Everflow Eastern Partners 10-K 25 Mar 21 2020 FY Annual report Financial data

Document And Entity Information

Document And Entity Information - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Mar. 10, 2021	Jun. 30, 2020
Document Information [Line Items]
Entity Registrant Name	EVERFLOW EASTERN PARTNERS LP
Entity Central Index Key	0000868082
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	No
Entity Emerging Growth Company	false
Entity Small Business	true
Entity Interactive Data Current	Yes
Entity Common Stock, Shares Outstanding (in shares)		5,441,928
Entity Public Float			$ 0
Entity Shell Company	false
Document Type	10-K
Document Period End Date	Dec. 31, 2020
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	FY
Amendment Flag	false
Title of 12(g) Security	Units of Limited Partnership Interest

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($)	Dec. 31, 2020	Dec. 31, 2019
CURRENT ASSETS
Cash and equivalents	$ 10,249,207	$ 11,757,057
Investments	20,372,652	20,107,580
Production accounts receivable	815,419	1,208,634
Other	79,950	8,150
Total current assets	31,517,228	33,081,421
PROPERTY AND EQUIPMENT
Proved properties (successful efforts accounting method)	142,912,812	174,633,910
Pipeline and support equipment	719,988	791,756
Corporate and other	2,093,989	2,090,250
Gross property and equipment	145,726,789	177,515,916
Less accumulated depreciation, depletion, amortization and write down	138,424,885	168,720,741
Net property and equipment	7,301,904	8,795,175
OTHER ASSETS	131,863	131,624
TOTAL ASSETS	38,950,995	42,008,220
CURRENT LIABILITIES
Accounts payable	2,470,720	2,136,590
Accrued expenses	1,575,935	1,425,492
Total current liabilities	4,046,655	3,562,082
DEFERRED INCOME TAXES	27,900	45,700
OPERATIONAL ADVANCES	2,653,099	2,463,685
ASSET RETIREMENT OBLIGATIONS	14,564,400	16,640,632
COMMITMENTS AND CONTINGENCIES
LIMITED PARTNERS' EQUITY, SUBJECT TO REPURCHASE RIGHT
Authorized - 8,000,000 Units Issued and outstanding - 5,441,928 and 5,492,967 Units, respectively	17,442,684	19,063,258
GENERAL PARTNER'S EQUITY	216,257	232,863
Total partners' equity	17,658,941	19,296,121
TOTAL LIABILITIES AND PARTNERS' EQUITY	$ 38,950,995	$ 42,008,220

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parentheticals) - shares	Dec. 31, 2020	Dec. 31, 2019
Limited partner's equity, units authorized (in shares)	8,000,000	8,000,000
Limited partner's equity, units issued (in shares)	5,441,928	5,492,967
Limited partner's equity, units outstanding (in shares)	5,441,928	5,492,967

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
REVENUES
Total revenues	$ 3,824,550	$ 7,844,912
DIRECT COST OF REVENUES
Production costs	1,955,265	2,612,507
Well management and operating	244,474	321,004
Depreciation, depletion and amortization	970,115	600,180
Accretion expense	243,468	273,023
Total direct cost of revenues	3,413,322	3,806,714
GENERAL AND ADMINISTRATIVE EXPENSE	2,024,011	2,267,337
Total cost of revenues	5,437,333	6,074,051
INCOME (LOSS) FROM OPERATIONS	(1,612,783)	1,770,861
OTHER INCOME
Investment income	273,419	590,333
Gain on disposal of property and equipment	1,067,994	27,775
Total other income	1,341,413	618,108
INCOME (LOSS) BEFORE INCOME TAXES	(271,370)	2,388,969
INCOME TAX EXPENSE (BENEFIT)
Current	(50,300)	28,292
Deferred	(17,800)	5,000
Total income tax expense (benefit)	(68,100)	33,292
NET INCOME (LOSS)	(203,270)	2,355,677
Allocation of Partnership Net Income (Loss):
Limited Partners	(200,806)	2,327,392
General Partner	(2,464)	28,285
Net income (loss)	$ (203,270)	$ 2,355,677
Net income (loss) per unit (in dollars per share)	$ (0.04)	$ 0.42
Oil and Gas [Member]
REVENUES
Total revenues	$ 3,413,680	$ 7,298,279
Oil and Gas Service [Member]
REVENUES
Total revenues	405,560	538,401
Product and Service, Other [Member]
REVENUES
Total revenues	$ 5,310	$ 8,232

