Annual report pursuant to Section 13 and 15(d)

SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES (Tables)

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SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES (Tables)
 12 Months Ended
Dec. 31, 2020
Extractive Industries [Abstract]  
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure
Capitalized costs related to Tellurian’s natural gas producing activities are summarized as follows (in thousands):
December 31,
2020 2019 2018
Proved properties $ 62,718  $ 142,494  $ 101,459 
Unproved properties —  —  10,204 
Gross capitalized costs 62,718  142,494  111,663 
Accumulated DD&A (37,639) (21,010) (1,335)
Net capitalized costs $ 25,079  $ 121,484  $ 110,328 
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure
Costs incurred in natural gas property acquisition (inclusive of producing well costs), exploration and development activities are summarized as follows (in thousands):
Year Ended December 31,
2020 2019 2018
Property acquisitions:
Proved $ 1,307  $ 45,484  $ 13,261 
Unproved —  —  204 
Exploration costs —  —  — 
Development —  800  2,104 
Costs incurred $ 1,307  $ 46,284  $ 15,569 
Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure
The following table includes revenues and expenses directly associated with our natural gas and condensate producing activities. It does not include any interest costs or indirect general and administrative costs and, therefore, is not necessarily indicative of the contribution to consolidated net operating results of our natural gas operations. Tellurian’s results of operations from natural gas and condensate producing activities for the periods presented are as follows (in thousands):
Year Ended December 31,
2020 2019 2018
Natural gas sales $ 30,441  $ 28,774  $ 4,423 
Operating costs 15,814  14,923  11,251 
Depreciation, depletion and amortization 16,703  19,736  1,228 
Impairment charge 81,065  —  2,699 
Total operating costs and expenses 113,582  34,659  15,178 
Results of operations $ (83,141) $ (5,885) $ (10,755)
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities
Gas
(MMcf)		 Condensate
(Mbbl)		 Gas Equivalent
(MMcfe)
Proved reserves:
December 31, 2017 327,118  10  327,180 
Extensions, discoveries and other additions 22,481  —  22,481 
Revisions of previous estimates (84,061) (2) (84,072)
Production (1,399) (1) (1,405)
Sale of reserves-in-place —  —  — 
Purchases of reserves-in-place 715  —  715 
December 31, 2018 264,854  7  264,899 
Extensions, discoveries and other additions 12,848  —  12,848 
Revisions of previous estimates 4,737  (6) 4,696 
Production (13,901) (1) (13,905)
Sale of reserves-in-place —  —  — 
Purchases of reserves-in-place —  —  — 
December 31, 2019 268,538  —  268,538 
Extensions, discoveries and other additions —  —  — 
Revisions of previous estimates (152,132) —  (152,132)
Production (16,898) —  (16,898)
Sale of reserves-in-place —  —  — 
Purchases of reserves-in-place —  —  — 
December 31, 2020 99,508  —  99,508 
Proved developed reserves:
December 31, 2018 17,522  7  17,567 
December 31, 2019 30,699  —  30,699 
December 31, 2020 26,593  —  26,593 
Proved undeveloped reserves:
December 31, 2018 247,332  —  247,332 
December 31, 2019 237,839  —  237,839 
December 31, 2020 72,915  —  72,915 
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure
The following summary sets forth our future net cash flows relating to proved natural gas and condensate reserves based on the standardized measure (in thousands):
Year Ended December 31,
2020 2019 2018
Future cash inflows $ 132,563  $ 534,577  $ 676,454 
Future production costs (34,624) (102,268) (105,341)
Future development costs (71,557) (287,111) (264,239)
Future income tax provisions —  (6,612) (54,564)
Future net cash flows 26,382  138,586  252,310 
Less effect of a 10% discount factor (19,497) (85,415) (106,499)
Standardized measure of discounted future net cash flows $ 6,885  $ 53,171  $ 145,811 
The following table sets forth the changes in the standardized measure of discounted future net cash flows (in thousands):
December 31, 2017 $ 88,202 
Sales and transfers of gas and condensate produced, net of production costs (1,773)
Net changes in prices and production costs 27,530 
Extensions, discoveries, additions and improved recovery, net of related costs 13,334 
Development costs incurred 545 
Revisions of estimated development costs 9,663 
Revisions of previous quantity estimates 12,991 
Accretion of discount 11,112 
Net change in income taxes (9,472)
Purchases of reserves in place 844 
Sales of reserves in place — 
Changes in timing and other (7,165)
December 31, 2018 $ 145,811 
Sales and transfers of gas and condensate produced, net of production costs (21,704)
Net changes in prices and production costs (134,366)
Extensions, discoveries, additions and improved recovery, net of related costs 2,019 
Development costs incurred 23,485 
Revisions of estimated development costs 6,165 
Revisions of previous quantity estimates (12,660)
Accretion of discount 17,821 
Net change in income taxes 28,316 
Purchases of reserves in place — 
Sales of reserves in place — 
Changes in timing and other (1,716)
December 31, 2019 $ 53,171 
Sales and transfers of gas and condensate produced, net of production costs (20,211)
Net changes in prices and production costs (58,136)
Extensions, discoveries, additions and improved recovery, net of related costs — 
Development costs incurred — 
Revisions of estimated development costs — 
Revisions of previous quantity estimates 26,133 
Accretion of discount 5,725 
Net change in income taxes 4,077 
Purchases of reserves in place — 
Sales of reserves in place — 
Changes in timing and other (3,874)
December 31, 2020 $ 6,885