CNX Resources (CNX) 10-K 10 Feb 20 2019 FY Annual report Financial data

Cover Page

Cover Page - USD ($)	12 Months Ended
	Dec. 31, 2019	Jan. 20, 2020	Jun. 30, 2019
Document Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2019
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
Entity Shell Company	false
Entity Public Float			$ 800,152,980
Entity Common Stock, Shares Outstanding		186,642,962
Documents Incorporated by Reference	Portions of CNX's Proxy Statement for the Annual Meeting of Shareholders to be held on May 6, 2020, are incorporated by reference in Items 10, 11, 12, 13 and 14 of Part III.
Amendment Flag	false
Document Fiscal Year Focus	2019
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

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Gain (Loss) on Commodity Derivative Instruments	$ 376,105	$ (30,212)	$ 206,930
Other Operating Income	13,678	26,942	69,182
Total Revenue and Other Operating Income	1,922,449	1,730,434	1,455,131
Operating Expense
Lease Operating Expense	65,443	95,139	88,932
Production, Ad Valorem, and Other Fees	27,461	32,750	29,267
Depreciation, Depletion and Amortization	508,463	493,423	412,036
Purchased Gas Costs	90,553	64,817	52,597
Impairment of Exploration and Production Properties	327,400	0	137,865
Impairment of Unproved Properties and Expirations	119,429	0	0
Impairment of Other Intangible Assets	0	18,650	0
Selling, General and Administrative Costs	143,550	134,806	93,211
Other Operating Expense	79,255	72,412	112,369
Total Operating Expense	1,736,473	1,226,963	1,357,216
Other Expense (Income)
Other Expense (Income)	2,862	(14,571)	3,825
Gain on Asset Sales and Abandonments, net	(35,563)	(157,015)	(188,063)
Gain on Previously Held Equity Interest	0	(623,663)	0
Loss on Debt Extinguishment	7,614	54,118	2,129
Interest Expense	151,379	145,934	161,443
Total Other Expense (Income)	126,292	(595,197)	(20,666)
Total Costs and Expenses	1,862,765	631,766	1,336,550
Earnings from Continuing Operations Before Income Tax	59,684	1,098,668	118,581
Income Tax Expense (Benefit)	27,736	215,557	(176,458)
Income from Continuing Operations	31,948	883,111	295,039
Income from Discontinued Operations, net	0	0	85,708
Net Income	31,948	883,111	380,747
Less: Net Income Attributable to Noncontrolling Interests	112,678	86,578	0
Net (Loss) Income Attributable to CNX Resources Shareholders	$ (80,730)	$ 796,533	$ 380,747
Basic
Income (Loss) from Continuing Operations (in usd per share)	$ (0.42)	$ 3.75	$ 1.29
Income (Loss) from Discontinued Operations (in usd per share)	0	0	0.37
Total Basic Earnings (Loss) Per Share (in usd per share)	(0.42)	3.75	1.66
Diluted
Income (Loss) from Continuing Operations (in usd per share)	(0.42)	3.71	1.28
Income (Loss) from Discontinued Operations (in usd per share)	0	0	0.37
Total Diluted Earnings (Loss) Per Share (in usd per share)	(0.42)	3.71	1.65
Dividends Declared Per Share (in usd per share)	$ 0	$ 0	$ 0
Natural Gas, NGLs and Oil Revenue
Revenue	$ 1,364,325	$ 1,577,937	$ 1,125,224
Purchased Gas Revenue
Revenue	94,027	65,986	53,795
Midstream Revenue
Revenue	74,314	89,781	0
Transportation, Gathering and Compression
Operating Expense
Cost of Goods and Services Sold	330,539	302,933	382,865
Exploration and Production Related Other Costs
Operating Expense
Cost of Goods and Services Sold	$ 44,380	$ 12,033	$ 48,074

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Net Income (Loss) Attributable to Parent [Abstract]
Net Income	$ 31,948	$ 883,111	$ 380,747
Other Comprehensive (Loss) Income:
Actuarially Determined Long-Term Liability Adjustments (Net of tax: $1,664, ($792), ($7,365))	(4,701)	1,672	12,228
Comprehensive Income	27,247	884,783	392,975
Less: Comprehensive Income Attributable to Noncontrolling Interests	112,678	86,578	0
Comprehensive (Loss) Income Attributable to CNX Resources Shareholders	$ (85,431)	$ 798,205	$ 392,975

Consolidated Statement of Com_2

Consolidated Statement of Comprehensive Income Parentheticals - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Statement of Comprehensive Income [Abstract]
Actuarially determined long-term liability adjustments, tax	$ 1,664	$ (792)	$ (7,365)

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Current Assets:
Cash and Cash Equivalents	$ 16,283	$ 17,198
Accounts and Notes Receivable:
Trade (Note 19)	133,480	252,424
Other Receivables	13,679	11,077
Supplies Inventories	6,984	9,715
Recoverable Income Taxes	62,425	149,481
Derivative Instruments (Note 21)	247,794	40,240
Prepaid Expenses	17,456	21,551
Total Current Assets	498,101	501,686
Property, Plant and Equipment (Note 10):
Property, Plant and Equipment	10,572,006	9,567,428
Less—Accumulated Depreciation, Depletion and Amortization	3,435,431	2,624,984
Total Property, Plant and Equipment—Net	7,136,575	6,942,444
Other Assets:
Operating Lease Right-of-Use Asset	187,097
Investment in Affiliates	16,710	18,663
Derivative Instruments (Note 21)	314,096	213,098
Goodwill (Note 11)	796,359	796,359
Other Intangible Assets (Note 11)	96,647	103,200
Other	15,221	16,720
Total Other Assets	1,426,130	1,148,040
TOTAL ASSETS	9,060,806	8,592,170
Current Liabilities:
Accounts Payable	202,553	229,806
Derivative Instruments (Note 21)	40,971	61,661
Current Portion of Finance Lease Obligations (Note 15)	7,164	6,997
Current Portion of Operating Lease Obligations	61,670
Other Accrued Liabilities (Note 13)	216,581	224,511
Total Current Liabilities	528,939	522,975
Non-Current Liabilities:
Long-Term Debt (Note 14)	2,754,443	2,378,205
Finance Lease Obligations (Note 15)	7,706
Finance Lease Obligations (Note 15)		13,299
Operating Lease Obligations	110,466
Derivative Instruments (Note 21)	115,138	92,221
Deferred Income Taxes (Note 8)	476,108	398,682
Asset Retirement Obligations (Note 9)	63,377	37,479
Other	42,320	67,566
Total Non-Current Liabilities	3,569,558	2,987,452
TOTAL LIABILITIES	4,098,497	3,510,427
Stockholders’ Equity:
Common Stock, $0.01 Par Value; 500,000,000 Shares Authorized, 186,642,962 Issued and Outstanding at December 31, 2019; 198,663,342 Issued and Outstanding at December 31, 2018	1,870	1,990
Capital in Excess of Par Value	2,199,605	2,264,063
Preferred Stock, 15,000,000 Shares Authorized, None Issued and Outstanding	0	0
Retained Earnings	1,971,676	2,071,809
Accumulated Other Comprehensive Loss	(12,605)	(7,904)
Total CNX Resources Stockholders’ Equity	4,160,546	4,329,958
Noncontrolling Interest	801,763	751,785
TOTAL STOCKHOLDERS' EQUITY	4,962,309	5,081,743
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$ 9,060,806	$ 8,592,170

Consolidated Balance Sheets Par

Consolidated Balance Sheets Parentheticals - $ / shares	Dec. 31, 2019	Dec. 31, 2018
Common Stock
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)	186,642,962	198,663,342
Common Stock, Outstanding (in shares)	186,642,962	198,663,342
Preferred Stock
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

Consolidated Statements of Stoc

Consolidated Statements of Stockholders' Equity - USD ($) $ in Thousands	Total	Total CNX Resources Corporation Stockholders' Equity	Common Stock and Capital in Excess of Par Value	Retained Earnings	Accumulated Other Comprehensive Loss	Non-Controlling Interest
Balance, Beginning of Period at Dec. 31, 2016	$ 3,940,888		$ 2,463,162	$ 1,727,789	$ (392,556)	$ 142,493
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock			1,009
Purchase and Retirement of Common Stock			(51,287)	(51,922)
Amortization of Stock-Based Compensation Awards			16,983			0
Distribution of CONSOL Energy, Inc.			22,697	(594,122)	371,852	(142,493)
Net Income	380,747			380,747		0
Shares Withheld for Taxes				(6,681)		0
ASU 2018-02 Reclassification				0	0
Other Comprehensive (Loss) Income					12,228
Distributions to CNXM Noncontrolling Interest Holders						0
Acquisition of CNX Gathering, LLC						0
Balance, End of Period at Dec. 31, 2017	3,899,899	$ 3,899,899	2,452,564	1,455,811	(8,476)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock			1,713
Purchase and Retirement of Common Stock			(207,154)	(176,598)
Amortization of Stock-Based Compensation Awards			18,930			2,411
Distribution of CONSOL Energy, Inc.			0	0	0	0
Net Income	883,111			796,533		86,578
Shares Withheld for Taxes				(5,037)		(348)
ASU 2018-02 Reclassification	1,100			1,100	(1,100)
Other Comprehensive (Loss) Income					1,672
Distributions to CNXM Noncontrolling Interest Holders						(55,433)
Acquisition of CNX Gathering, LLC						718,577
Balance, End of Period at Dec. 31, 2018	5,081,743	4,329,958	2,266,053	2,071,809	(7,904)	751,785
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock			565
Purchase and Retirement of Common Stock	(115,477)		(101,688)	(13,789)
Amortization of Stock-Based Compensation Awards			36,545			1,880
Distribution of CONSOL Energy, Inc.			0	0	0	0
Net Income	31,948			(80,730)		112,678
Shares Withheld for Taxes				(5,614)		(696)
ASU 2018-02 Reclassification				0	0
Other Comprehensive (Loss) Income					(4,701)
Distributions to CNXM Noncontrolling Interest Holders						(63,884)
Acquisition of CNX Gathering, LLC						0
Balance, End of Period at Dec. 31, 2019	$ 4,962,309	$ 4,160,546	$ 2,201,475	$ 1,971,676	$ (12,605)	$ 801,763

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Cash Flows from Operating Activities:
Net Income	$ 31,948	$ 883,111	$ 380,747
Adjustments to Reconcile Net Income to Net Cash Provided by Continuing Operating Activities:
Net Income from Discontinued Operations	0	0	(85,708)
Depreciation, Depletion and Amortization	508,463	493,423	412,036
Amortization of Deferred Financing Costs	7,747	8,361	10,630
Impairment of Exploration and Production Properties	327,400	0	137,865
Impairment of Unproved Properties and Expirations	119,429	0	0
Impairment of Other Intangible Assets	0	18,650	0
Stock-Based Compensation	38,425	21,341	16,983
Gain on Asset Sales and Abandonments, net	(35,563)	(157,015)	(188,063)
Gain on Previously Held Equity Interest	0	(623,663)	0
Loss on Debt Extinguishment	7,614	54,118	2,129
(Gain) Loss on Commodity Derivative Instruments	(376,105)	30,212	(206,930)
Net Cash Received (Paid) in Settlement of Commodity Derivative Instruments	69,780	(69,720)	(41,174)
Deferred Income Taxes	79,092	345,560	(142,829)
Equity in Earnings of Affiliates	(2,103)	(5,363)	(49,830)
Return on Equity Investment	4,056	0	0
Changes in Operating Assets:
Accounts and Notes Receivable	118,622	(57,734)	(32,792)
Supplies Inventories	2,731	1,027	4,254
Recoverable Income Taxes	87,050	(118,498)	76,196
Prepaid Expenses	3,115	(1,391)	631
Changes in Other Assets	1,000	4,904	22,018
Changes in Operating Liabilities:
Accounts Payable	(6,405)	12,760	45,669
Accrued Interest	4,529	(5,839)	(2,955)
Other Operating Liabilities	13,242	53,135	81,969
Changes in Other Liabilities	(23,507)	(1,556)	(7,778)
Net Cash Provided by Continuing Operating Activities	980,560	885,823	433,068
Net Cash Provided by Discontinued Operating Activities	0	0	215,619
Net Cash Provided by Operating Activities	980,560	885,823	648,687
Cash Flows from Investing Activities:
Capital Expenditures	(1,192,599)	(1,116,397)	(632,846)
CNX Gathering LLC Acquisition, Net of Cash Acquired	0	(299,272)	0
Proceeds from Asset Sales	45,160	511,767	414,185
Net Distributions from Equity Affiliates	0	9,250	42,873
Net Cash Used in Continuing Investing Activities	(1,147,439)	(894,652)	(175,788)
Net Cash Used in Discontinued Investing Activities	0	0	(46,133)
Net Cash Used in Investing Activities	(1,147,439)	(894,652)	(221,921)
Cash Flows from Financing Activities:
Net Proceeds from CNX Revolving Credit Facility	49,000	612,000	0
Payments on Miscellaneous Borrowings	(7,149)	(7,165)	(8,037)
Payments on Long-Term Notes	(405,876)	(955,019)	(239,716)
Net Proceeds from (Payments on) CNXM Revolving Credit Facility	227,750	(65,500)	0
Distributions to CNXM Noncontrolling Interest Holders	(63,884)	(55,433)	0
Proceeds from Spin-Off of CONSOL Energy Inc.	0	0	425,000
Proceeds from Issuance of Common Stock	565	1,713	1,009
Shares Withheld for Taxes	(6,310)	(5,385)	(6,681)
Purchases of Common Stock	(117,477)	(381,752)	(103,209)
Debt Issuance and Financing Fees	(10,655)	(20,599)	(361)
Net Cash Provided by (Used in) Continuing Financing Activities	165,964	(483,140)	68,005
Net Cash Used in Discontinued Financing Activities	0	0	(31,903)
Net Cash Provided by (Used in) Financing Activities	165,964	(483,140)	36,102
Net (Decrease) Increase in Cash and Cash Equivalents	(915)	(491,969)	462,868
Cash and Cash Equivalents at Beginning of Period	17,198	509,167	46,299
Cash and Cash Equivalents at End of Period	16,283	17,198	509,167
CNX Senior Notes
Cash Flows from Financing Activities:
Proceeds from Issuance of Senior Notes	500,000	0	0
CNXM Senior Notes
Cash Flows from Financing Activities:
Proceeds from Issuance of Senior Notes	$ 0	$ 394,000	$ 0

Significant Accounting Policies

Significant Accounting Policies	12 Months Ended
	Dec. 31, 2019
Accounting Policies [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, and its wholly-owned and majority-owned and/or controlled subsidiaries, including certain variable interest entities that the Company is required to consolidate pursuant to the Consolidation topic of the Financial Accounting Standards Board (FASB) Accounting Standards Codification. The portion of these entities that is not owned by the Company is presented as non-controlling interest. 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. Discontinued Operations: Businesses divested are classified in the Consolidated Financial Statements as either discontinued operations or held for sale when the provision of Accounting Standards Codification (ASC) Topic 205 or ASC Topic 360 are met. For businesses classified as discontinued operations, the balance sheet amounts and results of operations are reclassified from their historical presentation to assets and liabilities of discontinued operations in the Consolidated Balance Sheets and to discontinued operations in the Consolidated Statements of Income and Cash Flows for all periods presented. The gains or losses associated with these divested businesses are recorded in discontinued operations in the Consolidated Statements of Income. The disclosures outside of Note 5- Discontinued Operations, for all periods presented, in the accompanying notes generally do not include the assets, liabilities, or operating results of businesses classified as discontinued operations. 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), 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, stock-based compensation and salary retirement benefits. Cash and Cash Equivalents: 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. Trade Accounts Receivable: Trade accounts receivable are recorded at the invoiced amount and do not bear interest. CNX reserves for specific accounts receivable when it is probable that all or a part of an outstanding balance will not be collected, such as customer bankruptcies. Collectability is determined based on terms of sale, credit status of customers and various other circumstances. CNX regularly reviews collectability and establishes or adjusts the allowance as necessary using the specific identification method. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote. Reserves for uncollectable amounts were not material in the periods presented. In addition, there were no material financing receivables with a contractual maturity greater than one year at December 31, 2019 or 2018 . 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. DD&A 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. 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. 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 Improvements Life 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. In February 2017, the Company approved a plan to sell its subsidiaries Knox Energy LLC and Coalfield Pipeline Company (collectively, “Knox”). Knox met all of the criteria to be classified as held for sale in February 2017. As part of the required evaluation under the held for sale guidance, Knox’s book value was evaluated, and it was determined that the approximate fair value less costs to sell Knox was less than the carrying value of the net assets to be sold. The resulting impairment of $ 137,865 was included in Impairment of Exploration and Production Properties in the Consolidated Statements of Income during the year ended December 31, 2017. The sale of Knox closed in the second quarter of 2017 (See Note 6 - Acquisitions and Dispositions for more information). The disposal of Knox did not represent a strategic shift that would have had a major effect on the Company’s operations and financial results and was, therefore, not classified as a discontinued operation in accordance with Topic 205, Presentation of Financial Statements, and Topic 360, Property, Plant and Equipment. 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 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 $ 44,380 , $ 12,033 and $ 48,074 for the years ended December 31, 2019 , 2018 and 2017 , 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 6 - 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, which is the sole reporting unit within the Midstream 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 or common unit price with regards to CNX Midstream Partners LP ("CNXM"), regulatory and legal developments, and other relevant factors. In connection with the annual 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. 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 five-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 our annual assessment of goodwill in the fourth quarter of 2019, 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 6 - 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 6 - 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, 2019 , 2018 and 2017 , 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, 2019, 2018 and 2017. Total matching contribution payments and costs were $3,460 , $3,205 and $2,866 for the years ended December 31, 2019 , 2018 and 2017 , 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 midstream revenue 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 17 - Stock-Based Compensation for more information. Derivative Instruments: CNX enters into financial derivative instruments to manage its exposure to commodity price volatility. The derivatives are accounted for as an asset or a liability in the accompanying Consolidated Balance Sheets at their fair value, generally measured based upon Level 2 inputs, which is further described in Note 20 - Fair Value of Financial Instruments. Changes in the fair values of derivatives are recorded in earnings. All of the Company's derivative instruments are subject to master netting arrangements with its counterparties, none of which currently require CNX to post collateral for any of its hedges. However, as stated in the counterparty master agreements, if the Company's obligations with one 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 hedges that are in a liability position in excess of defined thresholds. 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 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 will be 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. Early adoption is permitted. The adoption of this guidance is not expected to have a material impact on the Company's financial statements. In November 2019, the FASB issued ASU 2019-11 - Financial Instruments - Credit Losses (Topic 326), which clarifies and addresses specific issues about certain aspects of the amendments in ASU 2016-13. In May 2019, the FASB issued ASU 2019-05 - Financial Instruments - Credit Losses (Topic 326), which provides optional targeted transition relief to entities adopting ASU 2016-13. ASU 2016-13 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 will be 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. ASU 2019-05 provides the option to irrevocably elect the fair value option for certain financial assets previously measured at amortized cost basis. For those entities, the targeted transition relief will increase comparability of financial statement information by providing an option to align measurement methodologies for similar financial assets. The amendments in this ASU will be applied using the modified-retrospective approach and, for public entities, are effective for fiscal years beginning after December 15, 2019 and interim periods within those annual periods. Early adoption is permitted. 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, 2019 , with no effect on previously reported net income, stockholders' equity, or statement of cash flows. Subsequent Events:

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [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 additional shares from stock options, performance stock options, restricted stock units and performance share units, if dilutive. 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. CNXM's dilutive units did not have a material impact on the Company's earnings per share calculations for 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, 2019 2018 2017 Anti-Dilutive Options 4,696,264 2,285,775 2,773,423 Anti-Dilutive Restricted Stock Units 1,282,582 — 18,598 Anti-Dilutive Performance Share Units 752,899 145,217 — Anti-Dilutive Performance Share Options 927,268 927,268 927,268 7,659,013 3,358,260 3,719,289 The computations for basic and diluted earnings per share are as follows: For the Years Ended December 31, 2019 2018 2017 Income from Continuing Operations $ 31,948 $ 883,111 $ 295,039 Less: Net Income Attributable to Non-Controlling Interest 112,678 86,578 — Net (Loss) Income from Continuing Operations Attributable to CNX Resources Shareholders $ (80,730 ) $ 796,533 $ 295,039 Income from Discontinued Operations — — 85,708 Net (Loss) Income Attributable to CNX Resources Shareholders $ (80,730 ) $ 796,533 $ 380,747 Weighted-average shares of common stock outstanding 190,727,122 212,348,581 228,835,112 Effect of diluted shares — 2,280,384 2,116,700 Weighted-average diluted shares of common stock outstanding 190,727,122 214,628,965 230,951,812 (Loss) Earnings Per Share: Basic (Continuing Operations) $ (0.42 ) $ 3.75 $ 1.29 Basic (Discontinued Operations) — — 0.37 Total Basic $ (0.42 ) $ 3.75 $ 1.66 Diluted (Continuing Operations) $ (0.42 ) $ 3.71 $ 1.28 Diluted (Discontinued Operations) — — 0.37 Total Diluted $ (0.42 ) $ 3.71 $ 1.65 Shares of common stock outstanding were as follows: For the Years Ended December 31, 2019 2018 2017 Balance, Beginning of Year 198,663,342 223,743,322 229,443,008 Issuance Related to Stock-Based Compensation (1) 909,107 814,344 711,214 Retirement of Common Stock (2) (12,929,487 ) (25,894,324 ) (6,410,900 ) Balance, End of Year 186,642,962 198,663,342 223,743,322 (1) See Note 17 - Stock-Based Compensation for additional information. (2) See Note 7 - Stock Repurchase for additional information.

Changes in Accumulated Other Co

Changes in Accumulated Other Comprehensive Loss	12 Months Ended
	Dec. 31, 2019
Equity [Abstract]
Changes in Accumulated Other Comprehensive Loss	CHANGES IN ACCUMULATED OTHER COMPREHENSIVE LOSS: Changes in Accumulated Other Comprehensive Loss related to pension obligations, net of tax, were as follows: Amount Balance at December 31, 2018 $ (7,904 ) Other Comprehensive Loss before Reclassifications (4,868 ) Amounts Reclassified from Accumulated Other Comprehensive Loss, net of tax 167 Balance at December 31, 2019 $ (12,605 ) The following table shows the reclassification of adjustments out of Accumulated Other Comprehensive Loss: For the Years Ended December 31, 2019 2018 2017 Actuarially Determined Long-Term Liability Adjustments* (Note 16) Amortization of Prior Service Costs $ (17 ) $ (193 ) $ (2,775 ) Recognized Net Actuarial Loss 242 302 23,043 Total 225 109 20,268 Less: Tax Benefit 58 173 7,499 Net of Tax $ 167 $ (64 ) $ 12,769 *Excludes amounts related to the remeasurement of the actuarially determined pension obligations for the years ended December 31, 2019, 2018 and 2017. The table above only shows the reclassifications out of Accumulated Other Comprehensive Loss that relates to continuing operations. In February 2018, the FASB issued ASU 2018-02 - Income Statement - Reporting Comprehensive Income (Topic 220), which eliminates the stranded tax effects resulting from the Tax Cuts and Jobs Act. The Company early adopted this ASU, resulting in the reclassification of $1,100 related to stranded tax effects from Accumulated Other Comprehensive Loss to Retained Earnings during the year ended December 31, 2018.

Revenue From Contracts With Cus

Revenue From Contracts With Customers	12 Months Ended
	Dec. 31, 2019
Revenue from Contract with Customer [Abstract]
Revenue From Contracts With Customers	REVENUE FROM CONTRACTS WITH CUSTOMERS: On January 1, 2018, the Company adopted ASU 2014-09, Revenue from Contracts with Customers and all the related amendments using the modified retrospective method, which did not result in any changes to previously reported financial information. The updates were applied only to contracts that were not complete as of January 1, 2018. 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, NGLs 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, NGLs 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, NGLs 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. Midstream revenue consists of revenues generated from natural gas gathering activities. 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, 2019 2018 2017 Revenue from Contracts with Customers Natural Gas Revenue $ 1,251,013 $ 1,391,459 $ 945,382 NGLs Revenue 104,139 165,883 156,132 Condensate Revenue 8,751 17,559 20,531 Oil Revenue 422 3,036 3,179 Total Natural Gas, NGLs and Oil Revenue 1,364,325 1,577,937 1,125,224 Purchased Gas Revenue 94,027 65,986 53,795 Midstream Revenue 74,314 89,781 — Other Sources of Revenue and Other Operating Income Gain (Loss) on Commodity Derivative Instruments 376,105 (30,212 ) 206,930 Other Operating Income 13,678 26,942 69,182 Total Revenue and Other Operating Income $ 1,922,449 $ 1,730,434 $ 1,455,131 The disaggregated revenue information corresponds with the Company’s segment reporting found in Note 24 - 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 $252,424 and $133,480 , respectively, as of December 31, 2019 . 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, NGLs 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 $ 156,620 as of December 31, 2019 . The Company expects to recognize net revenue of $ 38,928 in the next 12 months and $ 53,322 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 and NGL 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 estimates 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, 2019 , 2018 , and 2017

Discontinued Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2019
Discontinued Operations and Disposal Groups [Abstract]
Discontinued Operations	DISCONTINUED OPERATIONS: In November 2017, CNX completed the tax-free spin-off of its coal business resulting in two independent, publicly traded companies: (i) a coal company, CONSOL Energy, formerly known as CONSOL Mining Corporation and (ii) CNX, a natural gas exploration and production company, formerly known as CONSOL Energy, Inc. Following the separation, CONSOL Energy and its subsidiaries hold the coal assets previously held by CNX, including its Pennsylvania Mining Complex, Baltimore Marine Terminal, its direct and indirect ownership interest in CONSOL Coal Resources LP, formerly known as CNXC Coal Resources LP, and other related coal assets previously held by CNX. The coal business has been reclassified to discontinued operations for all periods presented. The following table details selected financial information for the divested business included within discontinued operations: For the Year Ended December 31, 2017 Coal Revenue $ 1,067,841 Other Outside Sales 60,066 Freight-Outside Coal 66,297 Miscellaneous Other Income 73,645 Total Revenue and Other Income 1,267,849 Total Costs 1,147,254 Income from Operations Before Income Taxes 120,595 Income Tax Expense 23,984 Less: Net Income Attributable to Noncontrolling Interest 10,903 Income from Discontinued Operations, net $ 85,708

Acquisitions and Dispositions

Acquisitions and Dispositions	12 Months Ended
	Dec. 31, 2019
Business Combinations [Abstract]
Acquisitions And Dispositions	ACQUISITIONS AND DISPOSITIONS: 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 11 - 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 (then named "CONE Gathering LLC"), for a cash purchase price of $305,000 and the mutual release of all outstanding claims (the "Midstream Acquisition"). CNX Gathering owns a 100% membership interest in CNX Midstream GP LLC (the "general partner"), which is the general partner of CNXM. 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 20 - 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. The CNXM limited partner units are 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 Noble 2,620 Fair Value of Previously Held Equity Interest 799,033 Total Estimated Fair Value of Consideration Transferred $ 1,106,653 The following is a summary of the fair values of the net assets acquired: Fair Value of Assets Acquired: Amount 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 Post-Acquisition Operating Results (Midstream Acquisition) The Midstream Acquisition contributed the following to the Company's Midstream segment: For the Years Ended December 31, 2019 2018 Midstream Revenue $ 307,024 $ 258,074 Earnings from Continuing Operations Before Income Tax $ 166,654 $ 133,811 Unaudited Pro Forma Information (Midstream Acquisition) The following unaudited pro forma combined financial information presents the Company’s results as though the Midstream Acquisition had been completed at January 1, 2017. The pro forma combined financial information has been included for comparative purposes and is not necessarily indicative of the results that might have actually occurred had the acquisition been completed at January 1, 2017; furthermore, the financial information is not intended to be a projection of future results. For the Year Ended (in thousands, except per share data) (unaudited) December 31, 2017 Pro Forma Total Revenue and Other Operating Income $ 1,553,078 Pro Forma Net Income from Continuing Operations $ 427,381 Less: Pro Forma Net Income Attributable to Noncontrolling Interests $ 74,251 Pro Forma Net Income from Continuing Operations Attributable to CNX $ 353,130 Pro Forma Income per Share from Continuing Operations (Basic) $ 1.33 Pro Forma Income per Share from Continuing Operations (Diluted) $ 1.33 In September 2017, CNX closed on the sale of approximately 22,000 acres of surface land in Colorado. The net cash proceeds of $23,703 are included in Proceeds from Asset Sales in the Consolidated Statements of Cash Flows and the net gain on the transaction of $18,758 is included in Gain on Asset Sales and Abandonments, net in the Consolidated Statements of Income. In a two-part closing in July and September 2017, CNX executed the sale of approximately 7,500 net undeveloped acres of the Marcellus Shale in Allegheny and Westmoreland counties, Pennsylvania. The total cash proceeds of $36,649 are included in Proceeds from Asset Sales in the Consolidated Statements of Cash Flows and the net gain on the transaction of $15,251 is included in Gain on Asset Sales and Abandonments, net in the Consolidated Statements of Income. In June 2017, CNX closed on the sale of approximately 11,100 net undeveloped acres of the Marcellus and Utica Shale in Allegheny, Washington, and Westmoreland counties, Pennsylvania. The total cash proceeds of $83,500 are included in Proceeds from Asset Sales in the Consolidated Statements of Cash Flows and the net gain on the transaction of $58,541 is included in Gain on Asset Sales and Abandonments, net in the Consolidated Statements of Income. In June 2017, the Company finalized the sale of 12 producing wells, 15 drilled but uncompleted wells (DUCs), and approximately 11,000 net developed and undeveloped Marcellus and Utica acres in Doddridge and Wetzel counties in West Virginia that were previously classified as held for sale. CNX received total cash proceeds of $125,507 , which is included in Proceeds from Asset Sales in the Consolidated Statements of Cash Flows, as well as undeveloped acreage. The net loss on the sale of $9,430 is included in Gain on Asset Sales and Abandonments net in the Consolidated Statements of Income. In May 2017, CNX finalized the sale of approximately 6,300 net undeveloped acres of the Utica-Point Pleasant Shale in Jefferson, Belmont and Guernsey counties, Ohio that were previously classified as held for sale. The total cash proceeds of $76,585 are included in Proceeds from Asset Sales in the Consolidated Statements of Cash Flows and the net gain on the transaction of $72,346 is included in Gain on Asset Sales and Abandonments, net in the Consolidated Statements of Income. In April 2017, CNX finalized the sale of its Knox Energy LLC and Coalfield Pipeline Company subsidiaries that were previously classified as held for sale. At closing, CNX received net cash proceeds of $19,055 , which is included in Proceeds from Asset Sales in the Consolidated Statements of Cash Flows. The net gain on the sale of these assets was $606 and is included in the Gain on Asset Sales and Abandonments, net in the Consolidated Statements of Income. In February 2017, Knox met all of the criteria to be classified as held for sale. As part of the required evaluation under the held for sale guidance, Knox’s book value was evaluated, and it was determined that the approximate fair value less costs to sell Knox was less than the carrying value of the net assets to be sold. The resulting impairment of $ 137,865 is included in Impairment of Exploration and Production Properties in the Consolidated Statements of Income during the year ended December 31, 2017.

