorded depreciation, depletion and amortization expense related to proved gas properties using the units-of-production method of $400,758, $423,488, and $412,588 for the years ended December 31, 2020, 2019, and 2018, respectively.

Property, plant and equipment is recorded at cost upon acquisition. Expenditures which extend the useful lives of existing plant and equipment are capitalized. Interest costs applicable to major asset additions are capitalized during the construction period. Planned major maintenance costs which do not extend the useful lives of existing plant and equipment are expensed as incurred.

Depreciation of plant and equipment is calculated on the straight-line method over their estimated useful lives or lease terms, generally as follows:
Years
Buildings and Improvements
10 to 45
Machinery and Equipment
3 to 25
Gathering and Transmission
30 to 40
Leasehold ImprovementsLife of Lease
Costs for purchased software are capitalized and amortized using the straight-line method over the estimated useful life which does not exceed seven years.
Impairment of Long-Lived Assets Impairment of Long-Lived Assets: Impairment of long-lived assets is recorded when indicators of impairment are present and the undiscounted cash flows estimated to be generated by those assets are less than the assets' carrying value. The carrying value of the assets is then reduced to its estimated fair value which is usually measured based on an estimate of future discounted cash flows. Impairment of equity investments is recorded when indicators of impairment are present, and the estimated fair value of the investment is less than the assets' carrying value.
Impairment of Proved and Unproved Properties
Impairment of Proved Properties:

CNX performs a quantitative impairment test whenever events or changes in circumstances indicate that an asset group's carrying amount may not be recoverable, over proved properties using the published NYMEX forward prices, timing, methods and other assumptions consistent with historical periods. When indicators of impairment are present, tests require that the Company first compare expected future undiscounted cash flows by asset group to their respective carrying values. If the carrying amount exceeds the estimated undiscounted future cash flows, a reduction of the carrying amount of the natural gas properties to their estimated fair values is required, which is determined based on discounted cash flow techniques using significant assumptions including projected revenues, future commodity prices and a market-specific weighted average cost of capital which are affected by expectations about future market and economic conditions. 

During the year ended December 31, 2020, CNX recognized certain indicators of impairments specific to our Southwest Pennsylvania Coalbed Methane asset group and determined that the carrying value of that asset group was not recoverable. The fair value of the asset group was estimated by using level 3 inputs which consisted of discounting the estimated future cash flows using discount rates and other assumptions that market participants would use in their estimates of fair value. As a result, an impairment of $61,849 was recognized and is included in Impairment of Exploration and Production Properties in the Consolidated Statements of Income. The impairment was related to an economic decision to temporarily idle certain wells and the related processing facility during the first quarter.
During the fourth quarter of 2019, CNX identified certain indicators of impairment specific to our Central Pennsylvania Marcellus asset group and determined that the carrying value of that asset group was not recoverable. The fair value of the asset group was estimated by using level 3 inputs which consisted of discounting the estimated future cash flows using discount rates and other assumptions that market participants would use in their estimates of fair value. As a result, an impairment of $327,400 was included in Impairment of Exploration and Production Properties in the Consolidated Statements of Income. This impairment was related to 56 operated wells and approximately 51,000 acres within our Central Pennsylvania Marcellus proved properties in Armstrong, Indiana, Jefferson and Westmoreland counties. The majority of these properties were developed prior to 2013 and the last of these properties were developed in 2015.
Impairment of Unproved Properties:
Capitalized costs of unproved oil and gas properties are evaluated at least annually for recoverability on a prospective basis. Indicators of potential impairment include, but are not limited to, changes brought about by economic factors, commodity price outlooks, our geologists’ evaluation of the property, favorable or unfavorable activity on the property being evaluated and/or adjacent properties, potential shifts in business strategy employed by management and historical experience. The likelihood of an impairment of unproved oil and gas properties increases as the expiration of a lease term approaches if drilling activity has not commenced. If it is determined that the Company does not intend to drill on the property prior to expiration or does not have the intent and ability to extend, renew, trade, or sell the lease prior to expiration, an impairment expense is recorded. Expense for lease expirations that were not previously impaired are recorded as the leases expire.
Impairment of Goodwill and Definite-Lived Intangible Assets
Impairment of Goodwill:

In connection with the Midstream Acquisition (See Note 4 - Acquisitions and Dispositions for more information), CNX recorded $796,359 of goodwill through the application of purchase accounting. The goodwill recorded was allocated in its entirety to the Midstream reporting unit within the Shale segment.

Goodwill is the cost of an acquisition less the fair value of the identifiable net assets of the acquired business. Goodwill is not amortized, but rather it is evaluated for impairment annually during the fourth quarter, or more frequently if recent events or prevailing conditions indicate it is more likely than not that the fair value of a reporting unit is less than its carrying value. These indicators include, but are not limited to, overall financial performance, industry and market considerations, anticipated future cash flows and discount rates, changes in the stock price with regards to CNX, regulatory and legal developments, and other relevant factors.

In connection with the annual evaluation of goodwill for impairment or earlier if an impairment indicator is identified, CNX may first consider qualitative factors to assess whether there are indicators that it is more likely than not that the fair value of a reporting unit may not exceed its carrying amount. If after assessing such factors or circumstances, CNX determines it is more likely than not that the fair value of a reporting unit is greater than its carrying amount, then a quantitative assessment is not required. If CNX chooses to bypass the qualitative assessment, or if it chooses to perform a qualitative assessment but is unable to qualitatively conclude that no impairment has occurred, then CNX will perform a quantitative assessment. In the case of a quantitative assessment, CNX estimates the fair value of the reporting unit with which the goodwill is associated using level 3 inputs and compares it to the carrying value. If the estimated fair value of a reporting unit is less than its carrying value, an impairment charge is recognized for the excess of the reporting unit's carrying value over its fair value. The Company uses a combination of the income approach (generally a discounted cash flow method) and market approach (which may include the guideline public company method and/or the guideline transaction method) to estimate the fair value of a reporting unit.

The income approach is used to estimate value based on the present value of future economic benefits that are expected to be produced by an asset or business entity. This approach generally involves two general steps:

(i) The first step involves establishing a forecast of the estimated future net cash flows expected to accrue directly or indirectly to the owner of the asset over its remaining useful life or to the owner of the business entity (including a
reporting unit).
(ii) The second step involves discounting these estimated future net cash flows to their present value using a market rate of return.

CNX determined the fair value based on estimated future revenues and earnings before deducting net interest expense (interest expense less interest income) and income taxes (EBITDA - a non-GAAP financial measure), and also included estimates for capital expenditures, discounted to present value using an industry rate adjusted for company-specific risk, which management feels reflects the overall level of inherent risk of the reporting unit. These assumptions are affected by expectations about future market, industry and economic conditions. Cash flow projections were derived from board approved budgeted amounts, a seven-year operating forecast and an estimate of future cash flows. Subsequent cash flows were developed using growth or contraction rates that management believes are reasonably likely to occur.

The estimates of future cash flows and EBITDA are subjective in nature and are subject to impacts from business risks as described in Item 1A. Risk Factors of this Form 10-K. The fair value estimation process requires considerable judgment and determining the fair value is sensitive to changes in assumptions impacting management’s estimates of future financial results. Although CNX believes the estimates and assumptions used in estimating the fair value are reasonable and appropriate, different assumptions and estimates could materially impact the estimated fair value. Future results could differ from our current estimates and assumptions.

In connection with CNX's assessment of goodwill in the first quarter of 2020 in relation to the deteriorating macroeconomic conditions, and the decline in the observable market value of CNXM securities both in relation to the COVID-19 pandemic and the overall decline in the master limited partnership (MLP) market space, an impairment indicator was identified. CNX bypassed the qualitative assessment and performed a quantitative test that utilized a combination of the income and market approaches to estimate the fair value of the Midstream reporting unit. As a result of this assessment, CNX concluded that the carrying value exceed its estimated fair value, and as a result, an impairment of $473,045 was included in Impairment of Goodwill in the Consolidated Statements of Income.

In connection with our annual assessment of goodwill in the fourth quarter of 2020, we bypassed the qualitative assessment and performed a quantitative test that utilized a combination of the income and market approaches to estimate the fair value of the Midstream reporting unit. As a result of this assessment, we concluded that the estimated fair value exceeded carrying value, and accordingly no adjustment to goodwill was necessary. However, the margin by which the fair value of the Midstream reporting unit exceeded its carrying value was less than 10%. As a result, this reporting unit is susceptible to impairment risk from further adverse macroeconomic conditions or other adverse factors such as future gathering volumes being less than those currently estimated. Any such adverse changes in the future could reduce the underlying cash flows used to estimate fair values and could result in a decline in fair value that could trigger future impairment charges relating to the Midstream reporting unit.

Impairment of Definite-Lived Intangible Assets:

Definite-lived intangible assets are amortized on a straight-line basis over their estimated economic lives and they are reviewed for impairment when indicators of impairment are present.

In connection with the Midstream Acquisition (See Note 4 - Acquisitions and Dispositions for more information), CNX recorded $128,781 of other intangible assets, which are comprised of customer relationships, through the application of purchase accounting.

In May 2018, CNX determined that the carrying value of a portion of the customer relationship intangible assets that were acquired in connection with the Midstream acquisition exceeded their fair value in conjunction with the Asset Exchange Agreement with HG Energy II Appalachia, LLC (See Note 4 - Acquisitions and Dispositions for more information). CNX recognized an impairment on this intangible asset of $18,650, which is included in Impairment of Other Intangible Assets in the Consolidated Statements of Income.

The customer relationships intangible asset is amortized on a straight-line basis over approximately 17 years.
Income Taxes
Income Taxes:
Deferred tax assets and liabilities are recognized for the expected future tax consequences of events that have been recognized in the Company's financial statements or tax returns. The provision for income taxes represents income taxes paid or
payable for the current year and the change in deferred taxes, excluding the effects of acquisitions during the year. Deferred taxes result from differences between the financial and tax bases of the Company's assets and liabilities and are adjusted for changes in tax rates and tax laws when changes are enacted. Valuation allowances are recorded to reduce deferred tax assets when it is more likely than not that a deferred tax benefit will not be realized. CNX evaluates all tax positions taken on the state and federal tax filings to determine if the position is more likely than not to be sustained upon examination. For positions that do not meet the more likely than not to be sustained criteria, the Company determines, on a cumulative probability basis, the largest amount of benefit that is more likely than not to be realized upon ultimate settlement. A previously recognized tax position is reversed when it is subsequently determined that a tax position no longer meets the more likely than not threshold to be sustained. The evaluation of the sustainability of a tax position and the probable amount that is more likely than not is based on judgment, historical experience and on various other assumptions that the Company believes are reasonable under the circumstances. The results of these estimates, that are not readily apparent from other sources, form the basis for recognizing an uncertain tax position liability. Actual results could differ from those estimates upon subsequent resolution of identified matters.
Asset Retirement Obligations
Asset Retirement Obligations:

CNX accrues for dismantling and removing costs of gas-related facilities and related surface reclamation using the accounting treatment prescribed by the Asset Retirement and Environmental Obligations Topic of the FASB Accounting Standards Codification. This topic requires the fair value of an asset retirement obligation be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. Estimates are regularly reviewed by management and are revised for changes in future estimated costs and regulatory requirements. The present value of the estimated asset retirement costs is capitalized as part of the carrying amount of the long-lived asset. Amortization of the capitalized asset retirement cost is generally determined on a units-of-production basis. Accretion of the asset retirement obligation is recognized over time and generally will escalate over the life of the producing asset, typically as production declines. Accretion is included in Depreciation, Depletion and Amortization in the Consolidated Statements of Income.
Investment Plan Investment Plan: CNX has an investment plan that is available to most employees. Throughout the years ended December 31, 2020, 2019 and 2018, the Company's matching contribution was 6% of eligible compensation contributed by eligible employees. The Company may also make discretionary contributions to the Plan ranging from 1% to 6% of eligible compensation for eligible employees (as defined by the Plan).
Revenue Recognition
Revenue Recognition:

Revenues are recognized when the recognition criteria of ASC 606 are met, which generally occurs at the point in which title passes to the customers. For natural gas, NGL and oil revenue, this occurs at the contractual point of delivery. For revenues generated from natural gas gathering services provided to third-parties, this occurs when obligations under the terms of the contract with the shipper are satisfied.
CNX sells natural gas to accommodate the delivery points of its customers. In general, this gas is purchased at market price and re-sold on the same day at market price less a small transaction fee. These matching buy/sell transactions include a legal right of offset of obligations and have been simultaneously entered into with the counterparty. These transactions qualify for netting under the Nonmonetary Transactions Topic of the FASB Accounting Standards Codification and are, therefore, recorded net within the Consolidated Statements of Income in the Purchased Gas Revenue line.
CNX purchases natural gas produced by third-parties at market prices less a fee. The gas purchased from third-parties is then resold to end users or gas marketers at current market prices. These revenues and expenses are recorded gross as Purchased Gas Revenue and Purchase Gas Costs, respectively, in the Consolidated Statements of Income. Purchased gas revenue is recognized when title passes to the customer. Purchased gas costs are recognized when title passes to CNX from the third-party.
Contingencies
Contingencies:

From time to time, CNX, or its subsidiaries, are subject to various lawsuits and claims with respect to such matters as personal injury, wrongful death, damage to property, exposure to hazardous substances, governmental regulations (including environmental remediation), employment and contract disputes and other claims and actions, arising out of the normal course of
business. Liabilities are recorded when it is probable that obligations have been incurred and the amounts can be reasonably estimated. Estimates are developed through consultation with legal counsel involved in the defense of these matters and are based upon the nature of the lawsuit, progress of the case in court, view of legal counsel, prior experience in similar matters and management's intended response. Environmental liabilities are not discounted or reduced by possible recoveries from third-parties. Legal fees associated with defending these various lawsuits and claims are expensed when incurred.
Stock-Based Compensation Stock-Based Compensation: Stock-based compensation expense for all stock-based compensation awards is based on the grant date fair value estimated in accordance with the provisions of the Stock Compensation Topic of the FASB Accounting Standards Codification. CNX recognizes these compensation costs on a straight-line basis over the requisite service period of the award, which is generally the award's vesting term. See Note 15 - Stock-Based Compensation for more information.
Derivative Instruments
Derivative Instruments:

CNX enters into interest rate swap agreements to manage its exposure to interest rate volatility. These swaps change the variable-rate cash flow exposure on the debt obligations to fixed cash flows. The change in fair value of the interest rate swap agreements are accounted for on a mark-to-market basis with the changes in fair value recorded in current period earnings.
CNX enters into financial derivative instruments to manage its exposure to commodity price volatility. Natural gas commodity hedges are accounted for on a mark-to-market basis with changes in fair value recorded in current period earnings.
None of the Company's counterparty master agreements currently require CNX to post collateral for any of its positions. However, as stated in the counterparty master agreements, if CNX's obligations with any of its counterparties cease to be secured on the same basis as similar obligations with the other lenders under the credit facility, CNX would be required to post collateral for instruments in a liability position in excess of defined thresholds. All of the Company's derivative instruments are subject to master netting arrangements with the counterparties. CNX recognizes all financial derivative instruments as either assets or liabilities at fair value in the Consolidated Balance Sheets on a gross basis, generally measured based upon Level 2 inputs, which is further described in Note 18 - Fair Value of Financial Instruments.
Each of the Company's counterparty master agreements allows, in the event of default, the ability to elect early termination of outstanding contracts. If early termination is elected, CNX and the applicable counterparty would net settle all open hedge positions.
CNX is exposed to credit risk in the event of non-performance by counterparties, whose creditworthiness is subject to continuing review. Historically, CNX has not experienced any issues of non-performance by derivative counterparties.
Recent Accounting Pronouncements
Recent Accounting Pronouncements:

In August 2020, the FASB issued Accounting Standards Update (ASU) 2020-06 - Accounting for Convertible Instruments and Contracts in an Entity's Own Equity. This ASU simplifies an entity's accounting for convertible instruments by eliminating two of the three models in ASC 470-20 that require separate accounting for embedded conversion features, simplifies the settlement assessment that entities are required to perform to determine whether a contract qualifies for equity classification, requires entities to use the if-converted method for all convertible instruments in the diluted EPS calculation and include the effect of potential share settlement (if the effect is more dilutive) for instruments that may be settled in cash or shares, except for certain liability-classified share-based payment awards, requires new disclosures about events that occur during the reporting period and cause conversion contingencies to be met and about the fair value of an entity's convertible debt at the instrument level, among other things. The amendments in this ASU are effective for public entities for fiscal years beginning after December 15, 2021, including interim periods within those fiscal years, and can be adopted through either a modified retrospective method of transition or a fully retrospective method of transition. Early adoption is permitted, but no earlier than fiscal years beginning after December 15, 2020, including interim periods within those fiscal years. The Company is still evaluating the effect of adopting this guidance.

In March 2020, the FASB issued ASU 2020-04 - Reference Rate Reform - Facilitation of the Effects of Reference Rate Reform on Financial Reporting (Topic 848). This ASU provides optional expedient and exceptions for applying generally accepted accounting principles to contracts, hedging relationships, and other transactions affected by reference rate reform if certain criteria are met. In response to the concerns about structural risks of interbank offered rates (IBORs) and, particularly, the risk of cessation of the London Interbank Offered Rate (LIBOR), regulators in several jurisdictions around the world have undertaken reference rate reform initiatives to identify alternative reference rates that are more observable or transaction based
and less susceptible to manipulation. The ASU provides companies with optional guidance to ease the potential accounting burden associated with transitioning away from reference rates that are expected to be discontinued. In January 2021, the FASB issued ASU 2021-01, which clarifies that certain provisions in Topic 848, if elected by an entity, apply to derivative instruments that use an interest rate for margining, discounting, or contract price alignment that is modified as a result of reference rate reform. The amendments in these ASUs are effective for all entities as of March 12, 2020 through December 31, 2022. The Company is still evaluating the effect of adopting this guidance.

