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Supplemental Oil And Gas Information | 12 Months Ended
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Dec. 31, 2020
Supplemental Oil And Gas Information [Abstract] |
Supplemental Oil And Gas Information | 14. Supplemental Oil and Gas Information (unaudited) ﻿ Information with respect to the Company’s oil and gas producing activities is presented in the following tables. Estimates of reserves quantities, as well as future production and discounted cash flows before income taxes, were determined by LaRoche Petroleum Consultants Ltd. All of the Company’s reserves were located in the United States. ﻿ Capitalized Costs Related to Oil and Gas Producing Activities ﻿ The table below reflects our capitalized costs related to our oil and gas producing activities at December 31, 2020 and 2019 (in thousands): ﻿ ﻿
﻿ |  |  |  |  |  |
﻿ |  |  |  |  |  |
﻿ |  | Years Ended December 31,
﻿ |  | 2020 |  | 2019
﻿Oil and gas properties |  | $ | 6,752 |  | $ | 6,751
﻿Ceiling test impairment |  | $ | (3,855) |  | $ | —
﻿Oil and gas properties, net of ceiling test impairment |  | $ | 2,897 |  | $ | 6,751
﻿ |  |  |  |  |  |
﻿Unevaluated properties |  |  | — |  |  | —
﻿ |  |  |  |  |  |
﻿Accumulated depreciation, depletion and amortization |  |  | (2,935) |  |  | (2,366)
﻿Ceiling test impairment |  |  | 2,935 |  |  | —
﻿Accumulated depreciation, depletion and amortization, net of ceiling test impairment |  |  | — |  |  | (2,366)
﻿ |  |  |  |  |  |
﻿Oil and gas properties, net |  | $ | 2,897 |  | $ | 4,385
﻿ Oil and Gas Related Costs ﻿ The following table sets forth information concerning costs incurred, including accruals, related to the Company’s oil and gas property acquisition, exploration and development activities (in thousands): ﻿ ﻿
﻿ |  |  |  |  |  |
﻿ |  |  |  |  |  |
﻿ |  | Years Ended December 31,
﻿ |  | 2020 |  | 2019
﻿Property acquisitions proved |  | $ | — |  | $ | —
﻿Property acquisitions unproved |  |  | 6 |  |  | 14
﻿Exploration cost |  |  | 1 |  |  | 491
﻿Development cost |  |  | 14 |  |  | 7
﻿Total |  | $ | 21 |  | $ | 512
Results of Operations from Oil and Gas Producing Activities ﻿ The following table sets forth the Company’s results of operations from oil and gas producing activities (in thousands): ﻿
﻿ |  |  |  |  |  |
﻿ |  |  |  |  |  |
﻿ |  | Years Ended December 31,
﻿ |  | 2020 |  | 2019
﻿Revenues |  | $ | 3,038 |  | $ | 4,911
﻿Production costs and taxes |  |  | (3,104) |  |  | (3,398)
﻿Depletion |  |  | (569) |  |  | (637)
﻿Income (loss) from oil and gas producing activities |  | $ | (635) |  | $ | 876
﻿ In the presentation above, no deduction has been made for indirect costs such as general corporate overhead or interest expense. No income taxes are reflected above due to the Company’s operating tax loss carry-forward position. ﻿ Estimated Quantities of Oil and Gas Reserves ﻿ The following table sets forth the Company’s net proved oil and gas reserves and the changes in net proved oil and gas reserves for the years ended December 31, 2018, 2019 and 2020. All of the Company’s proved reserves are located in the United States of America. ﻿
﻿ |  |  |  |  |  |
﻿ |  |  |  |  |  |
﻿ |  | Oil (MBbl) |  | Gas (MMcf) |  | MBOE
﻿Proved reserves at December 31, 2018 |  | 1,094 |  | — |  | 1,094
﻿Revisions of previous estimates |  | (203) |  | — |  | (203)
﻿Improved recovery |  | — |  | — |  | —
﻿Purchase of reserves in place |  | — |  | — |  | —
﻿Extensions and discoveries |  | 8 |  | — |  | 8
﻿Production |  | (94) |  | — |  | (94)
﻿Sales of reserves in place |  | (2) |  | — |  | (2)
﻿Proved reserves at December 31, 2019 |  | 803 |  | — |  | 803
﻿Revisions of previous estimates |  | (200) |  | — |  | (200)
﻿Improved recovery |  | — |  | — |  | —
﻿Purchase of reserves in place |  | — |  | — |  | —
﻿Extensions and discoveries |  | — |  | — |  | —
﻿Production |  | (86) |  | — |  | (86)
﻿Sales of reserves in place |  | — |  | — |  | —
﻿Proved reserves at December 31, 2020 |  | 517 |  | — |  | 517
﻿ |  |  |  |  |  |
﻿Proved developed reserves at: |  |  |  |  |  |
﻿December 31, 2018 |  | 976 |  | — |  | 976
﻿December 31, 2019 |  | 803 |  | — |  | 803
﻿December 31, 2020 |  | 517 |  | — |  | 517
﻿ |  |  |  |  |  |
﻿Proved undeveloped reserves at: |  |  |  |  |  |
﻿December 31, 2018 |  | 118 |  | — |  | 118
﻿December 31, 2019 |  | — |  | — |  | —
﻿December 31, 2020 |  | — |  | — |  | —
﻿ The Company’s Proved Undeveloped Reserves at December 31, 2018 included 7 locations and no locations at December 31, 2019 and 2020. During 2019, all Proved Undeveloped locations were removed from the Company’s Proved Reserves primarily due to the low oil prices experienced during 2019. The price remained low during 2020 resulting in the Company not being able to recognize any Proved Undeveloped locations at December 31, 2020. ﻿ The following table identifies the Company’s net proved reserve value by category and the respective present values, before income taxes, discounted at 10% as a percentage of total proved reserves (in thousands): ﻿ ﻿ ﻿