Stock Repurchase

Stock Repurchase	12 Months Ended
	Dec. 31, 2019
Equity [Abstract]
Stock Repurchase	STOCK REPURCHASE: Since the October 30, 2017 inception of the current stock repurchase program, CNX's Board of Directors has approved in total a $ 750,000 stock repurchase program, which is 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, 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 .

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES: Income tax expense (benefit) provided on earnings from continuing operations consisted of: For the Years Ended December 31, 2019 2018 2017 Current: U.S. Federal $ (51,243 ) $ (130,003 ) $ (31,791 ) U.S. State (113 ) — (1,838 ) (51,356 ) (130,003 ) (33,629 ) Deferred: U.S. Federal 47,717 319,813 (166,112 ) U.S. State 31,375 25,747 23,283 79,092 345,560 (142,829 ) Total Income Tax Expense (Benefit) $ 27,736 $ 215,557 $ (176,458 ) The components of the net deferred taxes are as follows: December 31, 2019 2018 Deferred Tax Assets: Net Operating Loss- Federal $ 202,913 $ 124,341 Net Operating Loss - State 130,430 110,339 Alternative Minimum Tax 51,241 102,482 Foreign Tax Credit 43,194 43,194 Interest Limitation 25,734 32,147 Gas Well Closing 17,888 10,140 Equity Compensation 9,308 13,096 Salary Retirement 9,236 9,434 Finance Lease 1,209 1,624 Other 10,030 13,714 Total Deferred Tax Assets 501,183 460,511 Valuation Allowance (125,054 ) (94,455 ) Net Deferred Tax Assets 376,129 366,056 Deferred Tax Liabilities: Property, Plant and Equipment (593,401 ) (606,342 ) Investment in Partnership (145,424 ) (125,253 ) Gas Derivatives (105,721 ) (26,160 ) Advance Gas Royalties (3,337 ) (3,384 ) Other (4,354 ) (3,599 ) Total Deferred Tax Liabilities (852,237 ) (764,738 ) Net Deferred Tax Liability $ (476,108 ) $ (398,682 ) 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. For the years ended December 31, 2019 and 2018 , 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, 2019 , the Company has a deferred tax asset related to federal net operating losses of $202,913 , which expire at various times between 2034 and 2038. However, because of the Tax Cuts and Jobs Act (the “Act”) enacted on December 22, 2017, the anticipated federal net operating losses generated in 2018 and 2019 do not expire but may only offset 80% of taxable income in any given year. The Act preserved the deductibility of intangible drilling costs for federal income tax purposes, which allows the Company to deduct a portion of drilling costs in the year incurred and minimizes current year taxes payable in periods of taxable income. The Act also repealed the corporate alternative minimum tax (AMT) for tax years beginning January 1, 2018 and provides that existing 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. The Company has reclassified $51,241 in 2019 and $102,482 in 2018 from Deferred Income Taxes to Recoverable Income Taxes in the Consolidated Balance Sheets in anticipation of the AMT refunds expected to be received in 2020 and received in 2019. The Company has a deferred tax asset relating to federal AMT credits of $51,241 and $102,482 , as of December 31, 2019 and 2018 , respectively, a decrease of $51,241 from the prior year that resulted from the anticipated and actual refund of the AMT credits. During 2018, the valuation allowance relating to federal AMT credits decreased by $12,413 as the Internal Revenue Service (IRS) announced that refunds of AMT credits are no longer subject to government sequestration. A valuation allowance on foreign tax credits of $43,194 has also been recorded at December 31, 2019 and 2018 . The foreign tax credits expire at various times between 2021 and 2023. A valuation allowance on charitable contribution carry-forwards of $658 and $3,297 has been recorded as of December 31, 2019 and 2018 , respectively. The Company's valuation allowance for charitable contributions decreased by $2,639 in 2019 due to expiration of the carry forward period. The remaining charitable contribution carry-forwards expire at various times between 2020 and 2024. CNX continues to report, on an after federal tax basis, a deferred tax asset related to state operating losses of $130,430 with a related valuation allowance of $81,202 at December 31, 2019 . The deferred tax asset related to state operating losses, on an after-tax adjusted basis, was $110,339 with a related valuation allowance of $47,964 at December 31, 2018 . A review of positive and negative evidence regarding these state tax benefits concluded that the valuation allowances for various CNX subsidiaries was warranted. These NOLs expire at various times between 2020 and 2039. 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, 2019 2018 2017 Amount Percent Amount Percent Amount Percent Statutory U.S. Federal Income Tax Rate $ 12,534 21.0 % $ 230,721 21.0 % $ 41,503 35.0 % Net Effect of State Income Taxes 1,333 2.2 60,814 5.6 15,538 13.1 Non-Controlling Interest (23,662 ) (39.6 ) (18,181 ) (1.7 ) — — Uncertain Tax Positions — — (4,265 ) (0.4 ) 27,359 23.1 Effect of Spin on Federal NOL's — — — — 24,942 21.0 Accrual to Tax Return Reconciliation 603 1.0 3,028 0.3 (1,147 ) (1.0 ) Effect of Equity Compensation 8,771 14.7 — — — — Effect of Change in State Valuation Allowance 33,238 55.6 (22,684 ) (2.1 ) (430 ) (0.4 ) Effect of Change in Federal Valuation Allowance (2,640 ) (4.4 ) (18,110 ) (1.7 ) (145,772 ) (122.9 ) Other Deferred Adjustments (1,691 ) (2.8 ) 5,957 0.6 7,616 6.4 Effect of Federal and State Rate Reductions (3,842 ) (6.4 ) (27,429 ) (2.5 ) (131,784 ) (111.1 ) Effect of Federal Tax Credits 2,881 4.8 1,208 0.1 (19,081 ) (16.1 ) Other 211 0.4 4,498 0.4 4,798 4.0 Income Tax Expense (Benefit) / Effective Rate $ 27,736 46.5 % $ 215,557 19.6 % $ (176,458 ) (148.9 )% 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 a 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 6 - 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 2019 and 2018 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 are under review by the IRS and the Joint Committee on Taxation. The 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. As discussed above, CNX has credits that are to be refunded between 2019 and 2021 because of the Act and monetization opportunities under current law in 2018. The Company recorded a net tax benefit to reflect the impact of the Act as of December 31, 2017, as it is required to reflect the change in the period in which the law is enacted. Largely, the benefits recorded in the period ending December 31, 2017 related to the Act are in recognition of the revaluation of deferred tax assets and liabilities, a benefit of $ 115,291 . The Company's effective tax rate for 2018 and 2017 reflects the release of previously recorded valuation allowances against AMT credit carry-forwards of $ 12,413 and $ 154,385 , respectively, as those credits will now be able to be monetized under the Act and, according to an IRS announcement, are no longer subject to government sequestration. The Act is also a comprehensive tax reform bill containing a number of other provisions that either currently or in the future could impact CNX. The effect of certain limitations effective for the tax year 2018 and forward, specifically related to the deductibility of executive compensation, have been evaluated. The Company anticipates U.S. regulatory agencies will issue further regulations which may alter these estimates. The IRS issued rules pertaining to the application of limitations for executive compensation related to contracts existing prior to November 2, 2017, and provisions in the Act addressing the deductibility of interest expense after January 1, 2018. The Company will continue to refine its estimates to incorporate new or better information as it comes available. Under the provisions of Staff Accounting Bulletin 118 (SAB 118), as of December 31, 2017, we had not completed our accounting for all of the enactment-date income tax effects of the Act under ASC 740, Income Taxes, for the remeasurement of deferred tax assets and liabilities. As of December 31, 2018, CNX completed its accounting for all of the enactment-date income tax effects of the Act. A reconciliation of the beginning and ending gross amounts of unrecognized tax benefits is as follows: For the Years Ended December 31, 2019 2018 Balance at Beginning of Period $ 31,516 $ 37,813 Increase in Unrecognized Tax Benefits Resulting from Tax Positions Taken During Prior Periods — 2,140 Reduction in Unrecognized Tax Benefits Because of the Lapse of the Applicable Statute of Limitations — (8,437 ) Balance at End of Period $ 31,516 $ 31,516 If these unrecognized tax benefits were recognized, $31,516 would affect CNX's effective income tax rate for 2019 and 2018 . In 2018, CNX recognized an increase in unrecognized tax benefits of $2,140 for tax benefits resulting from a revision to our tax position taken on our 2017 federal tax return for the marginal well credit. CNX recognized a reduction to unrecognized tax benefits of $ 8,437 from a position taken on a state tax return. CNX recognizes accrued interest related to unrecognized tax benefits in its interest expense. As of December 31, 2019 and 2018 , the Company reported no accrued liability relating to uncertain tax positions in Other Liabilities in the Consolidated Balance Sheets. The accrued interest liability includes interest income of $644 and interest expense of $337 recorded in the Company's Consolidated Statements of Income for the year ended December 31, 2018. During the years ended December 31, 2019 and 2018 , 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, 2019 and 2018 . 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 2016. The Joint Committee on Taxation is in the process of reviewing the NOL carryback returns for tax years 2016 and 2017. The review is expected to be completed in 2020. The Joint Committee on Taxation concluded its review of the audit of tax year 2015 on March 21, 2018. The audit resulted in a $ 108,651 reduction to CNX’s NOL, primarily due to a reduction in the depreciation as an offset to the bonus depreciation taken in the 2010-2013 IRS audit. There was no current cash tax impact from the audit.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2019
Asset Retirement Obligation [Abstract]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS: The reconciliation of changes in asset retirement obligations is as follows: As of December 31, 2019 2018 Balance, Beginning of Year $ 38,554 $ 204,070 Obligations Divested (Note 6) — (196,643 ) Accretion Expense 9,458 9,874 Obligations Incurred 2,933 4,795 Obligations Settled (4,231 ) (5,323 ) Revisions in Estimated Cash Flows 21,740 21,781 Balance, End of Year $ 68,454 $ 38,554

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2019
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	PROPERTY, PLANT AND EQUIPMENT: December 31, Property, Plant and Equipment 2019 2018 Intangible Drilling Cost $ 4,688,497 $ 4,120,283 Gas Gathering Equipment 2,463,866 2,126,895 Proved Gas Properties 1,208,046 1,135,411 Gas Wells and Related Equipment 1,042,000 859,359 Unproved Gas Properties 755,590 927,667 Surface Land and Other Equipment 226,285 238,487 Other 187,722 159,326 Total Property, Plant and Equipment 10,572,006 9,567,428 Less: Accumulated Depreciation, Depletion and Amortization 3,435,431 2,624,984 Total Property, Plant and Equipment - Net $ 7,136,575 $ 6,942,444 During the years ended December 31, 2019 and 2018 , the Company capitalized $5,482 and $1,075 , 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, 2019 and 2018 , respectively. These assets will be amortized using the units-of-production method and reclassified to proved gas properties when placed in service. December 31, 2019 2018 Unproved Gas Properties $ 755,590 $ 927,667 Advance Royalties 12,770 12,863 Total $ 768,360 $ 940,530 As of December 31, 2019 and 2018 , Property, Plant and Equipment includes a gross asset related to finance leases of $ 72,916 and $ 73,144 , respectively. Included in Gas Gathering Equipment is a finance lease for the Jewell Ridge Pipeline of $ 66,919 at December 31, 2019 and 2018 . CNX also maintains finance leases for vehicles of $ 5,997 and $ 6,225 at December 31, 2019 and 2018 , respectively, which is included in Other. Accumulated amortization for finance leases was $ 63,008 and $ 59,517 at December 31, 2019 and 2018

Goodwill and Other Intangible A

Goodwill and Other Intangible Assets	12 Months Ended
	Dec. 31, 2019
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 6 - 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. All goodwill is attributed to the Midstream reportable segment. The carrying amount and accumulated amortization of other intangible assets consist of the following: December 31, 2019 2018 Other Intangible Assets Gross Amortizable Asset - Customer Relationships $ 109,752 $ 109,752 Less: Accumulated Amortization - Customer Relationships 13,105 6,552 Total Other Intangible Assets, net $ 96,647 $ 103,200 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 in the current period. 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 $6,553 and $6,931 for the years ended December 31, 2019 and 2018 , respectively. There was no such expense for the year ended December 31, 2017. The estimated annual amortization expense is expected to approximate $ 6,552

Revolving Credit Facilities

Revolving Credit Facilities	12 Months Ended
	Dec. 31, 2019
Short-term Debt, Other Disclosures [Abstract]
Revolving Credit Facilities	REVOLVING CREDIT FACILITIES: CNX Resources Corporation (CNX) In April 2019, CNX amended its senior secured 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 the commitments to $3,000,000 . The borrowing base was reaffirmed at $2,100,000 , including a $650,000 letters of credit aggregate sub-limit. 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. If the aggregate principal amount of the existing 5.875% Senior Notes due in April 2022 and certain other publicly traded debt securities outstanding 91 days prior to the earliest maturity of such debt (the "Springing Maturity Date") is greater than $500,000 , then the Credit Facility will mature on the Springing Maturity Date. In October 2019, as part of the semi-annual borrowing base redetermination, the lenders increased CNX's borrowing base to $2,300,000 , including maintaining a $650,000 letters of credit sub-limit. Under the terms of the amended 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 0.25% to 1.25% ; or • the LIBOR rate, which is the LIBOR rate plus a margin ranging from 1.25% to 2.25% . The CNX Credit Facility is secured by substantially all of the assets of CNX and certain of its subsidiaries (excluding the Excluded Subsidiaries, which includes CNX Midstream GP LLC and CNXM and their respective subsidiaries). Fees and interest rate spreads are based on the percentage of facility utilization, measured quarterly. Availability under the Credit Facility is limited to a borrowing base, which is determined by the lenders' syndication agent and approved by the required number of lenders in good faith by calculating a value of CNX's proved natural gas reserves. 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 80% of the value of its proved reserves and 80% 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, 2019 . 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. At December 31, 2018 , the CNX Credit Facility had $612,000 borrowings outstanding and $198,396 letters of credit outstanding, leaving $1,289,604 of unused capacity. CNX Midstream Partners LP (CNXM) In April 2019, CNXM amended its senior secured revolving 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. Among other things, the revolving credit facility now includes (i) the addition of a restricted payment basket permitting cash repurchases of Incentive Distribution Rights (IDRs) subject to a pro forma secured leverage ratio of 3.00 to 1.00, a pro forma total leverage ratio of 4.00 to 1.00 and pro forma availability of 20% of commitments and (ii) a restricted payment basket for the repurchase of LP units not to exceed Available Cash (as defined in the partnership agreement) in any quarter, of up to $150,000 per year and up to $200,000 during the life of the facility. Under the terms of the amended agreement, borrowings under the revolving 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 includes the ability to issue letters of credit up to $100,000 in the aggregate. The CNXM revolving credit facility contains a number of affirmative and negative covenants that include, among others, covenants that, except in certain circumstances, restrict the ability of CNXM, its subsidiary guarantors and certain of its non-guarantor, non-wholly-owned subsidiaries, except in certain circumstances, to: (i) create, incur, assume or suffer to exist indebtedness; (ii) create or permit to exist liens on their properties; (iii) prepay certain indebtedness unless there is no default or event of default under the revolving facility; (iv) make or pay any dividends or distributions in excess of certain amounts; (v) merge with or into another person, liquidate or dissolve; or acquire all or substantially all of the assets of any going concern or going line of business or acquire all or a substantial portion of another person’s assets; (vi) make particular investments and loans; (vii) sell, transfer, convey, assign or dispose of its assets or properties other than in the ordinary course of business and other select instances; (viii) deal with any affiliate except in the ordinary course of business on terms no less favorable to CNXM than it would otherwise receive in an arm’s length transaction; and (ix) amend in any material manner its certificate of incorporation, bylaws, or other organizational documents without giving prior notice to the lenders and, in some cases, obtaining the consent of the lenders. 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 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, 2019 . The CNXM revolving 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 revolving credit facility. At December 31, 2019 , the CNXM credit facility had $311,750 of borrowings outstanding. CNXM had the maximum amount of revolving credit available for borrowing at December 31, 2019 , or $288,250 . At December 31, 2018 , the CNXM credit facility had $84,000

Other Accrued Liabilities

Other Accrued Liabilities	12 Months Ended
	Dec. 31, 2019
Other Liabilities Disclosure [Abstract]
Other Accrued Liabilities	OTHER ACCRUED LIABILITIES: December 31, 2019 2018 Royalties $ 74,061 $ 92,005 Accrued Interest 30,862 26,333 Short-Term Incentive Compensation 21,030 20,482 Transportation Charges 16,533 19,661 Deferred Revenue 13,964 17,693 Accrued Other Taxes 9,115 7,300 Accrued Payroll & Benefits 6,248 6,533 Other 38,105 31,851 Current Portion of Long-Term Liabilities: Asset Retirement Obligations 5,076 1,075 Salary Retirement 1,587 1,578 Total Other Accrued Liabilities $ 216,581 $ 224,511

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2019
Long-term Debt, Other Disclosures [Abstract]
Long-term Debt	LONG-TERM DEBT: December 31, 2019 2018 Senior Notes due April 2022 at 5.875% (Principal of $894,307 and $1,294,307 plus Unamortized Premium of $1,001 and $2,069, respectively) $ 895,308 $ 1,296,376 CNX Credit Facility 661,000 612,000 Senior Notes due March 2027 at 7.25%, 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 $4,625 and $5,375, respectively)* 395,375 394,625 CNX Midstream Partners LP Revolving Credit Facility* 311,750 84,000 Less: Unamortized Debt Issuance Costs 8,990 8,796 Long-Term Debt $ 2,754,443 $ 2,378,205 *CNX is not a guarantor of CNXM's 6.50% senior notes due in March 2026 or CNXM's senior secured revolving credit facility. At December 31, 2019, 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 2020 $ — 2021 — 2022 894,307 2023 — 2024 972,750 Thereafter 900,000 Total Long-Term Debt Maturities $ 2,767,057 During the year ended December 31, 2019 , CNX completed a private offering of $ 500,000 of 7.25% senior notes due in March 2027 . The notes are guaranteed by most of CNX's subsidiaries but do not include CNXM's general partner or CNXM. During the year ended December 31, 2019 , CNX purchased $ 400,000 of its outstanding 5.875% senior notes due in April 2022 . As part of this transaction, a loss of $ 7,614 was included in Loss on Debt Extinguishment in the Consolidated Statements of Income. During the year ended December 31, 2018 , CNXM completed a private offering of $ 400,000 of 6.50% senior notes due in March 2026 less $ 6,000 of unamortized bond discount. CNX is not a guarantor of CNXM's 6.50% senior notes due in March 2026 or CNXM's senior secured revolving credit facility. During the year ended December 31, 2018 , CNX purchased $ 411,375 of its outstanding 5.875% senior notes due in April 2022 . As part of this transaction, a loss of $ 15,320 was included in 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 in April 2023 . As part of this transaction, a loss of $ 38,798 was included in Loss on Debt Extinguishment in the Consolidated Statements of Income. During the year ended December 31, 2017 , CNX purchased $ 144,318 of its outstanding 5.875% senior notes due in April 2022 . As part of this transaction, a loss of $ 110 was included in Loss on Debt Extinguishment in the Consolidated Statements of Income. During the year ended December 31, 2017 , CNX called the remaining $ 74,470 balance on its 8.25% senior notes due in April 2020 and the remaining $ 20,611 balance on its 6.375% senior notes due in March 2021 . As part of these transactions, a loss of $ 2,019 was included in Loss on Debt Extinguishment in the Consolidated Statements of Income.

Leases

Leases	12 Months Ended
	Dec. 31, 2019
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 Year Ended December 31, 2019 Operating Lease Cost $ 73,809 Finance Lease Cost: Amortization of Right-of-Use Assets 5,242 Interest on Lease Liabilities 1,241 Short-term Lease Cost 5,547 Variable Lease Cost* 17,337 Total Lease Cost $ 103,176 *Amount recognized in the Consolidated Balance Sheet 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. Amount recognized in the Consolidated Balance Sheet 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 and $16,797 for the years ended December 31, 2018 and 2017, respectively. Amounts recognized in the Consolidated Balance Sheet are as follows: December 31, 2019 Operating Leases: Operating Lease Right-of-Use Asset $ 187,097 Current Portion of Operating Lease Obligations $ 61,670 Operating Lease Obligations 110,466 Total Operating Lease Liabilities $ 172,136 Finance Leases: Property, Plant and Equipment $ 72,916 Less—Accumulated Depreciation, Depletion and Amortization 63,008 Property, Plant and Equipment—Net $ 9,908 Current Portion of Finance Lease Obligations $ 7,164 Finance Lease Obligations 7,706 Total Finance Lease Liabilities $ 14,870 Supplemental cash flow information related to leases was as follows: For the Year Ended December 31, 2019 Cash Paid for Amounts Included in the Measurement of Lease Liabilities: Operating Cash Flows from Operating Leases $ 66,827 Operating Cash Flows from Finance Leases $ 1,241 Financing Cash Flows from Finance Leases $ 7,149 Right-of-Use Assets Obtained in Exchange for Lease Obligations: Operating Leases $ 15,347 Finance Leases $ 1,846 Maturities of lease liabilities are as follows: Operating Finance Leases Leases Year Ended December 31, 2020 $ 68,663 $ 7,968 2021 59,410 7,142 2022 23,789 436 2023 5,453 433 2024 5,433 127 Thereafter 30,822 — Total Lease Payments 193,570 16,106 Less: Interest 21,434 1,236 Present Value of Lease Liabilities $ 172,136 $ 14,870 Lease terms and discount rates are as follows: December 31, 2019 Weighted Average Remaining Lease Term (years): Operating Leases 4.39 Finance Leases 2.16 Weighted Average Discount Rate: Operating Leases 4.96 % Finance Leases 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 Year Ended December 31, 2019 Operating Lease Cost $ 73,809 Finance Lease Cost: Amortization of Right-of-Use Assets 5,242 Interest on Lease Liabilities 1,241 Short-term Lease Cost 5,547 Variable Lease Cost* 17,337 Total Lease Cost $ 103,176 *Amount recognized in the Consolidated Balance Sheet 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. Amount recognized in the Consolidated Balance Sheet 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 and $16,797 for the years ended December 31, 2018 and 2017, respectively. Amounts recognized in the Consolidated Balance Sheet are as follows: December 31, 2019 Operating Leases: Operating Lease Right-of-Use Asset $ 187,097 Current Portion of Operating Lease Obligations $ 61,670 Operating Lease Obligations 110,466 Total Operating Lease Liabilities $ 172,136 Finance Leases: Property, Plant and Equipment $ 72,916 Less—Accumulated Depreciation, Depletion and Amortization 63,008 Property, Plant and Equipment—Net $ 9,908 Current Portion of Finance Lease Obligations $ 7,164 Finance Lease Obligations 7,706 Total Finance Lease Liabilities $ 14,870 Supplemental cash flow information related to leases was as follows: For the Year Ended December 31, 2019 Cash Paid for Amounts Included in the Measurement of Lease Liabilities: Operating Cash Flows from Operating Leases $ 66,827 Operating Cash Flows from Finance Leases $ 1,241 Financing Cash Flows from Finance Leases $ 7,149 Right-of-Use Assets Obtained in Exchange for Lease Obligations: Operating Leases $ 15,347 Finance Leases $ 1,846 Maturities of lease liabilities are as follows: Operating Finance Leases Leases Year Ended December 31, 2020 $ 68,663 $ 7,968 2021 59,410 7,142 2022 23,789 436 2023 5,453 433 2024 5,433 127 Thereafter 30,822 — Total Lease Payments 193,570 16,106 Less: Interest 21,434 1,236 Present Value of Lease Liabilities $ 172,136 $ 14,870 Lease terms and discount rates are as follows: December 31, 2019 Weighted Average Remaining Lease Term (years): Operating Leases 4.39 Finance Leases 2.16 Weighted Average Discount Rate: Operating Leases 4.96 % Finance Leases 6.92 %

Pension

Pension	12 Months Ended
	Dec. 31, 2019
Defined Contribution Plan [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 Balances Sheets. The reconciliation of changes in the benefit obligation, plan assets and funded status of the pension benefits is as follows: December 31, 2019 2018 Change in Benefit Obligation: Benefit Obligation at Beginning of Period $ 33,569 $ 36,280 Service Cost 209 302 Interest Cost 1,338 1,265 Actuarial Loss (Gain) 4,865 (2,645 ) Plan Amendments 1,728 — Plan Curtailments — (126 ) Benefits and Other Payments (1,513 ) (1,507 ) Benefit Obligation at End of Period $ 40,196 $ 33,569 Change in Plan Assets: Fair Value of Plan Assets at Beginning of Period $ — $ — Company Contributions 1,513 1,507 Benefits and Other Payments (1,513 ) (1,507 ) Fair Value of Plan Assets at End of Period $ — $ — Funded Status: Current Liabilities $ (1,587 ) $ (1,578 ) Noncurrent Liabilities (38,609 ) (31,991 ) Net Obligation Recognized $ (40,196 ) $ (33,569 ) Amounts Recognized in Accumulated Other Comprehensive Loss Consist of: Net Actuarial Loss $ 15,361 $ 10,738 Prior Service Cost (Credit) 1,727 (17 ) Total 17,088 10,721 Less: Tax Benefit 4,483 2,817 Net Amount Recognized $ 12,605 $ 7,904 The components of the net periodic benefit cost are as follows: For the Years Ended December 31, 2019 2018 2017 Components of Net Periodic Benefit Cost: Service Cost $ 209 $ 302 $ 375 Interest Cost 1,338 1,265 1,201 Amortization of Prior Service Credits (17 ) (193 ) (362 ) Recognized Net Actuarial Loss 242 865 1,525 Curtailment Gain — (416 ) — Net Periodic Benefit Cost $ 1,772 $ 1,823 $ 2,739 Amounts included in accumulated other comprehensive loss which are expected to be recognized in 2020 net periodic benefit cost: Pension Benefits Prior Service Cost Recognition $ (221 ) Actuarial Loss Recognition $ (383 ) 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, 2019 2018 Projected Benefit Obligation $ 40,196 $ 33,569 Accumulated Benefit Obligation $ 40,196 $ 33,169 Fair Value of Plan Assets $ — $ — Assumptions: The weighted-average assumptions used to determine benefit obligations are as follows: As of December 31, 2019 2018 Discount Rate 3.36 % 4.37 % Rate of Compensation Increase — % 3.63 % 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, 2019 2018 2017 Discount Rate 4.37 % 4.28 % 4.26 % Rate of Compensation Increase 3.63 % 4.05 % 3.90 % Cash Flows: CNX expects to pay benefits of $1,588 from the non-qualified pension plan in 2020. The following benefit payments, which reflect expected future service, are expected to be paid: Pension Year ended December 31, Benefits 2020 $ 1,588 2021 $ 1,670 2022 $ 1,760 2023 $ 1,866 2024 $ 2,063 Year 2025-2029 $ 11,207