In March 2020, the FASB issued ASU 2020-03 - Codification Improvements to Financial Instruments. This ASU improves and clarifies various financial instruments topics, including the CECL standard. The ASU includes seven different issues that describe the areas of improvement and the related amendments to GAAP, intended to make the standards easier to understand and apply by eliminating inconsistencies and providing clarifications. The amendments in this ASU have different effective dates. The adoption of this guidance is not expected to have a material impact on the Company's financial statements.
Reclassifications
Reclassifications:
Certain amounts in prior periods have been reclassified to conform with the report classifications of the year ended December 31, 2020, with no effect on previously reported net income, stockholders' equity, or statement of cash flows.
Subsequent Events
Subsequent Events:

The Company has evaluated all subsequent events through the date the financial statements were issued. No material recognized or non-recognizable subsequent events were identified.
v3.20.4
Significant Accounting Policies (Tables)
 12 Months Ended
Dec. 31, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]  
Schedule of Cash and Cash Equivalents
The following table provides a reconciliation of cash, cash equivalents, and restricted cash to amounts shown in the statement of cash flows:
December 31,
202020192018
Cash and Cash Equivalents$15,617 $16,283 $17,198 
Restricted Cash, Current Portion735 — — 
Restricted Cash, Less Current Portion 5,247 — — 
Total Cash, Cash Equivalents and Restricted Cash$21,599 $16,283 $17,198 
Restrictions on Cash and Cash Equivalents
The following table provides a reconciliation of cash, cash equivalents, and restricted cash to amounts shown in the statement of cash flows:
December 31,
202020192018
Cash and Cash Equivalents$15,617 $16,283 $17,198 
Restricted Cash, Current Portion735 — — 
Restricted Cash, Less Current Portion 5,247 — — 
Total Cash, Cash Equivalents and Restricted Cash$21,599 $16,283 $17,198 
Schedule of Allowance for Credit Loss
The following represents the roll forward of the allowance for credit losses for the years ended:
December 31,
20202019
Allowance for Credit Losses - Trade, Beginning of Year$— $— 
Provision for Expected Credit Losses84 — 
Allowance for Credit Losses - Trade, End of Period$84 $— 
Allowance for Credit Losses - Other Receivables, Beginning of Year$2,463 $2,038 
Provision for Expected Credit Losses2,760 595 
Write-off of Uncollectible Accounts(1,975)(170)
Allowance for Credit Losses - Other Receivables, End of Period$3,248 $2,463 
Schedule of Property, Plant and Equipment, Useful Lives
Depreciation of plant and equipment is calculated on the straight-line method over their estimated useful lives or lease terms, generally as follows:
Years
Buildings and Improvements
10 to 45
Machinery and Equipment
3 to 25
Gathering and Transmission
30 to 40
Leasehold ImprovementsLife of Lease
December 31,
Property, Plant and Equipment20202019
Intangible Drilling Cost$4,965,252 $4,688,497 
Gas Gathering Equipment2,510,917 2,463,866 
Proved Gas Properties1,253,094 1,208,046 
Gas Wells and Related Equipment1,120,061 1,042,000 
Unproved Gas Properties725,705 755,590 
Surface Land and Other Equipment199,322 226,285 
Other 189,645 187,722 
Total Property, Plant and Equipment10,963,996 10,572,006 
Less: Accumulated Depreciation, Depletion and Amortization3,938,451 3,435,431 
Total Property, Plant and Equipment - Net$7,025,545 $7,136,575 
v3.20.4
Earnings Per Share (Tables)
 12 Months Ended
Dec. 31, 2020
Earnings Per Share [Abstract]  
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share
The table below sets forth the share-based awards that have been excluded from the computation of diluted earnings per share because their effect would be antidilutive:
For the Years Ended December 31,
 202020192018
Anti-Dilutive Options4,200,509 4,696,264 2,285,775 
Anti-Dilutive Restricted Stock Units2,160,727 1,282,582 — 
Anti-Dilutive Performance Share Units721,244 752,899 145,217 
Anti-Dilutive Performance Share Options— 927,268 927,268 
7,082,480 7,659,013 3,358,260 
Schedule of Earnings Per Share, Basic and Diluted
The computations for basic and diluted (loss) earnings per share are as follows:
For the Years Ended December 31,
 202020192018
Net (Loss) Income$(428,744)$31,948 $883,111 
Less: Net Income Attributable to Non-Controlling Interest55,031 112,678 86,578 
Net (Loss) Income Attributable to CNX Resources Shareholders$(483,775)$(80,730)$796,533 
Weighted-Average Shares of Common Stock Outstanding199,225,441 190,727,122 212,348,581 
Effect of Diluted Shares*— — 2,280,384 
Weighted-Average Diluted Shares of Common Stock Outstanding199,225,441 190,727,122 214,628,965 
(Loss) Earnings Per Share:
Basic$(2.43)$(0.42)$3.75 
Diluted$(2.43)$(0.42)$3.71 
*During periods in which the Company incurs a net loss, diluted weighted average shares outstanding are equal to basic weighted average shares outstanding because the effect of all equity awards is antidilutive.
Schedule of Shares of Common Stock Outstanding
Shares of common stock outstanding were as follows:
For the Years Ended December 31,
 202020192018
Balance, Beginning of Year186,642,962 198,663,342 223,743,322 
Issuance Related to Stock-Based Compensation (1)882,335 909,107 814,344 
Retirement of Common Stock (2)(4,138,527)(12,929,487)(25,894,324)
Issuance Related to CNXM Merger37,054,223 — — 
Balance, End of Year220,440,993 186,642,962 198,663,342 
(1) See Note 15 - Stock-Based Compensation for additional information.
(2) See Note 5 - Stock Repurchase for additional information.
v3.20.4
Revenue From Contracts With Customers (Tables)
 12 Months Ended
Dec. 31, 2020
Revenue from Contract with Customer [Abstract]  
Disaggregation of Revenue
The following table is a disaggregation of revenue by major source:
For the Years Ended December 31,
202020192018
Revenue from Contracts with Customers:
Natural Gas Revenue$823,132 $1,251,013 $1,391,459 
NGL Revenue64,138 104,139 165,883 
Oil/Condensate Revenue9,475 9,173 20,595 
Total Natural Gas, NGL and Oil Revenue896,745 1,364,325 1,577,937 
Purchased Gas Revenue105,792 94,027 65,986 
Other Sources of Revenue and Other Operating Income:
Gain (Loss) on Commodity Derivative Instruments 172,982 376,105 (30,212)
Other Revenue and Operating Income82,459 87,992 116,723 
Total Revenue and Other Operating Income$1,257,978 $1,922,449 $1,730,434 
v3.20.4
Acquisitions and Dispositions (Tables)
 12 Months Ended
Dec. 31, 2020
Business Combinations [Abstract]  
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed
Amount
Cash Consideration$305,000 
CNX Gathering Cash on Hand at January 3, 2018 Distributed to Noble2,620 
Fair Value of Previously Held Equity Interest799,033 
Total Estimated Fair Value of Consideration Transferred$1,106,653 

The following is a summary of the fair values of the net assets acquired:
Amount
Fair Value of Assets Acquired:
Cash and Cash Equivalents$8,348 
Accounts and Notes Receivable21,199 
Prepaid Expense2,006 
Other Current Assets163 
Property, Plant and Equipment, net1,043,340 
Intangible Assets128,781 
Other593 
Total Assets Acquired1,204,430 
Fair Value of Liabilities Assumed:
Accounts Payable26,059 
CNXM Revolving Credit Facility149,500 
Total Liabilities Assumed175,559 
Total Identifiable Net Assets1,028,871 
Fair Value of Noncontrolling Interest in CNXM(718,577)
Goodwill796,359 
Net Assets Acquired$1,106,653 

Post-Acquisition Operating Results (Midstream Acquisition)

The Midstream Acquisition contributed the following to the Midstream reporting unit within the Shale segment:
Schedule of Pro Forma Information
For the Years Ended December 31,
202020192018
Other Revenue and Operating Income$64,710 $74,314 $89,781 
Earnings Before Income Tax$156,818 $166,654 $133,811 
v3.20.4
Income Taxes (Tables)
 12 Months Ended
Dec. 31, 2020
Income Tax Disclosure [Abstract]  
Schedule of Components of Income Tax Expense (Benefit)
Income tax (benefit) expense provided on earnings consisted of:
For the Years Ended December 31,
202020192018
Current:
U.S. Federal
$(55,799)$(51,243)$(130,003)
U.S. State
12 (113)— 
(55,787)(51,356)(130,003)
Deferred:
U.S. Federal
(83,080)47,717 319,813 
U.S. State
(35,220)31,375 25,747 
(118,300)79,092 345,560 
Total Income Tax (Benefit) Expense$(174,087)$27,736 $215,557 
Schedule of Deferred Tax Assets and Liabilities
The components of the net deferred taxes are as follows:
December 31,
20202019
Deferred Tax Assets:
Net Operating Loss- Federal
$215,936 $202,913 
Net Operating Loss - State
129,641 130,430 
Foreign Tax Credit43,194 43,194 
Operating Lease Right-of-Use Assets28,085 47,849 
Gas Well Closing24,251 17,888 
Salary Retirement11,478 9,236 
Equity Compensation6,639 9,308 
Alternative Minimum Tax— 51,241 
Interest Limitation— 25,734 
Other
9,416 10,030 
Total Deferred Tax Assets
468,640 547,823 
Valuation Allowance
(123,098)(125,054)
Net Deferred Tax Assets
345,542 422,769 
Deferred Tax Liabilities:
Property, Plant and Equipment
(649,917)(593,401)
Investment in Partnership
(85,882)(145,424)
Gas Derivatives
(26,882)(105,721)
   Operating Lease Liabilities (28,287)(46,640)
   Discount on Convertible Notes(18,097)— 
Advance Gas Royalties
(2,519)(3,337)
Other
(211)(4,354)
Total Deferred Tax Liabilities
(811,795)(898,877)
Net Deferred Tax Liability
$(466,253)$(476,108)
Schedule of Effective Income Tax Rate Reconciliation
The following is a reconciliation, stated as a percentage of pretax income, of the United States statutory federal income tax rate to CNX's effective tax rate:
 For the Years Ended December 31,
 202020192018
 AmountPercentAmountPercentAmountPercent
Statutory U.S. Federal Income Tax Rate$(126,595)21.0 %$12,534 21.0 %$230,721 21.0 %
Net Effect of State Income Taxes(32,336)5.5 1,333 2.2 60,814 5.6 
Non-Controlling Interest(11,556)1.9 (23,662)(39.6)(18,181)(1.7)
Uncertain Tax Positions375 (0.1)— — (4,265)(0.4)
Accrual to Tax Return Reconciliation
13 — 603 1.0 3,028 0.3 
Effect of Equity Compensation4,311 (0.7)8,771 14.7 — — 
Effect of Change in State Valuation Allowance(2,004)0.3 33,238 55.6 (22,684)(2.1)
Effect of Change in Federal Valuation Allowance48 — (2,640)(4.4)(18,110)(1.7)
Other Deferred Adjustments1,166 (0.2)(1,691)(2.8)5,957 0.6 
Effect of Federal and State Rate Reductions(1,450)0.2 (3,842)(6.4)(27,429)(2.5)
Effect of Federal Tax Credits(6,284)1.0 2,881 4.8 1,208 0.1 
Other225 — 211 0.4 4,498 0.4 
Income Tax (Benefit) Expense / Effective Rate$(174,087)28.9 %$27,736 46.5 %$215,557 19.6 %
Reconciliation of Unrecognized Tax Benefits
A reconciliation of the beginning and ending gross amounts of unrecognized tax benefits is as follows:
For the Years Ended
December 31,
20202019
Balance at Beginning of Period$31,516 $31,516 
Increase in Unrecognized Tax Benefits Resulting from Tax Positions Taken During Prior Periods
1,726 — 
Reduction in Unrecognized Tax Benefits Because of the Lapse of the Applicable Statute of Limitations(1,351)— 
Balance at End of Period$31,891 $31,516 
v3.20.4
Asset Retirement Obligations (Tables)
 12 Months Ended
Dec. 31, 2020
Asset Retirement Obligation [Abstract]  
Schedule of Change in Asset Retirement Obligation
The reconciliation of changes in asset retirement obligations is as follows:
December 31,
20202019
Balance, Beginning of Year$68,454 $38,554 
Obligations Divested(703)— 
Accretion Expense11,067 9,458 
Obligations Incurred2,806 2,933 
Obligations Settled(7,905)(4,231)
Revisions in Estimated Cash Flows19,449 21,740 
Balance, End of Year$93,168 $68,454 
v3.20.4
Property, Plant and Equipment (Tables)
 12 Months Ended
Dec. 31, 2020
Property, Plant and Equipment [Abstract]  
Property, Plant and Equipment
Depreciation of plant and equipment is calculated on the straight-line method over their estimated useful lives or lease terms, generally as follows:
Years
Buildings and Improvements
10 to 45
Machinery and Equipment
3 to 25
Gathering and Transmission
30 to 40
Leasehold ImprovementsLife of Lease
December 31,
Property, Plant and Equipment20202019
Intangible Drilling Cost$4,965,252 $4,688,497 
Gas Gathering Equipment2,510,917 2,463,866 
Proved Gas Properties1,253,094 1,208,046 
Gas Wells and Related Equipment1,120,061 1,042,000 
Unproved Gas Properties725,705 755,590 
Surface Land and Other Equipment199,322 226,285 
Other 189,645 187,722 
Total Property, Plant and Equipment10,963,996 10,572,006 
Less: Accumulated Depreciation, Depletion and Amortization3,938,451 3,435,431 
Total Property, Plant and Equipment - Net$7,025,545 $7,136,575 
Schedule of Amortization Expense Per Unit of Production
December 31,
20202019
Unproved Gas Properties$725,705 $755,590 
Advance Royalties9,676 12,770 
     Total$735,381 $768,360 
v3.20.4
Goodwill and Other Intangible Assets (Tables)
 12 Months Ended
Dec. 31, 2020
Goodwill and Intangible Assets Disclosure [Abstract]  
Schedule of Goodwill
Changes in the carrying amount of goodwill consist of the following activity:
Amount
December 31, 2019$796,359 
Impairment473,045 
December 31, 2020$323,314 
Schedule of Finite-Lived Intangible Assets
The carrying amount and accumulated amortization of other intangible assets consist of the following:
December 31,
20202019
Other Intangible Assets:
Gross Amortizable Asset - Customer Relationships$109,752 $109,752 
Less: Accumulated Amortization - Customer Relationships19,657 13,105 
Total Other Intangible Assets, net$90,095 $96,647 
v3.20.4
Other Accrued Liabilities (Tables)
 12 Months Ended
Dec. 31, 2020
Other Liabilities Disclosure [Abstract]  
Schedule of Accrued Liabilities
December 31,
20202019
Royalties$72,401 $74,061 
Accrued Interest26,549 30,862 
Short-Term Incentive Compensation20,340 21,030 
Transportation Charges15,969 16,533 
Deferred Revenue10,986 13,964 
Accrued Other Taxes10,580 9,115 
Accrued Payroll & Benefits5,009 6,248 
Other26,697 37,610 
Current Portion of Long-Term Liabilities:
Asset Retirement Obligations8,455 5,076 
Salary Retirement
1,787 1,587 
Total Other Accrued Liabilities$198,773 $216,086 
v3.20.4
Long-Term Debt (Tables)
 12 Months Ended
Dec. 31, 2020
Long-term Debt, Other Disclosures [Abstract]  
Schedule of Long-term Debt
December 31,
20202019
Senior Notes due March 2027 at 7.25% (Principal of $700,000 and $500,000, respectively, plus Unamortized Premium of $6,686 at December 31, 2020)
$706,686 $500,000 
Senior Notes due January 2029 at 6.00%, Issued at Par Value
500,000 — 
CNX Midstream Partners LP Senior Notes due March 2026 at 6.50% (Principal of $400,000 less Unamortized Discount of $3,875 and $4,625, respectively)*
396,125 395,375 
CNX Midstream Partners LP Revolving Credit Facility* 291,000 311,750 
Convertible Senior Notes due May 2026 at 2.25% (Principal of $345,000 less Unamortized Discount and Issuance Costs of $107,735)
237,265 — 
CNX Revolving Credit Facility160,800 661,000 
Cardinal States Gathering Company Credit Facility maturing in March 2028 (Principal of $114,985 less Unamortized Discount of $1,126)
113,859 — 
CSG Holdings II LLC Credit Facility maturing in March 2027 (Principal of $45,559 less Unamortized Discount of $441)
45,118 — 
Senior Notes due April 2022 at 5.875% (Principal of $894,307 plus Unamortized Premium of $1,001 at December 31, 2019)
— 895,308 
Less: Unamortized Debt Issuance Costs26,852 8,990 
2,424,001 2,754,443 
Less: Amounts Due in One Year22,574 — 
Long-Term Debt$2,401,427 $2,754,443 
Schedule of Maturities of Long-term Debt
At December 31, 2020, annual undiscounted maturities of CNX and CNXM long-term debt during the next five years and thereafter are as follows:
Year ended December 31,Amount
2021$22,574 
202223,712 
202324,469 
2024474,366 
202523,057 
Thereafter1,989,166 
      Total Long-Term Debt Maturities$2,557,344 
Convertible Debt
The net carrying amount of the liability and equity components of the Convertible Notes was as follows:
December 31, 2020
Liability Component:
Principal$345,000 
Unamortized Discount(101,367)
Unamortized Issuance Costs(6,368)
Net Carrying Amount$237,265 
Equity Component, net of Purchase Discounts and Issuance Costs78,317 
Interest expense related to the Convertible Notes is as follows:
For the Year Ended
December 31, 2020
Contractual Interest Expense $5,175 
Amortization of Debt Discount9,516 
Amortization of Issuance Costs655 
Total Interest Expense $15,346 
v3.20.4
Leases (Tables)
 12 Months Ended
Dec. 31, 2020
Leases [Abstract]  
Schedule of Lease Cost
The components of lease cost were as follows:
For the Years Ended December 31,
20202019
Operating Lease Cost$74,703 $73,809 
Finance Lease Cost:
Amortization of Right-of-Use Assets
4,959 5,242 
Interest on Lease Liabilities
739 1,241 
Short-term Lease Cost3,252 5,547 
Variable Lease Cost*9,634 17,337 
Total Lease Cost$93,287 $103,176 
*Amounts recognized in the Consolidated Balance Sheets for natural gas drilling rigs are measured using the rates that would be paid if the rigs were idle, as this represents the minimum payment that could be made under the contract. Variable lease cost represents amounts paid for natural gas drilling rigs above this minimum when the rigs are in use. Amounts recognized in the Consolidated Balance Sheets for electric fracturing equipment are measured using minimum pumping hours under the contract; however, pumping hours may exceed the minimum and vary period to period. Any such amounts paid related to pumping hours in excess of the minimum represent variable lease cost.
Lease terms and discount rates are as follows:
December 31,
20202019
Weighted Average Remaining Lease Term (years):
Operating Leases
4.684.39
Finance Leases
1.372.16
Weighted Average Discount Rate:
Operating Leases
4.40 %4.96 %
Finance Leases
6.33 %6.92 %
Schedule of Balance Sheet Information Amounts recognized in the Consolidated Balance Sheets are as follows:
December 31,
20202019
Operating Leases:
Operating Lease Right-of-Use Asset$108,683 $187,097 
Current Portion of Operating Lease Obligations$52,575 $61,670 
Operating Lease Obligations53,235 110,466 
Total Operating Lease Liabilities
$105,810 $172,136 
Finance Leases:
Property, Plant and Equipment$72,653 $72,916 
Less—Accumulated Depreciation, Depletion and Amortization67,508 63,008 
Property, Plant and Equipment—Net
$5,145 $9,908 
Current Portion of Finance Lease Obligations$6,876 $7,164 
Finance Lease Obligations1,057 7,706 
Total Finance Lease Liabilities
$7,933 $14,870 
Supplemental cash flow information related to leases was as follows:
For the Years Ended December 31,
20202019
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating Cash Flows from Operating Leases
$62,610 $66,827 
Operating Cash Flows from Finance Leases
$739 $1,241 
Financing Cash Flows from Finance Leases
$7,155 $7,149 
Right-of-Use Assets Obtained in Exchange for Lease Obligations:
Operating Leases
$4,027 $15,347 
Finance Leases
$257 $1,846 
Maturity of Lease Liability, Operating
Maturities of lease liabilities are as follows:
OperatingFinance
LeasesLeases
Year Ended December 31,
2021$56,190 $7,138 
202221,592 446 
20235,453 442 
20245,433 155 
20254,824 38 
Thereafter25,996 40 
Total Lease Payments119,488 8,259 
Less: Interest13,678 326 
Present Value of Lease Liabilities$105,810 $7,933 
Maturity of Lease Liability, Financing
Maturities of lease liabilities are as follows:
OperatingFinance
LeasesLeases
Year Ended December 31,
2021$56,190 $7,138 
202221,592 446 
20235,453 442 
20245,433 155 
20254,824 38 
Thereafter25,996 40 
Total Lease Payments119,488 8,259 
Less: Interest13,678 326 
Present Value of Lease Liabilities$105,810 $7,933 
v3.20.4
Pension (Tables)
 12 Months Ended
Dec. 31, 2020
Retirement Benefits [Abstract]  
Schedule of Changes in Accumulated Postemployment Benefit Obligations
The reconciliation of changes in the benefit obligation, plan assets and funded status of the pension benefits is as follows:
December 31,
20202019
Change in Benefit Obligation:
Benefit Obligation at Beginning of Period
$40,196 $33,569 
Service Cost
247 209 
Interest Cost
1,179 1,338 
Actuarial Loss4,098 4,865 
Plan Amendments
— 1,728 
Benefits and Other Payments
(1,644)(1,513)
Benefit Obligation at End of Period$44,076 $40,196 
Change in Plan Assets:
Fair Value of Plan Assets at Beginning of Period
$— $— 
Company Contributions
1,644 1,513 
Benefits and Other Payments
(1,644)(1,513)
Fair Value of Plan Assets at End of Period$— $— 
Funded Status:
Current Liabilities
$(1,787)$(1,587)
Noncurrent Liabilities
(42,289)(38,609)
Net Obligation Recognized$(44,076)$(40,196)
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of:
Net Actuarial Loss
$19,075 $15,361 
Prior Service Cost1,506 1,727 
Total
20,581 17,088 
Less: Tax Benefit
5,397 4,483 
Net Amount Recognized$15,184 $12,605 
Schedule of Defined Benefit Plans Disclosures
The components of the net periodic benefit cost are as follows:
For the Years Ended December 31,
 202020192018
Components of Net Periodic Benefit Cost:
Service Cost
$247 $209 $302 
Interest Cost
1,179 1,338 1,265 
Amortization of Prior Service Cost (Credit)221 (17)(193)
Recognized Net Actuarial Loss
383 242 865 
Curtailment Gain
— — (416)
Net Periodic Benefit Cost$2,030 $1,772 $1,823 
Schedule of Accumulated Benefit Obligations in Excess of Fair Value of Plan Assets
The following table provides information related to the pension plan with an accumulated benefit obligation in excess of plan assets:
As of December 31,
20202019
Projected Benefit Obligation$44,076 $40,196 
Accumulated Benefit Obligation$43,886 $40,196 
Fair Value of Plan Assets$— $— 
Schedule of Assumptions Used
The weighted-average assumptions used to determine benefit obligations are as follows:
As of December 31,
20202019
Discount Rate2.47 %3.36 %
Rate of Compensation Increase— %— %
Interest Credited Rate2.26 %3.01 %