Consolidated Statements of Part

Consolidated Statements of Partners' Equity	USD ($)
PARTNERS' EQUITY – BEGINNING OF YEAR at Dec. 31, 2018	$ 18,709,962
Net income (loss)	2,355,677
Cash distributions ($0.25 per unit in 2020 and $0.30 per unit in 2019)	(1,684,936)
Repurchase of Units	(129,582)
Options exercised	45,000
PARTNERS' EQUITY – END OF YEAR at Dec. 31, 2019	19,296,121
Net income (loss)	(203,270)
Cash distributions ($0.25 per unit in 2020 and $0.30 per unit in 2019)	(1,390,016)
Repurchase of Units	(69,694)
Options exercised	25,800
PARTNERS' EQUITY – END OF YEAR at Dec. 31, 2020	$ 17,658,941

Consolidated Statements of Pa_2

Consolidated Statements of Partners' Equity (Parentheticals) - $ / shares	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Cash distribution per unit (in dollars per share)	$ 0.25	$ 0.30

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	$ (203,270)	$ 2,355,677
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	1,043,892	677,256
Accretion expense	243,468	273,023
Unrealized gain on investments	(403)	(69,208)
Gain on disposal of property and equipment	(1,067,994)	(27,775)
Deferred income taxes	(17,800)	5,000
Changes in assets and liabilities:
Production accounts receivable	393,215	453,035
Other current assets	(71,800)	56,531
Other assets	(239)	(5,828)
Accounts payable	(31,422)	266,705
Accrued expenses	(130,709)	(93,262)
Operational advances	189,414	328,053
Total adjustments	549,622	1,863,530
Net cash provided by operating activities	346,352	4,219,207
CASH FLOWS FROM INVESTING ACTIVITIES
Purchase of investments	(264,669)	(2,974,236)
Purchase of property and equipment	(117,890)	(323,903)
Proceeds from disposal of property and equipment	104,269	38,639
Settlement of disposal of property and equipment	(468,934)
Net cash used in investing activities	(747,224)	(3,259,500)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from loan	326,932
Distributions	(1,390,016)	(1,684,936)
Repurchase of Units	(69,694)	(129,582)
Proceeds from options exercised	25,800	45,000
Net cash used in financing activities	(1,106,978)	(1,769,518)
NET CHANGE IN CASH AND EQUIVALENTS	(1,507,850)	(809,811)
CASH AND EQUIVALENTS AT BEGINNING OF YEAR	11,757,057	12,566,868
CASH AND EQUIVALENTS AT END OF YEAR	10,249,207	11,757,057
Supplemental disclosures of cash flow information:
Cash paid during the year for income taxes	$ 22,949	$ 40,215