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2019
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 2016, the Company's Shareholders adopted and approved a 10,550,000 increase to the total number of shares available for issuance, which brought the total number of shares of common stock that can be covered by grants in accordance with the terms of the Equity Incentive Plan, after adjustment for the separation of the coal business from the gas business on November 28, 2017, to 48,915,944 . At December 31, 2019 , 5,560,610 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 vest over a five-year term at 20% 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, 2019 , 2018 and 2017 was $ 36,545 , $ 18,930 and $ 16,983 , respectively. As of December 31, 2019 , CNX has $ 7,346 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 2.24 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 terms of the CNX Equity Plan and the outstanding awards, in the event of certain changes in the outstanding common stock of CNX or its capital structure, including by reason of a spin-off, the administrator of the CNX Equity Plan is required to appropriately adjust the number, exercise price, kind of shares, performance goals or other terms and conditions of Awards granted thereunder. In connection with the Separation, the Board of Directors of CNX has determined that it is appropriate that the outstanding awards be equitably adjusted pursuant to the terms of the CNX Equity Plan and/or converted into awards issued under the CONSOL Energy Inc. (CEIX) Equity Incentive Plan, such that the intrinsic value of the outstanding awards immediately following the separation remains the same as the intrinsic value of such awards immediately prior to the Separation. The separation resulted in a modification of the equity plans but did not have a material impact on the financial statements as of the date of Separation (See Note 5 - Discontinued Operations for more information). 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, 2019 , 2018 and 2017 was $50 , $143 , and $353 respectively, based on the following assumptions and weighted average fair values: December 31, 2019 2018 2017 Weighted Average Fair Value of Grants $ 3.48 $ 6.50 $ 6.19 Risk-free Interest Rate 2.13 % 2.66 % 1.66 % Expected Dividend Yield — % — % — % Expected Forfeiture Rate — % — % — % Expected Volatility 43.60 % 52.68 % 50.85 % Expected Term in Years 6.50 3.71 3.71 A summary of the status of stock options granted is presented below: Weighted Average Weighted Remaining Aggregate Average Contractual Intrinsic Exercise Term (in Value (in Shares Price years) thousands) Outstanding at December 31, 2018 5,442,920 $ 18.74 Granted 14,368 $ 7.54 Exercised (79,468 ) $ 6.87 Forfeited (4,208 ) $ 6.87 Expired (677,348 ) $ 24.29 Outstanding at December 31, 2019 4,696,264 $ 18.05 4.49 $ 5,280 Exercisable at December 31, 2019 4,681,896 $ 18.04 4.47 $ 5,261 At December 31, 2019 , there are 4,224,415 employee stock options outstanding under the Equity Incentive Plan. Non-employee director stock options vest one year after the grant date. There are 471,849 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, 2019 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, 2019 . 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, 2019 , 2018 and 2017 was $175 , $ 2,077 , and $1,067 , respectively. Cash received from option exercises for the years ended December 31, 2019 , 2018 and 2017 was $546 , $ 1,714 and $1,002 , respectively. The tax impact from option exercises totaled $46 , $ 569 and $205 for the years ended December 31, 2019 , 2018 and 2017 , 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, 2019 , 2018 and 2017 was $ 10,844 , $ 13,768 and $ 14,328 , respectively. The total fair value of restricted stock units vested during the years ended December 31, 2019 , 2018 and 2017 was $ 10,391 , $ 6,437 and $ 12,805 , 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 of Weighted Average Shares Grant Date Fair Value Nonvested at December 31, 2018 1,427,151 $14.30 Granted 963,426 $11.26 Vested (1,052,235 ) $14.27 Forfeited (305,142 ) $13.50 Nonvested at December 31, 2019 1,033,200 $11.71 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, 2019 , 2018 and 2017 was $ 6,741 , $ 8,570 and $ 9,789 , respectively. The total fair value of performance share units vested during the years ended December 31, 2019 , 2018 and 2017 was $4,668 , $ 7,547 and $17,646 , 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 of Weighted Average Shares Grant Date Fair Value Nonvested at December 31, 2018 1,344,985 $19.93 Granted 407,056 $16.56 PSUs Issued as a Result of 200% Payout 156,918 $22.63 Vested (345,282 ) $22.21 Forfeited (162,841 ) $17.83 Nonvested at December 31, 2019 1,400,836 $18.91 Performance Options: Under the Equity Incentive Plan in 2010, CNX granted certain employees performance options, 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. There were 927,268 performance options outstanding and exercisable at a weighted average exercise price of $39.00 and a weighted average remaining contractual term of 0.46 years as of December 31, 2019 .

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2019
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 5 - Discontinued Operations and Note 6 - Acquisitions and Dispositions. As of December 31, 2019 , 2018 and 2017 , CNX purchased goods and services related to capital projects in the amount of $ 43,982 , $ 58,246 and $35,437 , respectively, which are included in accounts payable. The following table shows cash paid (received): For the Years Ended December 31, 2019 2018 2017 Interest (Net of Amounts Capitalized) $ 143,111 $ 144,756 $ 152,047 Income Taxes $ (138,409 ) $ (11,505 ) $ (121,773 )

Concentrations of Credit Risk a

Concentrations of Credit Risk and Major Customers	12 Months Ended
	Dec. 31, 2019
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, 2019 2018 Gas Wholesalers $ 115,641 $ 232,638 NGL, Condensate & Processing Facilities 10,140 12,595 Other 7,699 7,191 Total Accounts Receivable Trade $ 133,480 $ 252,424 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 in the Gas Wholesalers balance above. As of December 31, 2018 , receivables of $30,872 and $26,417 due from NJR Energy Services Company and Direct Energy Business Marketing LLC , respectively, were included. No other customers made up more than 10% of the total balances. 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. During the year ended December 31, 2017 , sales to Direct Energy Business Marketing LLC were $153,565 and sales to NJR Energy Services Company were $147,595 , each of which comprised over 10% of the Company's revenue from contracts with external customers for the period.

Fair Value of Financial Instrum

Fair Value of Financial Instruments	12 Months Ended
	Dec. 31, 2019
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 One - Quoted prices for identical instruments in active markets. Level Two - 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 Three - 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 Fair Value Measurements at Description Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Gas Derivatives $ — $ 405,781 $ — $ — $ 99,456 $ — The carrying amounts and fair values of financial instruments for which the fair value option was not elected are as follows: December 31, 2019 December 31, 2018 Carrying Amount Fair Value Carrying Amount Fair Value Cash and Cash Equivalents $ 16,283 $ 16,283 $ 17,198 $ 17,198 Long-Term Debt (Excluding Debt Issuance Costs) $ 2,763,433 $ 2,619,676 $ 2,387,001 $ 2,290,537 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.

Derivative Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	DERIVATIVE INSTRUMENTS: In June 2019, CNX entered into an interest rate swap agreement to manage its exposure to interest rate volatility. The interest rate swap agreement relates to $160,000 of borrowings under CNX’s senior secured revolving credit facility (See Note 12 - Revolving Credit Facilities) and has the economic effect of modifying the variable-interest obligation into a fixed-interest obligation over a three-year period. The change in fair value of the interest rate swap agreement is accounted for on a mark-to-market basis with changes in fair value recorded in current period earnings. The fair value at December 31, 2019 and the corresponding change in fair value from inception through December 31, 2019 was nominal. CNX enters into financial derivative instruments to manage its exposure to commodity price volatility. These natural gas and NGL 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 one 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 its 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 2019 2018 Settle Through Natural Gas Commodity Swaps (Bcf) 1,460.6 1,484.4 2025 Natural Gas Basis Swaps (Bcf) 1,290.4 1,056.6 2025 The gross fair value of CNX's derivative instruments was as follows: Asset Derivative Instruments Liability Derivative Instruments December 31, December 31, 2019 2018 2019 2018 Commodity Swaps: Current Assets $ 234,238 $ 28,612 Current Liabilities $ 345 $ 34,640 Other Assets 288,543 164,310 Non-Current Liabilities 9,693 52,011 Total Asset $ 522,781 $ 192,922 Total Liability $ 10,038 $ 86,651 Basis Only Swaps: Current Assets $ 13,556 $ 11,628 Current Liabilities $ 40,626 $ 27,021 Other Assets 25,553 48,788 Non-Current Liabilities 105,445 40,210 Total Asset $ 39,109 $ 60,416 Total Liability $ 146,071 $ 67,231 The effect of derivative instruments on the Company's Consolidated Statements of Income was as follows: For the Years Ended December 31, 2019 2018 2017 Cash Received (Paid) in Settlement of Commodity Derivative Instruments: Commodity Swaps: Natural Gas $ 82,899 $ (41,098 ) $ (34,928 ) Propane — — (1,216 ) Natural Gas Basis Swaps (13,119 ) (28,622 ) (5,030 ) Total Cash Received (Paid) in Settlement of Commodity Derivative Instruments 69,780 (69,720 ) (41,174 ) Unrealized Gain (Loss) on Commodity Derivative Instruments: Commodity Swaps: Natural Gas 406,472 33,026 319,605 Propane — — 1,147 Natural Gas Basis Swaps (100,147 ) 6,482 (72,648 ) Total Unrealized Gain on Commodity Derivative Instruments 306,325 39,508 248,104 Gain (Loss) on Commodity Derivative Instruments: Commodity Swaps: Natural Gas $ 489,371 $ (8,072 ) $ 284,677 Propane — — (69 ) Natural Gas Basis Swaps (113,266 ) (22,140 ) (77,678 ) Total Gain (Loss) on Commodity Derivative Instruments $ 376,105 $ (30,212 ) $ 206,930 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.

Commitments and Contingent Liab

Commitments and Contingent Liabilities	12 Months Ended
	Dec. 31, 2019
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. At December 31, 2019 , 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 Years 3-5 Years Beyond 5 Years Letters of Credit: Firm Transportation $ 197,776 $ 148,526 $ 49,250 $ — $ — Other 6,950 6,200 750 — — Total Letters of Credit 204,726 154,726 50,000 — — Surety Bonds: Employee-Related 2,600 2,600 — — — Environmental 12,763 12,503 260 — — Financial Guarantees 81,670 81,670 — — — Other 9,254 7,970 1,284 — — Total Surety Bonds 106,287 104,743 1,544 — — Total Commitments $ 311,013 $ 259,469 $ 51,544 $ — $ — Excluded from the above table are commitments and guarantees entered into in conjunction with the spin-off of the Company's coal business (See Note 5 - Discontinued Operations). 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. 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, 2019 , the purchase obligations for each of the next five years and beyond were as follows: Obligations Due Amount Less than 1 year $ 256,613 1 - 3 years 483,807 3 - 5 years 406,915 More than 5 years 1,072,748 Total Purchase Obligations $ 2,220,083

Variable Interest Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Variable Interest Entities	VARIABLE INTEREST ENTITIES: The Company determined CNXM, of which the Company owned an approximately 34% limited partner interest (prior to the IDR Elimination transaction - See Note 25 - Subsequent Event) and 100% of the general partner interest, to be a variable interest entity. As a result of the Midstream Acquisition (see Note 6 - Acquisitions and Dispositions), the Company has the power through the Company's ownership and control of CNXM's general partner (CNX Midstream GP LLC) to direct the activities that most significantly impact CNXM's economic performance. In addition, through its limited partner interest in CNXM, the Company has the obligation to absorb the losses of CNXM and the right to receive benefits in accordance with such interests. As the Company has a controlling financial interest and is the primary beneficiary of CNXM, the Company consolidated CNXM commencing January 3, 2018. The risks associated with the operations of CNXM are discussed in its Annual Report on Form 10-K for the year ended December 31, 2019 filed with the SEC on February 10, 2020 and its other periodic reports filed thereafter. The following table presents amounts included in the Company's Consolidated Balance Sheets that were for the use or obligation of CNXM: December 31, 2019 2018 Assets: Cash $ 31 $ 3,966 Receivables - Related Party 21,076 17,073 Receivables - Third Party 7,935 7,028 Other Current Assets 1,976 2,383 Property, Plant and Equipment, net 1,195,591 891,775 Operating Lease ROU Asset 4,731 — Other Assets 3,262 3,203 Total Assets $ 1,234,602 $ 925,428 Liabilities: Accounts Payable and Accrued Liabilities $ 67,290 $ 43,919 Accounts Payable - Related Party 4,787 4,980 Revolving Credit Facility 311,750 84,000 Long-Term Debt 394,162 393,215 Total Liabilities $ 777,989 $ 526,114 The following table summarizes CNXM's Consolidated Statements of Operations and Cash Flows, inclusive of affiliate amounts: For the Years Ended December 31, 2019 2018 Revenue Gathering Revenue - Related Party $ 231,482 $ 167,048 Gathering Revenue - Third Party 74,315 89,620 Total Revenue 305,797 256,668 Expenses Operating Expense - Related Party 22,943 19,814 Operating Expense - Third Party 23,964 27,343 General and Administrative Expense - Related Party 15,928 13,867 General and Administrative Expense - Third Party 5,769 8,595 Loss on Asset Sales and Abandonments, net 7,229 2,501 Depreciation Expense 24,371 21,939 Interest Expense 30,293 23,614 Total Expense 130,497 117,673 Net Income $ 175,300 $ 138,995 Net Cash Provided by Operating Activities $ 217,062 $ 180,115 Net Cash Used in Investing Activities $ (327,615 ) $ (138,869 ) Net Cash Provided by (Used in) Financing Activities $ 106,618 $ (40,474 ) Prior to the acquisition of Noble's interest on January 3, 2018, CNX accounted for its interests in CNX Gathering and CNXM as an equity-method investment. The following transactions were included in Other Operating Income and Transportation, Gathering and Compression in the Consolidated Statements of Income: For the Year Ended December 31, 2017 Other Operating Income: Equity in Earnings of Affiliates - CNX Gathering $ 9,823 Equity in Earnings of Affiliates - CNXM $ 38,523 Transportation, Gathering and Compression: Gathering Services - CNX Gathering $ 914 Gathering Services - CNXM $ 136,068 In March 2018, CNXM closed on its acquisition of CNX's remaining 95% interest in the gathering system and related assets commonly referred to as the Shirley-Penns System, in exchange for cash consideration in the amount of $265,000 . CNXM funded the cash considerations with proceeds from the issuance of its 6.50% senior notes due 2026 (See Note 14 - Long-Term Debt). At December 31, 2019 and 2018 , CNX had a net payable of $16,362 and $12,202

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2019
Segment Reporting [Abstract]
Segment Information	SEGMENT INFORMATION: CNX consists of two principal business divisions: Exploration and Production (E&P) and Midstream. The principal activity of the E&P Division, which includes four reportable segments, is to produce pipeline quality natural gas for sale primarily to gas wholesalers. The E&P Division's reportable segments are Marcellus Shale, Utica Shale, Coalbed Methane and Other Gas. The Other Gas Segment is primarily related to shallow oil and gas production which is not significant to the Company due to the sale of substantially all of CNX's shallow oil and gas assets in the 2018 period (See Note 6 - Acquisitions and Dispositions for more information). It also includes the Company's purchased gas activities, unrealized gain or loss on commodity derivative instruments, exploration and production related other costs, impairments of exploration and production properties and unproved properties and expirations, as well as various other operating activities assigned to the E&P Division but not allocated to each individual segment. CNX's Midstream Division's principal activity is the ownership, operation, development and acquisition of natural gas gathering and other midstream energy assets of CNX Gathering and CNXM, which provide natural gas gathering services for the Company's produced gas, as well as for other independent third-parties in the Marcellus Shale and Utica Shale in Pennsylvania and West Virginia. Excluded from the Midstream Division are the gathering assets and operations of CNX that have not been contributed to CNX Gathering and CNXM. As a result of the Midstream Acquisition (See Note 6 - Acquisitions and Dispositions for more information), CNX owns and controls 100% of CNX Gathering, making CNXM a single-sponsor master limited partnership and thus the Company began consolidating CNXM on January 3, 2018. The Midstream Division is comprised of a single Midstream segment. The Company's unallocated expenses include other expense, gain on asset sales related to non-core assets, gain on previously held equity interest, loss on debt extinguishment, impairment of other intangible assets and income taxes. In the preparation of the following information, intersegment sales have been recorded at amounts approximating market prices. Operating profit for each segment is based on sales less identifiable operating and non-operating expenses. Assets are reflected at the division level for E&P and are not allocated between each individual E&P segment. These assets are not allocated to each individual segment due to the diverse asset base controlled by CNX, whereby each individual asset may service more than one segment within the division. An allocation of such asset base would not be meaningful or representative on a segment by segment basis. Industry segment results for the year ended December 31, 2019 are: Marcellus Shale Utica Shale Coalbed Methane Other Gas Total E&P Midstream Unallocated Intercompany Eliminations Consolidated Natural Gas, NGLs and Oil Revenue $ 934,728 $ 264,548 $ 163,893 $ 1,156 $ 1,364,325 $ — $ — $ — $ 1,364,325 (A) Purchased Gas Revenue — — — 94,027 94,027 — — — 94,027 Midstream Revenue — — — — — 307,024 — (232,710 ) 74,314 Gain on Commodity Derivative Instruments 47,475 14,943 7,335 306,352 376,105 — — — 376,105 Other Operating Income — — — 14,057 14,057 — — (379 ) 13,678 (B) Total Revenue and Other Operating Income $ 982,203 $ 279,491 $ 171,228 $ 415,592 $ 1,848,514 $ 307,024 $ — $ (233,089 ) $ 1,922,449 Earnings (Loss) From Continuing Operations Before Income Tax $ 234,284 $ 87,972 $ 35,170 $ (497,869 ) $ (140,443 ) $ 166,654 $ 33,473 $ — $ 59,684 Segment Assets $ 6,745,091 $ 2,230,676 $ 78,708 $ 6,331 $ 9,060,806 (C) Depreciation, Depletion and Amortization $ 474,352 $ 34,111 $ — $ — $ 508,463 Capital Expenditures $ 867,860 $ 324,739 $ — $ — $ 1,192,599 (A) 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. (B) Includes equity in earnings of unconsolidated affiliates of $2,103 for Total E&P. (C) Includes investments in unconsolidated equity affiliates of $16,710 for Total E&P. Industry segment results for the year ended December 31, 2018 are: Marcellus Shale Utica Shale Coalbed Methane Other Gas Total E&P Midstream Unallocated Intercompany Eliminations Consolidated Natural Gas, NGLs and Oil Revenue $ 903,316 $ 445,880 $ 212,884 $ 15,857 $ 1,577,937 $ — $ — $ — $ 1,577,937 (D) Purchased Gas Revenue — — — 65,986 65,986 — — — 65,986 Midstream Revenue — — — — — 258,074 — (168,293 ) 89,781 (Loss) Gain on Commodity Derivative Instruments (40,444 ) (19,882 ) (8,767 ) 38,881 (30,212 ) — — — (30,212 ) Other Operating Income — — — 27,218 27,218 — — (276 ) 26,942 (E) Total Revenue and Other Operating Income $ 862,872 $ 425,998 $ 204,117 $ 147,942 $ 1,640,929 $ 258,074 $ — $ (168,569 ) $ 1,730,434 Earnings (Loss) From Continuing Operations Before Income Tax $ 254,310 $ 194,164 $ 49,719 $ (253,577 ) $ 244,616 $ 133,811 $ 720,241 $ — $ 1,098,668 Segment Assets $ 6,518,597 $ 1,919,117 $ 166,679 $ (12,223 ) $ 8,592,170 (F) Depreciation, Depletion and Amortization $ 461,149 $ 32,274 $ — $ — $ 493,423 Capital Expenditures $ 974,059 $ 142,338 $ — $ — $ 1,116,397 (D) 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. (E) Includes equity in earnings of unconsolidated affiliates of $5,363 for Total E&P. (F) Includes investments in unconsolidated equity affiliates of $18,663 for Total E&P. Industry segment results for the year ended December 31, 2017 are: Marcellus Shale Utica Shale Coalbed Methane Other Gas Total E&P Unallocated Consolidated Natural Gas, NGLs and Oil Revenue $ 646,188 $ 217,020 $ 208,677 $ 53,339 $ 1,125,224 $ — $ 1,125,224 (G) Purchased Gas Revenue — — — 53,795 53,795 — 53,795 (Loss) Gain on Commodity Derivative Instruments (30,336 ) 1,367 (9,589 ) 245,488 206,930 — 206,930 Other Operating Income — — — 69,182 69,182 — 69,182 (H) Total Revenue and Other Operating Income $ 615,852 $ 218,387 $ 199,088 $ 421,804 $ 1,455,131 $ — $ 1,455,131 Earnings (Loss) From Continuing Operations Before Income Tax $ 91,436 $ 64,741 $ 20,346 $ (240,050 ) $ (63,527 ) $ 182,108 $ 118,581 Segment Assets $ 6,391,223 $ 540,690 $ 6,931,913 (I) Depreciation, Depletion and Amortization $ 412,036 $ — $ 412,036 Capital Expenditures $ 632,846 $ — $ 632,846 (G) Included in Total Natural Gas, NGLs and Oil Revenue are sales of $153,656 to Direct Energy Business Marketing LLC and $147,595 to NJR Energy Services Company, each of which comprises over 10% of revenue from contracts with external customers for the period. (H) Includes equity in earnings of unconsolidated affiliates of $ 49,830 for Total E&P. (I) Includes investments in unconsolidated equity affiliates of $197,921 for Total E&P. Reconciliation of Segment Information to Consolidated Amounts: Revenue and Other Operating Income: For the Years Ended December 31, 2019 2018 2017 Total Segment Revenue from Contracts with External Customers $ 1,532,666 $ 1,733,704 $ 1,179,019 Gain (Loss) on Commodity Derivative Instruments 376,105 (30,212 ) 206,930 Other Operating Income 13,678 26,942 69,182 Total Consolidated Revenue and Other Operating Income $ 1,922,449 $ 1,730,434 $ 1,455,131 Earnings (Loss) From Continuing Operations Before Income Tax: For the Years Ended December 31, 2019 2018 2017 Segment Earnings (Loss) Before Income Taxes for Reportable Business Segments: E&P $ (140,443 ) $ 244,616 $ (63,527 ) Midstream 166,654 133,811 — Total Segment Earnings (Loss) Before Income Taxes for Reportable Business Segments 26,211 378,427 (63,527 ) Unallocated Expenses: Other (Expense) Income (1,396 ) 14,571 (3,826 ) Gain on Certain Asset Sales 42,483 154,775 188,063 Gain on Previously Held Equity Interest — 623,663 — Loss on Debt Extinguishment (7,614 ) (54,118 ) (2,129 ) Impairment of Other Intangible Assets — (18,650 ) — Earnings from Continuing Operations Before Income Tax $ 59,684 $ 1,098,668 $ 118,581 Total Assets: December 31, 2019 2018 Segment Assets for Total Reportable Business Segments: E&P $ 6,745,091 $ 6,518,597 Midstream 2,230,676 1,919,117 Intercompany Eliminations 6,331 (12,223 ) Items Excluded from Segment Assets: Cash and Cash Equivalents 16,283 17,198 Recoverable Income Taxes 62,425 149,481 Total Consolidated Assets $ 9,060,806 $ 8,592,170

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2019
Subsequent Events [Abstract]
Subsequent Events	SUBSEQUENT EVENT On January 29, 2020, CNX and CNXM entered into and closed definitive agreements to eliminate CNXM’s IDRs held by its general partner and to convert the 2.0% general partner interest in CNXM into a non-economic general partnership interest (collectively, the "IDR Elimination Transaction"). Pursuant to the IDR Elimination Transaction agreements, CNX will receive the following consideration in exchange for the IDRs and the 2.0% general partner interest: • 26 million CNXM common units; • 3 million new CNXM Class B units. The newly issued Class B units will not receive or accrue distributions until January 1, 2022, at which time they will automatically convert into CNXM common units on a one -for-one basis; and • $135,000 to be paid in three installments of $50,000 due December 31, 2020, $50,000 due December 31, 2021 and $35,000 due December 31, 2022. As a result of the IDR Elimination Transaction, CNX now owns 47.7 million common units, or approximately 53.1% , of the outstanding limited partner interests in CNXM, excluding the Class B units. Upon conversion of the Class B units to CNXM common units on January 1, 2022, CNX's ownership will increase to 50.7 million