The discount rates are determined using a Company-specific yield curve model (above-mean) developed with the assistance of an external actuary. The Company-specific yield curve models (above-mean) use a subset of the expanded bond universe to determine the Company-specific discount rate. Bonds used in the yield curve are rated AA by Moody's or Standard & Poor's as of the measurement date. The yield curve models parallel the plans' projected cash flows, and the underlying cash flows of the bonds included in the models exceed the cash flows needed to satisfy the Company plans.

The weighted-average assumptions used to determine net periodic benefit cost are as follows:
For the Years ended December 31,
202020192018
Discount Rate3.36 %4.37 %4.28 %
Rate of Compensation Increase— %3.63 %4.05 %
Interest Credited Rate2.47 %3.39 %3.94 %
Schedule of Expected Benefit Payments
The following benefit payments, which reflect expected future service, are expected to be paid:
Pension
Year ended December 31,Benefits
2021$1,787 
2022$1,846 
2023$1,913 
2024$1,977 
2025$2,049 
Year 2026-2030$11,172 
v3.20.4
Stock-Based Compensation (Tables)
 12 Months Ended
Dec. 31, 2020
Share-based Payment Arrangement, Noncash Expense [Abstract]  
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions
The total fair value of options granted during the years ended December 31, 2020, 2019 and 2018 was $1,066, $50, and $143 respectively, based on the following assumptions and weighted average fair values:
December 31,
202020192018
Weighted Average Fair Value of Grants$3.56 $3.48 $6.50 
Risk-free Interest Rate1.61 %2.13 %2.66 %
Expected Dividend Yield— %— %— %
Expected Forfeiture Rate— %— %— %
Expected Volatility55.33 %43.60 %52.68 %
Expected Term in Years5.116.503.71
Share-based Compensation, Stock Options, Activity
A summary of the status of stock options granted is presented below:
Weighted
Average
WeightedRemainingAggregate
AverageContractualIntrinsic
ExerciseTerm (inValue (in
SharesPriceyears)thousands)
Outstanding at December 31, 20194,696,264 $18.05 
Granted299,541 $10.46 
Exercised(298,513)$6.87 
Forfeited(3,561)$10.53 
Expired(493,222)$43.53 
Outstanding at December 31, 20204,200,509 $15.32 4.18$9,430 
Exercisable at December 31, 20203,908,444 $15.68 3.81$9,330 
Schedule of Nonvested Restricted Stock Units Activity
The following table represents the nonvested restricted stock units and their corresponding fair value (based upon the closing share price) at the date of grant:
Number ofWeighted Average
SharesGrant Date Fair Value
Nonvested at December 31, 20191,033,200 $11.71
Granted1,251,065 $8.49
RSUs granted in conversion, as a result of the CNXM Merger204,619 $18.01
Vested(577,834)$10.95
Forfeited(39,923)$9.65
Nonvested at December 31, 20201,871,127 $10.10
Schedule of Nonvested Performance-based Units Activity
The following table represents the nonvested performance share units and their corresponding fair value (based upon the Monte Carlo Methodology) on the date of grant:
Number ofWeighted Average
SharesGrant Date Fair Value
Nonvested at December 31, 20191,400,836 $18.91
Granted660,634 $5.79
PSUs Issued 112,158 $20.39
Vested(274,716)$20.82
Forfeited(131,474)$18.37
Nonvested at December 31, 20201,767,438 $13.85
v3.20.4
Supplemental Cash Flow Information (Tables)
 12 Months Ended
Dec. 31, 2020
Supplemental Cash Flow Information [Abstract]  
Schedule of Cash Flow, Supplemental Disclosures
The following table shows cash paid (received):
For the Years Ended December 31,
202020192018
Interest (Net of Amounts Capitalized)
$141,992 $143,111 $144,756 
Income Taxes
$(118,125)$(138,409)$(11,505)
v3.20.4
Concentrations of Credit Risk and Major Customers - (Tables)
 12 Months Ended
Dec. 31, 2020
Risks and Uncertainties [Abstract]  
Schedules of Concentration of Risk, by Risk Factor Concentration of credit risk is summarized below:
December 31,
20202019
Gas Wholesalers$133,253 $115,641 
NGL, Condensate & Processing Facilities
7,008 10,140 
Other5,752 7,699 
Allowance for Credit Losses(84)— 
Total Accounts Receivable Trade
$145,929 $133,480 
v3.20.4
Fair Value of Financial Instruments (Tables)
 12 Months Ended
Dec. 31, 2020
Fair Value Disclosures [Abstract]  
Fair Value, Assets Measured on Recurring Basis
The financial instrument measured at fair value on a recurring basis is summarized below:
 Fair Value Measurements at December 31, 2020Fair Value Measurements at December 31, 2019
DescriptionLevel 1Level 2Level 3Level 1Level 2Level 3
Gas Derivatives$— $117,545 $— $— $405,781 $— 
Interest Rate Swaps$— $(14,270)$— $— $(1,219)$— 
Fair Value, by Balance Sheet Grouping
The carrying amounts and fair values of financial instruments for which the fair value option was not elected are as follows:
 December 31, 2020December 31, 2019
 Carrying
Amount		Fair
Value		Carrying
Amount		Fair
Value
Cash and Cash Equivalents$15,617 $15,617 $16,283 $16,283 
Long-Term Debt (Excluding Debt Issuance Costs)$2,450,853 $2,638,251 $2,763,433 $2,619,676 
v3.20.4
Derivative Instruments (Tables)
 12 Months Ended
Dec. 31, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]  
Schedule of Notional Amounts of Outstanding Derivative Positions
The total notional amounts of production of CNX's derivative instruments were as follows:
December 31,Forecasted to
20202019Settle Through
Natural Gas Commodity Swaps (Bcf)1,256.9 1,460.6 2025
Natural Gas Basis Swaps (Bcf)1,294.1 1,290.4 2026
Interest Rate Swaps$569,972 $160,000 2028
Schedule of Derivative Liabilities at Fair Value
The gross fair value of CNX's derivative instruments was as follows:
December 31,
20202019
Current Assets:
  Commodity Derivative Instruments:
     Commodity Swaps$53,668 $234,238 
     Basis Only Swaps30,848 13,556 
  Interest Rate Swaps141 — 
Total Current Assets$84,657 $247,794 
Other Non-Current Assets:
  Commodity Derivative Instruments:
     Commodity Swaps$134,661 $288,543 
     Basis Only Swaps52,903 25,553 
  Interest Rate Swaps673 — 
Total Other Non-Current Assets$188,237 $314,096 
Current Liabilities:
  Commodity Derivative Instruments:
     Commodity Swaps$23,506 $345 
     Basis Only Swaps14,491 40,626 
  Interest Rate Swaps4,332 495 
Total Current Liabilities$42,329 $41,466 
Non-Current Liabilities:
  Commodity Derivative Instruments:
     Commodity Swaps$59,388 $9,693 
     Basis Only Swaps57,150 105,445 
  Interest Rate Swaps10,752 724 
Total Non-Current Liabilities$127,290 $115,862 
Schedule of Derivative Assets at Fair Value
The gross fair value of CNX's derivative instruments was as follows:
December 31,
20202019
Current Assets:
  Commodity Derivative Instruments:
     Commodity Swaps$53,668 $234,238 
     Basis Only Swaps30,848 13,556 
  Interest Rate Swaps141 — 
Total Current Assets$84,657 $247,794 
Other Non-Current Assets:
  Commodity Derivative Instruments:
     Commodity Swaps$134,661 $288,543 
     Basis Only Swaps52,903 25,553 
  Interest Rate Swaps673 — 
Total Other Non-Current Assets$188,237 $314,096 
Current Liabilities:
  Commodity Derivative Instruments:
     Commodity Swaps$23,506 $345 
     Basis Only Swaps14,491 40,626 
  Interest Rate Swaps4,332 495 
Total Current Liabilities$42,329 $41,466 
Non-Current Liabilities:
  Commodity Derivative Instruments:
     Commodity Swaps$59,388 $9,693 
     Basis Only Swaps57,150 105,445 
  Interest Rate Swaps10,752 724 
Total Non-Current Liabilities$127,290 $115,862 
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value
The effect of derivative instruments on the Company's Consolidated Statements of Income was as follows:
For the Years Ended December 31,
202020192018
Cash Received (Paid) in Settlement of Commodity Derivative Instruments:
  Natural Gas:
   Commodity Swaps$390,547 $82,899 $(41,098)
    Basis Swaps70,670 (13,119)(28,622)
Total Cash Received (Paid) in Settlement of Commodity Derivative Instruments461,217 69,780 (69,720)
Unrealized (Loss) Gain on Commodity Derivative Instruments:
 Natural Gas:
    Commodity Swaps(407,308)406,472 33,026 
    Basis Swaps119,073 (100,147)6,482 
Total Unrealized (Loss) Gain on Commodity Derivative Instruments(288,235)306,325 39,508 
Gain (Loss) on Commodity Derivative Instruments:
  Natural Gas:
    Commodity Swaps(16,761)489,371 (8,072)
    Basis Swaps189,743 (113,266)(22,140)
Total Gain (Loss) on Commodity Derivative Instruments$172,982 $376,105 $(30,212)

The effect of interest rate swaps on Interest Expense in the Company's Consolidated Statements of Income was as follows:
For the Years Ended December 31,
20202019
Cash (Paid) Received in Settlement of Interest Rate Swaps$(3,141)$223 
Unrealized Loss on Interest Rate Swaps(13,051)(1,219)
Loss on Interest Rate Swaps$(16,192)$(996)
v3.20.4
Commitments and Contingent Liabilities (Tables)
 12 Months Ended
Dec. 31, 2020
Commitments and Contingencies Disclosure [Abstract]  
Long-term Purchase Commitment
At December 31, 2020, CNX has provided the following financial guarantees, unconditional purchase obligations, and letters of credit to certain third-parties as described by major category in the following tables. These amounts represent the maximum potential of total future payments that the Company could be required to make under these instruments. These amounts have not been reduced for potential recoveries under recourse or collateralization provisions. Generally, recoveries under reclamation bonds would be limited to the extent of the work performed at the time of the default. No amounts related to these unconditional purchase obligations and letters of credit are recorded as liabilities in the financial statements. CNX management believes that the commitments in the following table will expire without being funded, and therefore will not have a material adverse effect on financial condition.

 Amount of Commitment Expiration Per Period
 Total
Amounts
Committed		Less Than
1  Year		1-3 Years3-5 YearsBeyond
5  Years
Letters of Credit:
Firm Transportation$178,352 $178,352 $— $— $— 
Other6,950 6,950 — — — 
Total Letters of Credit185,302 185,302 — — — 
Surety Bonds:
Employee-Related2,600 2,600 — — — 
Environmental12,447 12,187 260 — — 
Financial Guarantees81,670 81,670 — — — 
Other9,183 7,899 1,284 — — 
Total Surety Bonds105,900 104,356 1,544 — — 
Total Commitments$291,202 $289,658 $1,544 $— $— 
Unrecorded Unconditional Purchase Obligations Disclosure
As of December 31, 2020, the purchase obligations for each of the next five years and beyond were as follows:
Obligations DueAmount
Less than 1 year$253,692 
1 - 3 years431,282 
3 - 5 years390,693 
More than 5 years985,201 
Total Purchase Obligations$2,060,868 
v3.20.4
Segment Information (Tables)
 12 Months Ended
Dec. 31, 2020
Segment Reporting [Abstract]  
Schedule of Segment Reporting Information, by Segment
Industry segment results for the year ended December 31, 2020 are:
ShaleCoalbed
Methane		OtherConsolidated
Natural Gas, NGLs and Oil Revenue$781,038 $114,366 $1,341 $896,745 (A)
Purchased Gas Revenue— — 105,792 105,792 
Gain (Loss) on Commodity Derivative Instruments337,269 39,884 (204,171)172,982 (B)
Other Operating Income64,710 — 17,749 82,459 (C)
Total Revenue and Other Operating Income$1,183,017 $154,250 $(79,289)$1,257,978   
Total Operating Expense$709,036 $127,845 $860,863 $1,697,744 
Earnings (Loss) Before Income Tax$473,981 $26,405 $(1,103,217)$(602,831)
Segment Assets$6,068,933 $1,095,816 $877,015 $8,041,764 (D)
Depreciation, Depletion and Amortization
$416,441 $69,745 $15,635 $501,821   
Capital Expenditures$474,545 $9,789 $2,957 $487,291   

(A)     Included in Total Natural Gas, NGLs and Oil Revenue are sales of $167,390 to Direct Energy Business Marketing LLC, which comprises over 10% of revenue from contracts with external customers for the period.
(B)    Included in Other is a realized gain on commodity derivative instruments of $83,997 related to the monetization of hedges (see Note 19 - Derivative Instruments for more information).
(C)    Includes midstream revenue of $64,710 and equity in loss of unconsolidated affiliates of $688 for Shale and Other, respectively.
(D)    Includes investments in unconsolidated equity affiliates of $16,022 .
Industry segment results for the year ended December 31, 2019 are:
ShaleCoalbed
Methane		OtherConsolidated
Natural Gas, NGLs and Oil Revenue$1,199,276 $163,893 $1,156 $1,364,325 (E)
Purchased Gas Revenue— — 94,027 94,027 
Gain on Commodity Derivative Instruments
62,418 7,335 306,352 376,105   
Other Revenue and Operating Income74,314 — 13,678 87,992 (F)
Total Revenue and Other Operating Income$1,336,008 $171,228 $415,213 $1,922,449   
Total Operating Expense$787,488 $135,778 $813,207 $1,736,473 
Earnings (Loss) Before Income Tax$548,520 $35,450 $(524,286)$59,684 
Segment Assets$6,527,245 $1,222,005 $1,311,556 $9,060,806 (G)
Depreciation, Depletion and Amortization
$427,219 $73,189 $8,055 $508,463   
Capital Expenditures$1,175,091 $11,333 $6,175 $1,192,599 
(E)     Included in Total Natural Gas, NGLs and Oil Revenue are sales of $214,980 to Direct Energy Business Marketing LLC and $147,540 to NJR Energy Services Company, each of which comprises over 10% of revenue from contracts with external customers for the period.
(F)    Includes midstream revenue of $74,314 and equity in earnings of unconsolidated affiliates of $2,103 for Shale and Other, respectively.
(G)    Includes investments in unconsolidated equity affiliates of $16,710.