Note 1 - Organization and Summa

Note 1 - Organization and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Organization, Consolidation and Presentation of Financial Statements Disclosure and Significant Accounting Policies [Text Block]	Note 1. Organization and Summary of Significant Accounting Policies A. Organization and Principles of Consolidation – Everflow Eastern Partners, L.P. ("Everflow") is a Delaware limited partnership which was organized in September 1990 Everflow Management Limited, LLC ("EML"), an Ohio limited liability company, is the general partner of Everflow and, as such, is authorized to perform all acts necessary or desirable to carry out the purposes and conduct of the business of Everflow. The members of EML include Everflow Management Corporation ("EMC"); two one one September 1990 no no The consolidated financial statements include the accounts of Everflow, its wholly-owned subsidiaries, including EEI, and interests with joint venture partners (collectively, the "Company"), which are accounted for under the proportional consolidation method. All significant accounts and transactions between the consolidated entities have been eliminated. B. Use of Estimates – The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America ("generally accepted accounting principles" or "GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Significant estimates impacting the Company's financial statements include revenue and expense accruals and oil and gas reserve quantities. In the oil and gas industry, and especially as related to the Company's natural gas sales, the processing of actual transactions generally occurs 60 90 C. Fair Value of Financial Instruments – The fair values of cash and equivalents, accounts receivable, accounts payable and other short-term obligations approximate their carrying values because of the short maturity of these financial instruments. The carrying values of the Company's long-term obligations approximate their fair value because they are considered to be at current market rates. In accordance with generally accepted accounting principles, rates available to the Company at the balance sheet dates are used to estimate the fair value of existing obligations. D. Cash and Equivalents – The Company considers all highly liquid debt instruments purchased with an original maturity of three may may, $2,653,099 $2,463,685 December 31, 2020 2019, $720,200 $390,000 December 31, 2020 2019, E. Investments – The Company's investments are classified as available-for-sale securities and consist of shares held in a mutual fund that invests primarily in investment grade, U.S. dollar denominated short-term fixed and floating rate debt securities. The mutual fund seeks current income while seeking to maintain a low volatility of principal. The Financial Accounting Standards Board established a framework for measuring fair value and expands disclosures about fair value measurements by establishing a fair value hierarchy that prioritizes the inputs and defines valuation techniques used to measure fair value. The hierarchy gives highest priority to Level I inputs and lowest priority to Level III inputs. The three Level I – Quoted prices are available in active markets for identical financial instruments as of the reporting date. Level II – Pricing inputs are other than quoted prices in active markets, which are either directly or indirectly observable as of the reporting date, and fair value is determined through the use of models or other valuation methodologies. Level III – Pricing inputs are unobservable for the financial instrument and include situations where there is little, if any, market activity for the financial instrument. The inputs into the determination of fair value require significant management judgment or estimation. The Company's investments are carried at fair market value based on quoted prices available in active markets and are therefore classified as Level I. F. Property and Equipment – The Company uses the successful efforts method of accounting for oil and gas exploration and production activities. Under successful efforts, costs to acquire mineral interests in oil and gas properties, to drill and equip development wells and related asset retirement costs are capitalized. Costs of development wells (on properties the Company has no not not no Capitalized costs of proved properties, after considering estimated dismantlement and abandonment costs and estimated salvage values, are amortized by the unit-of-production method based upon estimated proved developed reserves. Depletion, depreciation and amortization on proved properties amounted to $903,226 $553,953 2020 2019, On sale or retirement of a unit of a proved property (which generally constitutes the amortization base), the cost and related accumulated depreciation, depletion, amortization and write down are eliminated from the property accounts, and the resultant gain or loss is recognized. Generally accepted accounting principles require that long-lived assets (including oil and gas properties) and certain identifiable intangibles be reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not not not 2020 2019. Pipeline and support equipment and other corporate property and equipment are recorded at cost and depreciated principally on the straight-line method over their estimated useful lives (pipeline and support equipment - 10 15 3 7 39 40 $66,889 $46,227 December 31, 2020 2019, $73,777 $77,076 December 31, 2020 2019, Maintenance and repairs of property and equipment are expensed as incurred. Major renewals and improvements are capitalized, and the assets replaced are retired. G. Asset Retirement Obligations – Generally accepted accounting principles require the fair value of a liability for an asset retirement obligation to be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. For the Company, these obligations include dismantlement, plugging and abandonment of crude oil and natural gas wells and associated pipelines and equipment. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset. The liability is accreted to its then present value each period, and the capitalized cost is depleted over the estimated useful life of the related asset. The estimated liability is based on historical experience in dismantling, plugging and abandoning wells, estimated remaining lives of those wells based on reserves estimates, estimates of the external cost to dismantle, plug and abandon the wells in the future and federal and state regulatory requirements. The liability is discounted using an assumed credit-adjusted risk-free interest rate. Revisions to the liability will likely occur due to: changes in estimates of dismantlement, plugging and abandonment costs, changes in estimated remaining lives of the wells, changes in federal or state regulations regarding plugging and abandonment requirements, and other factors. Gain on disposal of property and equipment includes approximately $1,009,200 2020. The schedule below is a reconciliation of the Company's liability for the years ended December 31: 2020 2019 Beginning of period $ 17,221,632 $ 17,003,486 Liabilities incurred 2,860 3,745 Liabilities settled (2,472,560 ) (58,622 ) Accretion expense 243,468 273,023 End of period $ 14,995,400 $ 17,221,632 H. Revenue Recognition – Revenues from contracts with customers are recognized when performance obligations are satisfied in accordance with contractual terms. For the sale of crude oil and natural gas from operated properties, the Company generally considers each unit (BBL or MCF) to be a separate performance obligation. The transaction price may Crude oil and natural gas sales derived from third Crude oil and natural gas sales represent the Company's share of revenues, net of royalties and other revenue interests owned by other parties. When settling crude oil and natural gas 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. Based on the Company's judgment, the Company's performance obligations have been satisfied and an unconditional right to consideration exists at December 31, 2020 2019, December 31, 2020 2019, The Company utilizes the sales method to account for gas production volume imbalances. Under this method, revenue is recognized only when gas is produced and sold on the Company's behalf. The Company had no December 31, 2020 2019. The Company frequently participates (and may no I. Income Taxes – Everflow is not not EEI accounts for income taxes under generally accepted accounting principles, which require income taxes be provided for all items (as they relate to EEI) in the consolidated statements of operations regardless of the period when such items are reported for income tax purposes. Therefore, deferred tax assets and liabilities are recognized for temporary differences between the financial reporting basis and tax basis of certain EEI assets and liabilities. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which the temporary differences are expected to be recovered or settled. The impact on deferred taxes of changes in tax rates and laws, if any, is reflected in the financial statements in the period of enactment. Items giving rise to deferred taxes consist primarily of temporary differences arising from differences in financial reporting and tax reporting methods for EEI's proved properties and percentage depletion credits. The Company believes that it has appropriate support for any tax positions taken and, as such, does not J. Allocation of Income and Per Unit Data – Under the terms of the limited partnership agreement, initially 99% 1% may 3 Net income (loss) per limited partner Unit have been computed based on the weighted average number of Units outstanding during each year presented. K. Subsequent Event – In March 2021, third 34 $560,000 L. New Accounting Standards – In June 2016, 2016 13, 2016 13” 2016 13 2016 13 not 2016 13 December 15, 2019, 2016 13 January 1, 2020 no The Company has reviewed all other recently issued accounting standards in order to determine their effects, if any, on the consolidated financial statements. Based on that review, the Company believes that none M. Reclassifications – Certain prior period amounts have been reclassified to conform with the current period's presentation.