Supplemental Gas Data (unaudite

Supplemental Gas Data (unaudited)	12 Months Ended
	Dec. 31, 2019
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, 2019 2018 Intangible Drilling Costs $ 4,688,497 $ 4,120,283 Proved Gas Properties 1,208,046 1,135,411 Gas Gathering Assets 1,110,977 1,099,047 Unproved Gas Properties 755,590 927,667 Gas Wells and Related Equipment 1,042,000 856,973 Other Gas Assets 73,479 54,395 Total Property, Plant and Equipment $ 8,878,589 $ 8,193,776 Accumulated Depreciation, Depletion and Amortization (3,263,221 ) (2,475,917 ) Net Capitalized Costs $ 5,615,368 $ 5,717,859 Costs incurred for property acquisition, exploration and development (*): For the Years Ended December 31, 2019 2018 2017 Property Acquisitions: Proved Properties $ 36,710 $ 38,621 $ 15,850 Unproved Properties 24,760 36,248 32,038 Development 739,874 844,081 544,809 Exploration 79,855 61,604 48,020 Total $ 881,199 $ 980,554 $ 640,717 __________ (*) Includes costs incurred whether capitalized or expensed. Results of Operations for Producing Activities: For the Years Ended December 31, 2019 2018 2017 Natural Gas, NGLs and Oil Revenue $ 1,364,325 $ 1,577,937 $ 1,125,224 Gain (Loss) on Commodity Derivative Instruments 376,105 (30,212 ) 206,930 Purchased Gas Revenue 94,027 65,986 53,795 Total Revenue 1,834,457 1,613,711 1,385,949 Lease Operating Expense 65,443 95,139 88,932 Production, Ad Valorem, and Other Fees 27,461 32,750 29,267 Transportation, Gathering and Compression 516,879 424,206 382,865 Purchased Gas Costs 90,553 64,817 52,597 Impairment of Exploration and Production Properties 327,400 — 137,865 Impairment of Undeveloped Properties 119,429 — — Exploration Costs 44,380 12,033 48,074 Depreciation, Depletion and Amortization 474,352 461,149 412,036 Total Costs 1,665,897 1,090,094 1,151,636 Pre-tax Operating Income 168,560 523,617 234,313 Income Tax Expense (Benefit) 78,398 102,629 (348,676 ) Results of Operations for Producing Activities excluding Corporate and Interest Costs $ 90,162 $ 420,988 $ 582,989 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, 2019 2018 2017 Production (MMcfe) 539,149 507,104 407,166 Total Average Sales Price Before Effects of Commodity Derivative Financial Settlements (per Mcfe) $ 2.53 $ 3.11 $ 2.76 Average Effects of Commodity Derivative Financial Settlements (per Mcfe) $ 0.14 $ (0.15 ) $ (0.11 ) Total Average Sales Price Including Effects of Commodity Derivative Financial Settlements (per Mcfe) $ 2.66 $ 2.97 $ 2.66 Average Lifting Costs, Excluding Ad Valorem and Severance Taxes (per Mcfe) $ 0.12 $ 0.19 $ 0.22 During the years ended December 31, 2019 , 2018 and 2017 , the Company drilled 75.7 , 83.9 , and 90.0 net development wells, respectively. There was 1.0 net dry development well in 2019 , and no net dry development wells in 2018 or 2017 . During the years ended December 31, 2019 and 2017 , the Company drilled 5.0 and 4.0 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 2019 , 2018 or 2017 . At December 31, 2019 , there were 35.0 net development wells and 1.0 exploratory well that are drilled but uncompleted. Additionally, there are 7.0 net developmental wells that have been completed and are awaiting final tie-in to production. CNX is committed to provide 532.3 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, 2019 , the number of producing wells, developed acreage and undeveloped acreage: Gross Net(1) Producing Gas Wells (including Gob Wells) 6,512 4,510 Producing Oil Wells 151 — Acreage Position: Proved Developed Acreage 337,700 337,700 Proved Undeveloped Acreage 28,916 28,916 Unproved Acreage 5,192,777 3,868,533 Total Acreage 5,559,393 4,235,149 ____________ (1) Net acres include acreage attributable to the Company's working interests of the properties. Additional adjustments (either increases or decreases) may be required as the Company further develops title to and further confirms its rights with respect to its various properties in anticipation of development. The Company believes that its 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. The input data verification includes reviews of the price and operating, and development cost assumptions 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 15 years of experience in the oil and gas industry. The Company's gas reserves results, which are reported in the Supplemental Gas Data year ended December 31, 2019 Form 10-K, were audited by 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 12 years of experience in the oil and gas industry. The gas reserves estimates are as follows: Condensate Consolidated Natural Gas NGLs & Crude Oil Operations (MMcf) (Mbbls) (Mbbls) (MMcfe) Balance December 31, 2016 (a) 5,828,399 60,532 10,009 6,251,648 Revisions (b) (202,735 ) 1,162 (5,834 ) (232,321 ) Price Changes 173,738 1,188 (159 ) 181,470 Extensions and Discoveries (c) 1,769,029 17,887 1,800 1,887,153 Production (364,893 ) (6,456 ) (589 ) (407,166 ) Sales of Reserves In-Place (81,780 ) (2,622 ) (277 ) (99,172 ) Balance December 31, 2017 (a) 7,121,758 71,691 4,950 7,581,612 Revisions (d) 313,091 441 865 320,925 Price Changes 28,100 32 4 28,315 Extensions and Discoveries (c) 839,268 16,247 4,010 960,808 Production (468,228 ) (6,011 ) (468 ) (507,104 ) Purchases of Reserves In-Place 317,437 756 — 321,975 Sales of Reserves In-Place (e) (715,088 ) (17,252 ) (1,100 ) (825,196 ) Balance December 31, 2018 (a) 7,436,338 65,904 8,261 7,881,335 Revisions (f) (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 Proved developed reserves: December 31, 2017 4,051,526 56,022,000 3,567,000 4,409,065 December 31, 2018 4,242,579 40,180,000 1,870,000 4,494,878 December 31, 2019 4,473,534 59,800,000 1,087,000 4,838,858 Proved undeveloped reserves: December 31, 2017 3,070,232 15,669,000 1,383,000 3,172,547 December 31, 2018 3,193,759 25,724,000 6,391,000 3,386,457 December 31, 2019 3,464,873 16,044,000 4,278,000 3,586,809 __________ (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 downward revisions for 2017 are due to corporate planning changes by our JV partner in Ohio Utica which resulted in all PUD's being removed, causing a 458 Bcfe downward revision, offset, in part, by improved well performance due to the enhanced RCS completions and improved operating costs. (c) Extensions and Discoveries in 2017 , 2018 , and 2019 are due to the addition of wells on the Company's Marcellus and Utica Shale acreage more than one offset location away with continued use of reliable technology. (d) 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. (e) 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 6 - Acquisitions and Dispositions for more information. (f) The downward revisions in 2019 are primarily due to removal of 872 Bcfe in reserves from plan changes which are the result of our continued focus on optimization and high grading initiatives. 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 and optimization which increased reserves by 657 Bcfe. For the Year Ended December 31, 2019 Proved Undeveloped Reserves (MMcfe) Beginning Proved Undeveloped Reserves 3,386,457 Undeveloped Reserves Transferred to Developed (a) (752,970 ) Revisions Due to 5 Year Rule (303,787 ) Price Revisions 2,147 Revisions Due to Plan Changes (b) (872,495 ) Revisions Due to Changes Due to Well Performance (c) 556,881 Extension and Discoveries (d) 1,570,576 Ending Proved Undeveloped Reserves(e) 3,586,809 _________ (a) During 2019 , various exploration and development drilling and evaluations were completed. Approximately, $ 334,062 of capital was spent in the year ended December 31, 2019 related to undeveloped reserves that were transferred to developed. (b) The downward revisions for 2019 plan changes is due to removal of a portion of our Marcellus and Utica locations from our proved undeveloped reserves. (c) The upward revisions due to well performance is due to results from Marcellus Shale production. (d) Extensions and discoveries are due mainly to the addition of wells on our Marcellus and Utica Shale acreage more than one offset location away with continued use of reliable technology. (e) Included in proved undeveloped reserves at December 31, 2019 are approximately 248,570 MMcfe of reserves that have been reported for more than five years. 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. At December 31, 2019 there was one well pending the determination of proved reserves. The following table represents the capitalized exploratory well cost activity as indicated: December 31, 2019 2018 2017 Costs reclassified to wells, equipment and facilities based on the determination of proved reserves $ 59,981 $ 46,614 $ 40,149 Costs expensed due to determination of dry hole or abandonment of project $ — $ 809 $ — 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, 2019 2018 2017 Future Cash Flows (a) Revenues $ 19,489,588 $ 26,610,100 $ 19,261,578 Production Costs (7,903,120 ) (7,730,451 ) (7,234,303 ) Development Costs (1,121,073 ) (1,600,128 ) (1,710,585 ) Income Tax Expense (2,720,994 ) (4,147,075 ) (2,475,981 ) Future Net Cash Flows 7,744,401 13,132,446 7,840,709 Discounted to Present Value at a 10% Annual Rate (4,673,932 ) (8,476,989 ) (4,709,311 ) Total Standardized Measure of Discounted Net Cash Flows $ 3,070,469 $ 4,655,457 $ 3,131,398 (a) 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. For 2017 , the reserves were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2017 , adjusted for energy content and a regional price differential. For 2017 , this adjusted natural gas price was $2.44 per Mcf, the adjusted oil price was $38.65 per barrel and the adjusted NGL price was $23.61 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, 2019 2018 2017 Balance at Beginning of Period $ 4,655,457 $ 3,131,398 $ 955,117 Net Changes in Sales Prices and Production Costs (2,826,725 ) 1,732,229 1,983,475 Sales Net of Production Costs (1,130,685 ) (995,630 ) (831,131 ) Net Change Due to Revisions in Quantity Estimates (252,796 ) 307,030 (145,496 ) Net Change Due to Extensions, Discoveries and Improved Recovery 654,027 534,052 588,574 Development Costs Incurred During the Period 739,874 844,081 544,809 Difference in Previously Estimated Development Costs Compared to Actual Costs Incurred During the Period (323,922 ) (434,817 ) (129,427 ) Purchase of Reserves In-Place — 209,630 — Sales of Reserves In-Place — (434,103 ) (55,277 ) Changes in Estimated Future Development Costs (24,469 ) (49,294 ) (233,017 ) Net Change in Future Income Taxes 409,797 (507,410 ) (404,582 ) Timing and Other 586,591 (69,087 ) 712,764 Accretion 583,320 387,378 145,589 Total Discounted Cash Flow at End of Period $ 3,070,469 $ 4,655,457 $ 3,131,398

Supplemental Quarterly Info (Un

Supplemental Quarterly Info (Unaudited)	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Information Disclosure [Abstract]
Supplemental Quarterly Info (Unaudited)	Supplemental Quarterly Information (unaudited): (Dollars in thousands, except per share data) Three Months Ended March 31, June 30, September 30, December 31, 2019 2019 2019 2019 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 ) Three Months Ended March 31, June 30, September 30, December 31, 2018 2018 2018 2018 Revenue (A) $ 485,019 $ 393,590 $ 393,223 $ 431,660 Expenses (B) $ 167,785 $ 140,040 $ 123,779 $ 148,480 Net Income (C) $ 545,546 $ 61,394 $ 146,756 $ 129,415 Net Income Attributable to CNX Resources Shareholders $ 527,563 $ 42,014 $ 125,029 $ 101,927 Earnings Per Share Basic Earnings Per Share $ 2.38 $ 0.19 $ 0.59 $ 0.51 Diluted Earnings Per Share $ 2.35 $ 0.19 $ 0.59 $ 0.50 (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 DD&A, impairment charges, selling, general and administrative, loss on debt extinguishment, interest expense and other expense. (C) Includes impairment charges of $327,400 and $119,429 that were recorded during the three months ended December 31, 2019 related to CNX's exploration and productions properties and unproved properties, respectively, and $18,650 that was recorded during the three months ended June 30, 2018 related to CNX's intangible assets. See Note 1 - Significant Accounting Policies in Item 8 of this Form 10-K for additional information.

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2019
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) Additions Deductions Balance at Release of Balance at Beginning Charged to Valuation Charged to End of Period Expense Allowance Expense of Period Year Ended December 31, 2019 State Operating Loss Carry-Forwards $ 47,964 $ 33,238 $ — $ — $ 81,202 Charitable Contributions 3,297 — (2,639 ) — 658 Foreign Tax Credits 43,194 — — — 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 Differences 9,088 — (9,088 ) — — Charitable Contributions 3,156 141 — — 3,297 162(m) Officers Compensation 5,957 — (5,957 ) — — AMT Credit 12,413 1,983 (14,396 ) — — Foreign Tax Credits 44,402 — (1,208 ) — 43,194 Total $ 136,576 $ 2,124 $ (44,245 ) $ — $ 94,455 Year Ended December 31, 2017 State Operating Loss Carry-Forwards $ 60,488 $ — $ 1,072 $ — $ 61,560 Deferred Deductible Temporary Differences 10,590 — (1,502 ) — 9,088 Charitable Contributions 5,052 — (1,896 ) — 3,156 162(m) Officers Compensation — — 5,957 5,957 AMT Credit 166,798 — (154,385 ) — 12,413 Foreign Tax Credits 39,850 4,552 — — 44,402 Total $ 282,778 $ 4,552 $ (150,754 ) $ — $ 136,576

Significant Accounting Polici_2

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Basis of Consolidation	Basis of Consolidation: The Consolidated Financial Statements include the accounts of CNX Resources Corporation, and its wholly-owned and majority-owned and/or controlled subsidiaries, including certain variable interest entities that the Company is required to consolidate pursuant to the Consolidation topic of the Financial Accounting Standards Board (FASB) Accounting Standards Codification. The portion of these entities that is not owned by the Company is presented as non-controlling interest. 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.
Discontinued Operations	Discontinued Operations: Businesses divested are classified in the Consolidated Financial Statements as either discontinued operations or held for sale when the provision of Accounting Standards Codification (ASC) Topic 205 or ASC Topic 360 are met. For businesses classified as discontinued operations, the balance sheet amounts and results of operations are reclassified from their historical presentation to assets and liabilities of discontinued operations in the Consolidated Balance Sheets and to discontinued operations in the Consolidated Statements of Income and Cash Flows for all periods presented. The gains or losses associated with these divested businesses are recorded in discontinued operations in the Consolidated Statements of Income. The disclosures outside of Note 5- Discontinued Operations, for all periods presented, in the accompanying notes generally do not include the assets, liabilities, or operating results of businesses classified as discontinued operations.
Use of Estimates	Use of Estimates:
Cash and Cash Equivalents	Cash and Cash Equivalents:
Trade Accounts Receivable	Trade Accounts Receivable: Trade accounts receivable are recorded at the invoiced amount and do not bear interest. CNX reserves for specific accounts receivable when it is probable that all or a part of an outstanding balance will not be collected, such as customer bankruptcies. Collectability is determined based on terms of sale, credit status of customers and various other circumstances. CNX regularly reviews collectability and establishes or adjusts the allowance as necessary using the specific identification method. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote. Reserves for uncollectable amounts were not material in the periods presented. In addition, there were no material financing receivables with a contractual maturity greater than one year at December 31, 2019 or 2018 .
Inventories	Inventories:
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. DD&A 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. 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. 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 Improvements Life of Lease
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 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 6 - 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, which is the sole reporting unit within the Midstream 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 or common unit price with regards to CNX Midstream Partners LP ("CNXM"), regulatory and legal developments, and other relevant factors. In connection with the annual 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. 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 five-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 our annual assessment of goodwill in the fourth quarter of 2019, 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 6 - 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 6 - 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.
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, 2019 , 2018 and 2017 , 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%
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 midstream revenue 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 17 - Stock-Based Compensation for more information.
Accounting for Derivative Instruments	Derivative Instruments: CNX enters into financial derivative instruments to manage its exposure to commodity price volatility. The derivatives are accounted for as an asset or a liability in the accompanying Consolidated Balance Sheets at their fair value, generally measured based upon Level 2 inputs, which is further described in Note 20 - Fair Value of Financial Instruments. Changes in the fair values of derivatives are recorded in earnings. All of the Company's derivative instruments are subject to master netting arrangements with its counterparties, none of which currently require CNX to post collateral for any of its hedges. However, as stated in the counterparty master agreements, if the Company's obligations with one 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 hedges that are in a liability position in excess of defined thresholds. 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 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 will be 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. Early adoption is permitted. The adoption of this guidance is not expected to have a material impact on the Company's financial statements. In November 2019, the FASB issued ASU 2019-11 - Financial Instruments - Credit Losses (Topic 326), which clarifies and addresses specific issues about certain aspects of the amendments in ASU 2016-13. In May 2019, the FASB issued ASU 2019-05 - Financial Instruments - Credit Losses (Topic 326), which provides optional targeted transition relief to entities adopting ASU 2016-13. ASU 2016-13 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 will be 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. ASU 2019-05 provides the option to irrevocably elect the fair value option for certain financial assets previously measured at amortized cost basis. For those entities, the targeted transition relief will increase comparability of financial statement information by providing an option to align measurement methodologies for similar financial assets. The amendments in this ASU will be applied using the modified-retrospective approach and, for public entities, are effective for fiscal years beginning after December 15, 2019 and interim periods within those annual periods. Early adoption is permitted. 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, 2019 , 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 other than what is disclosed in Note 25 - Subsequent Event.

Significant Accounting Polici_3

Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
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 Improvements Life of Lease December 31, Property, Plant and Equipment 2019 2018 Intangible Drilling Cost $ 4,688,497 $ 4,120,283 Gas Gathering Equipment 2,463,866 2,126,895 Proved Gas Properties 1,208,046 1,135,411 Gas Wells and Related Equipment 1,042,000 859,359 Unproved Gas Properties 755,590 927,667 Surface Land and Other Equipment 226,285 238,487 Other 187,722 159,326 Total Property, Plant and Equipment 10,572,006 9,567,428 Less: Accumulated Depreciation, Depletion and Amortization 3,435,431 2,624,984 Total Property, Plant and Equipment - Net $ 7,136,575 $ 6,942,444

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [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, 2019 2018 2017 Anti-Dilutive Options 4,696,264 2,285,775 2,773,423 Anti-Dilutive Restricted Stock Units 1,282,582 — 18,598 Anti-Dilutive Performance Share Units 752,899 145,217 — Anti-Dilutive Performance Share Options 927,268 927,268 927,268 7,659,013 3,358,260 3,719,289
Schedule of Earnings Per Share, Basic and Diluted	The computations for basic and diluted earnings per share are as follows: For the Years Ended December 31, 2019 2018 2017 Income from Continuing Operations $ 31,948 $ 883,111 $ 295,039 Less: Net Income Attributable to Non-Controlling Interest 112,678 86,578 — Net (Loss) Income from Continuing Operations Attributable to CNX Resources Shareholders $ (80,730 ) $ 796,533 $ 295,039 Income from Discontinued Operations — — 85,708 Net (Loss) Income Attributable to CNX Resources Shareholders $ (80,730 ) $ 796,533 $ 380,747 Weighted-average shares of common stock outstanding 190,727,122 212,348,581 228,835,112 Effect of diluted shares — 2,280,384 2,116,700 Weighted-average diluted shares of common stock outstanding 190,727,122 214,628,965 230,951,812 (Loss) Earnings Per Share: Basic (Continuing Operations) $ (0.42 ) $ 3.75 $ 1.29 Basic (Discontinued Operations) — — 0.37 Total Basic $ (0.42 ) $ 3.75 $ 1.66 Diluted (Continuing Operations) $ (0.42 ) $ 3.71 $ 1.28 Diluted (Discontinued Operations) — — 0.37 Total Diluted $ (0.42 ) $ 3.71 $ 1.65
Schedule of Shares of Common Stock Outstanding	Shares of common stock outstanding were as follows: For the Years Ended December 31, 2019 2018 2017 Balance, Beginning of Year 198,663,342 223,743,322 229,443,008 Issuance Related to Stock-Based Compensation (1) 909,107 814,344 711,214 Retirement of Common Stock (2) (12,929,487 ) (25,894,324 ) (6,410,900 ) Balance, End of Year 186,642,962 198,663,342 223,743,322 (1) See Note 17 - Stock-Based Compensation for additional information. (2) See Note 7 - Stock Repurchase for additional information.

Changes in Accumulated Other _2

Changes in Accumulated Other Comprehensive Loss (Tables)	12 Months Ended
	Dec. 31, 2019
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income/(Loss)	Changes in Accumulated Other Comprehensive Loss related to pension obligations, net of tax, were as follows: Amount Balance at December 31, 2018 $ (7,904 ) Other Comprehensive Loss before Reclassifications (4,868 ) Amounts Reclassified from Accumulated Other Comprehensive Loss, net of tax 167 Balance at December 31, 2019 $ (12,605 )
Schedule of Reclassification of Adjustments to Accumulated Other Comprehensive Income	The following table shows the reclassification of adjustments out of Accumulated Other Comprehensive Loss: For the Years Ended December 31, 2019 2018 2017 Actuarially Determined Long-Term Liability Adjustments* (Note 16) Amortization of Prior Service Costs $ (17 ) $ (193 ) $ (2,775 ) Recognized Net Actuarial Loss 242 302 23,043 Total 225 109 20,268 Less: Tax Benefit 58 173 7,499 Net of Tax $ 167 $ (64 ) $ 12,769 *Excludes amounts related to the remeasurement of the actuarially determined pension obligations for the years ended December 31, 2019, 2018 and 2017. The table above only shows the reclassifications out of Accumulated Other Comprehensive Loss that relates to continuing operations.

Revenue From Contracts With C_2

Revenue From Contracts With Customers (Tables)	12 Months Ended
	Dec. 31, 2019
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, 2019 2018 2017 Revenue from Contracts with Customers Natural Gas Revenue $ 1,251,013 $ 1,391,459 $ 945,382 NGLs Revenue 104,139 165,883 156,132 Condensate Revenue 8,751 17,559 20,531 Oil Revenue 422 3,036 3,179 Total Natural Gas, NGLs and Oil Revenue 1,364,325 1,577,937 1,125,224 Purchased Gas Revenue 94,027 65,986 53,795 Midstream Revenue 74,314 89,781 — Other Sources of Revenue and Other Operating Income Gain (Loss) on Commodity Derivative Instruments 376,105 (30,212 ) 206,930 Other Operating Income 13,678 26,942 69,182 Total Revenue and Other Operating Income $ 1,922,449 $ 1,730,434 $ 1,455,131

Discontinued Operations (Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2019
Discontinued Operations and Disposal Groups [Abstract]
Schedule of Financial Information for Divested Business Within Discontinued Operations	The following table details selected financial information for the divested business included within discontinued operations: For the Year Ended December 31, 2017 Coal Revenue $ 1,067,841 Other Outside Sales 60,066 Freight-Outside Coal 66,297 Miscellaneous Other Income 73,645 Total Revenue and Other Income 1,267,849 Total Costs 1,147,254 Income from Operations Before Income Taxes 120,595 Income Tax Expense 23,984 Less: Net Income Attributable to Noncontrolling Interest 10,903 Income from Discontinued Operations, net $ 85,708

Acquisitions and Dispositions (

Acquisitions and Dispositions (Tables)	12 Months Ended
	Dec. 31, 2019
Business Combinations [Abstract]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	Fair Value of Consideration Transferred: Amount 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 Total Estimated Fair Value of Consideration Transferred $ 1,106,653 The following is a summary of the fair values of the net assets acquired: Fair Value of Assets Acquired: Amount 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
Schedule of Pro Forma Information	Post-Acquisition Operating Results (Midstream Acquisition) The Midstream Acquisition contributed the following to the Company's Midstream segment: For the Years Ended December 31, 2019 2018 Midstream Revenue $ 307,024 $ 258,074 Earnings from Continuing Operations Before Income Tax $ 166,654 $ 133,811 For the Year Ended (in thousands, except per share data) (unaudited) December 31, 2017 Pro Forma Total Revenue and Other Operating Income $ 1,553,078 Pro Forma Net Income from Continuing Operations $ 427,381 Less: Pro Forma Net Income Attributable to Noncontrolling Interests $ 74,251 Pro Forma Net Income from Continuing Operations Attributable to CNX $ 353,130 Pro Forma Income per Share from Continuing Operations (Basic) $ 1.33 Pro Forma Income per Share from Continuing Operations (Diluted) $ 1.33

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit)	Income tax expense (benefit) provided on earnings from continuing operations consisted of: For the Years Ended December 31, 2019 2018 2017 Current: U.S. Federal $ (51,243 ) $ (130,003 ) $ (31,791 ) U.S. State (113 ) — (1,838 ) (51,356 ) (130,003 ) (33,629 ) Deferred: U.S. Federal 47,717 319,813 (166,112 ) U.S. State 31,375 25,747 23,283 79,092 345,560 (142,829 ) Total Income Tax Expense (Benefit) $ 27,736 $ 215,557 $ (176,458 )
Schedule of Deferred Tax Assets and Liabilities	The components of the net deferred taxes are as follows: December 31, 2019 2018 Deferred Tax Assets: Net Operating Loss- Federal $ 202,913 $ 124,341 Net Operating Loss - State 130,430 110,339 Alternative Minimum Tax 51,241 102,482 Foreign Tax Credit 43,194 43,194 Interest Limitation 25,734 32,147 Gas Well Closing 17,888 10,140 Equity Compensation 9,308 13,096 Salary Retirement 9,236 9,434 Finance Lease 1,209 1,624 Other 10,030 13,714 Total Deferred Tax Assets 501,183 460,511 Valuation Allowance (125,054 ) (94,455 ) Net Deferred Tax Assets 376,129 366,056 Deferred Tax Liabilities: Property, Plant and Equipment (593,401 ) (606,342 ) Investment in Partnership (145,424 ) (125,253 ) Gas Derivatives (105,721 ) (26,160 ) Advance Gas Royalties (3,337 ) (3,384 ) Other (4,354 ) (3,599 ) Total Deferred Tax Liabilities (852,237 ) (764,738 ) Net Deferred Tax Liability $ (476,108 ) $ (398,682 )
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, 2019 2018 2017 Amount Percent Amount Percent Amount Percent Statutory U.S. Federal Income Tax Rate $ 12,534 21.0 % $ 230,721 21.0 % $ 41,503 35.0 % Net Effect of State Income Taxes 1,333 2.2 60,814 5.6 15,538 13.1 Non-Controlling Interest (23,662 ) (39.6 ) (18,181 ) (1.7 ) — — Uncertain Tax Positions — — (4,265 ) (0.4 ) 27,359 23.1 Effect of Spin on Federal NOL's — — — — 24,942 21.0 Accrual to Tax Return Reconciliation 603 1.0 3,028 0.3 (1,147 ) (1.0 ) Effect of Equity Compensation 8,771 14.7 — — — — Effect of Change in State Valuation Allowance 33,238 55.6 (22,684 ) (2.1 ) (430 ) (0.4 ) Effect of Change in Federal Valuation Allowance (2,640 ) (4.4 ) (18,110 ) (1.7 ) (145,772 ) (122.9 ) Other Deferred Adjustments (1,691 ) (2.8 ) 5,957 0.6 7,616 6.4 Effect of Federal and State Rate Reductions (3,842 ) (6.4 ) (27,429 ) (2.5 ) (131,784 ) (111.1 ) Effect of Federal Tax Credits 2,881 4.8 1,208 0.1 (19,081 ) (16.1 ) Other 211 0.4 4,498 0.4 4,798 4.0 Income Tax Expense (Benefit) / Effective Rate $ 27,736 46.5 % $ 215,557 19.6 % $ (176,458 ) (148.9 )%
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, 2019 2018 Balance at Beginning of Period $ 31,516 $ 37,813 Increase in Unrecognized Tax Benefits Resulting from Tax Positions Taken During Prior Periods — 2,140 Reduction in Unrecognized Tax Benefits Because of the Lapse of the Applicable Statute of Limitations — (8,437 ) Balance at End of Period $ 31,516 $ 31,516

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2019
Asset Retirement Obligation [Abstract]
Schedule of Change in Asset Retirement Obligation	The reconciliation of changes in asset retirement obligations is as follows: As of December 31, 2019 2018 Balance, Beginning of Year $ 38,554 $ 204,070 Obligations Divested (Note 6) — (196,643 ) Accretion Expense 9,458 9,874 Obligations Incurred 2,933 4,795 Obligations Settled (4,231 ) (5,323 ) Revisions in Estimated Cash Flows 21,740 21,781 Balance, End of Year $ 68,454 $ 38,554

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2019
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 Improvements Life of Lease December 31, Property, Plant and Equipment 2019 2018 Intangible Drilling Cost $ 4,688,497 $ 4,120,283 Gas Gathering Equipment 2,463,866 2,126,895 Proved Gas Properties 1,208,046 1,135,411 Gas Wells and Related Equipment 1,042,000 859,359 Unproved Gas Properties 755,590 927,667 Surface Land and Other Equipment 226,285 238,487 Other 187,722 159,326 Total Property, Plant and Equipment 10,572,006 9,567,428 Less: Accumulated Depreciation, Depletion and Amortization 3,435,431 2,624,984 Total Property, Plant and Equipment - Net $ 7,136,575 $ 6,942,444
Schedule of Amortization Expense Per Unit of Production	December 31, 2019 2018 Unproved Gas Properties $ 755,590 $ 927,667 Advance Royalties 12,770 12,863 Total $ 768,360 $ 940,530

Goodwill and Other Intangible_2

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2019
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Finite-Lived Intangible Assets	The carrying amount and accumulated amortization of other intangible assets consist of the following: December 31, 2019 2018 Other Intangible Assets Gross Amortizable Asset - Customer Relationships $ 109,752 $ 109,752 Less: Accumulated Amortization - Customer Relationships 13,105 6,552 Total Other Intangible Assets, net $ 96,647 $ 103,200

Other Accrued Liabilities (Tabl

Other Accrued Liabilities (Tables)	12 Months Ended
	Dec. 31, 2019
Other Liabilities Disclosure [Abstract]
Schedule of Accrued Liabilities	December 31, 2019 2018 Royalties $ 74,061 $ 92,005 Accrued Interest 30,862 26,333 Short-Term Incentive Compensation 21,030 20,482 Transportation Charges 16,533 19,661 Deferred Revenue 13,964 17,693 Accrued Other Taxes 9,115 7,300 Accrued Payroll & Benefits 6,248 6,533 Other 38,105 31,851 Current Portion of Long-Term Liabilities: Asset Retirement Obligations 5,076 1,075 Salary Retirement 1,587 1,578 Total Other Accrued Liabilities $ 216,581 $ 224,511

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2019
Long-term Debt, Other Disclosures [Abstract]
Schedule of Long-term Debt	December 31, 2019 2018 Senior Notes due April 2022 at 5.875% (Principal of $894,307 and $1,294,307 plus Unamortized Premium of $1,001 and $2,069, respectively) $ 895,308 $ 1,296,376 CNX Credit Facility 661,000 612,000 Senior Notes due March 2027 at 7.25%, 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 $4,625 and $5,375, respectively)* 395,375 394,625 CNX Midstream Partners LP Revolving Credit Facility* 311,750 84,000 Less: Unamortized Debt Issuance Costs 8,990 8,796 Long-Term Debt $ 2,754,443 $ 2,378,205
Schedule of Maturities of Long-term Debt	nnual undiscounted maturities of CNX and CNXM long-term debt during the next five years and thereafter are as follows: Year ended December 31, Amount 2020 $ — 2021 — 2022 894,307 2023 — 2024 972,750 Thereafter 900,000 Total Long-Term Debt Maturities $ 2,767,057

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2019
Leases [Abstract]
Schedule of Lease Cost	Lease terms and discount rates are as follows: December 31, 2019 Weighted Average Remaining Lease Term (years): Operating Leases 4.39 Finance Leases 2.16 Weighted Average Discount Rate: Operating Leases 4.96 % Finance Leases 6.92 % The components of lease cost were as follows: For the Year Ended December 31, 2019 Operating Lease Cost $ 73,809 Finance Lease Cost: Amortization of Right-of-Use Assets 5,242 Interest on Lease Liabilities 1,241 Short-term Lease Cost 5,547 Variable Lease Cost* 17,337 Total Lease Cost $ 103,176 *Amount recognized in the Consolidated Balance Sheet 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. Amount recognized in the Consolidated Balance Sheet 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.
Schedule of Balance Sheet Information	Amounts recognized in the Consolidated Balance Sheet are as follows: December 31, 2019 Operating Leases: Operating Lease Right-of-Use Asset $ 187,097 Current Portion of Operating Lease Obligations $ 61,670 Operating Lease Obligations 110,466 Total Operating Lease Liabilities $ 172,136 Finance Leases: Property, Plant and Equipment $ 72,916 Less—Accumulated Depreciation, Depletion and Amortization 63,008 Property, Plant and Equipment—Net $ 9,908 Current Portion of Finance Lease Obligations $ 7,164 Finance Lease Obligations 7,706 Total Finance Lease Liabilities $ 14,870 Supplemental cash flow information related to leases was as follows: For the Year Ended December 31, 2019 Cash Paid for Amounts Included in the Measurement of Lease Liabilities: Operating Cash Flows from Operating Leases $ 66,827 Operating Cash Flows from Finance Leases $ 1,241 Financing Cash Flows from Finance Leases $ 7,149 Right-of-Use Assets Obtained in Exchange for Lease Obligations: Operating Leases $ 15,347 Finance Leases $ 1,846
Maturity of Lease Liability, Operating	Maturities of lease liabilities are as follows: Operating Finance Leases Leases Year Ended December 31, 2020 $ 68,663 $ 7,968 2021 59,410 7,142 2022 23,789 436 2023 5,453 433 2024 5,433 127 Thereafter 30,822 — Total Lease Payments 193,570 16,106 Less: Interest 21,434 1,236 Present Value of Lease Liabilities $ 172,136 $ 14,870
Maturity of Lease Liability, Financing	Maturities of lease liabilities are as follows: Operating Finance Leases Leases Year Ended December 31, 2020 $ 68,663 $ 7,968 2021 59,410 7,142 2022 23,789 436 2023 5,453 433 2024 5,433 127 Thereafter 30,822 — Total Lease Payments 193,570 16,106 Less: Interest 21,434 1,236 Present Value of Lease Liabilities $ 172,136 $ 14,870