Industry segment results for the year ended December 31, 2018 are:
ShaleCoalbed
Methane		OtherConsolidated
Natural Gas, NGLs and Oil Revenue$1,349,196 $212,884 $15,857 $1,577,937 (H)
Purchased Gas Revenue— — 65,986 65,986 
(Loss) Gain on Commodity Derivative Instruments
(60,326)(8,768)38,882 (30,212)  
Other Revenue and Operating Income89,781 — 26,942 116,723 (I)
Total Revenue and Other Operating Income$1,378,651 $204,116 $147,667 $1,730,434   
Total Operating Expense$751,673 $154,121 $321,169 $1,226,963 
Earnings Before Income Tax$626,978 $49,995 $421,695 $1,098,668 
Segment Assets$6,268,113 $1,272,457 $1,051,600 $8,592,170 (J)
Depreciation, Depletion and Amortization
$404,503 $77,004 $11,916 $493,423   
Capital Expenditures$1,094,471 $17,083 $4,843 $1,116,397 
(H)    Included in Total Natural Gas, NGLs and Oil Revenue are sales of $219,472 to NJR Energy Services Company and $184,668 to Direct Energy Business Marketing LLC, each of which comprises over 10% of revenue from contracts with external customers for the period.
(I)    Includes midstream revenue of $89,781 and equity in earnings of unconsolidated affiliates of $5,363 for Shale and Other, respectively.
(J)    Includes investments in unconsolidated equity affiliates of $18,663.
Reconciliation of Revenue from Segments to Consolidated Revenue and Other Operating Income:
For the Years Ended December 31,
202020192018
Total Segment Revenue from Contracts with External Customers$1,067,247 $1,532,666 $1,733,704 
Gain (Loss) on Commodity Derivative Instruments172,982 376,105 (30,212)
Other Operating Income17,749 13,678 26,942 
Total Consolidated Revenue and Other Operating Income
$1,257,978 $1,922,449 $1,730,434 
v3.20.4
Supplemental Gas Data (unaudited) (Tables)
 12 Months Ended
Dec. 31, 2020
Extractive Industries [Abstract]  
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure
Capitalized Costs:
As of December 31,
20202019
Intangible Drilling Costs$4,965,252 $4,688,497 
Gas Gathering Assets2,510,916 2,463,866 
Proved Gas Properties1,253,094 1,208,046 
Gas Wells and Related Equipment1,120,061 1,042,000 
Unproved Gas Properties725,705 755,590 
Other Gas Assets95,734 73,479 
Total Property, Plant and Equipment10,670,762 10,231,478 
Accumulated Depreciation, Depletion and Amortization(3,852,593)(3,317,442)
Net Capitalized Costs$6,818,169 $6,914,036 
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure
Costs incurred for property acquisition, exploration and development (*):
For the Years Ended December 31,
202020192018
Property Acquisitions:
Proved Properties
$16,622 $36,710 $38,621 
Unproved Properties
8,060 24,760 36,248 
Development**432,438 1,063,945 986,419 
Exploration33,644 79,855 61,604 
Total$490,764 $1,205,270 $1,122,892 
__________
(*)    Includes costs incurred whether capitalized or expensed.
(**)    Includes development costs for midstream of $67 million, $325 million and $142 million for 2020, 2019 and 2018, respectively.
Results of Operations for Oil and Gas Producing Activities Disclosure
Results of Operations for Producing Activities:
For the Years Ended December 31,
202020192018
Natural Gas, NGLs and Oil Revenue$896,745 $1,364,325 $1,577,937 
Realized Gain (Loss) on Commodity Derivative Instruments 461,217 69,780 (69,720)
Unrealized (Loss) Gain on Commodity Derivative Instruments(288,235)306,325 39,508 
Purchased Gas Revenue105,792 94,027 65,986 
Total Revenue1,175,519 1,834,457 1,613,711 
Lease Operating Expense40,407 65,443 95,139 
Production, Ad Valorem and Other Fees24,196 27,461 32,750 
Transportation, Gathering and Compression285,683 330,539 302,933 
Purchased Gas Costs100,902 90,553 64,817 
Impairment of Exploration and Production Properties61,849 327,400 — 
Impairment of Undeveloped Properties— 119,429 — 
Exploration Costs14,994 44,380 12,033 
Depreciation, Depletion and Amortization501,821 508,463 493,423 
Total Costs1,029,852 1,513,668 1,001,095 
Pre-tax Operating Income145,667 320,789 612,616 
Income Tax Expense42,098 149,167 120,073 
Results of Operations for Producing Activities excluding Corporate and Interest Costs
$103,569 $171,622 $492,543 
Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure
The following is production, average sales price and average production costs, excluding ad valorem and severance taxes, per unit of production:
For the Years Ended December 31,
202020192018
Production (MMcfe)511,072 539,149 507,104 
Total Average Sales Price Before Effects of Commodity Derivative Financial Settlements (per Mcfe)$1.75 $2.53 $3.11 
Average Effects of Commodity Derivative Financial Settlements (per Mcfe)$0.74 $0.14 $(0.15)
Total Average Sales Price Including Effects of Commodity Derivative Financial Settlements (per Mcfe)
$2.49 $2.66 $2.97 
Average Lifting Costs, Excluding Ad Valorem and Severance Taxes (per Mcfe)$0.08 $0.12 $0.19 
Schedule of Gas and Oil Acreage
The following table sets forth, at December 31, 2020, the number of producing wells, developed acreage and undeveloped acreage:
Gross(1)Net(2)
Producing Gas Wells (including Gob Wells) - Working Interest4,712 4,401 
Producing Oil Wells - Working Interest— — 
Producing Gas Wells - Royalty Interest1,810 — 
Producing Oil Wells - Royalty Interest152 — 
Acreage Position:
   Proved Developed Acreage351,537 351,537 
   Proved Undeveloped Acreage43,713 43,713 
   Unproved Acreage4,986,196 3,637,982 
Total Acreage5,381,446 4,033,232 
____________
(1)    All of our acreage identified as proved developed and undeveloped is controlled fully by CNX through ownership of a 100% working interest.
(2)    Net acres include acreage attributable to our working interests in the properties. Additional adjustments (either increases or decreases) may be required as we further develop title to and further confirm our rights with respect to our various properties in anticipation of development. We believe that our assumptions and methodology in this regard are reasonable.
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities
The gas reserves estimates are as follows:
CondensateConsolidated
Natural GasNGLs& Crude OilOperations
(MMcf)(Mbbls)(Mbbls)(MMcfe)
Balance December 31, 2017 (a)7,121,758 71,691 4,950 7,581,612 
Revisions (b)313,091 441 865 320,925 
Price Changes28,100 32 4 28,315 
Extensions and Discoveries (c)839,268 16,247 4,010 960,808 
Production(468,228)(6,011)(468)(507,104)
Sales of Reserves In-Place (d)(715,088)(17,252)(1,100)(825,196)
Balance December 31, 2018 (a)7,436,338 65,904 8,261 7,881,335 
Revisions (e)(521,617)5,926 (5,418)(518,570)
Price Changes(40,773)(740)(5)(45,246)
Extensions and Discoveries (c)1,569,813 10,182 2,732 1,647,297 
Production(505,355)(5,428)(204)(539,149)
Balance December 31, 2019 (a)7,938,406 75,844 5,366 8,425,667 
Revisions (f)407,836 51,857 3,525 740,129 
Price Changes(1,019,523)(50,456)(4,946)(1,351,934)
Extensions and Discoveries (c)2,188,773 9,299 400 2,246,968 
Production(481,426)(4,677)(264)(511,072)
Balance December 31, 2020 (a)9,034,066 81,867 4,081 9,549,758 
Proved developed reserves:
December 31, 20184,242,579 40,180 1,870 4,494,878 
December 31, 20194,473,534 59,800 1,087 4,838,858 
December 31, 20204,939,283 42,204 1,207 5,199,748 
Proved undeveloped reserves:
December 31, 20183,193,759 25,724 6,391 3,386,457 
December 31, 20193,464,873 16,044 4,278 3,586,809 
December 31, 20204,094,783 39,664 2,874 4,350,010 
__________
(a)    Proved developed and proved undeveloped gas reserves are defined by SEC Rule 4.10(a) of Regulation S-X. Generally, these reserves would be commercially recovered under current economic conditions, operating methods and government regulations. CNX cautions that there are many inherent uncertainties in estimating proved reserve quantities, projecting future production rates and timing of development expenditures. Proved oil and gas reserves are estimated quantities of natural gas which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years
from known reservoirs under existing economic and operating conditions and government regulations. Proved developed reserves are reserves expected to be recovered through existing wells, with existing equipment and operating methods.
(b)    The upward revision for 2018 of 321 Bcfe is primarily due to a 472 Bcfe upward revision from increased performance through our continued focus on optimization. This is partially offset by a 151 Bcfe downward revision due to plan changes.
(c)    Extensions and Discoveries in 2018, 2019, and 2020 are due to the addition of wells on the Company's Shale acreage more than one offset location away with continued use of reliable technology. The Company uses reliable technologies when assigning reserves to undeveloped locations, including wire line open-hole log data, performance data, geological log cross sections, core data and statistical analysis. The statistical methods use production performance of analog wells and include data from operated and competitor wells. We also use geophysical data that includes data from our wells, published documents, state data-sits and data exchanges to confirm continuity of the formation. Total proved extensions and discoveries are a combination of proved developed and proved undeveloped reserves; and, extensions and discoveries for proven developed reserves are associated with non-operated assets and exploratory wells. In 2020 and 2019, the Company added 70 Bcfe and 77 Bcfe, respectively, related to exploratory and non-operated wells.
(d)    The sales of reserves in-place is related to the divestiture of our Utica JV assets and substantially all of our conventional properties. Refer to Note 4 - Acquisitions and Dispositions for more information.
(e)    The downward revisions in 2019 are due to changes in our five-year development plan due to increased dry gas investment which increased dry gas proved undeveloped reserves and decreased wet gas investment which lowered wet gas proved undeveloped reserves. The investment shift was a result of a significant decrease in forecasted liquids price realizations in the five-year plan. These five-year plan changes resulted in the removal of 872 Bcfe in reserves for wet gas investment. There was additionally a reduction of 304 Bcfe related to removal of proved undeveloped locations removed from our plans due to the SEC five-year development rule. These downward revisions were partially offset by efficiencies in operations investment in dry gas properties which increased reserves by 657 Bcfe.
(f)    Upward revisions in 2020 are due to performance revisions of 579 Bcfe related to production performance and an 853 Bcfe increase in reserves due to a decrease in operating costs in 2020. These upward revisions were partially offset by negative revisions of 677 Bcfe due to changes in our development plan related to the removal of four Utica wells and 23 Marcellus wells from our development plan.
For the Year
Ended
December 31,
2020
Proved Undeveloped Reserves (MMcfe)
Beginning Proved Undeveloped Reserves3,586,809 
Undeveloped Reserves Transferred to Developed (a)(1,152,598)
Price Revisions(380,200)
Revisions Due to Plan Changes (b)(691,054)
Revisions Due to Changes Due to Well Performance (c)810,727 
Extension and Discoveries (d)2,176,326 
Ending Proved Undeveloped Reserves(e)4,350,010 
_________
(a)    During 2020, various exploration and development drilling and evaluations were completed. Approximately, $257,952 of capital was spent in the year ended December 31, 2020 related to undeveloped reserves that were transferred to developed.
(b) The downward revisions for 2020 plan changes is due to the removal of 88 Bcfe of reserves related to 4 Utica wells and 579 Bcfe of reserves related to 23 Marcellus wells which were removed from our development plan.
(c)    The upward revisions due to a 342 Bcfe increase in reserves of liquids rich Marcellus production which requires processing due to a reduction in the Company's operating costs as a result of the CNXM take-in transaction completed in 2020. The remaining portion is due to production performance.
(d)    Extensions and discoveries are due mainly to the addition of 1,465 Bcfe related to 47 net Marcellus wells within our Southwest Pennsylvania and West Virginia dry gas operations and 711 Bcfe of 23 net Utica wells within our Central Pennsylvania and Southwest Pennsylvania operations. The Company uses reliable technologies when assigning reserves to undeveloped locations, including wire line open-hole log data, performance data, geological log cross sections, core data and statistical analysis. The statistical methods use production performance of analog wells and include data from operated and competitor wells. We also use geophysical data that includes data from our wells, published documents, state data-sites and data exchanges to confirm continuity of the formation.
(e)    Included in proved undeveloped reserves at December 31, 2020 are approximately 320,987 MMcfe of reserves that have been reported for more than five years. These reserves are all attributable to acreage within the current operating plan
identified by the life-of-mine timing maps for the Buchanan mine. The annual increase in proved undeveloped gob reserves is a result of a change in planned mining activity, which includes an expanded mining footprint, partially offset by the conversion to proved developed gob reserves. These reserves specifically relate to GOB (a rubble zone formed in the cavity created by the extraction of coal) production due to a complex fracture being generated in the overburden strata above the mined seam. Mining operations take a significant amount of time and our GOB forecasts are consistent with the future plans of the Buchanan Mine that was sold in March 2016 to Coronado IV LLC with the rights to this gas being retained by the Company. Evidence also exists that supports the continual operation of the mine beyond the current plan, unless there was an extreme circumstance resulting from an external factor. These reasons constitute the specific circumstances that exist to continue recognizing these reserves for CNX.
Schedule of Aging of Capitalized Exploratory Well Costs
The following table indicates the changes to the Company's suspended exploratory well costs for the three years ended December 31, 2020:
202020192018
Balance, Beginning of Period$8,984 $8,178 $6,388 
Additions to Capitalized Exploratory Well Costs Pending the Determination of Proved Reserves28,336 66,409 49,213 
Reclassifications to Wells, Facilities and Equipment Based on the Determination of Proved Reserves(28,258)(65,603)(46,614)
Capitalized Exploratory Well Costs Charged to Expense— — (809)
Balance, End of Period$9,062 $8,984 $8,178 
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure
The standardized measure is intended to provide a better means for comparing the value of CNX proved reserves at a given time with those of other gas producing companies than is provided by a comparison of raw proved reserve quantities.
December 31,
202020192018
Future Cash Flows (a)
Revenues
$16,577,563 $19,489,588 $26,610,100 
Production Costs
(6,071,763)(7,903,120)(7,730,451)
Development Costs (b)(1,957,519)(1,121,073)(1,600,128)
Income Tax Expense
(2,235,205)(2,720,994)(4,147,075)
Future Net Cash Flows6,313,076 7,744,401 13,132,446 
Discounted to Present Value at a 10% Annual Rate(3,677,340)(4,673,932)(8,476,989)
Total Standardized Measure of Discounted Net Cash Flows$2,635,736 $3,070,469 $4,655,457 
_________
(a)    For 2020, the reserves were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2020, adjusted for energy content and a regional price differential. For 2020, this adjusted natural gas price was $1.70 per Mcf, the adjusted oil price was $35.61 per barrel and the adjusted NGL price was $13.18 per barrel. In 2020, as the result of the CNXM take-in transaction (see Note 4 - Acquisitions and Dispositions), there was a change in production costs and development costs. Historically the production costs included contractual CNXM rates but in 2020 this was replaced with actual operating costs of the midstream infrastructure. Additionally, our development costs in 2020 include capital related to connecting undeveloped Shale wells to the midstream gathering systems; in prior years this was captured within the CNXM contractual rate within production costs. These changes resulted in an increase of $932 million to the current year Standardized Measure of Discounted Net Cash Flows.
(b)    Development costs for 2020 include $402,174 of plugging and abandonment costs and $286,724 of Midstream capital on an undiscounted pre-tax basis. On a PV-10 pre-tax discounted basis, these amounts equate to $18,357 and $231,512, respectively. The addition of Midstream capital is the result of the Merger that occurred on September 28, 2020 (See Note 4 - Acquisitions and Dispositions).

    For 2019, the reserves were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2019, adjusted for energy content and a regional price differential. For 2019, this adjusted natural gas price was $2.24 per Mcf, the adjusted oil price was $44.31 per barrel and the adjusted NGL price was $19.10 per barrel.

    For 2018, the reserves were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2018, adjusted for energy content and a regional price differential. For 2018, this adjusted natural gas price was $3.28 per Mcf, the adjusted oil price was $51.68 per barrel and the adjusted NGL price was $27.58 per barrel.
The following are the principal sources of change in the standardized measure of discounted future net cash flows for consolidated operations during:
December 31,
202020192018
Balance at Beginning of Period$3,070,469 $4,655,457 $3,131,398 
Net Changes in Sales Prices and Production Costs(819,247)(2,826,725)1,732,229 
Sales Net of Production Costs(719,441)(1,130,685)(995,630)
Net Change Due to Revisions in Quantity Estimates322,820 (252,796)307,030 
Net Change Due to Extensions, Discoveries and Improved Recovery268,196 654,027 534,052 
Development Costs Incurred During the Period434,273 739,874 844,081 
Difference in Previously Estimated Development Costs Compared to Actual Costs Incurred During the Period
(129,642)(323,922)(434,817)
Purchase of Reserves In-Place— — 209,630 
Sales of Reserves In-Place— — (434,103)
Changes in Estimated Future Development Costs(499,316)(24,469)(49,294)
Net Change in Future Income Taxes138,404 409,797 (507,410)
Timing and Other390,391 586,591 (69,087)
Accretion178,829 583,320 387,378 
     Total Discounted Cash Flow at End of Period$2,635,736 $3,070,469 $4,655,457 
v3.20.4
Supplemental Quarterly Information (unaudited) (Tables)
 12 Months Ended
Dec. 31, 2020
Quarterly Financial Information Disclosure [Abstract]  
Quarterly Financial Information
Three Months Ended
March 31,June 30,September 30,December 31,
2020202020202020
Revenue (a)$411,401 $145,088 $61,609 $622,131 
Expenses (b)$149,004 $125,548 $142,327 $134,775 
Net (Loss) Income (c)$(305,222)$(130,487)$(188,793)$195,758 
Net (Loss) Income Attributable to CNX Resources Shareholders$(329,086)$(145,749)$(204,698)$195,758 
(Loss) Earnings Per Share:
Basic (Loss) Earnings Per Share$(1.76)$(0.78)$(1.03)$0.88 
Diluted (Loss) Earnings Per Share$(1.76)$(0.78)$(1.03)$0.87 