Note 2 - Current Liabilities

Note 2 - Current Liabilities	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Accounts Payable and Accrued Liabilities Disclosure [Text Block]	Note 2. Current Liabilities The Company's accounts payable and accrued expenses consist of the following at December 31: 2020 2019 Accounts Payable: Production and related other $ 1,638,704 $ 1,768,723 Property and equipment disposal 468,934 - Other 300,440 304,488 Joint venture partner deposits 62,642 63,379 Total accounts payable $ 2,470,720 $ 2,136,590 Accrued Expenses: Payroll and retirement plan contributions $ 652,530 $ 651,856 Current portion of asset retirement obligations 431,000 581,000 Paycheck Protection Program loan 326,932 - Drilling 96,419 96,419 Federal, state and local taxes 36,154 35,917 Other 32,900 60,300 Total accrued expenses $ 1,575,935 $ 1,425,492 In March 2020, June 2020. April 2020, $326,932 January 2021. February 2021, Disposals of property and equipment reflect changes to accounts payable.

Note 3 - Partners' Equity

Note 3 - Partners' Equity	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Partners' Capital Notes Disclosure [Text Block]	Note 3. Partners' Equity Units represent limited partnership interests in Everflow. The Units are transferable subject only to the approval of any transfer by EML and to the laws governing the transfer of securities. The Units are not may The partnership agreement provides that Everflow will repurchase for cash up to 10% May 1 June 30 December 31 66% 10% 2021 December 31, 2020 $0.36 In June 2020, 81,039 $0.86 June 2019, 86,388 $1.50 June 2018, 68,261 $0.11 The Company has an Option Repurchase Plan (the "Option Plan") which permits the grant of options to repurchase certain Units to select officers and employees (the "Option Plan Participants"). The purpose of the Option Plan is to assist the Company in attracting and retaining officers and other key employees and to enable those individuals to acquire or increase their ownership interest in the Company in order to encourage them to promote the growth and profitability of the Company. The Option Plan is designed to align directly the financial interests of the Option Plan Participants with the financial interests of the Unitholders. The Company granted 30,000 June 2020, 2019 2018, All Units repurchased pursuant to the Repurchase Right are retired except for those Units issued through the exercise of options pursuant to the Option Plan. There were 5,441,928, 5,492,967 5,549,355 June 2020, 2019 2018, no December 31, 2020 2019

Note 4 - Retirement Plan

Note 4 - Retirement Plan	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Retirement Benefits [Text Block]	Note 4. Retirement Plan The Company has a defined contribution plan pursuant to Section 401 $187,300 $190,900 December 31, 2020 2019,

Note 5 - Business Segments, Ris

Note 5 - Business Segments, Risks and Major Customers	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Segment Reporting Disclosure [Text Block]	Note 5. Business Segments, Risks and Major Customers The Company operates exclusively in Ohio and Pennsylvania of the United States in the acquisition, exploration, development and production of oil and gas. The Company operates in an environment with many financial risks, including, but not may Management of the Company continually evaluates whether the Company can develop oil and gas properties at historical levels given current industry and market conditions. If the Company is unable to do so, it could be determined that it is in the best interests of the Company and its Unitholders to reorganize, liquidate or sell the Company. However, management cannot predict whether any sale transaction will be a viable alternative for the Company in the immediate future. Natural gas sales accounted for 64% 69% 2020 2019, 80% 79% 2020 2019, one December 31, 2020 2019 45% 50% 2020 2019, As of December 31, 2020, 570 70% 71% 2020 2019, The Company sells substantially all its crude oil production from operated wells to one The Company's production accounts receivable result from sales of natural gas and crude oil. A significant portion of the Company's production accounts receivable is due from the Company's major customers. The Company does not not not December 31, 2020 2019. 2021. not third may

Note 6 - Commitments and Contin

Note 6 - Commitments and Contingencies	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Commitments and Contingencies Disclosure [Text Block]	Note 6. Commitments and Contingencies The Company has multiple contracts with the Major Gas Purchaser which obligate the Major Gas Purchaser to purchase, and the Company to sell and deliver, certain quantities of natural gas production from the Company's oil and gas properties throughout the contract periods. Management believes the Company can meet its delivery commitments based on estimated production. The Company is party to various legal proceedings and claims in the ordinary course of its business and believes the outcome of such matters will not In March 2020, 19” 19 19.