Pension (Tables)

Pension (Tables)	12 Months Ended
	Dec. 31, 2019
Defined Contribution Plan [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, 2019 2018 Change in Benefit Obligation: Benefit Obligation at Beginning of Period $ 33,569 $ 36,280 Service Cost 209 302 Interest Cost 1,338 1,265 Actuarial Loss (Gain) 4,865 (2,645 ) Plan Amendments 1,728 — Plan Curtailments — (126 ) Benefits and Other Payments (1,513 ) (1,507 ) Benefit Obligation at End of Period $ 40,196 $ 33,569 Change in Plan Assets: Fair Value of Plan Assets at Beginning of Period $ — $ — Company Contributions 1,513 1,507 Benefits and Other Payments (1,513 ) (1,507 ) Fair Value of Plan Assets at End of Period $ — $ — Funded Status: Current Liabilities $ (1,587 ) $ (1,578 ) Noncurrent Liabilities (38,609 ) (31,991 ) Net Obligation Recognized $ (40,196 ) $ (33,569 ) Amounts Recognized in Accumulated Other Comprehensive Loss Consist of: Net Actuarial Loss $ 15,361 $ 10,738 Prior Service Cost (Credit) 1,727 (17 ) Total 17,088 10,721 Less: Tax Benefit 4,483 2,817 Net Amount Recognized $ 12,605 $ 7,904
Schedule of Defined Benefit Plans Disclosures	The components of the net periodic benefit cost are as follows: For the Years Ended December 31, 2019 2018 2017 Components of Net Periodic Benefit Cost: Service Cost $ 209 $ 302 $ 375 Interest Cost 1,338 1,265 1,201 Amortization of Prior Service Credits (17 ) (193 ) (362 ) Recognized Net Actuarial Loss 242 865 1,525 Curtailment Gain — (416 ) — Net Periodic Benefit Cost $ 1,772 $ 1,823 $ 2,739
Schedule of Amounts in Accumulated Other Comprehensive Income (Loss) to be Recognized over Next Fiscal Year	Amounts included in accumulated other comprehensive loss which are expected to be recognized in 2020 net periodic benefit cost: Pension Benefits Prior Service Cost Recognition $ (221 ) Actuarial Loss Recognition $ (383 )
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, 2019 2018 Projected Benefit Obligation $ 40,196 $ 33,569 Accumulated Benefit Obligation $ 40,196 $ 33,169 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, 2019 2018 Discount Rate 3.36 % 4.37 % Rate of Compensation Increase — % 3.63 % 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, 2019 2018 2017 Discount Rate 4.37 % 4.28 % 4.26 % Rate of Compensation Increase 3.63 % 4.05 % 3.90 %
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 2020 $ 1,588 2021 $ 1,670 2022 $ 1,760 2023 $ 1,866 2024 $ 2,063 Year 2025-2029 $ 11,207

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2019
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, 2019 , 2018 and 2017 was $50 , $143 , and $353 respectively, based on the following assumptions and weighted average fair values: December 31, 2019 2018 2017 Weighted Average Fair Value of Grants $ 3.48 $ 6.50 $ 6.19 Risk-free Interest Rate 2.13 % 2.66 % 1.66 % Expected Dividend Yield — % — % — % Expected Forfeiture Rate — % — % — % Expected Volatility 43.60 % 52.68 % 50.85 % Expected Term in Years 6.50 3.71 3.71
Share-based Compensation, Stock Options, Activity	A summary of the status of stock options granted is presented below: Weighted Average Weighted Remaining Aggregate Average Contractual Intrinsic Exercise Term (in Value (in Shares Price years) thousands) Outstanding at December 31, 2018 5,442,920 $ 18.74 Granted 14,368 $ 7.54 Exercised (79,468 ) $ 6.87 Forfeited (4,208 ) $ 6.87 Expired (677,348 ) $ 24.29 Outstanding at December 31, 2019 4,696,264 $ 18.05 4.49 $ 5,280 Exercisable at December 31, 2019 4,681,896 $ 18.04 4.47 $ 5,261
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 of Weighted Average Shares Grant Date Fair Value Nonvested at December 31, 2018 1,427,151 $14.30 Granted 963,426 $11.26 Vested (1,052,235 ) $14.27 Forfeited (305,142 ) $13.50 Nonvested at December 31, 2019 1,033,200 $11.71
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 of Weighted Average Shares Grant Date Fair Value Nonvested at December 31, 2018 1,344,985 $19.93 Granted 407,056 $16.56 PSUs Issued as a Result of 200% Payout 156,918 $22.63 Vested (345,282 ) $22.21 Forfeited (162,841 ) $17.83 Nonvested at December 31, 2019 1,400,836 $18.91

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2019
Supplemental Cash Flow Information [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	The following table shows cash paid (received): For the Years Ended December 31, 2019 2018 2017 Interest (Net of Amounts Capitalized) $ 143,111 $ 144,756 $ 152,047 Income Taxes $ (138,409 ) $ (11,505 ) $ (121,773 )

Concentrations of Credit Risk_2

Concentrations of Credit Risk and Major Customers - (Tables)	12 Months Ended
	Dec. 31, 2019
Risks and Uncertainties [Abstract]
Schedules of Concentration of Risk, by Risk Factor	CNX markets natural gas primarily to gas wholesalers in the United States. Concentration of credit risk is summarized below: December 31, 2019 2018 Gas Wholesalers $ 115,641 $ 232,638 NGL, Condensate & Processing Facilities 10,140 12,595 Other 7,699 7,191 Total Accounts Receivable Trade $ 133,480 $ 252,424

Fair Value of Financial Instr_2

Fair Value of Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2019
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 Fair Value Measurements at Description Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Gas Derivatives $ — $ 405,781 $ — $ — $ 99,456 $ —
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, 2019 December 31, 2018 Carrying Amount Fair Value Carrying Amount Fair Value Cash and Cash Equivalents $ 16,283 $ 16,283 $ 17,198 $ 17,198 Long-Term Debt (Excluding Debt Issuance Costs) $ 2,763,433 $ 2,619,676 $ 2,387,001 $ 2,290,537

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2019
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 2019 2018 Settle Through Natural Gas Commodity Swaps (Bcf) 1,460.6 1,484.4 2025 Natural Gas Basis Swaps (Bcf) 1,290.4 1,056.6 2025
Schedule of Derivative Liabilities at Fair Value	The gross fair value of CNX's derivative instruments was as follows: Asset Derivative Instruments Liability Derivative Instruments December 31, December 31, 2019 2018 2019 2018 Commodity Swaps: Current Assets $ 234,238 $ 28,612 Current Liabilities $ 345 $ 34,640 Other Assets 288,543 164,310 Non-Current Liabilities 9,693 52,011 Total Asset $ 522,781 $ 192,922 Total Liability $ 10,038 $ 86,651 Basis Only Swaps: Current Assets $ 13,556 $ 11,628 Current Liabilities $ 40,626 $ 27,021 Other Assets 25,553 48,788 Non-Current Liabilities 105,445 40,210 Total Asset $ 39,109 $ 60,416 Total Liability $ 146,071 $ 67,231
Schedule of Derivative Assets at Fair Value	The gross fair value of CNX's derivative instruments was as follows: Asset Derivative Instruments Liability Derivative Instruments December 31, December 31, 2019 2018 2019 2018 Commodity Swaps: Current Assets $ 234,238 $ 28,612 Current Liabilities $ 345 $ 34,640 Other Assets 288,543 164,310 Non-Current Liabilities 9,693 52,011 Total Asset $ 522,781 $ 192,922 Total Liability $ 10,038 $ 86,651 Basis Only Swaps: Current Assets $ 13,556 $ 11,628 Current Liabilities $ 40,626 $ 27,021 Other Assets 25,553 48,788 Non-Current Liabilities 105,445 40,210 Total Asset $ 39,109 $ 60,416 Total Liability $ 146,071 $ 67,231
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, 2019 2018 2017 Cash Received (Paid) in Settlement of Commodity Derivative Instruments: Commodity Swaps: Natural Gas $ 82,899 $ (41,098 ) $ (34,928 ) Propane — — (1,216 ) Natural Gas Basis Swaps (13,119 ) (28,622 ) (5,030 ) Total Cash Received (Paid) in Settlement of Commodity Derivative Instruments 69,780 (69,720 ) (41,174 ) Unrealized Gain (Loss) on Commodity Derivative Instruments: Commodity Swaps: Natural Gas 406,472 33,026 319,605 Propane — — 1,147 Natural Gas Basis Swaps (100,147 ) 6,482 (72,648 ) Total Unrealized Gain on Commodity Derivative Instruments 306,325 39,508 248,104 Gain (Loss) on Commodity Derivative Instruments: Commodity Swaps: Natural Gas $ 489,371 $ (8,072 ) $ 284,677 Propane — — (69 ) Natural Gas Basis Swaps (113,266 ) (22,140 ) (77,678 ) Total Gain (Loss) on Commodity Derivative Instruments $ 376,105 $ (30,212 ) $ 206,930

Commitments and Contingent Li_2

Commitments and Contingent Liabilities (Tables)	12 Months Ended
	Dec. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Long-term Purchase Commitment	At December 31, 2019 , 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 Years 3-5 Years Beyond 5 Years Letters of Credit: Firm Transportation $ 197,776 $ 148,526 $ 49,250 $ — $ — Other 6,950 6,200 750 — — Total Letters of Credit 204,726 154,726 50,000 — — Surety Bonds: Employee-Related 2,600 2,600 — — — Environmental 12,763 12,503 260 — — Financial Guarantees 81,670 81,670 — — — Other 9,254 7,970 1,284 — — Total Surety Bonds 106,287 104,743 1,544 — — Total Commitments $ 311,013 $ 259,469 $ 51,544 $ — $ —
Unrecorded Unconditional Purchase Obligations Disclosure	As of December 31, 2019 , the purchase obligations for each of the next five years and beyond were as follows: Obligations Due Amount Less than 1 year $ 256,613 1 - 3 years 483,807 3 - 5 years 406,915 More than 5 years 1,072,748 Total Purchase Obligations $ 2,220,083

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	12 Months Ended
	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Variable Interest Entities	The following table presents amounts included in the Company's Consolidated Balance Sheets that were for the use or obligation of CNXM: December 31, 2019 2018 Assets: Cash $ 31 $ 3,966 Receivables - Related Party 21,076 17,073 Receivables - Third Party 7,935 7,028 Other Current Assets 1,976 2,383 Property, Plant and Equipment, net 1,195,591 891,775 Operating Lease ROU Asset 4,731 — Other Assets 3,262 3,203 Total Assets $ 1,234,602 $ 925,428 Liabilities: Accounts Payable and Accrued Liabilities $ 67,290 $ 43,919 Accounts Payable - Related Party 4,787 4,980 Revolving Credit Facility 311,750 84,000 Long-Term Debt 394,162 393,215 Total Liabilities $ 777,989 $ 526,114 The following table summarizes CNXM's Consolidated Statements of Operations and Cash Flows, inclusive of affiliate amounts: For the Years Ended December 31, 2019 2018 Revenue Gathering Revenue - Related Party $ 231,482 $ 167,048 Gathering Revenue - Third Party 74,315 89,620 Total Revenue 305,797 256,668 Expenses Operating Expense - Related Party 22,943 19,814 Operating Expense - Third Party 23,964 27,343 General and Administrative Expense - Related Party 15,928 13,867 General and Administrative Expense - Third Party 5,769 8,595 Loss on Asset Sales and Abandonments, net 7,229 2,501 Depreciation Expense 24,371 21,939 Interest Expense 30,293 23,614 Total Expense 130,497 117,673 Net Income $ 175,300 $ 138,995 Net Cash Provided by Operating Activities $ 217,062 $ 180,115 Net Cash Used in Investing Activities $ (327,615 ) $ (138,869 ) Net Cash Provided by (Used in) Financing Activities $ 106,618 $ (40,474 ) For the Year Ended December 31, 2017 Other Operating Income: Equity in Earnings of Affiliates - CNX Gathering $ 9,823 Equity in Earnings of Affiliates - CNXM $ 38,523 Transportation, Gathering and Compression: Gathering Services - CNX Gathering $ 914 Gathering Services - CNXM $ 136,068

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2019
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	Industry segment results for the year ended December 31, 2019 are: Marcellus Shale Utica Shale Coalbed Methane Other Gas Total E&P Midstream Unallocated Intercompany Eliminations Consolidated Natural Gas, NGLs and Oil Revenue $ 934,728 $ 264,548 $ 163,893 $ 1,156 $ 1,364,325 $ — $ — $ — $ 1,364,325 (A) Purchased Gas Revenue — — — 94,027 94,027 — — — 94,027 Midstream Revenue — — — — — 307,024 — (232,710 ) 74,314 Gain on Commodity Derivative Instruments 47,475 14,943 7,335 306,352 376,105 — — — 376,105 Other Operating Income — — — 14,057 14,057 — — (379 ) 13,678 (B) Total Revenue and Other Operating Income $ 982,203 $ 279,491 $ 171,228 $ 415,592 $ 1,848,514 $ 307,024 $ — $ (233,089 ) $ 1,922,449 Earnings (Loss) From Continuing Operations Before Income Tax $ 234,284 $ 87,972 $ 35,170 $ (497,869 ) $ (140,443 ) $ 166,654 $ 33,473 $ — $ 59,684 Segment Assets $ 6,745,091 $ 2,230,676 $ 78,708 $ 6,331 $ 9,060,806 (C) Depreciation, Depletion and Amortization $ 474,352 $ 34,111 $ — $ — $ 508,463 Capital Expenditures $ 867,860 $ 324,739 $ — $ — $ 1,192,599 (A) 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. (B) Includes equity in earnings of unconsolidated affiliates of $2,103 for Total E&P. (C) Includes investments in unconsolidated equity affiliates of $16,710 for Total E&P. Industry segment results for the year ended December 31, 2018 are: Marcellus Shale Utica Shale Coalbed Methane Other Gas Total E&P Midstream Unallocated Intercompany Eliminations Consolidated Natural Gas, NGLs and Oil Revenue $ 903,316 $ 445,880 $ 212,884 $ 15,857 $ 1,577,937 $ — $ — $ — $ 1,577,937 (D) Purchased Gas Revenue — — — 65,986 65,986 — — — 65,986 Midstream Revenue — — — — — 258,074 — (168,293 ) 89,781 (Loss) Gain on Commodity Derivative Instruments (40,444 ) (19,882 ) (8,767 ) 38,881 (30,212 ) — — — (30,212 ) Other Operating Income — — — 27,218 27,218 — — (276 ) 26,942 (E) Total Revenue and Other Operating Income $ 862,872 $ 425,998 $ 204,117 $ 147,942 $ 1,640,929 $ 258,074 $ — $ (168,569 ) $ 1,730,434 Earnings (Loss) From Continuing Operations Before Income Tax $ 254,310 $ 194,164 $ 49,719 $ (253,577 ) $ 244,616 $ 133,811 $ 720,241 $ — $ 1,098,668 Segment Assets $ 6,518,597 $ 1,919,117 $ 166,679 $ (12,223 ) $ 8,592,170 (F) Depreciation, Depletion and Amortization $ 461,149 $ 32,274 $ — $ — $ 493,423 Capital Expenditures $ 974,059 $ 142,338 $ — $ — $ 1,116,397 (D) 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. (E) Includes equity in earnings of unconsolidated affiliates of $5,363 for Total E&P. (F) Includes investments in unconsolidated equity affiliates of $18,663 for Total E&P. Industry segment results for the year ended December 31, 2017 are: Marcellus Shale Utica Shale Coalbed Methane Other Gas Total E&P Unallocated Consolidated Natural Gas, NGLs and Oil Revenue $ 646,188 $ 217,020 $ 208,677 $ 53,339 $ 1,125,224 $ — $ 1,125,224 (G) Purchased Gas Revenue — — — 53,795 53,795 — 53,795 (Loss) Gain on Commodity Derivative Instruments (30,336 ) 1,367 (9,589 ) 245,488 206,930 — 206,930 Other Operating Income — — — 69,182 69,182 — 69,182 (H) Total Revenue and Other Operating Income $ 615,852 $ 218,387 $ 199,088 $ 421,804 $ 1,455,131 $ — $ 1,455,131 Earnings (Loss) From Continuing Operations Before Income Tax $ 91,436 $ 64,741 $ 20,346 $ (240,050 ) $ (63,527 ) $ 182,108 $ 118,581 Segment Assets $ 6,391,223 $ 540,690 $ 6,931,913 (I) Depreciation, Depletion and Amortization $ 412,036 $ — $ 412,036 Capital Expenditures $ 632,846 $ — $ 632,846 (G) Included in Total Natural Gas, NGLs and Oil Revenue are sales of $153,656 to Direct Energy Business Marketing LLC and $147,595 to NJR Energy Services Company, each of which comprises over 10% of revenue from contracts with external customers for the period. (H) Includes equity in earnings of unconsolidated affiliates of $ 49,830 for Total E&P. (I) Includes investments in unconsolidated equity affiliates of $197,921 for Total E&P.
Reconciliation of Revenue from Segments to Consolidated	Revenue and Other Operating Income: For the Years Ended December 31, 2019 2018 2017 Total Segment Revenue from Contracts with External Customers $ 1,532,666 $ 1,733,704 $ 1,179,019 Gain (Loss) on Commodity Derivative Instruments 376,105 (30,212 ) 206,930 Other Operating Income 13,678 26,942 69,182 Total Consolidated Revenue and Other Operating Income $ 1,922,449 $ 1,730,434 $ 1,455,131
Reconciliation of Operating Profit (Loss) from Segments to Consolidated	Earnings (Loss) From Continuing Operations Before Income Tax: For the Years Ended December 31, 2019 2018 2017 Segment Earnings (Loss) Before Income Taxes for Reportable Business Segments: E&P $ (140,443 ) $ 244,616 $ (63,527 ) Midstream 166,654 133,811 — Total Segment Earnings (Loss) Before Income Taxes for Reportable Business Segments 26,211 378,427 (63,527 ) Unallocated Expenses: Other (Expense) Income (1,396 ) 14,571 (3,826 ) Gain on Certain Asset Sales 42,483 154,775 188,063 Gain on Previously Held Equity Interest — 623,663 — Loss on Debt Extinguishment (7,614 ) (54,118 ) (2,129 ) Impairment of Other Intangible Assets — (18,650 ) — Earnings from Continuing Operations Before Income Tax $ 59,684 $ 1,098,668 $ 118,581
Reconciliation of Assets and Liabilities from Segment to Consolidated	Total Assets: December 31, 2019 2018 Segment Assets for Total Reportable Business Segments: E&P $ 6,745,091 $ 6,518,597 Midstream 2,230,676 1,919,117 Intercompany Eliminations 6,331 (12,223 ) Items Excluded from Segment Assets: Cash and Cash Equivalents 16,283 17,198 Recoverable Income Taxes 62,425 149,481 Total Consolidated Assets $ 9,060,806 $ 8,592,170

Supplemental Gas Data (unaudi_2

Supplemental Gas Data (unaudited) (Tables)	12 Months Ended
	Dec. 31, 2019
Extractive Industries [Abstract]
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure	Capitalized Costs: As of December 31, 2019 2018 Intangible Drilling Costs $ 4,688,497 $ 4,120,283 Proved Gas Properties 1,208,046 1,135,411 Gas Gathering Assets 1,110,977 1,099,047 Unproved Gas Properties 755,590 927,667 Gas Wells and Related Equipment 1,042,000 856,973 Other Gas Assets 73,479 54,395 Total Property, Plant and Equipment $ 8,878,589 $ 8,193,776 Accumulated Depreciation, Depletion and Amortization (3,263,221 ) (2,475,917 ) Net Capitalized Costs $ 5,615,368 $ 5,717,859
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, 2019 2018 2017 Property Acquisitions: Proved Properties $ 36,710 $ 38,621 $ 15,850 Unproved Properties 24,760 36,248 32,038 Development 739,874 844,081 544,809 Exploration 79,855 61,604 48,020 Total $ 881,199 $ 980,554 $ 640,717 __________ (*) Includes costs incurred whether capitalized or expensed.
Results of Operations for Oil and Gas Producing Activities Disclosure	Results of Operations for Producing Activities: For the Years Ended December 31, 2019 2018 2017 Natural Gas, NGLs and Oil Revenue $ 1,364,325 $ 1,577,937 $ 1,125,224 Gain (Loss) on Commodity Derivative Instruments 376,105 (30,212 ) 206,930 Purchased Gas Revenue 94,027 65,986 53,795 Total Revenue 1,834,457 1,613,711 1,385,949 Lease Operating Expense 65,443 95,139 88,932 Production, Ad Valorem, and Other Fees 27,461 32,750 29,267 Transportation, Gathering and Compression 516,879 424,206 382,865 Purchased Gas Costs 90,553 64,817 52,597 Impairment of Exploration and Production Properties 327,400 — 137,865 Impairment of Undeveloped Properties 119,429 — — Exploration Costs 44,380 12,033 48,074 Depreciation, Depletion and Amortization 474,352 461,149 412,036 Total Costs 1,665,897 1,090,094 1,151,636 Pre-tax Operating Income 168,560 523,617 234,313 Income Tax Expense (Benefit) 78,398 102,629 (348,676 ) Results of Operations for Producing Activities excluding Corporate and Interest Costs $ 90,162 $ 420,988 $ 582,989
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, 2019 2018 2017 Production (MMcfe) 539,149 507,104 407,166 Total Average Sales Price Before Effects of Commodity Derivative Financial Settlements (per Mcfe) $ 2.53 $ 3.11 $ 2.76 Average Effects of Commodity Derivative Financial Settlements (per Mcfe) $ 0.14 $ (0.15 ) $ (0.11 ) Total Average Sales Price Including Effects of Commodity Derivative Financial Settlements (per Mcfe) $ 2.66 $ 2.97 $ 2.66 Average Lifting Costs, Excluding Ad Valorem and Severance Taxes (per Mcfe) $ 0.12 $ 0.19 $ 0.22
Schedule of Gas and Oil Acreage	The following table sets forth, at December 31, 2019 , the number of producing wells, developed acreage and undeveloped acreage: Gross Net(1) Producing Gas Wells (including Gob Wells) 6,512 4,510 Producing Oil Wells 151 — Acreage Position: Proved Developed Acreage 337,700 337,700 Proved Undeveloped Acreage 28,916 28,916 Unproved Acreage 5,192,777 3,868,533 Total Acreage 5,559,393 4,235,149 ____________ (1) Net acres include acreage attributable to the Company's working interests of the properties. Additional adjustments (either increases or decreases) may be required as the Company further develops title to and further confirms its rights with respect to its various properties in anticipation of development. The Company believes that its 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: Condensate Consolidated Natural Gas NGLs & Crude Oil Operations (MMcf) (Mbbls) (Mbbls) (MMcfe) Balance December 31, 2016 (a) 5,828,399 60,532 10,009 6,251,648 Revisions (b) (202,735 ) 1,162 (5,834 ) (232,321 ) Price Changes 173,738 1,188 (159 ) 181,470 Extensions and Discoveries (c) 1,769,029 17,887 1,800 1,887,153 Production (364,893 ) (6,456 ) (589 ) (407,166 ) Sales of Reserves In-Place (81,780 ) (2,622 ) (277 ) (99,172 ) Balance December 31, 2017 (a) 7,121,758 71,691 4,950 7,581,612 Revisions (d) 313,091 441 865 320,925 Price Changes 28,100 32 4 28,315 Extensions and Discoveries (c) 839,268 16,247 4,010 960,808 Production (468,228 ) (6,011 ) (468 ) (507,104 ) Purchases of Reserves In-Place 317,437 756 — 321,975 Sales of Reserves In-Place (e) (715,088 ) (17,252 ) (1,100 ) (825,196 ) Balance December 31, 2018 (a) 7,436,338 65,904 8,261 7,881,335 Revisions (f) (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 Proved developed reserves: December 31, 2017 4,051,526 56,022,000 3,567,000 4,409,065 December 31, 2018 4,242,579 40,180,000 1,870,000 4,494,878 December 31, 2019 4,473,534 59,800,000 1,087,000 4,838,858 Proved undeveloped reserves: December 31, 2017 3,070,232 15,669,000 1,383,000 3,172,547 December 31, 2018 3,193,759 25,724,000 6,391,000 3,386,457 December 31, 2019 3,464,873 16,044,000 4,278,000 3,586,809 __________ (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 downward revisions for 2017 are due to corporate planning changes by our JV partner in Ohio Utica which resulted in all PUD's being removed, causing a 458 Bcfe downward revision, offset, in part, by improved well performance due to the enhanced RCS completions and improved operating costs. (c) Extensions and Discoveries in 2017 , 2018 , and 2019 are due to the addition of wells on the Company's Marcellus and Utica Shale acreage more than one offset location away with continued use of reliable technology. (d) 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. (e) 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 6 - Acquisitions and Dispositions for more information. (f) The downward revisions in 2019 are primarily due to removal of 872 Bcfe in reserves from plan changes which are the result of our continued focus on optimization and high grading initiatives. 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 and optimization which increased reserves by 657 Bcfe. For the Year Ended December 31, 2019 Proved Undeveloped Reserves (MMcfe) Beginning Proved Undeveloped Reserves 3,386,457 Undeveloped Reserves Transferred to Developed (a) (752,970 ) Revisions Due to 5 Year Rule (303,787 ) Price Revisions 2,147 Revisions Due to Plan Changes (b) (872,495 ) Revisions Due to Changes Due to Well Performance (c) 556,881 Extension and Discoveries (d) 1,570,576 Ending Proved Undeveloped Reserves(e) 3,586,809 _________ (a) During 2019 , various exploration and development drilling and evaluations were completed. Approximately, $ 334,062 of capital was spent in the year ended December 31, 2019 related to undeveloped reserves that were transferred to developed. (b) The downward revisions for 2019 plan changes is due to removal of a portion of our Marcellus and Utica locations from our proved undeveloped reserves. (c) The upward revisions due to well performance is due to results from Marcellus Shale production. (d) Extensions and discoveries are due mainly to the addition of wells on our Marcellus and Utica Shale acreage more than one offset location away with continued use of reliable technology. (e) Included in proved undeveloped reserves at December 31, 2019 are approximately 248,570 MMcfe of reserves that have been reported for more than five years. 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 represents the capitalized exploratory well cost activity as indicated: December 31, 2019 2018 2017 Costs reclassified to wells, equipment and facilities based on the determination of proved reserves $ 59,981 $ 46,614 $ 40,149 Costs expensed due to determination of dry hole or abandonment of project $ — $ 809 $ —
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, 2019 2018 2017 Future Cash Flows (a) Revenues $ 19,489,588 $ 26,610,100 $ 19,261,578 Production Costs (7,903,120 ) (7,730,451 ) (7,234,303 ) Development Costs (1,121,073 ) (1,600,128 ) (1,710,585 ) Income Tax Expense (2,720,994 ) (4,147,075 ) (2,475,981 ) Future Net Cash Flows 7,744,401 13,132,446 7,840,709 Discounted to Present Value at a 10% Annual Rate (4,673,932 ) (8,476,989 ) (4,709,311 ) Total Standardized Measure of Discounted Net Cash Flows $ 3,070,469 $ 4,655,457 $ 3,131,398 (a) 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. For 2017 , the reserves were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2017 , adjusted for energy content and a regional price differential. For 2017 , this adjusted natural gas price was $2.44 per Mcf, the adjusted oil price was $38.65 per barrel and the adjusted NGL price was $23.61 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, 2019 2018 2017 Balance at Beginning of Period $ 4,655,457 $ 3,131,398 $ 955,117 Net Changes in Sales Prices and Production Costs (2,826,725 ) 1,732,229 1,983,475 Sales Net of Production Costs (1,130,685 ) (995,630 ) (831,131 ) Net Change Due to Revisions in Quantity Estimates (252,796 ) 307,030 (145,496 ) Net Change Due to Extensions, Discoveries and Improved Recovery 654,027 534,052 588,574 Development Costs Incurred During the Period 739,874 844,081 544,809 Difference in Previously Estimated Development Costs Compared to Actual Costs Incurred During the Period (323,922 ) (434,817 ) (129,427 ) Purchase of Reserves In-Place — 209,630 — Sales of Reserves In-Place — (434,103 ) (55,277 ) Changes in Estimated Future Development Costs (24,469 ) (49,294 ) (233,017 ) Net Change in Future Income Taxes 409,797 (507,410 ) (404,582 ) Timing and Other 586,591 (69,087 ) 712,764 Accretion 583,320 387,378 145,589 Total Discounted Cash Flow at End of Period $ 3,070,469 $ 4,655,457 $ 3,131,398

Supplemental Quarterly Info (_2

Supplemental Quarterly Info (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Information	Three Months Ended March 31, June 30, September 30, December 31, 2019 2019 2019 2019 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 ) Three Months Ended March 31, June 30, September 30, December 31, 2018 2018 2018 2018 Revenue (A) $ 485,019 $ 393,590 $ 393,223 $ 431,660 Expenses (B) $ 167,785 $ 140,040 $ 123,779 $ 148,480 Net Income (C) $ 545,546 $ 61,394 $ 146,756 $ 129,415 Net Income Attributable to CNX Resources Shareholders $ 527,563 $ 42,014 $ 125,029 $ 101,927 Earnings Per Share Basic Earnings Per Share $ 2.38 $ 0.19 $ 0.59 $ 0.51 Diluted Earnings Per Share $ 2.35 $ 0.19 $ 0.59 $ 0.50 (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 DD&A, impairment charges, selling, general and administrative, loss on debt extinguishment, interest expense and other expense. (C) Includes impairment charges of $327,400 and $119,429 that were recorded during the three months ended December 31, 2019 related to CNX's exploration and productions properties and unproved properties, respectively, and $18,650 that was recorded during the three months ended June 30, 2018 related to CNX's intangible assets. See Note 1 - Significant Accounting Policies in Item 8 of this Form 10-K for additional information.