Three Months Ended
March 31,June 30,September 30,December 31,
2019201920192019
Revenue (a)$275,234 $602,109 $526,681 $504,747 
Expenses (b)$147,928 $153,835 $153,833 $182,035 
Net (Loss) Income (c)$(64,651)$192,694 $143,960 $(240,055)
Net (Loss) Income Attributable to CNX Resources Shareholders$(87,337)$162,477 $115,538 $(271,408)
(Loss) Earnings Per Share:
Basic (Loss) Earnings Per Share$(0.44)$0.85 $0.62 $(1.45)
Diluted (Loss) Earnings Per Share$(0.44)$0.84 $0.61 $(1.45)
_________
(a) Includes natural gas, NGLs, and oil revenue; gain (loss) on commodity derivative instruments, purchased gas revenue and midstream revenue.
(b) Includes exploration and production costs and other operating expense; excludes depreciation, depletion and amortization, impairment charges, selling, general and administrative, gain (loss) on debt extinguishment, interest expense and other expense.
(c) Includes impairment charges of $61,849 and $473,045 that were recorded during the three months ended March 31, 2020 related to CNX's exploration and production properties and goodwill, respectively, and $327,400 and $119,429 that were recorded during the three months ended December 31, 2019 related to CNX's exploration and production properties and unproved properties, respectively. See Note 1 - Significant Accounting Policies in Item 8 of this Form 10-K for additional information.
v3.20.4
Significant Accounting Policies - Schedule of Cash and Restricted Cash (Details) - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Dec. 31, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]        
Cash and Cash Equivalents $ 15,617 $ 16,283 $ 17,198  
Restricted Cash, Current Portion 735 0 0  
Restricted Cash, Less Current Portion 5,247 0 0  
Total Cash, Cash Equivalents and Restricted Cash $ 21,599 $ 16,283 $ 17,198 $ 509,167
v3.20.4
Significant Accounting Policies - Trade Accounts Receivable and Allowance for Credit Losses (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]    
Receivables related to contracts with customers $ 145,929 $ 133,480
Other receivables 4,238 13,679
Trade Receivables    
Accounts Receivable, Allowance for Credit Loss [Roll Forward]    
Allowance for Credit Losses, Beginning of Period 0 0
Provision for Expected Credit Losses 84 0
Allowance for Credit Losses, End of Period 84 0
Other Receivables    
Accounts Receivable, Allowance for Credit Loss [Roll Forward]    
Allowance for Credit Losses, Beginning of Period 2,463 2,038
Provision for Expected Credit Losses 2,760 595
Write-off of Uncollectible Accounts (1,975) (170)
Allowance for Credit Losses, End of Period $ 3,248 $ 2,463
v3.20.4
Significant Accounting Policies - Property, Plant and Equipment (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Property, Plant and Equipment [Line Items]      
Depreciation, depletion and amortization $ 501,821 $ 508,463 $ 493,423
Building and Improvements | Minimum      
Property, Plant and Equipment [Line Items]      
Useful life of property, plant and equipment 10 years    
Building and Improvements | Maximum      
Property, Plant and Equipment [Line Items]      
Useful life of property, plant and equipment 45 years    
Machinery and Equipment | Minimum      
Property, Plant and Equipment [Line Items]      
Useful life of property, plant and equipment 3 years    
Machinery and Equipment | Maximum      
Property, Plant and Equipment [Line Items]      
Useful life of property, plant and equipment 25 years    
Gathering and Transmission | Minimum      
Property, Plant and Equipment [Line Items]      
Useful life of property, plant and equipment 30 years    
Gathering and Transmission | Maximum      
Property, Plant and Equipment [Line Items]      
Useful life of property, plant and equipment 40 years    
Gas Properties      
Property, Plant and Equipment [Line Items]      
Depreciation, depletion and amortization $ 400,758 $ 423,488 $ 412,588
Purchased Software      
Property, Plant and Equipment [Line Items]      
Useful life of property, plant and equipment 7 years    
v3.20.4
Significant Accounting Policies - Impairment of Proved and Unproved Properties (Details)
a in Thousands, $ in Thousands
 3 Months Ended 12 Months Ended
Mar. 31, 2020
USD ($)
Dec. 31, 2019
USD ($)
a
well
Dec. 31, 2020
USD ($)
Dec. 31, 2019
USD ($)
a
well
Dec. 31, 2018
USD ($)
Productive Wells [Line Items]          
Impairment of proved and unproved properties $ 61,849 $ 327,400 $ 61,849 $ 327,400 $ 0
Impairment of unproved properties $ 473,045 $ 119,429 0 119,429 0
Exploration and Production Related Other Costs          
Productive Wells [Line Items]          
Exploration expense     $ 14,994 $ 44,380 $ 12,033
Marcellus Shale | Central Pennsylvania          
Productive Wells [Line Items]          
Number of operated wells | well   56   56  
Net acres of land | a   51   51  
v3.20.4
Significant Accounting Policies - Impairment of Goodwill and Definite-Lived Intangible Assets (Details) - USD ($)
 1 Months Ended 12 Months Ended
Jan. 03, 2018
May 31, 2018
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Property, Plant and Equipment [Line Items]          
Impairment     $ 473,045,000 $ 0 $ 0
Impairment of intangible assets     0 0 18,650,000
Midstream          
Property, Plant and Equipment [Line Items]          
Goodwill acquired during period $ 796,359,000        
Other intangible assets $ 128,781,000        
Customer Relationships          
Property, Plant and Equipment [Line Items]          
Impairment of intangible assets     $ 0 $ 0 18,650,000
Useful life, customer relationship intangible assets     17 years    
Customer Relationships | Midstream          
Property, Plant and Equipment [Line Items]          
Impairment of intangible assets   $ 18,650,000     $ 18,650,000
Useful life, customer relationship intangible assets   17 years      
Midstream | Operating Segments | Maximum          
Property, Plant and Equipment [Line Items]          
Percentage of fair value in excess of carrying amount (less than)     10.00%    
v3.20.4
Significant Accounting Policies - Investment Plan (Details) - USD ($)
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Defined Contribution Plan Disclosure [Line Items]      
Company's matching contribution, percentage 6.00%    
Discretionary contributions to the Plan, amount $ 0 $ 0 $ 0
Total payment and cost to the Plan $ 2,976,000 $ 3,460,000 $ 3,205,000
Minimum      
Defined Contribution Plan Disclosure [Line Items]      
Discretionary contributions to the Plan, percentage 1.00%    
Maximum      
Defined Contribution Plan Disclosure [Line Items]      
Discretionary contributions to the Plan, percentage 6.00%    
v3.20.4
Earnings Per Share - Narrative (Details) - $ / shares
Sep. 28, 2020
Dec. 31, 2020
Apr. 30, 2020
Business Acquisition [Line Items]      
Entity shares issued per acquiree share (in shares) 0.88    
Convertible Debt | Convertible 2.25% Senior Notes Due 2026      
Business Acquisition [Line Items]      
Initial conversion price (in usd per share)   $ 12.84 $ 12.84
CNXM, CNX Midstream GP LLC, CNX Resources Holding LLC Merger Agreement      
Business Acquisition [Line Items]      
Entity shares issued per acquiree share (in shares) 0.88    
v3.20.4
Earnings Per Share - Anti-Dilutive Options and Units Excluded from Earnings Per Share (Details) - shares
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]      
Antidilutive securities excluded from the computation of diluted earnings per share (in shares) 7,082,480 7,659,013 3,358,260
Anti-Dilutive Options      
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]      
Antidilutive securities excluded from the computation of diluted earnings per share (in shares) 4,200,509 4,696,264 2,285,775
Anti-Dilutive Restricted Stock Units      
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]      
Antidilutive securities excluded from the computation of diluted earnings per share (in shares) 2,160,727 1,282,582 0
Anti-Dilutive Performance Share Units      
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]      
Antidilutive securities excluded from the computation of diluted earnings per share (in shares) 721,244 752,899 145,217
Anti-Dilutive Performance Share Options      
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]      
Antidilutive securities excluded from the computation of diluted earnings per share (in shares) 0 927,268 927,268
v3.20.4
Earnings Per Share - Computation of Basic and Diluted (Loss) (Details) - USD ($)
$ / shares in Units, $ in Thousands
 3 Months Ended 12 Months Ended
Dec. 31, 2020
Sep. 30, 2020
Jun. 30, 2020
Mar. 31, 2020
Dec. 31, 2019
Sep. 30, 2019
Jun. 30, 2019
Mar. 31, 2019
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Earnings Per Share [Abstract]                      
Net (Loss) Income $ 195,758 $ (188,793) $ (130,487) $ (305,222) $ (240,055) $ 143,960 $ 192,694 $ (64,651) $ (428,744) $ 31,948 $ 883,111
Less: Net Income Attributable to Non-Controlling Interest                 55,031 112,678 86,578
Net (Loss) Income Attributable to CNX Resources Shareholders $ 195,758 $ (204,698) $ (145,749) $ (329,086) $ (271,408) $ 115,538 $ 162,477 $ (87,337) $ (483,775) $ (80,730) $ 796,533
Weighted-Average Shares of Common Stock Outstanding (in shares)                 199,225,441 190,727,122 212,348,581
Effect of Diluted Shares (in shares)                 0 0 2,280,384
Weighted-Average Diluted Shares of Common Stock Outstanding (in shares)                 199,225,441 190,727,122 214,628,965
(Loss) Earnings Per Share:                      
Basic (in usd per share) $ 0.88 $ (1.03) $ (0.78) $ (1.76) $ (1.45) $ 0.62 $ 0.85 $ (0.44) $ (2.43) $ (0.42) $ 3.75
Diluted (in usd per share) $ 0.87 $ (1.03) $ (0.78) $ (1.76) $ (1.45) $ 0.61 $ 0.84 $ (0.44) $ (2.43) $ (0.42) $ 3.71
v3.20.4
Earnings Per Share - Shares of Common Stock Outstanding (Details) - shares
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Common Stock Outstanding [Roll Forward]      
Balance, Beginning of Year (in shares) 186,642,962    
Balance, End of Year (in shares) 220,440,993 186,642,962  
Common Stock      
Common Stock Outstanding [Roll Forward]      
Balance, Beginning of Year (in shares) 186,642,962 198,663,342 223,743,322
Issuance Related to Stock-Based Compensation (in shares) 882,335 909,107 814,344
Retirement of Common Stock (in shares) (4,138,527) (12,929,487) (25,894,324)
Issuance Related to CNXM Merger (in shares) 37,054,223 0 0
Balance, End of Year (in shares) 220,440,993 186,642,962 198,663,342
v3.20.4
Revenue From Contracts With Customers - Narrative (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Revenue from Contract with Customer [Abstract]    
Payment terms for contract with customers 25 days  
Receivables related to contracts with customers $ 145,929 $ 133,480
v3.20.4
Revenue From Contracts With Customers - Disaggregation of Revenue (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Disaggregation of Revenue [Line Items]      
Gain (Loss) on Commodity Derivative Instruments $ 172,982 $ 376,105 $ (30,212)
Other Revenue and Operating Income 82,459 87,992 116,723
Total Revenue and Other Operating Income 1,257,978 1,922,449 1,730,434
Total Natural Gas, NGL and Oil Revenue      
Disaggregation of Revenue [Line Items]      
Revenue 896,745 1,364,325 1,577,937
Natural Gas Revenue      
Disaggregation of Revenue [Line Items]      
Revenue 823,132 1,251,013 1,391,459
NGL Revenue      
Disaggregation of Revenue [Line Items]      
Revenue 64,138 104,139 165,883
Oil/Condensate Revenue      
Disaggregation of Revenue [Line Items]      
Revenue 9,475 9,173 20,595
Purchased Gas Revenue      
Disaggregation of Revenue [Line Items]      
Revenue $ 105,792 $ 94,027 $ 65,986
v3.20.4
Revenue From Contracts With Customers - Performance Obligation (Details)
$ in Thousands
Dec. 31, 2020
USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligations $ 120,275
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligations $ 55,500
Remaining performance obligations, expected timing of satisfaction 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligations $ 37,151
Remaining performance obligations, expected timing of satisfaction 1 year
v3.20.4
Acquisitions and Dispositions - Narrative (Details)
a in Thousands
 1 Months Ended 12 Months Ended
Sep. 28, 2020
USD ($)
shares
Aug. 31, 2018
USD ($)
a
May 02, 2018
USD ($)
well
Mar. 30, 2018
USD ($)
Jan. 03, 2018
USD ($)
Dec. 14, 2017
USD ($)
May 31, 2018
USD ($)
Dec. 31, 2020
USD ($)
a
shares
Dec. 31, 2019
USD ($)
shares
Dec. 31, 2018
USD ($)
Business Acquisition [Line Items]                    
Common stock outstanding (in shares) | shares               220,440,993 186,642,962  
Entity shares issued per acquiree share (in shares) | shares 0.88                  
Proved undeveloped acreage | a               43,713    
Proceeds from sale of assets               $ 48,322,000 $ 45,160,000 $ 511,767,000
Net gain (loss) on sale               21,224,000 35,563,000 157,015,000
Impairment of other intangibles               0 0 18,650,000
Gain on remeasurement of fair value of previously held equity interest               0 0 623,663,000
CNX Gathering                    
Business Acquisition [Line Items]                    
Ownership percentage in equity method investment           50.00%        
Customer Relationships                    
Business Acquisition [Line Items]                    
Impairment of other intangibles               0 $ 0 18,650,000
Ohio Utica Joint Venture Assets                    
Business Acquisition [Line Items]                    
Proved undeveloped acreage | a   26                
Proceeds from sale of assets   $ 381,124,000                
Net gain (loss) on sale   $ 130,710,000                
Asset Exchange Agreement with HG Energy                    
Business Acquisition [Line Items]                    
Net gain (loss) on sale     $ 286,000              
Cash proceeds from Asset Exchange Agreement     $ 7,000,000              
Number of wells added to existing commitment | well     40              
Shallow Oil, Gas, and CBM Assets in Pennsylvania and West Virginia                    
Business Acquisition [Line Items]                    
Net gain (loss) on sale       $ 4,227,000            
Cash consideration received in sale of oil and gas assets       89,921,000            
Asset retirement obligations assumed       $ 196,514,000            
CNXM                    
Business Acquisition [Line Items]                    
Common stock outstanding (in shares) | shares 42,107,071                  
CNXM | Public Unitholders                    
Business Acquisition [Line Items]                    
Ownership percentage in equity method investment 46.90%                  
CNXM | CNX                    
Business Acquisition [Line Items]                    
Ownership percentage in equity method investment 53.10%                  
CNXM CNX Midstream GP LLC CNX Resources Holding LLC Merger Agreements                    
Business Acquisition [Line Items]                    
Number of shares issued in acquisition | shares 37,054,223                  
Cash consideration transferred $ 384,623,000                  
Transaction costs               $ 11,271,000    
Midstream                    
Business Acquisition [Line Items]                    
Cash consideration transferred         $ 305,000,000          
Fair value of previously held equity interest         $ 799,033,000 $ 799,033,000        
Gain on remeasurement of fair value of previously held equity interest           $ 623,663,000        
Midstream | Customer Relationships                    
Business Acquisition [Line Items]                    
Impairment of other intangibles             $ 18,650,000     $ 18,650,000
v3.20.4
Acquisitions and Dispositions - Consideration Given In Acquisition (Details) - Midstream - USD ($)
$ in Thousands
Jan. 03, 2018
Dec. 14, 2017
Business Acquisition [Line Items]    
Cash Consideration $ 305,000  
CNX Gathering Cash on Hand at January 3, 2018 Distributed to Noble 2,620  
Fair Value of Previously Held Equity Interest 799,033 $ 799,033
Total Estimated Fair Value of Consideration Transferred $ 1,106,653  
v3.20.4
Acquisitions and Dispositions - Fair Value of Net Assets Acquired (Details) - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Jan. 03, 2018
Fair Value of Liabilities Assumed:      
Goodwill $ 323,314 $ 796,359  
Midstream      
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets [Abstract]      
Cash and Cash Equivalents     $ 8,348
Accounts and Notes Receivable     21,199
Prepaid Expense     2,006
Other Current Assets     163
Property, Plant and Equipment, net     1,043,340
Intangible Assets     128,781
Other     593
Total Assets Acquired     1,204,430
Fair Value of Liabilities Assumed:      
Accounts Payable     26,059
CNXM Revolving Credit Facility     149,500
Total Liabilities Assumed     175,559
Total Identifiable Net Assets     1,028,871
Fair Value of Noncontrolling Interest in CNXM     (718,577)
Goodwill     796,359
Net Assets Acquired     $ 1,106,653
v3.20.4
Acquisitions and Dispositions - Post Acquisition Operating Results (Details) - Midstream - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Business Acquisition [Line Items]      
Other Revenue and Operating Income $ 64,710 $ 74,314 $ 89,781
Earnings Before Income Tax $ 156,818 $ 166,654 $ 133,811
v3.20.4
Stock Repurchase (Details) - USD ($)
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Jan. 26, 2021
Equity [Abstract]        
Stock repurchased during period (in shares) 4,138,527 12,929,487 25,894,324  
Treasure stock acquired (in usd per share) $ 10.43 $ 8.91 $ 14.80  
Stock repurchased and retired $ 43,247,000 $ 115,477,000 $ 383,752,000  
Subsequent Event [Line Items]        
Share repurchase program, authorized amount $ 750,000,000      
Subsequent Event        
Subsequent Event [Line Items]        
Share repurchase program, authorized amount       $ 900,000,000
Amount available under the current stock repurchase program       $ 245,000,000
v3.20.4
Income Taxes - Income Tax Benefits (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Current:      
U.S. Federal $ (55,799) $ (51,243) $ (130,003)
U.S. State 12 (113) 0
Current income tax (benefit) (55,787) (51,356) (130,003)
Deferred:      
U.S. Federal (83,080) 47,717 319,813
U.S. State (35,220) 31,375 25,747
Deferred income tax (benefit) (118,300) 79,092 345,560
Income Tax (Benefit) Expense / Effective Rate $ (174,087) $ 27,736 $ 215,557
v3.20.4
Income Taxes - Net Deferred Tax Assets/Liabilities (Details) - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Deferred Tax Assets:    
Net Operating Loss- Federal $ 215,936 $ 202,913
Net Operating Loss - State 129,641 130,430
Foreign Tax Credit 43,194 43,194
Operating Lease Right-of-Use Assets 28,085 47,849
Gas Well Closing 24,251 17,888
Salary Retirement 11,478 9,236
Equity Compensation 6,639 9,308
Alternative Minimum Tax 0 51,241
Interest Limitation 0 25,734
Other 9,416 10,030
Total Deferred Tax Assets 468,640 547,823
Valuation Allowance (123,098) (125,054)
Net Deferred Tax Assets 345,542 422,769
Deferred Tax Liabilities:    
Property, Plant and Equipment (649,917) (593,401)
Investment in Partnership (85,882) (145,424)
Gas Derivatives (26,882) (105,721)