﻿ |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
﻿ |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
﻿ |  | Year Ended 12/31/2020 |  | Year Ended 12/31/2019 |  | Year Ended 12/31/2018
﻿ |  | Oil |  | Gas |  | Total |  | Oil |  | Gas |  | Total |  | Oil |  | Gas |  | Total
﻿Total proved reserves year-end reserve report |  | $ | 2,897 |  |  | — |  | $ | 2,897 |  | $ | 8,365 |  |  | — |  | $ | 8,365 |  | $ | 13,976 |  |  | — |  | $ | 13,976
﻿Proved developed producing reserves (PDP) |  | $ | 2,598 |  |  | — |  | $ | 2,598 |  | $ | 7,592 |  |  | — |  | $ | 7,592 |  | $ | 12,534 |  |  | — |  | $ | 12,534
﻿% of PDP reserves to total proved reserves |  |  | 90% |  |  | — |  |  | 90% |  |  | 91% |  |  | — |  |  | 91% |  |  | 90% |  |  | — |  |  | 90%
﻿Proved developed non- producing reserves |  | $ | 299 |  |  | — |  | $ | 299 |  | $ | 773 |  |  | — |  | $ | 773 |  | $ | 739 |  |  | — |  | $ | 739
﻿% of PDNP reserves to total proved reserves |  |  | 10% |  |  | — |  |  | 10% |  |  | 9% |  |  | — |  |  | 9% |  |  | 5% |  |  | — |  |  | 5%
﻿Proved undeveloped reserves (PUD) |  | $ | — |  |  | — |  | $ | — |  | $ | — |  |  | — |  | $ | — |  | $ | 703 |  |  | — |  | $ | 703
﻿% of PUD reserves to total proved reserves |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 5% |  |  | — |  |  | 5%
S tandardized Measure of Discounted Future Net Cash Flows ﻿ The standardized measure of discounted future net cash flows from the Company’s proved oil and gas reserves is presented in the following table (in thousands): ﻿ ﻿
﻿ |  |  |  |  |  |  |  |  |
﻿ |  |  |  |  |  |  |  |  |
﻿ |  | Years Ended December 31,
﻿ |  | 2020 |  | 2019 |  | 2018
﻿Future cash inflows |  | $ | 18,036 |  | $ | 40,655 |  | $ | 65,871
﻿Future production costs and taxes |  |  | (12,664) |  |  | (24,829) |  |  | (35,877)
﻿Future development costs |  |  | (538) |  |  | (542) |  |  | (2,833)
﻿Future income tax expenses |  |  | — |  |  | — |  |  | —
﻿Future net cash flows |  |  | 4,834 |  |  | 15,284 |  |  | 27,161
﻿ |  |  |  |  |  |  |  |  |
﻿Discount at 10% for timing of cash flows |  |  | (1,937) |  |  | (6,919) |  |  | (13,185)
﻿Standardized measure of discounted future net cash flows |  | $ | 2,897 |  | $ | 8,365 |  | $ | 13,976
﻿ The following are the principal sources of change in the standardized measure of discounted future net cash flows from the Company’s proved oil and gas reserves (in thousands): ﻿ ﻿
﻿ |  |  |  |  |  |  |  |  |
﻿ |  |  |  |  |  |  |  |  |
﻿ |  | Years Ended December 31,
﻿ |  | 2020 |  | 2019 |  | 2018
﻿Balance, beginning of year |  | $ | 8,365 |  | $ | 13,976 |  | $ | 8,170
﻿Sales, net of production costs and taxes |  |  | (210) |  |  | (1,646) |  |  | (2,611)
﻿Discoveries and extensions, net of costs |  |  | — |  |  | 154 |  |  | 798
﻿Purchase of reserves in place |  |  | — |  |  | — |  |  | 143
﻿Sale of reserves in place |  |  | — |  |  | (26) |  |  | —
﻿Net changes in prices and production costs |  |  | (2,893) |  |  | (3,348) |  |  | 4,304
﻿Revisions of quantity estimates |  |  | (2,353) |  |  | (3,058) |  |  | 2,180
﻿Previously estimated development cost incurred during the year |  |  | — |  |  | — |  |  | 210
﻿Changes in future development costs |  |  | (314) |  |  | 1,016 |  |  | 78
﻿Changes in timing and other |  |  | (389) |  |  | 86 |  |  | (4)
﻿Accretion of discount |  |  | 691 |  |  | 1,211 |  |  | 708
﻿Net change in income taxes |  |  | — |  |  | — |  |  | —
﻿Balance, end of year |  | $ | 2,897 |  | $ | 8,365 |  | $ | 13,976
﻿ Estimated future net cash flows represent an estimate of future net revenues from the production of proved reserves using average sales prices along with estimates of the operating costs, production taxes and future development and abandonment cost (less salvage value) necessary to produce such reserves. Future income taxes were calculated by applying the statutory federal and state income tax rates to pre-tax future net cash flows, net of the tax basis of the properties and utilizing available tax loss carryforwards related to oil and gas operations. The oil prices used for December 31, 2020, 2019, and 2018 were $34.87, and $50.65, and $60.21 per barrel of oil, respectively. The Company’s proved reserves as of December 31, 2020, 2019 and 2018 were measured by using commodity prices based on the twelve month unweighted arithmetic average of the first day of the month price for the period January through December. No deduction has been made for depreciation, depletion, or any indirect cost such as general corporate overhead or interest expense.

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