Significant Accounting Polici_4

Significant Accounting Policies (Details) a in Thousands	Jan. 03, 2018USD ($)	May 31, 2018USD ($)	Dec. 31, 2019USD ($)awell	Jun. 30, 2018USD ($)	Dec. 31, 2019USD ($)awell	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Property, Plant and Equipment [Line Items]
Producing Oil Wells | well			151,000		151,000
Impairment of proved and unproved properties			$ 327,400,000	$ 18,650,000	$ 327,400,000	$ 0	$ 137,865,000
Impairment of Unproved Properties and Expirations					119,429,000	0	0
Goodwill impairment test, measurement period			5 years
Impairment of intangible assets					$ 0	$ 18,650,000	$ 0
Company's matching contribution, percentage					6.00%	6.00%	6.00%
Discretionary contributions to the Plan, amount						$ 0	$ 0
Total payment and cost to the Plan					$ 3,460,000	3,205,000	2,866,000
Minimum
Property, Plant and Equipment [Line Items]
Discretionary contributions to the Plan, percentage					1.00%
Maximum
Property, Plant and Equipment [Line Items]
Discretionary contributions to the Plan, percentage					6.00%
Proved Properties
Property, Plant and Equipment [Line Items]
Impairment of proved and unproved properties						0	0
Unproved Properties
Property, Plant and Equipment [Line Items]
Impairment of proved and unproved properties							0
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
Knox and Coalfield
Property, Plant and Equipment [Line Items]
Impairment of long-lived assets							137,865,000
Exploration and Production Related Other Costs
Property, Plant and Equipment [Line Items]
Exploration expense					$ 44,380,000	12,033,000	$ 48,074,000
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]
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
Marcellus Shale | Central Pennsylvania
Property, Plant and Equipment [Line Items]
Producing Oil Wells | well			56		56
Net acres of land | a			51		51
Impairment of proved and unproved properties					$ 327,400,000
Midstream | Operating Segments | Maximum
Property, Plant and Equipment [Line Items]
Percentage of fair value in excess of carrying amount (less than)			10.00%		10.00%

Earnings Per Share Anti-Dilutiv

Earnings Per Share Anti-Dilutive Options and Units Excluded from Earnings Per Share (Details) - shares	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of diluted earnings per share (in shares)	7,659,013	3,358,260	3,719,289
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)	4,696,264	2,285,775	2,773,423
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)	1,282,582	0	18,598
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)	752,899	145,217	0
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)	927,268	927,268	927,268

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Numerator:
Income from Continuing Operations									$ 31,948	$ 883,111	$ 295,039
Less: Net Income Attributable to Noncontrolling Interests									112,678	86,578	0
Net (Loss) Income from Continuing Operations Attributable to CNX Resources Shareholders									(80,730)	796,533	295,039
Income from Discontinued Operations									0	0	85,708
Net (Loss) Income Attributable to CNX Resources Shareholders	$ (271,408)	$ 115,538	$ 162,477	$ (87,337)	$ 101,927	$ 125,029	$ 42,014	$ 527,563	$ (80,730)	$ 796,533	$ 380,747
Denominator:
Weighted-average shares of common stock outstanding (in shares)									190,727,122	212,348,581	228,835,112
Effect of diluted shares (in shares)									0	2,280,384	2,116,700
Weighted-average diluted shares of common stock outstanding (in shares)									190,727,122	214,628,965	230,951,812
(Loss) Earnings Per Share
Basic (Continuing Operations) (in usd per share)									$ (0.42)	$ 3.75	$ 1.29
Basic (Discontinued Operations) (in usd per share)									0	0	0.37
Total Basic Earnings (Loss) Per Share (in usd per share)	$ (1.45)	$ 0.62	$ 0.85	$ (0.44)	$ 0.51	$ 0.59	$ 0.19	$ 2.38	(0.42)	3.75	1.66
Diluted (Continuing Operations) (in usd per share)									(0.42)	3.71	1.28
Diluted (Discontinued Operations) (in usd per share)									0	0	0.37
Total Diluted Earnings (Loss) Per Share (in usd per share)	$ (1.45)	$ 0.61	$ 0.84	$ (0.44)	$ 0.50	$ 0.59	$ 0.19	$ 2.35	$ (0.42)	$ 3.71	$ 1.65

Shares of Common Stock Outstand

Shares of Common Stock Outstanding (Details) - Common Stock - shares	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Stock Option Activity Rollforward [Abstract]
Balance, Beginning of Year (in shares)	198,663,342	223,743,322	229,443,008
Issuance Related to Stock-Based Compensation (in shares)	909,107	814,344	711,214
Retirement of Common Stock (in shares)	(12,929,487)	(25,894,324)	(6,410,900)
Balance, End of Year (in shares)	186,642,962	198,663,342	223,743,322

Changes in Accumulated Other _3

Changes in Accumulated Other Comprehensive Income / (Loss) by Component (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Changes in Accumulated Other Comprehensive Loss [Roll Forward]
Balance, Beginning of Period	$ 5,081,743	$ 3,899,899	$ 3,940,888
Other Comprehensive Loss before Reclassifications	(4,868)
Amounts Reclassified from Accumulated Other Comprehensive Loss, net of tax	167
Balance, End of Period	4,962,309	5,081,743	3,899,899
Accumulated Other Comprehensive Loss
Changes in Accumulated Other Comprehensive Loss [Roll Forward]
Balance, Beginning of Period	(7,904)	(8,476)	(392,556)
Balance, End of Period	$ (12,605)	$ (7,904)	$ (8,476)

Changes in Accumulated Other _4

Changes in Accumulated Other Comprehensive Loss Reclassification of Adjustments out of AOCI (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net of Tax	$ 167
Actuarially Determined Long-Term Liability Adjustments (Note 16)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Reclassification from AOCI before tax	225	$ 109	$ 20,268
Reclassification from AOCI, tax (benefit)	58	173	7,499
Net of Tax	167	(64)	12,769
Amortization of Prior Service Costs
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Reclassification from AOCI before tax	(17)	(193)	(2,775)
Recognized Net Actuarial Loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Reclassification from AOCI before tax	$ 242	$ 302	$ 23,043

Changes in Accumulated Other _5

Changes in Accumulated Other Comprehensive Loss Narrative (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2018USD ($)
Equity [Abstract]
ASU 2018-02 Reclassification	$ 1,100

Revenue From Contracts With C_3

Revenue From Contracts With Customers Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Payment terms for contract with customers	25 days
Receivables related to contracts with customers	$ 133,480	$ 252,424

Revenue From Contracts With C_4

Revenue From Contracts With Customers Performance Obligation (Details) $ in Thousands	Dec. 31, 2019USD ($)
Revenue from Contract with Customer [Abstract]
Remaining performance obligations	$ 156,620
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue from Contract with Customer [Abstract]
Remaining performance obligations	$ 38,928
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligations, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue from Contract with Customer [Abstract]
Remaining performance obligations	$ 53,322
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligations, expected timing of satisfaction	2 years

Revenue From Contracts With C_5

Revenue From Contracts With Customers Disaggregation of Revenue (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Disaggregation of Revenue [Line Items]
Gain (Loss) on Commodity Derivative Instruments									$ 376,105	$ (30,212)	$ 206,930
Other Operating Income									13,678	26,942	69,182
Total Revenue and Other Operating Income	$ 504,747	$ 526,681	$ 602,109	$ 275,234	$ 431,660	$ 393,223	$ 393,590	$ 485,019	1,922,449	1,730,434	1,455,131
Total Natural Gas, NGLs and Oil Revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers									1,364,325	1,577,937	1,125,224
Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers									1,251,013	1,391,459	945,382
NGLs Revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers									104,139	165,883	156,132
Condensate Revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers									8,751	17,559	20,531
Oil Revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers									422	3,036	3,179
Purchased Gas Revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers									94,027	65,986	53,795
Midstream Revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers									$ 74,314	$ 89,781	$ 0

Discontinued Operations Narrati

Discontinued Operations Narrative (Details)	Nov. 30, 2017company
Discontinued Operations and Disposal Groups [Abstract]
Number of companies after spin-off	2

Discontinued Operations Financi

Discontinued Operations Financial Infomration for Discontinued Operations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Discontinued Operations and Disposal Groups [Abstract]
Coal Revenue			$ 1,067,841
Other Outside Sales			60,066
Freight-Outside Coal			66,297
Miscellaneous Other Income			73,645
Total Revenue and Other Income			1,267,849
Total Costs			1,147,254
Income from Operations Before Income Taxes			120,595
Income Tax Expense			23,984
Less: Net Income Attributable to Noncontrolling Interest			10,903
Income from Discontinued Operations, net	$ 0	$ 0	$ 85,708

Acquisitions and Dispositions N

Acquisitions and Dispositions Narrative (Details) $ in Thousands

Aug. 31, 2018USD ($)a

May 02, 2018USD ($)well

Mar. 30, 2018USD ($)

Jan. 03, 2018USD ($)

May 31, 2018USD ($)

Sep. 30, 2017USD ($)a

Jun. 30, 2017USD ($)awell

May 31, 2017USD ($)a

Apr. 30, 2017USD ($)

Sep. 30, 2018USD ($)

Dec. 31, 2019USD ($)awell

Dec. 31, 2018USD ($)

Dec. 31, 2017USD ($)

Dec. 14, 2017

Business Acquisition [Line Items]

Proved Undeveloped Acreage | a

28,916,000

Proceeds from sale of assets

$ 45,160

$ 511,767

$ 414,185

Net gain (loss) on sale

35,563

157,015

188,063

Impairment of other intangibles

0

18,650

0

Gain on remeasurement of fair value of previously held equity interest

$ 0

623,663

0

Producing Gas Wells (including Gob Wells) | well

12

6,512,000

Drilled but uncompleted wells | well

15

Midstream

Business Acquisition [Line Items]

Cash consideration transferred

$ 305,000

Fair value of previously held equity interest

799,033

Gain on remeasurement of fair value of previously held equity interest

$ 623,663

Ohio Utica Joint Venture Assets

Business Acquisition [Line Items]

Proved Undeveloped Acreage | a

26,000

Proceeds from sale of assets

$ 381,124

Net gain (loss) on sale

$ 130,710

Asset Exchange Agreement with HG Energy

Business Acquisition [Line Items]

Net gain (loss) on sale

$ 286

Cash proceeds from Asset Exchange Agreement

$ 7,000

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

Cash consideration received in sale of oil and gas assets

89,921

Asset retirement obligations assumed

$ 196,514

Surface Land, Colorado

Business Acquisition [Line Items]

Net gain (loss) on sale

$ 18,758

Net acres of land | a

22,000

Proceeds sale of land

$ 23,703

Marcellus Shale Acres, Allegheny and Westmoreland County

Business Acquisition [Line Items]

Net gain (loss) on sale

$ 15,251

Net acres of land | a

7,500

Proceeds sale of land

$ 36,649

Marcellus And Utica Shale, Allegheny, Washington And Westmoreland Counties

Business Acquisition [Line Items]

Net gain (loss) on sale

$ 58,541

Net acres of land | a

11,100

Proceeds sale of land

$ 83,500

Marcellus And Utica Acres, Doddridge And Wetzel Counties

Business Acquisition [Line Items]

Net gain (loss) on sale

$ 9,430

Net acres of land | a

11,000

Proceeds sale of land

$ 125,507

Utica Point Pleasant Shale Acres, Jefferson, Belmont And Guernsey Counties

Business Acquisition [Line Items]

Net gain (loss) on sale

$ 72,346

Net acres of land | a

6,300

Proceeds sale of land

$ 76,585

Knox and Coalfield

Business Acquisition [Line Items]

Net gain (loss) on sale

606

Impairment on Assets Held for Sale

$ 137,865

CNX Gathering

Business Acquisition [Line Items]

Ownership percentage in equity method investment

100.00%

50.00%

Customer Relationships | Midstream

Business Acquisition [Line Items]

Impairment of other intangibles

$ 18,650

$ 18,650

CONE Midstream GP LLC

Business Acquisition [Line Items]

Ownership percentage by parent

100.00%

Discontinued Operations, Disposed of by Sale | Knox and Coalfield

Business Acquisition [Line Items]

Proceeds from sale of subsidiary, previously classified as held for sale

$ 19,055

Acquisitions and Dispositions C

Acquisitions and Dispositions Consideration Given In Acquisition (Details) - Midstream $ in Thousands	Jan. 03, 2018USD ($)
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
Total Estimated Fair Value of Consideration Transferred	$ 1,106,653

Acquisitions and Dispositions F

Acquisitions and Dispositions Fair Value of Net Assets Acquired (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018	Jan. 03, 2018
Fair Value of Liabilities Assumed:
Goodwill (Note 11)	$ 796,359	$ 796,359
Midstream
Fair Value of Assets Acquired:
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 (Note 11)			796,359
Net Assets Acquired			$ 1,106,653

Acquisitions and Dispositions P

Acquisitions and Dispositions Post Acquisition Operating Results (Details) - Midstream - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Business Acquisition [Line Items]
Midstream Revenue	$ 307,024	$ 258,074
Earnings from Continuing Operations Before Income Tax	$ 166,654	$ 133,811

Acquisitions and Dispositions_2

Acquisitions and Dispositions Pro Forma Financial Information (Details) - Midstream $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2017USD ($)$ / shares
Business Acquisition [Line Items]
Pro Forma Total Revenue and Other Operating Income	$ 1,553,078
Pro Forma Net Income from Continuing Operations	427,381
Less: Pro Forma Net Income Attributable to Noncontrolling Interests	74,251
Pro Forma Net Income from Continuing Operations Attributable to CNX	$ 353,130
Pro Forma Income(Loss) per Share from Continuing Operations (Basic) (in usd per share) | $ / shares	$ 1.33
Pro Forma Income(Loss) per Share from Continuing Operations (Diluted) (in usd per share) | $ / shares	$ 1.33

Stock Repurchase (Details)

Stock Repurchase (Details)	12 Months Ended
	Dec. 31, 2019USD ($)$ / sharesshares
Equity [Abstract]
Share repurchase program, authorized amount	$ 750,000
Stock repurchased during period (in shares) | shares	12,929,487
Treasure stock acquired (in usd per share) | $ / shares	$ 8.91
Stock repurchased and retired	$ 115,477,000

Income Taxes Income Tax Benefit

Income Taxes Income Tax Benefits (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Current:
U.S. Federal	$ (51,243)	$ (130,003)	$ (31,791)
U.S. State	(113)	0	(1,838)
Current income tax (benefit)	(51,356)	(130,003)	(33,629)
Deferred:
U.S. Federal	47,717	319,813	(166,112)
U.S. State	31,375	25,747	23,283
Deferred income tax (benefit)	79,092	345,560	(142,829)
Income Tax Expense (Benefit) / Effective Rate	$ 27,736	$ 215,557	$ (176,458)

Income Taxes Net Deferred Tax A

Income Taxes Net Deferred Tax Assets/Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Deferred Tax Assets:
Net Operating Loss- Federal	$ 51,241	$ 102,482
Net Operating Loss - State	202,913	124,341
Alternative Minimum Tax	130,430	110,339
Foreign Tax Credit	43,194	43,194
Interest Limitation	25,734	32,147
Gas Well Closing	9,308	13,096
Equity Compensation	17,888	10,140
Salary Retirement	9,236	9,434
Finance Lease	1,209	1,624
Other	10,030	13,714
Total Deferred Tax Assets	501,183	460,511
Valuation Allowance	(125,054)	(94,455)
Net Deferred Tax Assets	376,129	366,056
Deferred Tax Liabilities:
Property, Plant and Equipment	(593,401)	(606,342)
Investment in Partnership	(145,424)	(125,253)
Gas Derivatives	(105,721)	(26,160)
Advance Gas Royalties	(3,337)	(3,384)
Other	(4,354)	(3,599)
Total Deferred Tax Liabilities	(852,237)	(764,738)
Net Deferred Tax Liability	$ 476,108	$ 398,682

Income Taxes Narrative (Details

Income Taxes Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Mar. 21, 2018
Valuation Allowance [Line Items]
Net Operating Loss - State	$ 202,913,000	$ 124,341,000
Deferred tas asset, federal alternative minimum tax credit	51,241,000	102,482,000
Decrease in federal alternative minimum tax	51,241,000
Valuation allowance on foreign tax credits	43,194,000	43,194,000
Valuation Allowance	125,054,000	94,455,000
Deferred tax asset related to state operating losses	130,430,000	110,339,000
Reduction in income tax expense due to non-controlling interest	(23,662,000)	(18,181,000)	$ 0
Tax Cuts And Jobs Act Of 2017, revaluation of deferred tax assets and liabilities, benefit			115,291,000
Tax Cuts and Jobs Act of 2017, AMT credit carryforward		12,413,000	$ 154,385,000
Tax Cuts And Jobs Act Of 2017, federal net operating loss carryback		23,483,000
Unrecognized tax benefits that would impact effective tax rate	31,516,000	31,516,000
Increase in Unrecognized Tax Benefits Resulting from Tax Positions Taken During Prior Periods	0	2,140,000
Reduction to unrecognized tax benefits, from position taken on state tax return	0	8,437,000
Accrued liability relating to uncertain tax positions	0	0
Interest income included in accrued interest liability	644,000	337,000
Accrued liabilities for tax penalties	0
Reduction to net operation loss, resulting from income tax examination				$ 108,651,000
Alternative Minimum Tax Credit
Valuation Allowance [Line Items]
Increase (decrease) in valuation allowance, federal alternative minimum tax credit		12,413,000
Charitable Contributions
Valuation Allowance [Line Items]
Increase (decrease) in valuation allowance, federal alternative minimum tax credit	(2,639,000)
Valuation Allowance	658,000	3,297,000
State operating losses
Valuation Allowance [Line Items]
Valuation Allowance	$ 81,202,000	$ 47,964,000

Income Taxes Effective Tax Rate

Income Taxes Effective Tax Rate Reconciliation (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Effective Income Tax Rate Reconciliation, Amount [Abstract]
Statutory U.S. Federal Income Tax Rate	$ 12,534	$ 230,721	$ 41,503
Net Effect of State Income Taxes	1,333	60,814	15,538
Non-Controlling Interest	(23,662)	(18,181)	0
Uncertain Tax Positions	0	(4,265)	27,359
Effect of Spin on Federal NOL's	0	0	24,942
Accrual to Tax Return Reconciliation	603	3,028	(1,147)
Effect of Equity Compensation	8,771	0	0
Effect of Change in State Valuation Allowance	33,238	(22,684)	(430)
Effect of Change in Federal Valuation Allowance	(2,640)	(18,110)	(145,772)
Other Deferred Adjustments	(1,691)	5,957	7,616
Effect of Federal and State Rate Reductions	(3,842)	(27,429)	(131,784)
Effect of Federal Tax Credits	2,881	1,208	(19,081)
Other	211	4,498	4,798
Income Tax Expense (Benefit) / Effective Rate	$ 27,736	$ 215,557	$ (176,458)
Effective Income Tax Rate Reconciliation, Percent [Abstract]
Statutory U.S. Federal Income Tax Rate	21.00%	21.00%	35.00%
Net Effect of State Income Taxes	2.20%	5.60%	13.10%
Non-Controlling Interest	(39.60%)	(1.70%)	0.00%
Uncertain Tax Positions	0.00%	(0.40%)	23.10%
Effect of Spin on Federal NOL's	0.00%	0.00%	21.00%
Accrual to Tax Return Reconciliation	1.00%	0.30%	(1.00%)
Effect of Equity Compensation	14.70%	0.00%	0.00%
Effect of Change in State Valuation Allowance	55.60%	(2.10%)	(0.40%)
Effect of Change in Federal Valuation Allowance	(4.40%)	(1.70%)	(122.90%)
Other Deferred Adjustments	(2.80%)	0.60%	6.40%
Effect of Federal and State Rate Reductions	(6.40%)	(2.50%)	(111.10%)
Effect of Federal Tax Credits	4.80%	0.10%	(16.10%)
Other	0.40%	0.40%	4.00%
Income Tax Expense (Benefit) / Effective Rate	46.50%	19.60%	(148.90%)

Income Taxes Reconcililation of

Income Taxes Reconcililation of Unrecognized Tax Benefits (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at Beginning of Period	$ 31,516	$ 37,813
Increase in Unrecognized Tax Benefits Resulting from Tax Positions Taken During Prior Periods	0	2,140
Reduction in Unrecognized Tax Benefits Because of the Lapse of the Applicable Statute of Limitations	0	(8,437)
Balance at End of Period	$ 31,516	$ 31,516

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance, Beginning of Year	$ 38,554	$ 204,070
Obligations Divested	0	(196,643)
Accretion Expense	9,458	9,874
Obligations Incurred	2,933	4,795
Obligations Settled	(4,231)	(5,323)
Revisions in Estimated Cash Flows	21,740	21,781
Balance, End of Year	$ 68,454	$ 38,554

Property, Plant and Equipment_2

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Property, Plant and Equipment [Abstract]
Intangible Drilling Cost	$ 4,688,497	$ 4,120,283
Gas Gathering Equipment	2,463,866	2,126,895
Proved Gas Properties	1,208,046	1,135,411
Gas Wells and Related Equipment	1,042,000	859,359
Unproved Gas Properties	755,590	927,667
Surface Land and Other Equipment	226,285	238,487
Other	187,722	159,326
Total	10,572,006	9,567,428
Less: Accumulated Depreciation, Depletion and Amortization	3,435,431	2,624,984
Total Property, Plant and Equipment—Net	$ 7,136,575	$ 6,942,444

Property, Plant and Equipment A

Property, Plant and Equipment Assets Amortized by Units of Production (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Property, Plant and Equipment [Line Items]
Unproved Gas Properties	$ 755,590	$ 927,667
Total	10,572,006	9,567,428
Assets amortized by units of production
Property, Plant and Equipment [Line Items]
Unproved Gas Properties	755,590	927,667
Advance Royalties	12,770	12,863
Total	$ 768,360	$ 940,530

Property, Plant and Equipment N

Property, Plant and Equipment Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Capital Leased Assets [Line Items]
Interest costs capitalized	$ 5,482	$ 1,075
Finance lease right-of-use assets, gross	72,916
Capital leased assets, gross		73,144
Accumulated amortization for finance lease right of use asset	63,008
Accumulated amortization for capital leases		59,517
Jewell Ridge Pipeline
Capital Leased Assets [Line Items]
Finance lease right-of-use assets, gross	66,919
Capital leased assets, gross		66,919
Vehicles
Capital Leased Assets [Line Items]
Finance lease right-of-use assets, gross	$ 5,997
Capital leased assets, gross		$ 6,225

Goodwill and Other Intangible_3

Goodwill and Other Intangible Assets (Details) - USD ($)	Jan. 03, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Goodwill [Line Items]
Impairment of intangible assets		$ 0	$ 18,650,000	$ 0
Amortization expense		6,553,000	6,931,000
Estimated annual amortization expense expected, 2020		6,552,000
Estimated annual amortization expense expected, 2021		6,522,000
Estimated annual amortization expense expected, 2022		6,522,000
Estimated annual amortization expense expected, 2023		6,522,000
Estimated annual amortization expense expected, 2024		$ 6,522,000
Midstream Acquisition
Goodwill [Line Items]
Goodwill acquired during period	$ 796,359,000
Other intangible assets	$ 128,781,000
Customer Relationships
Goodwill [Line Items]
Useful life, customer relationship intangible assets		17 years
Customer Relationships | Midstream Acquisition
Goodwill [Line Items]
Impairment of intangible assets		$ 0	$ 18,650,000	$ 0

Goodwill and Other Intangible_4

Goodwill and Other Intangible Assets Carrying Amount and Accumulated Amortization of Intangible Assets (Details) - Customer Relationships - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Other Intangible Assets
Gross Amortizable Asset - Customer Relationships	$ 109,752	$ 109,752
Less: Accumulated Amortization - Customer Relationships	13,105	6,552
Total Other Intangible Assets, net	$ 96,647	$ 103,200

Revolving Credit Facilities (De

Revolving Credit Facilities (Details)	1 Months Ended	9 Months Ended	12 Months Ended
	Apr. 30, 2019USD ($)	Sep. 30, 2019	Dec. 31, 2019USD ($)	Oct. 31, 2019USD ($)	Jun. 30, 2019USD ($)	Dec. 31, 2018USD ($)
Short-term Debt [Line Items]
Number of days outstanding, prior to springing maturity date		91 days
Value of proved reserves, percentage to mortgage			80.00%
Value of proved developing producing reserves, percentage to mortgage			80.00%
Revolving Credit Facility
Short-term Debt [Line Items]
Maximum borrowing capacity	$ 2,100,000,000
Accordion feature, increased commitment	3,000,000,000
Initial borrowing base	$ 2,100,000,000			$ 2,300,000,000
Net leverage ratio	3
Percentage of aggregate commitments available under credit facility	15.00%
Minimum threshold to activate springing maturity date			$ 500,000,000
Maximum net leverage ratio			4
Minimum current ratio			1
Borrowings outstanding			$ 661,000,000			$ 612,000,000
Letters of credit outstanding			204,726,000			198,396,000
Borrowings and issuance of letters of credit remaining capacity			1,234,274,000			1,289,604,000
Debt instrument, face amount					$ 160,000,000
Letter of Credit
Short-term Debt [Line Items]
Maximum borrowing capacity	$ 650,000,000			$ 650,000
CNXM | Revolving Credit Facility
Short-term Debt [Line Items]
Maximum borrowing capacity	600,000,000
Borrowings outstanding			$ 311,750,000			84,000,000
Increase in available borrowings	$ 250,000,000
Secured leverage ratio			3
Pro forma availability of commitments, percentage			20.00%
Basket of repurchase of LP units tied to Available Cash, annual limit			$ 150,000,000
Basket of repurchase of LP units tied to Available Cash, lifetime limit			200,000,000
Letters of credit, maximum borrowing capacity			$ 100,000,000
Maximum net leverage ratio			4
Interest coverage ratio			2.50
Current borrowing capacity			$ 288,250,000
CNXM | Minimum | Revolving Credit Facility
Short-term Debt [Line Items]
Maximum net leverage ratio			5.25
Maximum net leverage ratio			4.75
CNXM | Maximum | Revolving Credit Facility
Short-term Debt [Line Items]
Maximum net leverage ratio			5.50
Secured leverage ratio			3.50
Maximum net leverage ratio			5.25
5.875% Senior Notes due 2022
Short-term Debt [Line Items]
Stated rate, debt instrument		5.875%	5.875%
Debt instrument, face amount			$ 894,307,000			$ 1,294,307,000
5.875% Senior Notes due 2022 | CNXM | Minimum
Short-term Debt [Line Items]
Debt instrument, face amount			150,000,000
5.875% Senior Notes due 2022 | CNXM | Maximum
Short-term Debt [Line Items]
Debt instrument, face amount			$ 150,000,000
Federal Funds Open Rate
Short-term Debt [Line Items]
Basis spread on variable rate			0.50%
Federal Funds Open Rate | CNXM
Short-term Debt [Line Items]
Basis spread on variable rate			0.50%
One-Month LIBOR
Short-term Debt [Line Items]
Basis spread on variable rate			1.00%
One-Month LIBOR | Minimum
Short-term Debt [Line Items]
Basis spread on variable rate			0.25%
One-Month LIBOR | Maximum
Short-term Debt [Line Items]
Basis spread on variable rate			1.25%
One-Month LIBOR | CNXM
Short-term Debt [Line Items]
Basis spread on variable rate			1.00%
One-Month LIBOR | CNXM | Minimum
Short-term Debt [Line Items]
Basis spread on variable rate			0.50%
One-Month LIBOR | CNXM | Maximum
Short-term Debt [Line Items]
Basis spread on variable rate			1.50%
London Interbank Offered Rate (LIBOR) | Minimum
Short-term Debt [Line Items]
Basis spread on variable rate			1.25%
London Interbank Offered Rate (LIBOR) | Maximum
Short-term Debt [Line Items]
Basis spread on variable rate			2.25%
London Interbank Offered Rate (LIBOR) | CNXM | Minimum
Short-term Debt [Line Items]
Basis spread on variable rate			1.50%
London Interbank Offered Rate (LIBOR) | CNXM | Maximum
Short-term Debt [Line Items]
Basis spread on variable rate			2.50%