Operating Lease Liabilities (28,287) (46,640)
Discount on Convertible Notes (18,097) 0
Advance Gas Royalties (2,519) (3,337)
Other (211) (4,354)
Total Deferred Tax Liabilities (811,795) (898,877)
Net Deferred Tax Liability $ (466,253) $ (476,108)
v3.20.4
Income Taxes - Narrative (Details) - USD ($)
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Valuation Allowance [Line Items]      
Federal net operating losses $ 215,936,000 $ 202,913,000  
Deferred tas asset, federal alternative minimum tax credit 0 51,241,000  
Decrease in federal alternative minimum tax 51,241,000    
Valuation allowance on foreign tax credits 43,194,000 43,194,000  
Valuation allowance 123,098,000 125,054,000  
Deferred tax asset related to state operating losses 129,641,000 130,430,000  
Reduction in income tax expense due to non-controlling interest 11,556,000 23,662,000 $ 18,181,000
Benefit through realization of the Federal NOLs     23,483,000
AMT credit carry-forward     $ 12,413,000
Unrecognized tax benefits that would impact effective tax rate 31,891,000 31,516,000  
Increase in unrecognized tax benefits resulting from tax position taken on prior year return 1,726,000 0  
Reduction to unrecognized tax benefits, from position taken on state tax return 1,351,000 0  
Accrued liability relating to uncertain tax positions 0 0  
Interest related to income tax deficiencies 0 0  
Accrued liabilities for tax penalties 0 0  
State Operating Losses      
Valuation Allowance [Line Items]      
Valuation allowance $ 79,197,000 $ 81,202,000  
v3.20.4
Income Taxes - Effective Tax Rate Reconciliation (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Amount      
Statutory U.S. Federal Income Tax Rate $ (126,595) $ 12,534 $ 230,721
Net Effect of State Income Taxes (32,336) 1,333 60,814
Non-Controlling Interest (11,556) (23,662) (18,181)
Uncertain Tax Positions 375 0 (4,265)
Accrual to Tax Return Reconciliation 13 603 3,028
Effect of Equity Compensation 4,311 8,771 0
Effect of Change in State Valuation Allowance (2,004) 33,238 (22,684)
Effect of Change in Federal Valuation Allowance 48 (2,640) (18,110)
Other Deferred Adjustments 1,166 (1,691) 5,957
Effect of Federal and State Rate Reductions (1,450) (3,842) (27,429)
Effect of Federal Tax Credits (6,284) 2,881 1,208
Other 225 211 4,498
Income Tax (Benefit) Expense / Effective Rate $ (174,087) $ 27,736 $ 215,557
Percent      
Statutory U.S. Federal Income Tax Rate 21.00% 21.00% 21.00%
Net Effect of State Income Taxes 5.50% 2.20% 5.60%
Non-Controlling Interest 1.90% (39.60%) (1.70%)
Uncertain Tax Positions (0.10%) 0.00% (0.40%)
Accrual to Tax Return Reconciliation 0.00% 1.00% 0.30%
Effect of Equity Compensation (0.70%) 14.70% 0.00%
Effect of Change in State Valuation Allowance 0.30% 55.60% (2.10%)
Effect of Change in Federal Valuation Allowance 0.00% (4.40%) (1.70%)
Other Deferred Adjustments (0.20%) (2.80%) 0.60%
Effect of Federal and State Rate Reductions 0.20% (6.40%) (2.50%)
Effect of Federal Tax Credits 1.00% 4.80% 0.10%
Other 0.00% 0.40% 0.40%
Income Tax (Benefit) Expense / Effective Rate 28.90% 46.50% 19.60%
v3.20.4
Income Taxes - Reconciliation of Unrecognized Tax Benefits (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]    
Balance at Beginning of Period $ 31,516 $ 31,516
Increase in Unrecognized Tax Benefits Resulting from Tax Positions Taken During Prior Periods 1,726 0
Reduction in Unrecognized Tax Benefits Because of the Lapse of the Applicable Statute of Limitations (1,351) 0
Balance at End of Period $ 31,891 $ 31,516
v3.20.4
Asset Retirement Obligations (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]    
Balance, Beginning of Year $ 68,454 $ 38,554
Obligations Divested 703 0
Accretion Expense 11,067 9,458
Obligations Incurred 2,806 2,933
Obligations Settled (7,905) (4,231)
Revisions in Estimated Cash Flows 19,449 21,740
Balance, End of Year $ 93,168 $ 68,454
v3.20.4
Property, Plant and Equipment - Summary (Details) - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Property, Plant and Equipment [Abstract]    
Intangible Drilling Cost $ 4,965,252 $ 4,688,497
Gas Gathering Equipment 2,510,917 2,463,866
Proved Gas Properties 1,253,094 1,208,046
Gas Wells and Related Equipment 1,120,061 1,042,000
Unproved Gas Properties 725,705 755,590
Surface Land and Other Equipment 199,322 226,285
Other 189,645 187,722
Total 10,963,996 10,572,006
Less: Accumulated Depreciation, Depletion and Amortization 3,938,451 3,435,431
Total Property, Plant and Equipment—Net $ 7,025,545 $ 7,136,575
v3.20.4
Property, Plant and Equipment - Narrative (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Property, Plant and Equipment [Abstract]    
Interest costs capitalized $ 1,328 $ 5,482
v3.20.4
Property, Plant and Equipment - Assets Amortized by Units of Production (Details) - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Property, Plant and Equipment [Line Items]    
Unproved Gas Properties $ 725,705 $ 755,590
Total 10,963,996 10,572,006
Assets amortized by units of production    
Property, Plant and Equipment [Line Items]    
Unproved Gas Properties 725,705 755,590
Advance Royalties 9,676 12,770
Total $ 735,381 $ 768,360
v3.20.4
Goodwill and Other Intangible Assets - Narrative (Details) - USD ($)
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Jan. 03, 2018
Goodwill [Line Items]        
Goodwill $ 323,314,000 $ 796,359,000    
Impairment 473,045,000 0 $ 0  
Impairment of intangible assets 0 0 18,650,000  
Amortization expense 6,552,000 6,552,000 6,931,000  
Estimated annual amortization expense expected, 2021 6,552,000      
Estimated annual amortization expense expected, 2022 6,552,000      
Estimated annual amortization expense expected, 2023 6,552,000      
Estimated annual amortization expense expected, 2024 6,552,000      
Estimated annual amortization expense expected, 2025 6,552,000      
Customer Relationships        
Goodwill [Line Items]        
Impairment of intangible assets $ 0 $ 0 $ 18,650,000  
Useful life, customer relationship intangible assets 17 years      
Midstream Acquisition        
Goodwill [Line Items]        
Goodwill $ 323,314,000     $ 796,359,000
Other intangible assets       $ 128,781,000
v3.20.4
Goodwill and Other Intangible Assets - Changes in Carrying Amount of Goodwill (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Goodwill [Roll Forward]      
Beginning Balance $ 796,359    
Impairment 473,045 $ 0 $ 0
Ending Balance $ 323,314 $ 796,359  
v3.20.4
Goodwill and Other Intangible Assets - Carrying Amount and Accumulated Amortization of Intangible Assets (Details) - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Goodwill and Intangible Assets Disclosure [Abstract]    
Gross Amortizable Asset - Customer Relationships $ 109,752 $ 109,752
Less: Accumulated Amortization - Customer Relationships 19,657 13,105
Total Other Intangible Assets, net $ 90,095 $ 96,647
v3.20.4
Revolving Credit Facilities (Details)
 1 Months Ended 12 Months Ended
Apr. 30, 2020
USD ($)
Apr. 30, 2019
USD ($)
Dec. 31, 2020
USD ($)
Nov. 30, 2020
USD ($)
Oct. 31, 2020
USD ($)
Dec. 31, 2019
USD ($)
Jun. 30, 2019
USD ($)
Dec. 31, 2018
Short-term Debt [Line Items]                
Debt instrument, face amount $ 1,000              
Value of proved reserves, percentage to mortgage     85.00%          
Value of proved developing producing reserves, percentage to mortgage     85.00%          
Federal Funds Open Rate                
Short-term Debt [Line Items]                
Basis spread on variable rate (as a percent)     0.50%          
Federal Funds Open Rate | CNXM                
Short-term Debt [Line Items]                
Basis spread on variable rate (as a percent)     0.50%          
One-Month LIBOR                
Short-term Debt [Line Items]                
Basis spread on variable rate (as a percent)     1.00%          
One-Month LIBOR | CNXM                
Short-term Debt [Line Items]                
Basis spread on variable rate (as a percent)     1.00%          
One-Month LIBOR | Minimum                
Short-term Debt [Line Items]                
Basis spread on variable rate (as a percent)     0.75%          
One-Month LIBOR | Minimum | CNXM                
Short-term Debt [Line Items]                
Basis spread on variable rate (as a percent)     0.50%          
One-Month LIBOR | Maximum                
Short-term Debt [Line Items]                
Basis spread on variable rate (as a percent)     1.75%          
One-Month LIBOR | Maximum | CNXM                
Short-term Debt [Line Items]                
Basis spread on variable rate (as a percent)     1.50%          
LIBOR | Minimum                
Short-term Debt [Line Items]                
Basis spread on variable rate (as a percent)     1.75%          
LIBOR | Minimum | CNXM                
Short-term Debt [Line Items]                
Basis spread on variable rate (as a percent)     1.50%          
LIBOR | Maximum                
Short-term Debt [Line Items]                
Basis spread on variable rate (as a percent)     2.75%          
LIBOR | Maximum | CNXM                
Short-term Debt [Line Items]                
Basis spread on variable rate (as a percent)     2.50%          
Senior Notes due in January 2029 | Debt Instrument, Issuance, Period Two                
Short-term Debt [Line Items]                
Debt instrument, face amount       $ 500,000,000        
Stated rate, debt instrument       6.00%        
5.875% Senior Notes due 2022                
Short-term Debt [Line Items]                
Debt instrument, face amount           $ 894,307,000    
Stated rate, debt instrument     5.875%     0.00059%   5.875%
5.875% Senior Notes due 2022 | Minimum | CNXM                
Short-term Debt [Line Items]                
Debt instrument, face amount     $ 150,000,000          
5.875% Senior Notes due 2022 | Maximum | CNXM                
Short-term Debt [Line Items]                
Debt instrument, face amount     150,000,000          
Senior Notes due March 2026                
Short-term Debt [Line Items]                
Debt instrument, face amount     $ 400,000,000     $ 400,000,000    
Stated rate, debt instrument     0.065%     0.065%    
Revolving Credit Facility                
Short-term Debt [Line Items]                
Maximum borrowing capacity 1,900,000,000 $ 2,100,000,000   $ 1,775,000,000        
Accordion feature, increased commitment   $ 3,000,000,000            
Net leverage ratio   3.00            
Percentage of aggregate commitments available under credit facility   15.00%            
Amount of balance sheet cash that may have on hand 150,000,000              
Initial borrowing base 1,900,000,000     $ 1,775,000,000 $ 1,900,000,000      
Debt instrument, face amount             $ 160,000,000  
Maximum net leverage ratio     4.00          
Minimum current ratio     1.00          
Borrowings outstanding     $ 160,800,000     $ 661,000,000    
Letters of credit outstanding     185,272,000     204,726,000    
Borrowings and issuance of letters of credit remaining capacity     1,428,928,000     1,234,274,000    
Revolving Credit Facility | CNXM                
Short-term Debt [Line Items]                
Maximum borrowing capacity   $ 600,000,000            
Borrowings outstanding     291,000,000     311,750,000    
Letters of credit outstanding     $ 30,000          
Increase in available borrowings   250,000,000            
Letters of credit, maximum borrowing capacity   $ 100,000,000            
Interest coverage ratio     2.50          
Current borrowing capacity     $ 308,970,000     $ 288,250,000    
Revolving Credit Facility | Minimum | CNXM                
Short-term Debt [Line Items]                
Maximum net leverage ratio     5.25          
Maximum net leverage ratio     4.75          
Revolving Credit Facility | Maximum | CNXM                
Short-term Debt [Line Items]                
Maximum net leverage ratio     5.50          
Maximum net leverage ratio     5.25          
Secured leverage ratio     3.50          
Letter of Credit                
Short-term Debt [Line Items]                
Maximum borrowing capacity $ 650,000,000              
v3.20.4
Other Accrued Liabilities (Details) - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Other Liabilities Disclosure [Abstract]    
Royalties $ 72,401 $ 74,061
Accrued Interest 26,549 30,862
Short-Term Incentive Compensation 20,340 21,030
Transportation Charges 15,969 16,533
Deferred Revenue 10,986 13,964
Accrued Other Taxes 10,580 9,115
Accrued Payroll & Benefits 5,009 6,248
Other 26,697 37,610
Current Portion of Long-Term Liabilities:    
Asset Retirement Obligations 8,455 5,076
Salary Retirement 1,787 1,587
Total Other Accrued Liabilities $ 198,773 $ 216,086
v3.20.4
Long-Term Debt - Schedule of Long-Term Debt (Details) - USD ($)
Dec. 31, 2020
Apr. 30, 2020
Mar. 31, 2020
Dec. 31, 2019
Jun. 30, 2019
Dec. 31, 2018
Debt Instrument [Line Items]            
Debt instrument, face amount   $ 1,000        
Less: Unamortized Debt Issuance Costs $ 26,852,000     $ 8,990,000    
Long-term Debt Including Current Maturities 2,424,001,000     2,754,443,000    
Less: Amounts Due in One Year 22,574,000     0    
Long-Term Debt $ 2,401,427,000     $ 2,754,443,000    
Senior Notes due March 2027 at 7.25%            
Debt Instrument [Line Items]            
Stated rate, debt instrument 0.0725%     0.0725%    
Debt instrument, face amount $ 700,000,000     $ 500,000,000    
Debt Instrument, unamortized premium 6,686,000          
Long-term Debt Including Current Maturities $ 706,686,000     500,000,000    
Senior Notes due January 2029 at 6.00%            
Debt Instrument [Line Items]            
Stated rate, debt instrument 0.06%          
Long-term Debt Including Current Maturities $ 500,000,000     $ 0    
Senior Notes due March 2026            
Debt Instrument [Line Items]            
Stated rate, debt instrument 0.065%     0.065%    
Debt instrument, face amount $ 400,000,000     $ 400,000,000    
Debt instrument, unamortized discount 3,875,000     4,625,000    
Long-term Debt Including Current Maturities $ 396,125,000     395,375,000    
Senior Notes due May 2026            
Debt Instrument [Line Items]            
Stated rate, debt instrument 0.0225%          
Debt instrument, face amount $ 345,000,000          
Debt instrument, unamortized discount 107,735,000          
Long-term Debt Including Current Maturities $ 237,265,000     $ 0    
5.875% Senior Notes due 2022            
Debt Instrument [Line Items]            
Stated rate, debt instrument 5.875%     0.00059%   5.875%
Debt instrument, face amount       $ 894,307,000    
Debt Instrument, unamortized premium       1,001,000    
Long-term Debt Including Current Maturities $ 0     895,308,000    
Revolving Credit Facility            
Debt Instrument [Line Items]            
Debt instrument, face amount         $ 160,000,000  
Revolving Credit Facility | CNX Midstream Partners LP Revolving Credit Facility            
Debt Instrument [Line Items]            
Long-term Debt Including Current Maturities 291,000,000     311,750,000    
Revolving Credit Facility | CNX Revolving Credit Facility            
Debt Instrument [Line Items]            
Long-term Debt Including Current Maturities 160,800,000     661,000,000    
Credit Facility            
Debt Instrument [Line Items]            
Debt instrument, face amount     $ 175,000,000      
Credit Facility | Cardinal States Gathering Company Credit Facility            
Debt Instrument [Line Items]            
Debt instrument, face amount 114,985,000          
Debt instrument, unamortized discount 1,126,000          
Long-term Debt Including Current Maturities 113,859,000     0    
Credit Facility | CSG Holdings II LLC Credit Facility            
Debt Instrument [Line Items]            
Debt instrument, face amount 45,559,000          
Debt instrument, unamortized discount 441,000          
Long-term Debt Including Current Maturities $ 45,118,000     $ 0    
v3.20.4
Long-Term Debt - Maturities of Long-Term Debt (Details)
$ in Thousands
Dec. 31, 2020
USD ($)
Amount  
2021 $ 22,574
2022 23,712
2023 24,469
2024 474,366
2025 23,057
Thereafter 1,989,166
Total Long-Term Debt Maturities $ 2,557,344
v3.20.4
Long-Term Debt - Narrative (Details)
 1 Months Ended 12 Months Ended
Sep. 30, 2020
USD ($)
Apr. 30, 2020
USD ($)
day
$ / shares
Dec. 31, 2020
USD ($)
$ / shares
Dec. 31, 2019
USD ($)
Dec. 31, 2018
USD ($)
Nov. 30, 2020
USD ($)
Mar. 31, 2020
USD ($)
Jun. 30, 2019
USD ($)
Apr. 30, 2019
USD ($)
Debt Instrument [Line Items]                  
Debt instrument, face amount   $ 1,000              
Gain on debt extinguishment     $ 10,101,000 $ (7,614,000) $ (54,118,000)        
Proceeds from issuance of Convertible Notes     334,650,000 0 0        
Cost incurred with Capped Calls     35,673,000 0 $ 0        
Income tax benefit capped call   9,322,000              
Net impact of Capped Calls     26,351,000            
Senior Notes due in January 2029 | Debt Instrument, Issuance, Period Two                  
Debt Instrument [Line Items]                  
Debt instrument, face amount           $ 500,000,000      
Stated rate, debt instrument           6.00%      
Senior Notes due March 2027 at 7.25%                  
Debt Instrument [Line Items]                  
Debt instrument, face amount     $ 700,000,000 $ 500,000,000          
Stated rate, debt instrument     0.0725% 0.0725%          
5.875% Senior Notes due 2022                  
Debt Instrument [Line Items]                  
Debt instrument, face amount       $ 894,307,000          
Stated rate, debt instrument     5.875% 0.00059% 5.875%        
Purchase of outstanding debt     $ 894,307,000 $ 400,000,000 $ 411,375,000        
Gain on debt extinguishment     10,101,000 (7,614,000) (15,320,000)        
Senior Notes due March 2026                  
Debt Instrument [Line Items]                  
Debt instrument, face amount     $ 400,000,000 $ 400,000,000          
Stated rate, debt instrument     0.065% 0.065%          
Senior Notes due April 2023                  
Debt Instrument [Line Items]                  
Debt instrument, face amount         $ 500,000,000        
Stated rate, debt instrument         8.00%        
Gain on debt extinguishment         $ 38,798,000        
Convertible 2.25% Senior Notes Due 2026 | Convertible Debt                  
Debt Instrument [Line Items]                  
Debt instrument, face amount   $ 345,000,000              
Stated rate, debt instrument   2.25%              
Conversion rate   77.8816              
Initial conversion price (in usd per share) | $ / shares   $ 12.84 $ 12.84            
Debt issuance costs gross   $ 10,350,000              
Convertible 2.25% Senior Notes Due 2026 | Convertible Debt | Debt Instrument, Redemption, Period One                  
Debt Instrument [Line Items]                  
Debt Instrument, Convertible, Threshold Percentage of Stock Price Trigger   130.00%              
Threshold trading days | day   20              
Threshold consecutive trading days | day   30              
Convertible 2.25% Senior Notes Due 2026 | Convertible Debt | Debt Instrument, Redemption, Period Two                  
Debt Instrument [Line Items]                  