Note 7 - Supplemental Informati

Note 7 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited)	12 Months Ended
	Dec. 31, 2020
Notes to Financial Statements
Oil and Gas Exploration and Production Industries Disclosures [Text Block]	Note 7. Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) The following supplemental unaudited oil and gas information is required by generally accepted accounting principles. The tables on the following pages set forth pertinent data with respect to the Company's oil and gas properties, all of which are located within the continental United States. CAPITALIZED COSTS RELATING TO OIL AND GAS PRODUCING ACTIVITIES Years ended December 31, 2020 2019 Proved oil and gas properties $ 142,912,812 $ 174,633,910 Pipeline and support equipment 719,988 791,756 Gross capitalized costs 143,632,800 175,425,666 Accumulated depreciation, depletion, amortization and write down 137,211,641 167,541,207 Net capitalized costs $ 6,421,159 $ 7,884,459 COSTS INCURRED IN OIL AND GAS PRODUCING ACTIVITIES Years ended December 31, 2020 2019 Property acquisition costs $ - $ 23,018 Development costs - 125,071 The Company had no 2020 2019. RESULTS OF OPERATIONS FOR OIL AND GAS PRODUCING ACTIVITIES Years ended December 31, 2020 2019 Crude oil and natural gas sales $ 3,413,680 $ 7,298,279 Production costs (1,955,265 ) (2,612,507 ) Depreciation, depletion and amortization (970,115 ) (600,180 ) Accretion expense (243,468 ) (273,023 ) Results of operations before income tax expense (benefit) 244,832 3,812,569 Income tax expense (benefit) (70,000 ) 30,000 Results of operations for oil and gas producing activities (excluding corporate overhead and financing costs) $ 314,832 $ 3,782,569 Income tax expense (benefit) was computed using statutory tax rates and reflects permanent differences that are reflected in the Company's consolidated income tax expense (benefit) for the year. ESTIMATED QUANTITIES OF PROVED OIL AND GAS RESERVES Oil Gas (BBLS) (MCF) Balance, January 1, 2019 386,000 16,358,000 Extensions, discoveries and other additions 20,000 95,000 Production (42,000 ) (1,840,000 ) Revision of previous estimates (35,000 ) (1,578,000 ) Balance, December 31, 2019 329,000 13,035,000 Production (31,000 ) (1,185,000 ) Revision of previous estimates (63,000 ) (6,100,000 ) Balance, December 31, 2020 235,000 5,750,000 The Company has not 100 December 31, 2020 2019, $33,300 December 31, 2020 2019, STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS December 31, 2020 2019 (Thousands of Dollars) Future cash inflows from sales of oil and gas $ 16,918 $ 45,488 Future production and development costs (11,227 ) (26,931 ) Future asset retirement obligations, net of salvage (13,879 ) (15,828 ) Future income tax expense (42 ) (170 ) Future net cash flows (8,230 ) 2,559 Effect of discounting future net cash flows at 10% per annum (334 ) (5,061 ) Standardized measure of discounted future net cash flows $ (8,564 ) $ (2,502 ) CHANGES IN THE STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS Years Ended December 31, 2020 2019 (Thousands of Dollars) Balance, beginning of year $ (2,502 ) $ 4,444 Extensions, discoveries and other additions - 551 Revision of quantity estimates (1,337 ) (1,650 ) Sales of crude oil and natural gas, net of production costs (1,458 ) (4,686 ) Net change in income taxes 79 88 Net changes in prices and production costs (7,748 ) (5,161 ) Accretion of discount (250 ) 444 Other 4,652 3,468 Balance, end of year $ (8,564 ) $ (2,502 ) There are numerous uncertainties inherent in estimating quantities of proved reserves and in projecting future rates of production and timing of development expenditures, including many factors beyond the control of the Company. The estimated future cash flows are determined based on crude oil and natural gas pricing parameters established by generally accepted accounting principles, adjusted for contract terms within contract periods, estimated production of proved crude oil and natural gas reserves, estimated future production and development costs of reserves and future retirement obligations (net of salvage), based on current economic conditions, and the estimated future income tax expense, based on year-end statutory tax rates (with consideration of future tax rates already legislated) to be incurred on pretax net cash flows less the tax basis of the properties involved. Such cash flows are then discounted using a 10% The methodology and assumptions used in calculating the standardized measure are those required by generally accepted accounting principles and United States Securities and Exchange Commission reporting requirements. It is not not Average adjusted natural gas prices used in the estimation of proved reserves were $1.46 $2.17 December 31, 2020 2019, $36.30 $52.14 December 31, 2020 2019,