Other Accrued Liabilities (Deta

Other Accrued Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Other Liabilities Disclosure [Abstract]
Royalties	$ 74,061	$ 92,005
Accrued Interest	30,862	26,333
Short-Term Incentive Compensation	21,030	20,482
Transportation Charges	16,533	19,661
Deferred Revenue	13,964	17,693
Accrued Other Taxes	9,115	7,300
Accrued Payroll & Benefits	6,248	6,533
Other	38,105	31,851
Current Portion of Long-Term Liabilities:
Asset Retirement Obligations	5,076	1,075
Salary Retirement	1,587	1,578
Total Other Accrued Liabilities	$ 216,581	$ 224,511

Long-Term Debt Schedule of Long

Long-Term Debt Schedule of Long-Term Debt (Details) - USD ($)	Dec. 31, 2019	Sep. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Less: Unamortized Debt Issuance Costs	$ 8,990,000		$ 8,796,000
Long-Term Debt	2,754,443,000		2,378,205,000
5.875% Senior Notes due 2022
Debt Instrument [Line Items]
Debt instrument, face amount	894,307,000		1,294,307,000
Debt Instrument, unamortized premium	$ 1,001,000		2,069,000
Stated rate, debt instrument	5.875%	5.875%
Long-Term Debt	$ 895,308,000		1,296,376,000
Senior Notes due March 2027 at 7.25%
Debt Instrument [Line Items]
Debt instrument, face amount	$ 500,000,000
Stated rate, debt instrument	7.25%
Long-Term Debt	$ 500,000,000		0
Senior Notes due March 2026
Debt Instrument [Line Items]
Debt instrument, face amount	400,000,000
Debt instrument, unamortized discount	$ 4,625,000		5,375,000
Stated rate, debt instrument	6.50%
Long-Term Debt	$ 395,375,000		394,625,000
CNX Revolving Credit Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Long-Term Debt	661,000,000		612,000,000
CNX Midstream Partners LP Revolving Credit Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Long-Term Debt	$ 311,750,000		$ 84,000,000

Long-Term Debt Maturities of Lo

Long-Term Debt Maturities of Long-Term Debt (Details) $ in Thousands	Dec. 31, 2019USD ($)
Maturities of Long-term Debt [Abstract]
2020	$ 0
2021	0
2022	894,307
2023	0
2024	972,750
Thereafter	900,000
Total Long-Term Debt Maturities	$ 2,767,057

Long-Term Debt Narrative (Detai

Long-Term Debt Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Sep. 30, 2019	Jun. 30, 2019
Debt Instrument [Line Items]
Gain (loss) on extinguishment of debt	$ (7,614,000)	$ (54,118,000)	$ (2,129,000)
Senior Notes due March 2027 at 7.25%
Debt Instrument [Line Items]
Debt instrument, face amount	$ 500,000,000
Stated rate, debt instrument	7.25%
5.875% Senior Notes due 2022
Debt Instrument [Line Items]
Debt instrument, face amount	$ 894,307,000	1,294,307,000
Purchase of outstanding debt	400,000,000	411,375,000	144,318,000
Gain (loss) on extinguishment of debt	$ (7,614,000)	(15,320,000)	(110,000)
Stated rate, debt instrument	5.875%			5.875%
Senior Notes due March 2026
Debt Instrument [Line Items]
Debt instrument, face amount	$ 400,000,000
Stated rate, debt instrument	6.50%
Senior Notes due April 2023
Debt Instrument [Line Items]
Purchase of outstanding debt	$ 500,000,000
Gain (loss) on extinguishment of debt		$ (38,798,000)
Stated rate, debt instrument	8.00%
Senior Notes Due April 2020
Debt Instrument [Line Items]
Purchase of outstanding debt			$ 74,470,000
Stated rate, debt instrument			8.25%
Senior Notes Due March 2021
Debt Instrument [Line Items]
Purchase of outstanding debt			$ 20,611,000
Stated rate, debt instrument		6.375%	6.375%
Senior Notes Due April 2020 and Senior Notes Due March 2021
Debt Instrument [Line Items]
Gain (loss) on extinguishment of debt			$ (2,019,000)
Revolving Credit Facility
Debt Instrument [Line Items]
Debt instrument, face amount					$ 160,000,000
CNXM | Senior Notes due March 2026
Debt Instrument [Line Items]
Debt instrument, face amount		$ 400,000,000
Unamortized bond discount		$ 6,000,000

Leases (Details)

Leases (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Operating leases rent expense	$ 21,441	$ 16,797
Minimum
Lessee, Lease, Description [Line Items]
Lease renewal term			1 year
Maximum
Lessee, Lease, Description [Line Items]
Lease renewal term			10 years

Leases - Components of Lease Co

Leases - Components of Lease Cost (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)
Leases [Abstract]
Operating Lease Cost	$ 73,809
Finance Lease Cost:
Amortization of Right-of-Use Assets	5,242
Interest on Lease Liabilities	1,241
Short-term Lease Cost	5,547
Variable Lease Cost	17,337
Total Lease Cost	$ 103,176

Leases - Balance Sheet Informat

Leases - Balance Sheet Information (Details) (Details) $ in Thousands	Dec. 31, 2019USD ($)
Operating Leases:
Operating Lease Right-of-Use Asset	$ 187,097
Current Portion of Operating Lease Obligations	61,670
Operating Lease Obligations	110,466
Total Operating Lease Liabilities	172,136
Finance Leases:
Property, Plant and Equipment	72,916
Less—Accumulated Depreciation, Depletion and Amortization	63,008
Property, Plant and Equipment—Net	9,908
Current Portion of Finance Lease Obligations	7,164
Finance Lease Obligations	7,706
Total Finance Lease Liabilities	$ 14,870

Leases - Supplemental Cash Flow

Leases - Supplemental Cash Flow Information (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating Cash Flows from Operating Leases	$ 66,827
Operating Cash Flows from Finance Leases	1,241
Financing Cash Flows from Finance Leases	7,149
Right-of-Use Assets Obtained in Exchange for Lease Obligations:
Operating Leases	15,347
Finance Leases	$ 1,846

Leases - Maturity of Lease Liab

Leases - Maturity of Lease Liability (Details) $ in Thousands	Dec. 31, 2019USD ($)
Operating Leases
2020	$ 68,663
2021	59,410
2022	23,789
2023	5,453
2024	5,433
Thereafter	30,822
Total Lease Payments	193,570
Less: Interest	21,434
Present Value of Lease Liabilities	172,136
Finance Leases
2020	7,968
2021	7,142
2022	436
2023	433
2024	127
Thereafter	0
Total Lease Payments	16,106
Less: Interest	1,236
Present Value of Lease Liabilities	$ 14,870

Leases - Terms and Discount Rat

Leases - Terms and Discount Rates (Details)	Dec. 31, 2019
Leases [Abstract]
Operating leases, weighted average remaining lease term	4 years 4 months 20 days
Finance leases, weighted average remaining lease term	2 years 1 month 28 days
Operating leases, weighted average discount rate	4.96%
Finance leases, weighted average discount rate	6.92%

Pension Reconciliation of Chang

Pension Reconciliation of Changed in Benefit Obligations, Plan Assets, and Funded Status of Pension Benefits (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Curtailment gain due to plan freeze	$ 0	$ 416	$ 0
Change in Benefit Obligation:
Benefit Obligation at Beginning of Period	33,569	36,280
Service Cost	209	302	375
Interest Cost	1,338	1,265	1,201
Actuarial Loss (Gain)	4,865	(2,645)
Plan Amendments	1,728	0
Plan Curtailments	0	(126)
Benefits and Other Payments	(1,513)	(1,507)
Benefit Obligation at End of Period	40,196	33,569	36,280
Change in Plan Assets:
Fair Value of Plan Assets at Beginning of Period	0	0
Company Contributions	1,513	1,507
Benefits and Other Payments	(1,513)	(1,507)
Fair Value of Plan Assets at End of Period	0	0	$ 0
Funded Status:
Current Liabilities	(1,587)	(1,578)
Noncurrent Liabilities	(38,609)	(31,991)
Net Obligation Recognized	(40,196)	(33,569)
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of:
Net Actuarial Loss	15,361	10,738
Prior Service Cost (Credit)	1,727	(17)
Total	17,088	10,721
Net Amount Recognized	12,605	7,904
Accumulated Defined Benefit Plans Adjustment Attributable to Parent
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of:
Less: Tax Benefit	$ 4,483	$ 2,817

Pension Components of Net Perio

Pension Components of Net Periodic Benefit Cost (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Contribution Plan [Abstract]
Service Cost	$ 209	$ 302	$ 375
Interest Cost	1,338	1,265	1,201
Amortization of Prior Service Credits	(17)	(193)	(362)
Recognized Net Actuarial Loss	242	865	1,525
Curtailment Gain	0	(416)	0
Net Periodic Benefit Cost	$ 1,772	$ 1,823	$ 2,739

Pension AOCI Expected to be Rec

Pension AOCI Expected to be Recognized in Net Periodic Benefit Cost (Details) $ in Thousands	Dec. 31, 2019USD ($)
Defined Contribution Plan [Abstract]
Prior Service Cost Recognition	$ (221)
Actuarial Loss Recognition	$ (383)

Pension Accumulated Benefit Obl

Pension Accumulated Benefit Obligation in Excess of Plan Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Defined Contribution Plan [Abstract]
Projected Benefit Obligation	$ 40,196	$ 33,569
Accumulated Benefit Obligation	40,196	33,169
Fair Value of Plan Assets	$ 0	$ 0

Pension Weighted Average Assump

Pension Weighted Average Assumptions (Details)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Discount Rate	3.36%	4.37%
Rate of Compensation Increase	0.00%	3.63%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Discount Rate	4.37%	4.28%	4.26%
Rate of Compensation Increase	3.63%	4.05%	3.90%

Pension Expected Future Benefit

Pension Expected Future Benefit Payment (Details) $ in Thousands	Dec. 31, 2019USD ($)
Defined Contribution Plan [Abstract]
Payment for pension benefits	$ 1,588
2020	1,588
2021	1,670
2022	1,760
2023	1,866
2024	2,063
Year 2025-2029	$ 11,207

Stock-Based Compensation Narrat

Stock-Based Compensation Narrative (Details) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)$ / sharesshares	Dec. 31, 2018USD ($)$ / sharesshares	Dec. 31, 2017USD ($)	Nov. 28, 2017shares	May 31, 2016shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares approved for increase in available for issuance (in shares) | shares				48,915,944
Common stock available for grant (in shares) | shares	5,560,610
Stock-based compensation expense | $	$ 36,545	$ 18,930	$ 16,983
Unrecognized compensation cost related to nonvested awards | $	$ 7,346
Recognition period, weighted average	2 years 2 months 26 days
Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award conversation ratio	1.62
Award vesting period	3 years
Vested (in shares) | shares	1,052,235
Fair value of RSUs granted during the year | $	$ 10,844	13,768	14,328
Fair value of restricted stock units vested during the year | $	$ 10,391	6,437	12,805
Restricted Stock Units | Accelerated Vesting
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vested (in shares) | shares	473,126
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vested (in shares) | shares	345,282
Fair value of RSUs granted during the year | $	$ 6,741	8,570	9,789
Fair value of performance share units vested | $	$ 4,668	7,547	17,646
Performance Share Units | Granted 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	3 years
Performance Share Units | Granted 2016-2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	5 years
Performance Share Units | Tranche One | Granted 2016-2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting rights percentage	20.00%
Performance Share Units | Tranche Two | Granted 2016-2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting rights percentage	20.00%
Performance Share Units | Tranche Three | Granted 2016-2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting rights percentage	20.00%
Performance Share Units | Tranche Four | Granted 2016-2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting rights percentage	20.00%
Performance Share Units | Tranche Five | Granted 2016-2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting rights percentage	20.00%
Performance Share Units | Accelerated Vesting
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vested (in shares) | shares	903,100
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
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					10,550,000
Employee Stock Option
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award conversation ratio	1
Award vesting period	3 years
Fair value of options granted during the year | $	$ 50	$ 143	353
Options outstanding (in shares) | shares	4,696,264	5,442,920
Intrinsic value of options exercised | $	$ 175	$ 2,077	1,067
Cash received from option exercises | $	546	1,714	1,002
Tax impact from option exercises | $	$ 46	$ 569	$ 205
Weighted average exercise price (in usd per share) | $ / shares	$ 18.05	$ 18.74
Weighted average remaining contractual term, outstanding	4 years 5 months 26 days
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
Weighted average remaining contractual term, outstanding	5 months 15 days
Director | Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	1 year
Director | Employee Stock Option
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	1 year
Options outstanding (in shares) | shares	471,849
Employee | Employee Stock Option
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options outstanding (in shares) | shares	4,224,415
Minimum | Southeastern Asset Management, Inc.
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Ownership percentage in equity method investment	25.00%

Stock-Based Compensation Option

Stock-Based Compensation Options Granted, Assumptions and Weighted Average Fair Value (Details) - $ / shares	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Share-based Payment Arrangement, Noncash Expense [Abstract]
Weighted average fair value of grants (in usd per share)	$ 3.48	$ 6.50	$ 6.19
Risk-free interest rate	2.13%	2.66%	1.66%
Expected dividend yield	0.00%	0.00%	0.00%
Expected forfeiture rate	0.00%	0.00%	0.00%
Expected volatility	43.60%	52.68%	50.85%
Expected term in years	6 years 6 months	3 years 8 months 15 days	3 years 8 months 15 days

Stock-Based Compensation Stock

Stock-Based Compensation Stock and Performance Options Rollforward (Details) - Employee Stock Option $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)$ / sharesshares
Shares
Beginning balance (in shares) | shares	5,442,920
Granted (in shares) | shares	14,368
Exercised (in shares) | shares	(79,468)
Forfeited (in shares) | shares	(4,208)
Expired (in shares) | shares	(677,348)
End balance (in shares) | shares	4,696,264
Exercisable at December 31, 2019 (in shares) | shares	4,681,896
Weighted Average Exercise Price
Beginning balance (in usd per share) | $ / shares	$ 18.74
Granted (in usd per share) | $ / shares	7.54
Exercised (in usd per share) | $ / shares	6.87
Forfeited (in usd per share) | $ / shares	6.87
Expired (in usd per share) | $ / shares	24.29
Ending balance (in usd per share) | $ / shares	18.05
Exercisable at December 31, 2019 (in usd per share) | $ / shares	$ 18.04
Weighted average remaining contractual term, outstanding	4 years 5 months 26 days
Weighted average remaining contractual term (in years), exercisable	4 years 5 months 19 days
Aggregate intrinsic value, outstanding | $	$ 5,280
Aggregate intrinsic value, exercisable | $	$ 5,261

Stock-Based Compensation Restri

Stock-Based Compensation Restricted and Performance Stock Unit Rollforward (Details) - $ / shares	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Restricted Stock Units
Number of Shares
Beginning nonvested balance (in shares)	1,427,151
Granted (in shares)	963,426
Vested (in shares)	(1,052,235)
Forfeited (in shares)	(305,142)
Ending nonvested balance (in shares)	1,033,200
Weighted Average Grant Date Fair Value
Beginning nonvested balance (in usd per share)	$ 11.71	$ 14.30
Granted (in usd per share)	11.26
Vested (in usd per share)	14.27
Forfeited (in usd per share)	13.50
Ending nonvested balance (in usd per share)	$ 11.71
Performance Share Units
Number of Shares
Beginning nonvested balance (in shares)	1,344,985
Granted (in shares)	407,056
PSUs issued as a result of 200% payout (in shares)	156,918
Vested (in shares)	(345,282)
Forfeited (in shares)	(162,841)
Ending nonvested balance (in shares)	1,400,836
Weighted Average Grant Date Fair Value
Beginning nonvested balance (in usd per share)	$ 18.91	$ 19.93
Granted (in usd per share)	16.56
PSUs issued as a result of 200% payout (in usd per share)	22.63
Vested (in usd per share)	22.21
Forfeited (in usd per share)	17.83
Ending nonvested balance (in usd per share)	$ 18.91

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information Supplemental Cash Flow (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Other Significant Noncash Transactions [Line Items]
Interest (Net of Amounts Capitalized)	$ 143,111	$ 144,756	$ 152,047
Income Taxes	(138,409)	(11,505)	(121,773)
Notes Received from Property Sales
Other Significant Noncash Transactions [Line Items]
Capital expenditures incurred, not yet paid	$ 43,982	$ 58,246	$ 35,437

Concentrations of Credit Risk_3

Concentrations of Credit Risk and Major Customers (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Concentration Risk [Line Items]
Receivables related to contracts with customers	$ 133,480	$ 252,424
NJR Energy Services Company
Concentration Risk [Line Items]
Revenue from contracts with customers	147,540	219,472	$ 147,595
Direct Energy Business Marketing LLC
Concentration Risk [Line Items]
Revenue from contracts with customers	214,980	184,668	$ 153,565
Accounts Receivable | Customer Concentration Risk
Concentration Risk [Line Items]
Receivables related to contracts with customers	133,480	252,424
Accounts Receivable | Customer Concentration Risk | Gas Wholesalers
Concentration Risk [Line Items]
Receivables related to contracts with customers	115,641	232,638
Accounts Receivable | Customer Concentration Risk | NGL, Condensate & Processing Facilities
Concentration Risk [Line Items]
Receivables related to contracts with customers	10,140	12,595
Accounts Receivable | Customer Concentration Risk | Other
Concentration Risk [Line Items]
Receivables related to contracts with customers	7,699	7,191
Accounts Receivable | Customer Concentration Risk | NJR Energy Services Company
Concentration Risk [Line Items]
Receivables related to contracts with customers	15,401	30,872
Accounts Receivable | Customer Concentration Risk | Direct Energy Business Marketing LLC
Concentration Risk [Line Items]
Receivables related to contracts with customers	$ 23,859	$ 26,417

Fair Value of Financial Instr_3

Fair Value of Financial Instruments Financial Instruments Measured at Fair Value on a Recurring Basis (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gas Derivatives	$ 0	$ 0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gas Derivatives	405,781	99,456
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gas Derivatives	$ 0	$ 0

Fair Value Disclosures (Details

Fair Value Disclosures (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and Cash Equivalents	$ 16,283	$ 17,198
Long-Term Debt (Excluding Debt Issuance Costs)	2,754,443	2,378,205
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and Cash Equivalents	16,283	17,198
Long-Term Debt (Excluding Debt Issuance Costs)	2,763,433	2,387,001
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and Cash Equivalents	16,283	17,198
Long-Term Debt (Excluding Debt Issuance Costs)	$ 2,619,676	$ 2,290,537

Derivative Instruments Narrativ

Derivative Instruments Narrative (Details)	1 Months Ended
	Jun. 30, 2019USD ($)
Revolving Credit Facility
Derivative [Line Items]
Debt instrument, face amount	$ 160,000,000
Interest Rate Swap
Derivative [Line Items]
Derivative term of contract	3 years

Derivative Instruments Notional

Derivative Instruments Notional Amounts of Derivative Instruments (Details) - Mcf Mcf in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Natural Gas Commodity Swaps (Bcf)
Derivative Instruments, Gain (Loss) [Line Items]
Derivative notional amount	1,460.6	1,484.4
Natural Gas Basis Swaps (Bcf)
Derivative Instruments, Gain (Loss) [Line Items]
Derivative notional amount	1,290.4	1,056.6

Derivative Instruments Fair Val

Derivative Instruments Fair Value of Derivative Instruments (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Asset Derivative Instruments
Current Assets	$ 247,794	$ 40,240
Other Assets	314,096	213,098
Liability Derivative Instruments
Current Liabilities	115,138	92,221
Non-Current Liabilities	40,971	61,661
Commodity Swaps
Asset Derivative Instruments
Current Assets	234,238	28,612
Other Assets	288,543	164,310
Total Asset	522,781	192,922
Liability Derivative Instruments
Current Liabilities	345	34,640
Non-Current Liabilities	9,693	52,011
Total Liability	10,038	86,651
Basis Only Swaps
Asset Derivative Instruments
Current Assets	13,556	11,628
Other Assets	25,553	48,788
Total Asset	39,109	60,416
Liability Derivative Instruments
Current Liabilities	40,626	27,021
Non-Current Liabilities	105,445	40,210
Total Liability	$ 146,071	$ 67,231

Derivative Instruments Effect o

Derivative Instruments Effect of Derivative Instrument on Statement of Income (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Derivative [Line Items]
Cash Received (Paid) in Settlement of Commodity Derivative Instruments:	$ 69,780	$ (69,720)	$ (41,174)
Unrealized Gain (Loss) on Commodity Derivative Instruments:	306,325	39,508	248,104
Gain (Loss) on Commodity Derivative Instruments	376,105	(30,212)	206,930
Natural Gas Basis Swaps
Derivative [Line Items]
Cash Received (Paid) in Settlement of Commodity Derivative Instruments:	(13,119)	(28,622)	(5,030)
Unrealized Gain (Loss) on Commodity Derivative Instruments:	(100,147)	6,482	(72,648)
Gain (Loss) on Commodity Derivative Instruments	(113,266)	(22,140)	(77,678)
Natural Gas | Commodity Swaps
Derivative [Line Items]
Cash Received (Paid) in Settlement of Commodity Derivative Instruments:	82,899	(41,098)	(34,928)
Unrealized Gain (Loss) on Commodity Derivative Instruments:	406,472	33,026	319,605
Gain (Loss) on Commodity Derivative Instruments	489,371	(8,072)	284,677
Propane | Commodity Swaps
Derivative [Line Items]
Cash Received (Paid) in Settlement of Commodity Derivative Instruments:	0	0	(1,216)
Unrealized Gain (Loss) on Commodity Derivative Instruments:	0	0	1,147
Gain (Loss) on Commodity Derivative Instruments	$ 0	$ 0	$ (69)

Maximum Potential Total of Futu

Maximum Potential Total of Future Payments Under Commitment Instruments (Details) $ in Thousands	Dec. 31, 2019USD ($)
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	$ 311,013
Letters of Credit:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	204,726
Surety Bonds:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	106,287
Less Than 1 Year
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	259,469
Less Than 1 Year | Letters of Credit:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	154,726
Less Than 1 Year | Surety Bonds:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	104,743
1-3 Years
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	51,544
1-3 Years | Letters of Credit:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	50,000
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	197,776
Firm Transportation | Less Than 1 Year | Letters of Credit:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	148,526
Firm Transportation | 1-3 Years | Letters of Credit:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	49,250
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	9,254
Other | Less Than 1 Year | Letters of Credit:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	6,200
Other | Less Than 1 Year | Surety Bonds:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	7,970
Other | 1-3 Years | Letters of Credit:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	750
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	12,763
Environmental | Less Than 1 Year | Surety Bonds:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	12,503
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

Commitments and Contingent Li_3

Commitments and Contingent Liabilities Unrecorded Unconditional Purchase Obligation (Details) - Purchase Commitment $ in Thousands	Dec. 31, 2019USD ($)
Unrecorded Unconditional Purchase Obligation [Line Items]
Less than 1 year	$ 256,613
1 - 3 years	483,807
3 - 5 years	406,915
More than 5 years	1,072,748
Total Purchase Obligations	$ 2,220,083

Variable Interest Entities (Det

Variable Interest Entities (Details) - USD ($) $ in Thousands	1 Months Ended	12 Months Ended
	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018
Variable Interest Entity [Line Items]
Payable to affiliates		$ 16,362	$ 12,202
Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Variable interest entity, ownership percentage		34.00%
General Partner | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Variable interest entity, ownership percentage		100.00%
Senior Notes due March 2026
Variable Interest Entity [Line Items]
Stated rate, debt instrument		6.50%
Senior Notes due March 2026 | CNX Midstream Partners LP
Variable Interest Entity [Line Items]
Stated rate, debt instrument	6.50%
Shirley-Penns System
Variable Interest Entity [Line Items]
Cash consideration transferred	$ 265,000
CNXM | Shirley-Penns System
Variable Interest Entity [Line Items]
Ownership percentage by parent	95.00%

Variable Interest Entities Bala

Variable Interest Entities Balance Sheet (Details) - Variable Interest Entity, Primary Beneficiary - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
ASSETS
Total Assets	$ 1,234,602	$ 925,428
Liabilities:
Total Liabilities	777,989	526,114
Cash
ASSETS
Current assets	31	3,966
Receivables - Related Party
ASSETS
Current assets	21,076	17,073
Receivables - Third Party
ASSETS
Current assets	7,935	7,028
Other Current Assets
ASSETS
Current assets	1,976	2,383
Property, Plant and Equipment, net
ASSETS
Non-current assets	1,195,591	891,775
Operating Lease ROU Asset
ASSETS
Non-current assets	4,731
Other Assets
ASSETS
Non-current assets	3,262	3,203
Accounts Payable and Accrued Liabilities
Liabilities:
Current liabilities	67,290	43,919
Accounts Payable - Related Party
Liabilities:
Current liabilities	4,787	4,980
Revolving Credit Facility
Liabilities:
Current liabilities	311,750	84,000
Long-Term Debt
Liabilities:
Non-current liabilities	$ 394,162	$ 393,215

Variable Interest Entities Stat

Variable Interest Entities Statement of Operations and Cash Flows (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Revenue
Total Revenue and Other Operating Income	$ 504,747	$ 526,681	$ 602,109	$ 275,234	$ 431,660	$ 393,223	$ 393,590	$ 485,019	$ 1,922,449	$ 1,730,434	$ 1,455,131
Expenses
Loss on Asset Sales and Abandonments, net									(35,563)	(157,015)	(188,063)
Interest Expense									151,379	145,934	161,443
Total Costs and Expenses	182,035	153,833	153,835	147,928	148,480	123,779	140,040	167,785	1,862,765	631,766	1,336,550
Net (Loss) Income Attributable to CNX Resources Shareholders	$ (271,408)	$ 115,538	$ 162,477	$ (87,337)	$ 101,927	$ 125,029	$ 42,014	$ 527,563	(80,730)	796,533	380,747
Net Cash Provided by Operating Activities									980,560	885,823	648,687
Net Cash Used in Investing Activities									(1,147,439)	(894,652)	(221,921)
Net Cash Provided by (Used in) Financing Activities									165,964	(483,140)	$ 36,102
Variable Interest Entity, Primary Beneficiary
Revenue
Gathering Revenue - Related Party									231,482	167,048
Gathering Revenue - Third Party									74,315	89,620
Total Revenue and Other Operating Income									305,797	256,668
Expenses
Operating Expense - Related Party									22,943	19,814
Operating Expense - Third Party									23,964	27,343
General and Administrative Expense - Related Party									15,928	13,867
General and Administrative Expense - Third Party									5,769	8,595
Loss on Asset Sales and Abandonments, net									7,229	2,501
Depreciation Expense									24,371	21,939
Interest Expense									30,293	23,614
Total Costs and Expenses									130,497	117,673
Net (Loss) Income Attributable to CNX Resources Shareholders									175,300	138,995
Net Cash Provided by Operating Activities									217,062	180,115
Net Cash Used in Investing Activities									(327,615)	(138,869)
Net Cash Provided by (Used in) Financing Activities									$ 106,618	$ (40,474)

Variable Interest Entities Othe

Variable Interest Entities Other Operating Income and Transportation, Gathering and Compression (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Variable Interest Entity [Line Items]
Equity in Earnings	$ 2,103	$ 5,363	$ 49,830
CNX Gathering | Other Operating Income
Variable Interest Entity [Line Items]
Equity in Earnings		9,823
CNX Gathering | Transportation, Gathering and Compression
Variable Interest Entity [Line Items]
Equity in Earnings		914
CNXM | Other Operating Income
Variable Interest Entity [Line Items]
Equity in Earnings		38,523
CNXM | Transportation, Gathering and Compression
Variable Interest Entity [Line Items]
Equity in Earnings		$ 136,068