Debt Instrument, Convertible, Threshold Percentage of Stock Price Trigger   98.00%              
Threshold trading days | day   5              
Threshold consecutive trading days | day   10              
Convertible 2.25% Senior Notes Due 2026, Additional Option To Initial Purchasers | Convertible Debt                  
Debt Instrument [Line Items]                  
Debt instrument, face amount   $ 45,000,000              
Convertible 2.25% Senior Notes Due 2026, Liability Component | Convertible Debt                  
Debt Instrument [Line Items]                  
Debt issuance costs gross   7,024,000              
Convertible 2.25% Senior Notes Due 2026, Equity Component | Convertible Debt                  
Debt Instrument [Line Items]                  
Debt issuance costs gross   3,326,000              
Private Placement | Senior Notes due March 2027 at 7.25% | Debt Instrument, Issuance, Period Two                  
Debt Instrument [Line Items]                  
Debt instrument, face amount $ 200,000,000                
Stated rate, debt instrument 7.25%   7.25% 7.25%          
Unamortized premium $ 7,000,000                
Redemption price, percentage of principal amount redeemed 103.50%                
Effective yield (as a percent) 6.34%                
Capped Call Transaction                  
Debt Instrument [Line Items]                  
Cost incurred with Capped Calls   35,673,000              
Net impact of Capped Calls   $ 26,351,000              
Minimum | Capped Call Transaction | Call Option                  
Debt Instrument [Line Items]                  
Price per share (in usd per share) | $ / shares   $ 12.84              
Maximum | Capped Call Transaction | Call Option                  
Debt Instrument [Line Items]                  
Price per share (in usd per share) | $ / shares   $ 18.19              
Revolving Credit Facility                  
Debt Instrument [Line Items]                  
Debt instrument, face amount               $ 160,000,000  
Maximum borrowing capacity   $ 1,900,000,000       $ 1,775,000,000     $ 2,100,000,000
Credit Facility                  
Debt Instrument [Line Items]                  
Debt instrument, face amount             $ 175,000,000    
Credit Facility | CSG Holdings II LLC Credit Facility                  
Debt Instrument [Line Items]                  
Debt instrument, face amount     $ 45,559,000            
Maximum borrowing capacity     $ 50,000,000            
Credit Facility | CSG Holdings II LLC Credit Facility | 3-Month LIBOR                  
Debt Instrument [Line Items]                  
Basis spread on variable rate (as a percent)     6.75%            
Credit Facility | Cardinal States Gathering Company Credit Facility                  
Debt Instrument [Line Items]                  
Debt instrument, face amount     $ 114,985,000            
Maximum borrowing capacity     $ 125,000,000            
Credit Facility | Cardinal States Gathering Company Credit Facility | 3-Month LIBOR                  
Debt Instrument [Line Items]                  
Basis spread on variable rate (as a percent)     4.50%            
v3.20.4
Long-Term Debt - Schedule of Convertible Debt (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Debt Instrument [Line Items]    
Principal $ 2,557,344  
Net Carrying Amount 2,424,001 $ 2,754,443
Equity Component, net of Purchase Discounts and Issuance Costs 78,317  
Convertible Debt | Convertible 2.25% Senior Notes Due 2026    
Debt Instrument [Line Items]    
Principal 345,000  
Unamortized Discount (101,367)  
Unamortized Issuance Costs (6,368)  
Net Carrying Amount 237,265  
Equity Component, net of Purchase Discounts and Issuance Costs $ 78,317  
v3.20.4
Long-Term Debt - Schedule of Interest (Details) - Convertible Debt - Convertible 2.25% Senior Notes Due 2026
$ in Thousands
 12 Months Ended
Dec. 31, 2020
USD ($)
Debt Instrument [Line Items]  
Contractual Interest Expense $ 5,175
Amortization of Debt Discount 9,516
Amortization of Issuance Costs 655
Total Interest Expense $ 15,346
v3.20.4
Leases - Narrative (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2018
Dec. 31, 2020
Lessee, Lease, Description [Line Items]    
Operating leases rent expense $ 21,441  
Minimum    
Lessee, Lease, Description [Line Items]    
Lease renewal term   1 year
Maximum    
Lessee, Lease, Description [Line Items]    
Lease renewal term   10 years
v3.20.4
Leases - Components of Lease Cost (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Leases [Abstract]    
Operating Lease Cost $ 74,703 $ 73,809
Finance Lease Cost:    
Amortization of Right-of-Use Assets 4,959 5,242
Interest on Lease Liabilities 739 1,241
Short-term Lease Cost 3,252 5,547
Variable Lease Cost 9,634 17,337
Total Lease Cost $ 93,287 $ 103,176
v3.20.4
Leases - Balance Sheet Information (Details) (Details) - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Operating Leases:    
Operating Lease, Right-of-Use Asset $ 108,683 $ 187,097
Current Portion of Operating Lease Obligations 52,575 61,670
Operating Lease Obligations 53,235 110,466
Total Operating Lease Liabilities 105,810 172,136
Finance Leases:    
Property, Plant and Equipment 72,653 72,916
Less—Accumulated Depreciation, Depletion and Amortization 67,508 63,008
Property, Plant and Equipment—Net 5,145 9,908
Current Portion of Finance Lease Obligations 6,876 7,164
Finance Lease Obligations 1,057 7,706
Total Finance Lease Liabilities $ 7,933 $ 14,870
v3.20.4
Leases - Supplemental Cash Flow Information (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:    
Operating Cash Flows from Operating Leases $ 62,610 $ 66,827
Operating Cash Flows from Finance Leases 739 1,241
Financing Cash Flows from Finance Leases 7,155 7,149
Right-of-Use Assets Obtained in Exchange for Lease Obligations:    
Operating Leases 4,027 15,347
Finance Leases $ 257 $ 1,846
v3.20.4
Leases - Maturity of Lease Liability (Details) - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Operating Leases    
2021 $ 56,190  
2022 21,592  
2023 5,453  
2024 5,433  
2025 4,824  
Thereafter 25,996  
Total Lease Payments 119,488  
Less: Interest 13,678  
Present Value of Lease Liabilities 105,810 $ 172,136
Finance Leases    
2021 7,138  
2022 446  
2023 442  
2024 155  
2025 38  
Thereafter 40  
Total Lease Payments 8,259  
Less: Interest 326  
Present Value of Lease Liabilities $ 7,933 $ 14,870
v3.20.4
Leases - Terms and Discount Rates (Details)
Dec. 31, 2020
Dec. 31, 2019
Leases [Abstract]    
Operating leases, weighted average remaining lease term 4 years 8 months 4 days 4 years 4 months 20 days
Finance leases, weighted average remaining lease term 1 year 4 months 13 days 2 years 1 month 28 days
Operating leases, weighted average discount rate 4.40% 4.96%
Finance leases, weighted average discount rate 6.33% 6.92%
v3.20.4
Pension - Reconciliation of Changed in Benefit Obligations, Plan Assets, and Funded Status of Pension Benefits (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]      
Curtailment gain due to plan freeze $ 0 $ 0 $ 416
Change in Benefit Obligation:      
Benefit Obligation at Beginning of Period 40,196 33,569  
Service Cost 247 209 302
Interest Cost 1,179 1,338 1,265
Actuarial Loss 4,098 4,865  
Plan Amendments 0 1,728  
Benefits and Other Payments (1,644) (1,513)  
Benefit Obligation at End of Period 44,076 40,196 33,569
Change in Plan Assets:      
Fair Value of Plan Assets at Beginning of Period 0 0  
Company Contributions 1,644 1,513  
Benefits and Other Payments (1,644) (1,513)  
Fair Value of Plan Assets at End of Period 0 0 $ 0
Funded Status:      
Current Liabilities (1,787) (1,587)  
Noncurrent Liabilities (42,289) (38,609)  
Net Obligation Recognized (44,076) (40,196)  
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of:      
Net Actuarial Loss 19,075 15,361  
Prior Service Cost 1,506 1,727  
Total 20,581 17,088  
Net Amount Recognized 15,184 12,605  
Accumulated Defined Benefit Plans Adjustment Attributable to Parent      
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of:      
Less: Tax Benefit $ 5,397 $ 4,483  
v3.20.4
Pension - Components of Net Periodic Benefit Cost (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Retirement Benefits [Abstract]      
Service Cost $ 247 $ 209 $ 302
Interest Cost 1,179 1,338 1,265
Amortization of Prior Service Cost (Credit) 221 (17) (193)
Recognized Net Actuarial Loss 383 242 865
Curtailment Gain 0 0 (416)
Net Periodic Benefit Cost $ 2,030 $ 1,772 $ 1,823
v3.20.4
Pension - Accumulated Benefit Obligation in Excess of Plan Assets (Details) - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Retirement Benefits [Abstract]    
Projected Benefit Obligation $ 44,076 $ 40,196
Accumulated Benefit Obligation 43,886 40,196
Fair Value of Plan Assets $ 0 $ 0
v3.20.4
Pension - Weighted Average Assumptions (Details)
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]      
Discount Rate 2.47% 3.36%  
Rate of Compensation Increase 0.00% 0.00%  
Interest Credited Rate 2.26% 3.01%  
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]      
Discount Rate 3.36% 4.37% 4.28%
Rate of Compensation Increase 0.00% 3.63% 4.05%
Interest Credited Rate 2.47% 3.39% 3.94%
v3.20.4
Pension - Expected Future Benefit Payment (Details)
$ in Thousands
Dec. 31, 2020
USD ($)
Retirement Benefits [Abstract]  
2021 $ 1,787
2022 1,846
2023 1,913
2024 1,977
2025 2,049
Year 2026-2030 $ 11,172
v3.20.4
Stock-Based Compensation - Narrative (Details)
$ / shares in Units, $ in Thousands
 12 Months Ended
Sep. 28, 2020
shares
Dec. 31, 2020
USD ($)
$ / shares
shares
Dec. 31, 2019
USD ($)
$ / shares
shares
Dec. 31, 2018
USD ($)
May 31, 2020
shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]          
Common stock available for grant (in shares) | shares   14,081,055      
Stock-based compensation expense | $   $ 12,897 $ 36,545 $ 18,930  
Deferred tax benefit from stock-based compensation | $   2,134 $ 3,955 4,169  
Unrecognized compensation cost related to nonvested awards | $   $ 10,830      
Recognition period, weighted average   1 year 9 months 25 days      
Entity shares issued per acquiree share (in shares) | shares 0.88        
Options outstanding (in shares) | shares   4,200,509 4,696,264    
Weighted average exercise price (in usd per share) | $ / shares   $ 15.32 $ 18.05    
Minimum | Southeastern Asset Management, Inc.          
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]          
Ownership percentage in equity method investment   25.00% 25.00%    
Board Approved Share Increase          
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]          
Number of shares approved for increase in available for issuance (in shares) | shares         10,775,000
Stock Option          
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]          
Award conversation ratio   1      
Award vesting period   3 years      
Intrinsic value of options exercised | $   $ 1,263 $ 175 2,077  
Cash received from option exercises | $   2,052 546 1,714  
Tax impact from option exercises | $   $ 328 46 569  
Stock Option | Director          
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]          
Award vesting period   1 year      
Options outstanding (in shares) | shares   490,352      
Stock Option | Employee          
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]          
Options outstanding (in shares) | shares   3,710,157      
Performance Share Units          
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]          
Award conversation ratio   1.62      
Vested (in shares) | shares   274,716      
Fair value of RSUs granted during the year | $   $ 3,826 6,741 8,570  
Fair value of performance share units vested | $   $ 1,926 $ 4,668 7,547  
Performance Share Units | Accelerated Vesting          
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]          
Vested (in shares) | shares     903,100    
Performance Share Units | Granted in 2016-2019          
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]          
Award vesting period   5 years      
Award vesting rights percentage   20.00%      
Performance Share Units | Granted in 2020          
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]          
Award vesting period   3 years      
Award vesting rights percentage   33.30%      
Restricted Stock Units          
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]          
Vested (in shares) | shares   577,834      
Fair value of RSUs granted during the year | $   $ 10,619 $ 10,844 13,768  
Fair value of restricted stock units vested during the year | $   $ 4,798 $ 10,391 $ 6,437  
Restricted Stock Units | Director          
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]          
Award vesting period   1 year      
Restricted Stock Units | Accelerated Vesting          
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]          
Vested (in shares) | shares     473,126    
Restricted Stock Units and Performance Share Units          
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]          
Long-term equity-based compensation expense | $     $ 19,654    
Performance Options          
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]          
Options outstanding (in shares) | shares     927,268    
Weighted average exercise price (in usd per share) | $ / shares     $ 39.00    
v3.20.4
Stock-Based Compensation - Options Granted, Assumptions and Weighted Average Fair Value (Details) - Stock Option - USD ($)
$ / shares in Units, $ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Fair value of options granted during the year $ 1,066 $ 50 $ 143
Weighted average fair value of grants (in usd per share) $ 3.56 $ 3.48 $ 6.50
Risk-free interest rate (as a percent) 1.61% 2.13% 2.66%
Expected dividend yield (as a percent) 0.00% 0.00% 0.00%
Expected forfeiture rate (as a percent) 0.00% 0.00% 0.00%
Expected volatility (as a percent) 55.33% 43.60% 52.68%
Expected term in years 5 years 1 month 9 days 6 years 6 months 3 years 8 months 15 days
v3.20.4
Stock-Based Compensation - Stock and Performance Options Rollforward (Details)
$ / shares in Units, $ in Thousands
 12 Months Ended
Dec. 31, 2020
USD ($)
$ / shares
shares
Shares  
Beginning balance (in shares) | shares 4,696,264
Granted (in shares) | shares 299,541
Exercised (in shares) | shares (298,513)
Forfeited (in shares) | shares (3,561)
Expired (in shares) | shares (493,222)
End balance (in shares) | shares 4,200,509
Exercisable at December 31, 2020 (in shares) | shares 3,908,444
Weighted Average Exercise Price  
Beginning balance (in usd per share) | $ / shares $ 18.05
Granted (in usd per share) | $ / shares 10.46
Exercised (in usd per share) | $ / shares 6.87
Forfeited (in usd per share) | $ / shares 10.53
Expired (in usd per share) | $ / shares 43.53
Ending balance (in usd per share) | $ / shares 15.32
Exercisable at December 31, 2020 (in usd per share) | $ / shares $ 15.68
Weighted average remaining contractual term, outstanding 4 years 2 months 4 days
Weighted average remaining contractual term (in years), exercisable 3 years 9 months 21 days
Aggregate intrinsic value, outstanding | $ $ 9,430
Aggregate intrinsic value, exercisable | $ $ 9,330
v3.20.4
Stock-Based Compensation - Restricted and Performance Stock Unit Rollforward (Details) - $ / shares
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Restricted Stock Units    
Number of Shares    
Beginning nonvested balance (in shares) 1,033,200  
Granted (in shares) 1,251,065  
RSUs granted in conversion, as a result of the CNXM Merger (in shares) 204,619  
Vested (in shares) (577,834)  
Forfeited (in shares) (39,923)  
Ending nonvested balance (in shares) 1,871,127 1,033,200
Weighted Average Grant Date Fair Value    
Beginning nonvested balance (in usd per share) $ 10.10 $ 11.71
Granted (in usd per share) 8.49  
RSUs granted in conversion, as a result of the CNXM Merger (in usd per share) 18.01  
Vested (in usd per share) 10.95  
Forfeited (in usd per share) 9.65  
Ending nonvested balance (in usd per share) $ 10.10 $ 11.71
Performance Share Units    
Number of Shares    
Beginning nonvested balance (in shares) 1,400,836  
Granted (in shares) 660,634  
PSUs issued (in shares) 112,158  
Vested (in shares) (274,716)  
Forfeited (in shares) (131,474)  
Ending nonvested balance (in shares) 1,767,438 1,400,836
Weighted Average Grant Date Fair Value    
Beginning nonvested balance (in usd per share) $ 13.85 $ 18.91
Granted (in usd per share) 5.79  
PSUs issued (in usd per share) 20.39  
Vested (in usd per share) 20.82  
Forfeited (in usd per share) 18.37  
Ending nonvested balance (in usd per share) $ 13.85 $ 18.91
v3.20.4
Supplemental Cash Flow Information (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Other Significant Noncash Transactions [Line Items]      
Interest (Net of Amounts Capitalized) $ 141,992 $ 143,111 $ 144,756
Income Taxes (118,125) (138,409) (11,505)
Notes Received from Property Sales      
Other Significant Noncash Transactions [Line Items]      
Capital expenditures incurred, not yet paid $ 30,982 $ 43,982 $ 58,246
v3.20.4
Concentrations of Credit Risk and Major Customers - Summary (Details) - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Concentration Risk [Line Items]    
Total Accounts Receivable Trade $ 145,929 $ 133,480
Accounts Receivable | Customer Concentration Risk    
Concentration Risk [Line Items]    
Allowance for Credit Losses 84 0
Total Accounts Receivable Trade 145,929 133,480
Accounts Receivable | Customer Concentration Risk | Gas Wholesalers    
Concentration Risk [Line Items]    
Accounts Receivable Trade Before Allowance for Credit Losses 133,253 115,641
Accounts Receivable | Customer Concentration Risk | NGL, Condensate & Processing Facilities    
Concentration Risk [Line Items]    
Accounts Receivable Trade Before Allowance for Credit Losses 7,008 10,140
Accounts Receivable | Customer Concentration Risk | Other    
Concentration Risk [Line Items]    
Accounts Receivable Trade Before Allowance for Credit Losses $ 5,752 $ 7,699
v3.20.4
Concentrations of Credit Risk and Major Customers - Narrative (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Concentration Risk [Line Items]      
Receivables related to contracts with customers $ 145,929 $ 133,480  
Direct Energy Business Marketing LLC      
Concentration Risk [Line Items]      
Revenue from contracts with customers 167,390 214,980 $ 184,668
NJR Energy Services Company      
Concentration Risk [Line Items]      
Revenue from contracts with customers   147,540 $ 219,472
Accounts Receivable | Customer Concentration Risk      
Concentration Risk [Line Items]      
Receivables related to contracts with customers 145,929 133,480  
Accounts Receivable | Customer Concentration Risk | Direct Energy Business Marketing LLC      
Concentration Risk [Line Items]      
Receivables related to contracts with customers $ 19,995 23,859  
Accounts Receivable | Customer Concentration Risk | NJR Energy Services Company      
Concentration Risk [Line Items]      
Receivables related to contracts with customers   $ 15,401  
v3.20.4
Fair Value of Financial Instruments - Financial Instruments Measured at Fair Value on a Recurring Basis (Details) - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Level 1 | Gas Derivatives    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Derivative Asset $ 0 $ 0