Significant Accounting Policies

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2020
Accounting Policies [Abstract]
Organization Principles of Consolidation [Policy Text Block]	A. Organization and Principles of Consolidation – Everflow Eastern Partners, L.P. ("Everflow") is a Delaware limited partnership which was organized in September 1990 Everflow Management Limited, LLC ("EML"), an Ohio limited liability company, is the general partner of Everflow and, as such, is authorized to perform all acts necessary or desirable to carry out the purposes and conduct of the business of Everflow. The members of EML include Everflow Management Corporation ("EMC"); two one one September 1990 no no The consolidated financial statements include the accounts of Everflow, its wholly-owned subsidiaries, including EEI, and interests with joint venture partners (collectively, the "Company"), which are accounted for under the proportional consolidation method. All significant accounts and transactions between the consolidated entities have been eliminated.
Use of Estimates, Policy [Policy Text Block]	B. Use of Estimates – The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America ("generally accepted accounting principles" or "GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Significant estimates impacting the Company's financial statements include revenue and expense accruals and oil and gas reserve quantities. In the oil and gas industry, and especially as related to the Company's natural gas sales, the processing of actual transactions generally occurs 60 90
Fair Value of Financial Instruments, Policy [Policy Text Block]	C. Fair Value of Financial Instruments – The fair values of cash and equivalents, accounts receivable, accounts payable and other short-term obligations approximate their carrying values because of the short maturity of these financial instruments. The carrying values of the Company's long-term obligations approximate their fair value because they are considered to be at current market rates. In accordance with generally accepted accounting principles, rates available to the Company at the balance sheet dates are used to estimate the fair value of existing obligations.
Cash and Cash Equivalents, Policy [Policy Text Block]	D. Cash and Equivalents – The Company considers all highly liquid debt instruments purchased with an original maturity of three may may, $2,653,099 $2,463,685 December 31, 2020 2019, $720,200 $390,000 December 31, 2020 2019,
Investment, Policy [Policy Text Block]	E. Investments – The Company's investments are classified as available-for-sale securities and consist of shares held in a mutual fund that invests primarily in investment grade, U.S. dollar denominated short-term fixed and floating rate debt securities. The mutual fund seeks current income while seeking to maintain a low volatility of principal. The Financial Accounting Standards Board established a framework for measuring fair value and expands disclosures about fair value measurements by establishing a fair value hierarchy that prioritizes the inputs and defines valuation techniques used to measure fair value. The hierarchy gives highest priority to Level I inputs and lowest priority to Level III inputs. The three Level I – Quoted prices are available in active markets for identical financial instruments as of the reporting date. Level II – Pricing inputs are other than quoted prices in active markets, which are either directly or indirectly observable as of the reporting date, and fair value is determined through the use of models or other valuation methodologies. Level III – Pricing inputs are unobservable for the financial instrument and include situations where there is little, if any, market activity for the financial instrument. The inputs into the determination of fair value require significant management judgment or estimation. The Company's investments are carried at fair market value based on quoted prices available in active markets and are therefore classified as Level I.
Property, Plant and Equipment, Policy [Policy Text Block]	F. Property and Equipment – The Company uses the successful efforts method of accounting for oil and gas exploration and production activities. Under successful efforts, costs to acquire mineral interests in oil and gas properties, to drill and equip development wells and related asset retirement costs are capitalized. Costs of development wells (on properties the Company has no not not no Capitalized costs of proved properties, after considering estimated dismantlement and abandonment costs and estimated salvage values, are amortized by the unit-of-production method based upon estimated proved developed reserves. Depletion, depreciation and amortization on proved properties amounted to $903,226 $553,953 2020 2019, On sale or retirement of a unit of a proved property (which generally constitutes the amortization base), the cost and related accumulated depreciation, depletion, amortization and write down are eliminated from the property accounts, and the resultant gain or loss is recognized. Generally accepted accounting principles require that long-lived assets (including oil and gas properties) and certain identifiable intangibles be reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not not not 2020 2019. Pipeline and support equipment and other corporate property and equipment are recorded at cost and depreciated principally on the straight-line method over their estimated useful lives (pipeline and support equipment - 10 15 3 7 39 40 $66,889 $46,227 December 31, 2020 2019, $73,777 $77,076 December 31, 2020 2019, Maintenance and repairs of property and equipment are expensed as incurred. Major renewals and improvements are capitalized, and the assets replaced are retired.
Asset Retirement Obligation [Policy Text Block]	G. Asset Retirement Obligations – Generally accepted accounting principles require the fair value of a liability for an asset retirement obligation to be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. For the Company, these obligations include dismantlement, plugging and abandonment of crude oil and natural gas wells and associated pipelines and equipment. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset. The liability is accreted to its then present value each period, and the capitalized cost is depleted over the estimated useful life of the related asset. The estimated liability is based on historical experience in dismantling, plugging and abandoning wells, estimated remaining lives of those wells based on reserves estimates, estimates of the external cost to dismantle, plug and abandon the wells in the future and federal and state regulatory requirements. The liability is discounted using an assumed credit-adjusted risk-free interest rate. Revisions to the liability will likely occur due to: changes in estimates of dismantlement, plugging and abandonment costs, changes in estimated remaining lives of the wells, changes in federal or state regulations regarding plugging and abandonment requirements, and other factors. Gain on disposal of property and equipment includes approximately $1,009,200 2020. The schedule below is a reconciliation of the Company's liability for the years ended December 31: 2020 2019 Beginning of period $ 17,221,632 $ 17,003,486 Liabilities incurred 2,860 3,745 Liabilities settled (2,472,560 ) (58,622 ) Accretion expense 243,468 273,023 End of period $ 14,995,400 $ 17,221,632
Revenue from Contract with Customer [Policy Text Block]	H. Revenue Recognition – Revenues from contracts with customers are recognized when performance obligations are satisfied in accordance with contractual terms. For the sale of crude oil and natural gas from operated properties, the Company generally considers each unit (BBL or MCF) to be a separate performance obligation. The transaction price may Crude oil and natural gas sales derived from third Crude oil and natural gas sales represent the Company's share of revenues, net of royalties and other revenue interests owned by other parties. When settling crude oil and natural gas 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. Based on the Company's judgment, the Company's performance obligations have been satisfied and an unconditional right to consideration exists at December 31, 2020 2019, December 31, 2020 2019, The Company utilizes the sales method to account for gas production volume imbalances. Under this method, revenue is recognized only when gas is produced and sold on the Company's behalf. The Company had no December 31, 2020 2019. The Company frequently participates (and may no
Income Tax, Policy [Policy Text Block]	I. Income Taxes – Everflow is not not EEI accounts for income taxes under generally accepted accounting principles, which require income taxes be provided for all items (as they relate to EEI) in the consolidated statements of operations regardless of the period when such items are reported for income tax purposes. Therefore, deferred tax assets and liabilities are recognized for temporary differences between the financial reporting basis and tax basis of certain EEI assets and liabilities. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which the temporary differences are expected to be recovered or settled. The impact on deferred taxes of changes in tax rates and laws, if any, is reflected in the financial statements in the period of enactment. Items giving rise to deferred taxes consist primarily of temporary differences arising from differences in financial reporting and tax reporting methods for EEI's proved properties and percentage depletion credits. The Company believes that it has appropriate support for any tax positions taken and, as such, does not
Earnings Per Share, Policy [Policy Text Block]	J. Allocation of Income and Per Unit Data – Under the terms of the limited partnership agreement, initially 99% 1% may 3 Net income (loss) per limited partner Unit have been computed based on the weighted average number of Units outstanding during each year presented.
Subsequent Events, Policy [Policy Text Block]	K. Subsequent Event – In March 2021, third 34 $560,000
New Accounting Pronouncements, Policy [Policy Text Block]	L. New Accounting Standards – In June 2016, 2016 13, 2016 13” 2016 13 2016 13 not 2016 13 December 15, 2019, 2016 13 January 1, 2020 no The Company has reviewed all other recently issued accounting standards in order to determine their effects, if any, on the consolidated financial statements. Based on that review, the Company believes that none
Reclassification, Comparability Adjustment [Policy Text Block]	M. Reclassifications – Certain prior period amounts have been reclassified to conform with the current period's presentation.