Segment Information Industry Se

Segment Information Industry Segment Results (Details) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019USD ($)	Sep. 30, 2019USD ($)	Jun. 30, 2019USD ($)	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2019USD ($)segment	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 14, 2017
Segment Reporting Information [Line Items]
Number of divisions | segment									2
(Loss) Gain on Commodity Derivative Instruments									$ 376,105	$ (30,212)	$ 206,930
Other Operating Income									13,678	26,942	69,182
Total Revenue and Other Operating Income	$ 504,747	$ 526,681	$ 602,109	$ 275,234	$ 431,660	$ 393,223	$ 393,590	$ 485,019	1,922,449	1,730,434	1,455,131
Earnings (Loss) From Continuing Operations Before Income Tax									59,684	1,098,668	118,581
Segment Assets	9,060,806				8,592,170				9,060,806	8,592,170	6,931,913
Depreciation, Depletion and Amortization									508,463	493,423	412,036
Capital Expenditures									1,192,599	1,116,397	632,846
Equity in Earnings of Affiliates									2,103	5,363	49,830
Natural Gas, NGLs and Oil Sales
Segment Reporting Information [Line Items]
Revenue									1,364,325	1,577,937	1,125,224
Purchased Gas Revenue
Segment Reporting Information [Line Items]
Revenue									94,027	65,986	53,795
Midstream Revenue
Segment Reporting Information [Line Items]
Revenue									74,314	89,781	0
Direct Energy Business Marketing LLC
Segment Reporting Information [Line Items]
Revenue									214,980	184,668	153,565
Total Revenue and Other Operating Income									214,980	184,668	153,656
NJR Energy Services Company
Segment Reporting Information [Line Items]
Revenue									147,540	219,472	147,595
Total Revenue and Other Operating Income									147,540	219,472	147,595
Operating Segments
Segment Reporting Information [Line Items]
Revenue									1,532,666	1,733,704	1,179,019
Earnings (Loss) From Continuing Operations Before Income Tax									26,211	378,427	(63,527)
Investments in Unconsolidated Equity Affiliates	16,710				18,663				16,710	18,663	197,921
Corporate, Non-Segment
Segment Reporting Information [Line Items]
(Loss) Gain on Commodity Derivative Instruments									0	0	0
Other Operating Income									0	0	0
Total Revenue and Other Operating Income									0	0	0
Earnings (Loss) From Continuing Operations Before Income Tax									33,473	720,241	182,108
Segment Assets	78,708				166,679				78,708	166,679	540,690
Depreciation, Depletion and Amortization									0	0	0
Capital Expenditures									0	0	0
Corporate, Non-Segment | Natural Gas, NGLs and Oil Sales
Segment Reporting Information [Line Items]
Revenue									0	0	0
Corporate, Non-Segment | Purchased Gas Revenue
Segment Reporting Information [Line Items]
Revenue									0	0	0
Corporate, Non-Segment | Midstream Revenue
Segment Reporting Information [Line Items]
Revenue									0	0
Intercompany Eliminations
Segment Reporting Information [Line Items]
(Loss) Gain on Commodity Derivative Instruments									0	0
Other Operating Income									(379)	(276)
Total Revenue and Other Operating Income									(233,089)	(168,569)
Earnings (Loss) From Continuing Operations Before Income Tax									0	0
Segment Assets	$ 6,331				(12,223)				6,331	(12,223)
Depreciation, Depletion and Amortization									0	0
Capital Expenditures									0	0
Intercompany Eliminations | Natural Gas, NGLs and Oil Sales
Segment Reporting Information [Line Items]
Revenue									0	0
Intercompany Eliminations | Purchased Gas Revenue
Segment Reporting Information [Line Items]
Revenue									0	0
Intercompany Eliminations | Midstream Revenue
Segment Reporting Information [Line Items]
Revenue									$ (232,710)	(168,293)
Variable Interest Entity, Primary Beneficiary
Segment Reporting Information [Line Items]
Variable interest entity, ownership percentage									34.00%
Total Revenue and Other Operating Income									$ 305,797	256,668
CNX Gathering
Segment Reporting Information [Line Items]
Interest in equity method investment	100.00%								100.00%			50.00%
Exploration and Production Equipment
Segment Reporting Information [Line Items]
Number of reportable segments | segment									4
Exploration and Production Equipment | Operating Segments
Segment Reporting Information [Line Items]
(Loss) Gain on Commodity Derivative Instruments									$ 376,105	(30,212)	206,930
Other Operating Income									14,057	27,218	69,182
Total Revenue and Other Operating Income									1,848,514	1,640,929	1,455,131
Earnings (Loss) From Continuing Operations Before Income Tax									(140,443)	244,616	(63,527)
Segment Assets	$ 6,745,091				6,518,597				6,745,091	6,518,597	6,391,223
Depreciation, Depletion and Amortization									474,352	461,149	412,036
Capital Expenditures									867,860	974,059	632,846
Exploration and Production Equipment | Operating Segments | Natural Gas, NGLs and Oil Sales
Segment Reporting Information [Line Items]
Revenue									1,364,325	1,577,937	1,125,224
Exploration and Production Equipment | Operating Segments | Purchased Gas Revenue
Segment Reporting Information [Line Items]
Revenue									94,027	65,986	53,795
Exploration and Production Equipment | Operating Segments | Midstream Revenue
Segment Reporting Information [Line Items]
Revenue									0	0
Midstream | Operating Segments
Segment Reporting Information [Line Items]
(Loss) Gain on Commodity Derivative Instruments									0	0
Other Operating Income									0	0
Total Revenue and Other Operating Income									307,024	258,074
Earnings (Loss) From Continuing Operations Before Income Tax									166,654	133,811	0
Segment Assets	$ 2,230,676				$ 1,919,117				2,230,676	1,919,117
Depreciation, Depletion and Amortization									34,111	32,274
Capital Expenditures									324,739	142,338
Midstream | Operating Segments | Natural Gas, NGLs and Oil Sales
Segment Reporting Information [Line Items]
Revenue									0	0
Midstream | Operating Segments | Purchased Gas Revenue
Segment Reporting Information [Line Items]
Revenue									0	0
Midstream | Operating Segments | Midstream Revenue
Segment Reporting Information [Line Items]
Revenue									307,024	258,074
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Marcellus Shale
Segment Reporting Information [Line Items]
(Loss) Gain on Commodity Derivative Instruments									47,475	(40,444)	(30,336)
Other Operating Income									0	0	0
Total Revenue and Other Operating Income									982,203	862,872	615,852
Earnings (Loss) From Continuing Operations Before Income Tax									234,284	254,310	91,436
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Utica Shale
Segment Reporting Information [Line Items]
(Loss) Gain on Commodity Derivative Instruments									14,943	(19,882)	1,367
Other Operating Income									0	0	0
Total Revenue and Other Operating Income									279,491	425,998	218,387
Earnings (Loss) From Continuing Operations Before Income Tax									87,972	194,164	64,741
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Coalbed Methane
Segment Reporting Information [Line Items]
(Loss) Gain on Commodity Derivative Instruments									7,335	(8,767)	(9,589)
Other Operating Income									0	0	0
Total Revenue and Other Operating Income									171,228	204,117	199,088
Earnings (Loss) From Continuing Operations Before Income Tax									35,170	49,719	20,346
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Other Gas
Segment Reporting Information [Line Items]
(Loss) Gain on Commodity Derivative Instruments									306,352	38,881	245,488
Other Operating Income									14,057	27,218	69,182
Total Revenue and Other Operating Income									415,592	147,942	421,804
Earnings (Loss) From Continuing Operations Before Income Tax									(497,869)	(253,577)	(240,050)
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Natural Gas, NGLs and Oil Sales | Marcellus Shale
Segment Reporting Information [Line Items]
Revenue									934,728	903,316	646,188
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Natural Gas, NGLs and Oil Sales | Utica Shale
Segment Reporting Information [Line Items]
Revenue									264,548	445,880	217,020
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Natural Gas, NGLs and Oil Sales | Coalbed Methane
Segment Reporting Information [Line Items]
Revenue									163,893	212,884	208,677
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Natural Gas, NGLs and Oil Sales | Other Gas
Segment Reporting Information [Line Items]
Revenue									1,156	15,857	53,339
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Purchased Gas Revenue | Marcellus Shale
Segment Reporting Information [Line Items]
Revenue									0	0	0
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Purchased Gas Revenue | Utica Shale
Segment Reporting Information [Line Items]
Revenue									0	0	0
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Purchased Gas Revenue | Coalbed Methane
Segment Reporting Information [Line Items]
Revenue									0	0	0
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Purchased Gas Revenue | Other Gas
Segment Reporting Information [Line Items]
Revenue									94,027	65,986	$ 53,795
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Midstream Revenue | Marcellus Shale
Segment Reporting Information [Line Items]
Revenue									0	0
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Midstream Revenue | Utica Shale
Segment Reporting Information [Line Items]
Revenue									0	0
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Midstream Revenue | Coalbed Methane
Segment Reporting Information [Line Items]
Revenue									0	0
Reportable Subsegments | Exploration and Production Equipment | Operating Segments | Midstream Revenue | Other Gas
Segment Reporting Information [Line Items]
Revenue									$ 0	$ 0

Reconciliation of Segment Infor

Reconciliation of Segment Information, Revenue and Other Income (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting, Revenue Reconciling Item [Line Items]
Gain (Loss) on Commodity Derivative Instruments									$ 376,105	$ (30,212)	$ 206,930
Other Operating Income									13,678	26,942	69,182
Total Consolidated Revenue and Other Operating Income	$ 504,747	$ 526,681	$ 602,109	$ 275,234	$ 431,660	$ 393,223	$ 393,590	$ 485,019	1,922,449	1,730,434	1,455,131
Operating Segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Total Segment Revenue from Contracts with External Customers									$ 1,532,666	$ 1,733,704	$ 1,179,019

Segment Information Reconciliat

Segment Information Reconciliation of Earnings Before Income Tax (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Income (Loss)	$ 59,684	$ 1,098,668	$ 118,581
Gain on Certain Asset Sales	(2,862)	14,571	(3,825)
Gain on Certain Asset Sales	35,563	157,015	188,063
Loss on Debt Extinguishment	(7,614)	(54,118)	(2,129)
Impairment of Other Intangible Assets	0	(18,650)	0
Operating Segments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Income (Loss)	26,211	378,427	(63,527)
Corporate, Non-Segment
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Income (Loss)	33,473	720,241	182,108
Gain on Certain Asset Sales	(1,396)	14,571	(3,826)
Gain on Certain Asset Sales	42,483	154,775	188,063
Gain on Previously Held Equity Interest	0	623,663	0
Loss on Debt Extinguishment	(7,614)	(54,118)	(2,129)
Impairment of Other Intangible Assets	0	(18,650)	0
Exploration and Production Equipment | Operating Segments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Income (Loss)	(140,443)	244,616	(63,527)
Midstream | Operating Segments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Income (Loss)	$ 166,654	$ 133,811	$ 0

Segment Information Reconcili_2

Segment Information Reconciliation of Segment Information, Total Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Items Excluded from Segment Assets:
Segment Assets	$ 9,060,806	$ 8,592,170	$ 6,931,913
Recoverable Income Taxes	62,425	149,481
Intercompany Eliminations
Items Excluded from Segment Assets:
Segment Assets	6,331	(12,223)
Segment Reconciling Items
Items Excluded from Segment Assets:
Cash and Cash Equivalents	16,283	17,198
Recoverable Income Taxes	62,425	149,481
Exploration and Production Equipment | Operating Segments
Items Excluded from Segment Assets:
Segment Assets	6,745,091	6,518,597	$ 6,391,223
Midstream | Operating Segments
Items Excluded from Segment Assets:
Segment Assets	$ 2,230,676	$ 1,919,117

Subsequent Events (Details)

Subsequent Events (Details) - Variable Interest Entity, Primary Beneficiary - USD ($) $ in Thousands, shares in Millions	Jan. 29, 2020	Dec. 31, 2019	Jan. 01, 2022
Subsequent Event [Line Items]
Variable interest entity, ownership percentage		34.00%
General Partner
Subsequent Event [Line Items]
Variable interest entity, ownership percentage		100.00%
Limited Partner | Subsequent Event
Subsequent Event [Line Items]
Variable interest entity, ownership percentage	53.10%
Common Units | Subsequent Event
Subsequent Event [Line Items]
Limited partnership interests (in units)	47.7
IDR Elimination Transaction | Subsequent Event
Subsequent Event [Line Items]
Incentive distribution receivable, due next twelve months	$ 50,000
Incentive distribution receivable, due in two years	50,000
Incentive distribution receivable, due in three years	$ 35,000
IDR Elimination Transaction | General Partner | CNX Midstream GP LLC | Subsequent Event
Subsequent Event [Line Items]
Variable interest entity, ownership percentage	2.00%
IDR Elimination Transaction | Common Units | Subsequent Event
Subsequent Event [Line Items]
Limited Partners' capital account, issued (in units)	26
IDR Elimination Transaction | Capital Unit, Class B | Subsequent Event
Subsequent Event [Line Items]
Limited Partners' capital account, issued (in units)	3
Forecast | Common Units | Subsequent Event
Subsequent Event [Line Items]
Limited partnership interests (in units)			50.7
Forecast | IDR Elimination Transaction | Subsequent Event
Subsequent Event [Line Items]
Consideration to be received	$ 135,000

Supplemental Gas Data (unaudi_3

Supplemental Gas Data (unaudited) Capitalized Costs (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Extractive Industries [Abstract]
Intangible Drilling Cost	$ 4,688,497	$ 4,120,283
Proved Gas Properties	1,208,046	1,135,411
Gas Gathering Assets	1,110,977	1,099,047
Unproved Gas Properties	755,590	927,667
Gas Wells and Related Equipment	1,042,000	856,973
Other Gas Assets	73,479	54,395
Total Property, Plant and Equipment	8,878,589	8,193,776
Accumulated Depreciation, Depletion and Amortization	(3,263,221)	(2,475,917)
Net Capitalized Costs	$ 5,615,368	$ 5,717,859

Supplemental Gas Data (unaudi_4

Supplemental Gas Data (unaudited) Costs Incurred for Property Acquisition, Exploration and Development (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Property Acquisitions:
Proved Properties	$ 36,710	$ 38,621	$ 15,850
Unproved Properties	24,760	36,248	32,038
Development	739,874	844,081	544,809
Exploration	79,855	61,604	48,020
Total	$ 881,199	$ 980,554	$ 640,717

Supplemental Gas Data (unaudi_5

Supplemental Gas Data (unaudited) Results of Operations (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Dec. 31, 2019	Jun. 30, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Extractive Industries [Abstract]
Natural Gas, NGLs and Oil Revenue			$ 1,364,325	$ 1,577,937	$ 1,125,224
Gain (Loss) on Commodity Derivative Instruments			376,105	(30,212)	206,930
Gas Royalty Interests and Purchased Gas Sales			94,027	65,986	53,795
Total Revenue			1,834,457	1,613,711	1,385,949
Lease Operating Expense			65,443	95,139	88,932
Production, Ad Valorem, and Other Fees			27,461	32,750	29,267
Transportation, Gathering and Compression			516,879	424,206	382,865
Purchased Gas Costs			90,553	64,817	52,597
Impairment of Exploration and Production Properties	$ 327,400	$ 18,650	327,400	0	137,865
Impairment of Unproved Properties and Expirations			119,429	0	0
Exploration Costs			44,380	12,033	48,074
DD&A			474,352	461,149	412,036
Total Costs			1,665,897	1,090,094	1,151,636
Pre-tax Operating Income / (Loss)			168,560	523,617	234,313
Income Tax Benefit			78,398	102,629	(348,676)
Results of Operations for Producing Activities excluding Corporate and Interest Costs			$ 90,162	$ 420,988	$ 582,989

Supplemental Gas Data (unaudi_6

Supplemental Gas Data (unaudited) Average Unit Prices and Average Production Costs (Details) Mcfe in Thousands	12 Months Ended
	Dec. 31, 2019usd_per_mcfeMcfe	Dec. 31, 2018usd_per_mcfeMcfe	Dec. 31, 2017usd_per_mcfeMcfe
Average Sales Price and Production Costs Per Unit of Production [Line Items] (Deprecated 2019-01-31)
Production (MMcfe) | Mcfe	539,149	507,104	407,166
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)	2.53	3.11	2.76
Average Effects of Commodity Derivative Financial Settlements (per Mcfe)	0.14	(0.15)	(0.11)
Total Average Sales Price Including Effects of Commodity Derivative Financial Settlements (per Mcfe)	2.66	2.97	2.66
Average Lifting Costs, Excluding Ad Valorem and Severance Taxes (per Mcfe)	0.12	0.19	0.22

Supplemental Gas Data (unaudi_7

Supplemental Gas Data (unaudited) Narrative (Details) Mcf in Millions	12 Months Ended
	Dec. 31, 2019wellMcf	Dec. 31, 2018well	Dec. 31, 2017well
Extractive Industries [Abstract]
Net development wells drilled	75.7	83.9	90
Net dry development wells drilled	1	0	0
Net exploratory wells drilled	5	0	4
Net development wells drilled but uncompleted	35
Exploratory wells drilled but uncompleted	1
Net developmental wells completed, awaiting tie-in to production	7
Gas delivery commitment, remaining contractual volume | Mcf	532.3

Supplemental Gas Data (unaudi_8

Supplemental Gas Data (unaudited) Producing Wells, Developed Acreage and Undeveloped Acreage (Details) a in Thousands	Dec. 31, 2019awell	Jun. 30, 2017well
Gross
Producing Gas Wells (including Gob Wells) | well	6,512,000	12
Producing Oil Wells | well	151,000
Proved Developed Acreage	337,700
Proved Undeveloped Acreage	28,916
Unproved Acreage	5,192,777
Total Acreage	5,559,393
Net
Producing Gas Wells (including Gob Wells) | well	4,510,000
Producing Oil Wells | well	0
Proved Developed Acreage	337,700
Proved Undeveloped Acreage	28,916
Unproved Acreage	3,868,533
Total Acreage	4,235,149

Supplemental Gas Data (unaudi_9

Supplemental Gas Data (unaudited) Proved Undeveloped Reserves (Details) bbl in Thousands, Mcfe in Thousands, Mcf in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)wellMcfeMcfbbl	Dec. 31, 2018USD ($)McfeMcfbbl	Dec. 31, 2017USD ($)McfeMcfbbl
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Beginning balance (energy)	7,881,335	7,581,612	6,251,648
Revisions (energy)	(518,570)	320,925	(232,321)
Price changes (energy)	(45,246)	28,315	181,470
Extensions and Discoveries (energy)	1,647,297	960,808	1,887,153
Production (MMcfe)	(539,149)	(507,104)	(407,166)
Purchases of Reserves In-Place (energy)		321,975
Sales of Reserves In-Place (energy)		(825,196)	(99,172)
Ending balance (energy)	8,425,667	7,881,335	7,581,612
Proved developed resources (energy)	4,838,858	4,494,878	4,409,065
Proved undeveloped resources (energy)	3,586,809	3,386,457	3,172,547
Downward revision due to PUD removal (energy)	(304,000)		(458,000)
Upward revision from increased performance through optimization (energy)	657,000	472,000
Downward revision due to plan changes (energy)	872,000	151,000
Capital spent related to undeveloped reserves transferred to developed | $	$ 1,192,599	$ 1,116,397	$ 632,846
Reserves reported for more than five years	248,570
Number of wells pending determination of proved reserves | well	1
Proved Undeveloped
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Capital spent related to undeveloped reserves transferred to developed | $	$ 334,062
Proved Undeveloped
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Beginning balance (energy)	3,386,457
Undeveloped reserves transferred to developed	(752,970)
Extensions and Discoveries (energy)	1,570,576
Ending balance (energy)	3,586,809	3,386,457
Proved Undeveloped | Revisions Due to Five Year Rule
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Revisions (energy)	(303,787)
Proved Undeveloped | Price Revisions
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Revisions (energy)	2,147
Proved Undeveloped | Revisions Due to Plan Changes
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Revisions (energy)	(872,495)
Proved Undeveloped | Revisions Due to Changes Due to Well Performance
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Revisions (energy)	556,881
Natural Gas
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning balance (volume) | Mcf	7,436,338	7,121,758	5,828,399
Revisions (volume) | Mcf	(521,617)	313,091	(202,735)
Price Changes (volume) | Mcf	(40,773)	28,100	173,738
Extension and Discoveries (volume) | Mcf	1,569,813	839,268	1,769,029
Production (volume) | Mcf	(505,355)	(468,228)	(364,893)
Purchases of Reserves In-Place (volume) | Mcf		317,437
Sales of Reserves In-Place (volume) | Mcf		(715,088)	(81,780)
Ending balance (volume) | Mcf	7,938,406	7,436,338	7,121,758
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Proved developed resources (volume) | Mcf	4,473,534	4,242,579	4,051,526
Proved undeveloped resources (volume) | Mcf	3,464,873	3,193,759	3,070,232
NGLs
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning balance (volume) | bbl	65,904,000	71,691,000	60,532,000
Revisions (volume) | bbl	5,926,000	441,000	1,162,000
Price Changes (volume) | bbl	(740,000)	32,000	1,188,000
Extension and Discoveries (volume) | bbl	10,182,000	16,247,000	17,887,000
Production (volume) | bbl	(5,428,000)	(6,011,000)	(6,456,000)
Purchases of Reserves In-Place (volume) | bbl		756,000
Sales of Reserves In-Place (volume) | bbl		(17,252,000)	(2,622,000)
Ending balance (volume) | bbl	75,844,000	65,904,000	71,691,000
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Proved developed resources (volume) | bbl	59,800,000	40,180,000	56,022,000
Proved undeveloped resources (volume) | bbl	16,044,000	25,724,000	15,669,000
Condensate & Crude Oil
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning balance (volume) | bbl	8,261,000	4,950,000	10,009,000
Revisions (volume) | bbl	(5,418,000)	865,000	(5,834,000)
Price Changes (volume) | bbl	(5,000)	4,000	(159,000)
Extension and Discoveries (volume) | bbl	2,732,000	4,010,000	1,800,000
Production (volume) | bbl	(204,000)	(468,000)	(589,000)
Purchases of Reserves In-Place (volume) | bbl		0
Sales of Reserves In-Place (volume) | bbl		(1,100,000)	(277,000)
Ending balance (volume) | bbl	5,366,000	8,261,000	4,950,000
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Proved developed resources (volume) | bbl	1,087,000	1,870,000	3,567,000
Proved undeveloped resources (volume) | bbl	4,278,000	6,391,000	1,383,000

Supplemental Gas Data (unaud_10

Supplemental Gas Data (unaudited) Capitalized Exploratary Well Cost Activity (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Extractive Industries [Abstract]
Costs reclassified to wells, equipment and facilities based on the determination of proved reserves	$ 59,981	$ 46,614	$ 40,149
Costs expensed due to determination of dry hole or abandonment of project	$ 0	$ 809	$ 0

Supplemental Gas Data (unaud_11

Supplemental Gas Data (unaudited) Future Cash Flow of Proved Reserves (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)usd_per_mcfusd_per_bbl	Dec. 31, 2018USD ($)usd_per_mcfusd_per_bbl	Dec. 31, 2017USD ($)usd_per_mcfusd_per_bbl	Dec. 31, 2016USD ($)
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Revenues	$ 19,489,588	$ 26,610,100	$ 19,261,578
Production Costs	(7,903,120)	(7,730,451)	(7,234,303)
Development Costs	(1,121,073)	(1,600,128)	(1,710,585)
Income Tax Expense	(2,720,994)	(4,147,075)	(2,475,981)
Future Net Cash Flows	7,744,401	13,132,446	7,840,709
Discounted to Present Value at a 10% Annual Rate	(4,673,932)	(8,476,989)	(4,709,311)
Total Standardized Measure of Discounted Net Cash Flows	$ 3,070,469	$ 4,655,457	$ 3,131,398	$ 955,117
Natural Gas
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Adjusted oil price (in usd per barrel) | usd_per_mcf	2.24	3.28	2.44
Oil
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Adjusted oil price (in usd per barrel) | usd_per_bbl	44.31	51.68	38.65
NGLs
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Adjusted oil price (in usd per barrel) | usd_per_bbl	19.10	27.58	23.61

Supplemental Gas Data (unaud_12

Supplemental Gas Data (unaudited) Change in Standardized Measure of Discounted Future Net Cash Flows (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Balance at Beginning of Period	$ 4,655,457	$ 3,131,398	$ 955,117
Net Changes in Sales Prices and Production Costs	(2,826,725)	1,732,229	1,983,475
Sales Net of Production Costs	(1,130,685)	(995,630)	(831,131)
Net Change Due to Revisions in Quantity Estimates	(252,796)	307,030	(145,496)
Net Change Due to Extensions, Discoveries and Improved Recovery	654,027	534,052	588,574
Development Costs Incurred During the Period	739,874	844,081	544,809
Difference in Previously Estimated Development Costs Compared to Actual Costs Incurred During the Period	(323,922)	(434,817)	(129,427)
Purchase of Reserves In-Place	0	209,630	0
Sales of Reserves In-Place	0	(434,103)	(55,277)
Changes in Estimated Future Development Costs	(24,469)	(49,294)	(233,017)
Net Change in Future Income Taxes	409,797	(507,410)	(404,582)
Timing and Other	586,591	(69,087)	712,764
Accretion	583,320	387,378	145,589
Total standardized measure of discounted net cash flows	$ 3,070,469	$ 4,655,457	$ 3,131,398

Supplemental Quarterly Info (_3

Supplemental Quarterly Info (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Quarterly Financial Information Disclosure [Abstract]
Sales	$ 504,747	$ 526,681	$ 602,109	$ 275,234	$ 431,660	$ 393,223	$ 393,590	$ 485,019	$ 1,922,449	$ 1,730,434	$ 1,455,131
Costs and Expenses	182,035	153,833	153,835	147,928	148,480	123,779	140,040	167,785	1,862,765	631,766	1,336,550
Net Income	(240,055)	143,960	192,694	(64,651)	129,415	146,756	61,394	545,546	31,948	883,111	380,747
Net (Loss) Income Attributable to CNX Resources Shareholders	$ (271,408)	$ 115,538	$ 162,477	$ (87,337)	$ 101,927	$ 125,029	$ 42,014	$ 527,563	$ (80,730)	$ 796,533	$ 380,747
(Loss) Earnings Per Share
Basic earnings per share (in usd per share)	$ (1.45)	$ 0.62	$ 0.85	$ (0.44)	$ 0.51	$ 0.59	$ 0.19	$ 2.38	$ (0.42)	$ 3.75	$ 1.66
Diluted earnings per share (in usd per share)	$ (1.45)	$ 0.61	$ 0.84	$ (0.44)	$ 0.50	$ 0.59	$ 0.19	$ 2.35	$ (0.42)	$ 3.71	$ 1.65
Impairment of Exploration and Production Properties	$ 327,400						$ 18,650		$ 327,400	$ 0	$ 137,865
Impairment of Unproved Properties and Expirations									$ 119,429	$ 0	$ 0

Schedule II - Valuation and Q_2

Schedule II - Valuation and Qualifying Accounts (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period	$ 94,455	$ 136,576	$ 282,778
Charged to expense - additions	33,238	2,124	4,552
Release of valuation allowance - deductions	(2,639)	(44,245)	(150,754)
Charged to expense - deductions	0	0	0
Balance at end of period	125,054	94,455	136,576
State Operating Loss Carry-Forwards
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period	47,964	61,560	60,488
Charged to expense - additions	33,238	0	0
Release of valuation allowance - deductions	0	(13,596)	1,072
Charged to expense - deductions	0	0	0
Balance at end of period	81,202	47,964	61,560
Deferred Deductible Temporary Differences
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period	0	9,088	10,590
Charged to expense - additions		0	0
Release of valuation allowance - deductions		(9,088)	(1,502)
Charged to expense - deductions		0	0
Balance at end of period		0	9,088
Charitable Contributions
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period	3,297	3,156	5,052
Charged to expense - additions	0	141	0
Release of valuation allowance - deductions	(2,639)	0	(1,896)
Charged to expense - deductions	0	0	0
Balance at end of period	658	3,297	3,156
162(m) Officers Compensation
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period	0	5,957	0
Charged to expense - additions		0	0
Release of valuation allowance - deductions		(5,957)	5,957
Charged to expense - deductions		0
Balance at end of period		0	5,957
AMT Credit
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period	0	12,413	166,798
Charged to expense - additions		1,983	0
Release of valuation allowance - deductions		(14,396)	(154,385)
Charged to expense - deductions		0	0
Balance at end of period		0	12,413
Foreign Tax Credits
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period	43,194	44,402	39,850
Charged to expense - additions	0	0	4,552
Release of valuation allowance - deductions	0	(1,208)	0
Charged to expense - deductions	0	0	0
Balance at end of period	$ 43,194	$ 43,194	$ 44,402