Level 1 | Interest Rate Swaps    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Derivative Asset 0 0
Level 2 | Gas Derivatives    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Derivative Asset 117,545 405,781
Level 2 | Interest Rate Swaps    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Derivative Asset (14,270) (1,219)
Level 3 | Gas Derivatives    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Derivative Asset 0 0
Level 3 | Interest Rate Swaps    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Derivative Asset $ 0 $ 0
v3.20.4
Fair Value of Financial Instruments - Fair Value Disclosures (Details) - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]      
Cash and Cash Equivalents $ 15,617 $ 16,283 $ 17,198
Long-Term Debt (Excluding Debt Issuance Costs) 2,424,001 2,754,443  
Carrying Amount      
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]      
Cash and Cash Equivalents 15,617 16,283  
Long-Term Debt (Excluding Debt Issuance Costs) 2,450,853 2,763,433  
Fair Value      
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]      
Cash and Cash Equivalents 15,617 16,283  
Long-Term Debt (Excluding Debt Issuance Costs) $ 2,638,251 $ 2,619,676  
v3.20.4
Derivative Instruments - Narrative (Details) - USD ($)
 1 Months Ended 12 Months Ended
Apr. 03, 2020
Mar. 31, 2020
Jun. 30, 2019
Dec. 31, 2020
Dec. 31, 2019
Apr. 30, 2020
Derivative [Line Items]            
Debt instrument, face amount           $ 1,000
Cash received in settlement of derivatives       $ (3,141,000) $ 223,000  
Interest Rate Swap on Line Of Credit | Long            
Derivative [Line Items]            
Put option (as a percent)   0.25%        
Interest Rate Swap on Revolving Credit Facility | Long            
Derivative [Line Items]            
Put option (as a percent) 0.00% 0.00%        
Derivative term of contract 4 years 4 years        
Derivative notional amount $ 250,000,000          
Commodity Swap            
Derivative [Line Items]            
Cash received in settlement of derivatives       $ 54,982,000    
Credit Facility            
Derivative [Line Items]            
Debt instrument, face amount   $ 175,000,000        
Revolving Credit Facility            
Derivative [Line Items]            
Debt instrument, face amount     $ 160,000,000      
Credit facility, modification period     3 years      
v3.20.4
Derivative Instruments - Notional Amounts of Derivative Instruments (Details) - Mcf
Mcf in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Natural Gas Commodity Swaps (Bcf)    
Derivative Instruments, Gain (Loss) [Line Items]    
Derivative notional amount 1,256,900 1,460,600
Natural Gas Basis Swaps (Bcf)    
Derivative Instruments, Gain (Loss) [Line Items]    
Derivative notional amount 1,294,100 1,290,400
Interest Rate Swaps    
Derivative Instruments, Gain (Loss) [Line Items]    
Derivative notional amount 569,972 160,000
v3.20.4
Derivative Instruments - Fair Value of Derivative Instruments (Details) - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Derivative [Line Items]    
Total Current Assets $ 84,657 $ 247,794
Total Other Non-Current Assets 188,237 314,096
Total Current Liabilities 42,329 41,466
Total Non-Current Liabilities 127,290 115,862
Commodity Swaps    
Derivative [Line Items]    
Total Current Assets 53,668 234,238
Total Other Non-Current Assets 134,661 288,543
Total Current Liabilities 23,506 345
Total Non-Current Liabilities 59,388 9,693
Basis Only Swaps    
Derivative [Line Items]    
Total Current Assets 30,848 13,556
Total Other Non-Current Assets 52,903 25,553
Total Current Liabilities 14,491 40,626
Total Non-Current Liabilities 57,150 105,445
Interest Rate Swaps    
Derivative [Line Items]    
Total Current Assets 141 0
Total Other Non-Current Assets 673 0
Total Current Liabilities 4,332 495
Total Non-Current Liabilities $ 10,752 $ 724
v3.20.4
Derivative Instruments - Effect of Derivative Instrument on Statement of Income (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Derivative [Line Items]      
Cash Received (Paid) in Settlement of Commodity Derivative Instruments: $ 461,217 $ 69,780 $ (69,720)
Unrealized (Loss) Gain on Commodity Derivative Instruments: (288,235) 306,325 39,508
Gain (Loss) on Commodity Derivative Instruments 172,982 376,105 (30,212)
Cash (Paid) Received in Settlement of Interest Rate Swaps (3,141) 223  
Unrealized Loss on Interest Rate Swaps (13,051) (1,219)  
Basis Swaps      
Derivative [Line Items]      
Cash Received (Paid) in Settlement of Commodity Derivative Instruments: 70,670 (13,119) (28,622)
Unrealized (Loss) Gain on Commodity Derivative Instruments: 119,073 (100,147) 6,482
Gain (Loss) on Commodity Derivative Instruments 189,743 (113,266) (22,140)
Interest Rate Swaps      
Derivative [Line Items]      
Gain (Loss) on Commodity Derivative Instruments (16,192) (996)  
Natural Gas Revenue | Commodity Swaps      
Derivative [Line Items]      
Cash Received (Paid) in Settlement of Commodity Derivative Instruments: 390,547 82,899 (41,098)
Unrealized (Loss) Gain on Commodity Derivative Instruments: (407,308) 406,472 33,026
Gain (Loss) on Commodity Derivative Instruments $ (16,761) $ 489,371 $ (8,072)
v3.20.4
Commitments and Contingent Liabilities - Narrative (Details)
May 01, 2020
employee
Murray | Settlement Agreement Between Murray And UMWA [Member]  
Loss Contingencies [Line Items]  
Number of retirees 2,159
v3.20.4
Commitments and Contingent Liabilities - Maximum Potential Total of Future Payments Under Commitment Instruments (Details)
$ in Thousands
Dec. 31, 2020
USD ($)
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments $ 291,202
Letters of Credit  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 185,302
Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 105,900
Less Than 1  Year  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 289,658
Less Than 1  Year | Letters of Credit  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 185,302
Less Than 1  Year | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 104,356
1-3 Years  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 1,544
1-3 Years | Letters of Credit  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
1-3 Years | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 1,544
3-5 Years  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
3-5 Years | Letters of Credit  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
3-5 Years | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Beyond 5  Years  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Beyond 5  Years | Letters of Credit  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Beyond 5  Years | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Firm Transportation | Letters of Credit  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 178,352
Firm Transportation | Less Than 1  Year | Letters of Credit  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 178,352
Firm Transportation | 1-3 Years | Letters of Credit  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Firm Transportation | 3-5 Years | Letters of Credit  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Firm Transportation | Beyond 5  Years | Letters of Credit  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Other | Letters of Credit  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 6,950
Other | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 9,183
Other | Less Than 1  Year | Letters of Credit  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 6,950
Other | Less Than 1  Year | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 7,899
Other | 1-3 Years | Letters of Credit  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Other | 1-3 Years | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 1,284
Other | 3-5 Years | Letters of Credit  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Other | 3-5 Years | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Other | Beyond 5  Years | Letters of Credit  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Other | Beyond 5  Years | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Employee-Related | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 2,600
Employee-Related | Less Than 1  Year | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 2,600
Employee-Related | 1-3 Years | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Employee-Related | 3-5 Years | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Employee-Related | Beyond 5  Years | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Environmental | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 12,447
Environmental | Less Than 1  Year | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 12,187
Environmental | 1-3 Years | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 260
Environmental | 3-5 Years | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Environmental | Beyond 5  Years | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Financial Guarantees | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 81,670
Financial Guarantees | Less Than 1  Year | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 81,670
Financial Guarantees | 1-3 Years | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Financial Guarantees | 3-5 Years | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments 0
Financial Guarantees | Beyond 5  Years | Surety Bonds  
Loss Contingencies [Line Items]  
Maximum potential total of future payments under commitments $ 0
v3.20.4
Commitments and Contingent Liabilities - Unrecorded Unconditional Purchase Obligation (Details) - Purchase Commitment
$ in Thousands
Dec. 31, 2020
USD ($)
Unrecorded Unconditional Purchase Obligation [Line Items]  
Less than 1 year $ 253,692
1 - 3 years 431,282
3 - 5 years 390,693
More than 5 years 985,201
Total Purchase Obligations $ 2,060,868
v3.20.4
Segment Information - Industry Segment Results (Details)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
USD ($)
numberOfDivisions
numberOfSegments
Dec. 31, 2019
USD ($)
Dec. 31, 2018
USD ($)
Segment Reporting [Abstract]      
Number of divisions | numberOfDivisions 2    
Number of reportable segments | numberOfSegments 4    
Segment Reporting Information [Line Items]      
Gain (Loss) on Commodity Derivative Instruments $ 172,982 $ 376,105 $ (30,212)
Other Revenue and Operating Income 82,459 87,992 116,723
Total Revenue and Other Operating Income 1,257,978 1,922,449 1,730,434
Total Operating Expense 1,697,744 1,736,473 1,226,963
Earnings (Loss) Before Income Tax (602,831) 59,684 1,098,668
Segment Assets 8,041,764 9,060,806 8,592,170
Depreciation, Depletion and Amortization 501,821 508,463 493,423
Capital Expenditures 487,291 1,192,599 1,116,397
Equity in Earnings (Loss) of Affiliates (688) 2,103 5,363
Natural Gas, NGLs and Oil Revenue      
Segment Reporting Information [Line Items]      
Revenue 896,745 1,364,325 1,577,937
Purchased Gas Revenue      
Segment Reporting Information [Line Items]      
Revenue 105,792 94,027 65,986
Direct Energy Business Marketing LLC      
Segment Reporting Information [Line Items]      
Revenue 167,390 214,980 184,668
Total Revenue and Other Operating Income   214,980 184,668
NJR Energy Services Company      
Segment Reporting Information [Line Items]      
Revenue   147,540 219,472
Total Revenue and Other Operating Income 167,390 147,540 219,472
Operating Segments      
Segment Reporting Information [Line Items]      
Revenue 1,067,247 1,532,666 1,733,704
Investments in Unconsolidated Equity Affiliates 16,022 16,710 18,663
Corporate, Non-Segment | Natural Gas | Commodity Swap      
Segment Reporting Information [Line Items]      
Gain (Loss) on Commodity Derivative Instruments 83,997    
Reportable Subsegments | Exploration and Production | Operating Segments      
Segment Reporting Information [Line Items]      
Total Operating Expense     321,169
Segment Assets     1,051,600
Depreciation, Depletion and Amortization     11,916
Capital Expenditures     4,843
Reportable Subsegments | Exploration and Production | Operating Segments | Shale      
Segment Reporting Information [Line Items]      
Gain (Loss) on Commodity Derivative Instruments 337,269 62,418 (60,326)
Other Revenue and Operating Income 64,710 74,314 89,781
Total Revenue and Other Operating Income 1,183,017 1,336,008 1,378,651
Total Operating Expense 709,036 787,488 751,673
Earnings (Loss) Before Income Tax 473,981 548,520 626,978
Segment Assets 6,068,933 6,527,245 6,268,113
Depreciation, Depletion and Amortization 416,441 427,219 404,503
Capital Expenditures 474,545 1,175,091 1,094,471
Reportable Subsegments | Exploration and Production | Operating Segments | Coalbed Methane      
Segment Reporting Information [Line Items]      
Gain (Loss) on Commodity Derivative Instruments 39,884 7,335 (8,768)
Other Revenue and Operating Income 0 0 0
Total Revenue and Other Operating Income 154,250 171,228 204,116
Total Operating Expense 127,845 135,778 154,121
Earnings (Loss) Before Income Tax 26,405 35,450 49,995
Segment Assets 1,095,816 1,222,005 1,272,457
Depreciation, Depletion and Amortization 69,745 73,189 77,004
Capital Expenditures 9,789 11,333 17,083
Reportable Subsegments | Exploration and Production | Operating Segments | Other      
Segment Reporting Information [Line Items]      
Gain (Loss) on Commodity Derivative Instruments (204,171) 306,352 38,882
Other Revenue and Operating Income 17,749 13,678 26,942
Total Revenue and Other Operating Income (79,289) 415,213 147,667
Total Operating Expense 860,863 813,207  
Earnings (Loss) Before Income Tax (1,103,217) (524,286) 421,695
Segment Assets 877,015 1,311,556  
Depreciation, Depletion and Amortization 15,635 8,055  
Capital Expenditures 2,957 6,175  
Reportable Subsegments | Exploration and Production | Operating Segments | Shale and Other      
Segment Reporting Information [Line Items]      
Equity in Earnings (Loss) of Affiliates (688) 2,103 5,363
Reportable Subsegments | Exploration and Production | Operating Segments | Natural Gas, NGLs and Oil Revenue | Shale      
Segment Reporting Information [Line Items]      
Revenue 781,038 1,199,276 1,349,196
Reportable Subsegments | Exploration and Production | Operating Segments | Natural Gas, NGLs and Oil Revenue | Coalbed Methane      
Segment Reporting Information [Line Items]      
Revenue 114,366 163,893 212,884
Reportable Subsegments | Exploration and Production | Operating Segments | Natural Gas, NGLs and Oil Revenue | Other      
Segment Reporting Information [Line Items]      
Revenue 1,341 1,156 15,857
Reportable Subsegments | Exploration and Production | Operating Segments | Purchased Gas Revenue | Shale      
Segment Reporting Information [Line Items]      
Revenue 0 0 0
Reportable Subsegments | Exploration and Production | Operating Segments | Purchased Gas Revenue | Coalbed Methane      
Segment Reporting Information [Line Items]      
Revenue 0 0 0
Reportable Subsegments | Exploration and Production | Operating Segments | Purchased Gas Revenue | Other      
Segment Reporting Information [Line Items]      
Revenue $ 105,792 $ 94,027 $ 65,986
v3.20.4
Segment Information - Reconciliation of Segment Information, Revenue and Other Income (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Segment Reporting, Revenue Reconciling Item [Line Items]      
Gain (Loss) on Commodity Derivative Instruments $ 172,982 $ 376,105 $ (30,212)
Other Operating Income 17,749 13,678 26,942
Total Consolidated Revenue and Other Operating Income 1,257,978 1,922,449 1,730,434
Operating Segments      
Segment Reporting, Revenue Reconciling Item [Line Items]      
Total Segment Revenue from Contracts with External Customers $ 1,067,247 $ 1,532,666 $ 1,733,704
v3.20.4
Supplemental Gas Data (unaudited) - Capitalized Costs (Details) - USD ($)
$ in Thousands
Dec. 31, 2020
Dec. 31, 2019
Extractive Industries [Abstract]    
Intangible Drilling Cost $ 4,965,252 $ 4,688,497
Gas Gathering Assets 2,510,916 2,463,866
Proved Gas Properties 1,253,094 1,208,046
Gas Wells and Related Equipment 1,120,061 1,042,000
Unproved Gas Properties 725,705 755,590
Other Gas Assets 95,734 73,479
Total Property, Plant and Equipment 10,670,762 10,231,478
Accumulated Depreciation, Depletion and Amortization (3,852,593) (3,317,442)
Net Capitalized Costs $ 6,818,169 $ 6,914,036
v3.20.4
Supplemental Gas Data (unaudited) - Costs Incurred for Property Acquisition, Exploration and Development (Details) - USD ($)
$ in Thousands
 12 Months Ended
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Property Acquisitions:      
Proved Properties $ 16,622 $ 36,710 $ 38,621
Unproved Properties 8,060 24,760 36,248
Development** 432,438 1,063,945 986,419
Exploration 33,644 79,855 61,604
Total 490,764 1,205,270 1,122,892
Midstream      
Property Acquisitions:      
Development** $ 67,000 $ 325,000 $ 142,000
v3.20.4
Supplemental Gas Data (unaudited) - Results of Operations (Details) - USD ($)
$ in Thousands
 3 Months Ended 12 Months Ended
Mar. 31, 2020
Dec. 31, 2019
Dec. 31, 2020
Dec. 31, 2019
Dec. 31, 2018
Extractive Industries [Abstract]          
Natural Gas, NGLs and Oil Revenue     $ 896,745 $ 1,364,325 $ 1,577,937
Realized Gain (Loss) on Commodity Derivative Instruments     461,217 69,780 (69,720)
Unrealized (Loss) Gain on Commodity Derivative Instruments     (288,235) 306,325 39,508
Purchased Gas Revenue     105,792 94,027 65,986
Total Revenue     1,175,519 1,834,457 1,613,711
Lease Operating Expense     40,407 65,443 95,139
Production, Ad Valorem and Other Fees     24,196 27,461 32,750
Transportation, Gathering and Compression     285,683 330,539 302,933
Purchased Gas Costs     100,902 90,553 64,817
Impairment of Exploration and Production Properties $ 61,849 $ 327,400 61,849 327,400 0
Impairment of Unproved Properties and Expirations $ 473,045 $ 119,429 0 119,429 0
Exploration Costs     14,994 44,380 12,033
Depreciation, Depletion and Amortization     501,821 508,463 493,423
Total Costs     1,029,852 1,513,668 1,001,095
Pre-tax Operating Income     145,667 320,789 612,616
Income Tax Expense     42,098 149,167 120,073
Results of Operations for Producing Activities excluding Corporate and Interest Costs     $ 103,569 $ 171,622 $ 492,543
v3.20.4
Supplemental Gas Data (unaudited) - Average Unit Prices and Average Production Costs (Details)
Mcfe in Thousands
 12 Months Ended
Dec. 31, 2020
usd_per_mcfe
Mcfe
Dec. 31, 2019
usd_per_mcfe
Mcfe
Dec. 31, 2018
usd_per_mcfe
Mcfe
Average Sales Price and Production Costs Per Unit of Production [Line Items] (Deprecated 2019-01-31)      
Production (MMcfe) | Mcfe 511,072 539,149 507,104
Natural Gas, Per Thousand Cubic Feet      
Average Sales Price and Production Costs Per Unit of Production [Line Items] (Deprecated 2019-01-31)      
Total Average Sales Price Before Effects of Commodity Derivative Financial Settlements (per Mcfe) 1.75 2.53 3.11
Average Effects of Commodity Derivative Financial Settlements (per Mcfe) 0.74 0.14 (0.15)
Total Average Sales Price Including Effects of Commodity Derivative Financial Settlements (per Mcfe) 2.49 2.66 2.97
Average Lifting Costs, Excluding Ad Valorem and Severance Taxes (per Mcfe) 0.08 0.12 0.19