Note 1 - Organization and Sum_2

Note 1 - Organization and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2020
Notes Tables
Schedule of Asset Retirement Obligations [Table Text Block]	2020 2019 Beginning of period $ 17,221,632 $ 17,003,486 Liabilities incurred 2,860 3,745 Liabilities settled (2,472,560 ) (58,622 ) Accretion expense 243,468 273,023 End of period $ 14,995,400 $ 17,221,632

Note 2 - Current Liabilities (T

Note 2 - Current Liabilities (Tables)	12 Months Ended
	Dec. 31, 2020
Notes Tables
Schedule of Accounts Payable and Accrued Liabilities [Table Text Block]	2020 2019 Accounts Payable: Production and related other $ 1,638,704 $ 1,768,723 Property and equipment disposal 468,934 - Other 300,440 304,488 Joint venture partner deposits 62,642 63,379 Total accounts payable $ 2,470,720 $ 2,136,590 Accrued Expenses: Payroll and retirement plan contributions $ 652,530 $ 651,856 Current portion of asset retirement obligations 431,000 581,000 Paycheck Protection Program loan 326,932 - Drilling 96,419 96,419 Federal, state and local taxes 36,154 35,917 Other 32,900 60,300 Total accrued expenses $ 1,575,935 $ 1,425,492

Note 7 - Supplemental Informa_2

Note 7 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2020
Notes Tables
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]	CAPITALIZED COSTS RELATING TO OIL AND GAS PRODUCING ACTIVITIES Years ended December 31, 2020 2019 Proved oil and gas properties $ 142,912,812 $ 174,633,910 Pipeline and support equipment 719,988 791,756 Gross capitalized costs 143,632,800 175,425,666 Accumulated depreciation, depletion, amortization and write down 137,211,641 167,541,207 Net capitalized costs $ 6,421,159 $ 7,884,459
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure [Table Text Block]	COSTS INCURRED IN OIL AND GAS PRODUCING ACTIVITIES Years ended December 31, 2020 2019 Property acquisition costs $ - $ 23,018 Development costs - 125,071
Results of Operations for Oil and Gas Producing Activities Disclosure [Table Text Block]	RESULTS OF OPERATIONS FOR OIL AND GAS PRODUCING ACTIVITIES Years ended December 31, 2020 2019 Crude oil and natural gas sales $ 3,413,680 $ 7,298,279 Production costs (1,955,265 ) (2,612,507 ) Depreciation, depletion and amortization (970,115 ) (600,180 ) Accretion expense (243,468 ) (273,023 ) Results of operations before income tax expense (benefit) 244,832 3,812,569 Income tax expense (benefit) (70,000 ) 30,000 Results of operations for oil and gas producing activities (excluding corporate overhead and financing costs) $ 314,832 $ 3,782,569
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Table Text Block]	ESTIMATED QUANTITIES OF PROVED OIL AND GAS RESERVES Oil Gas (BBLS) (MCF) Balance, January 1, 2019 386,000 16,358,000 Extensions, discoveries and other additions 20,000 95,000 Production (42,000 ) (1,840,000 ) Revision of previous estimates (35,000 ) (1,578,000 ) Balance, December 31, 2019 329,000 13,035,000 Production (31,000 ) (1,185,000 ) Revision of previous estimates (63,000 ) (6,100,000 ) Balance, December 31, 2020 235,000 5,750,000
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure [Table Text Block]	STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS December 31, 2020 2019 (Thousands of Dollars) Future cash inflows from sales of oil and gas $ 16,918 $ 45,488 Future production and development costs (11,227 ) (26,931 ) Future asset retirement obligations, net of salvage (13,879 ) (15,828 ) Future income tax expense (42 ) (170 ) Future net cash flows (8,230 ) 2,559 Effect of discounting future net cash flows at 10% per annum (334 ) (5,061 ) Standardized measure of discounted future net cash flows $ (8,564 ) $ (2,502 )
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows [Table Text Block]	CHANGES IN THE STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS Years Ended December 31, 2020 2019 (Thousands of Dollars) Balance, beginning of year $ (2,502 ) $ 4,444 Extensions, discoveries and other additions - 551 Revision of quantity estimates (1,337 ) (1,650 ) Sales of crude oil and natural gas, net of production costs (1,458 ) (4,686 ) Net change in income taxes 79 88 Net changes in prices and production costs (7,748 ) (5,161 ) Accretion of discount (250 ) 444 Other 4,652 3,468 Balance, end of year $ (8,564 ) $ (2,502 )

Note 1 - Organization and Sum_3

Note 1 - Organization and Summary of Significant Accounting Policies (Details Textual)	1 Months Ended	9 Months Ended	12 Months Ended
	Mar. 25, 2021USD ($)	Sep. 30, 2020	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
General Partner, Assets			$ 0
General Partner, Operations			0
Cash and Equivalents Maturity Period (Month)			90 days
OPERATIONAL ADVANCES			$ 2,653,099	$ 2,463,685
Depletion, Depreciation and Amortization on Proved Properties			903,226	553,953
Impairment of Oil and Gas Properties			0	0
Noncash Settlements of Asset Retirement Obligations			1,009,200
Gas Balancing Payable			$ 0	0
Number of Uncertain Tax Positions			0
Subsequent Event [Member]
Number of Oil and Gas Properties Sold	34
Gain (Loss) on Disposition of Oil and Gas and Timber Property, Total	$ 560,000
Limited Partner [Member]
Initial Percentage of Revenue and Cost Allocation			99.00%
General Partner [Member]
Initial Percentage of Revenue and Cost Allocation			1.00%
Pipeline and Support Equipment [Member]
Depreciation, Total			$ 66,889	46,227
Other Corporate Equipment [Member]
Depreciation, Total			73,777	77,076
Employee [Member]
Related Party Deposit Liabilities			$ 720,200	$ 390,000
Minimum [Member]
Actual Processing Time for Sales Transaction (Day)		60 days
Minimum [Member] | Pipeline and Support Equipment [Member]
Property, Plant and Equipment, Useful Life (Year)			10 years
Minimum [Member] | Other Corporate Equipment [Member]
Property, Plant and Equipment, Useful Life (Year)			3 years
Minimum [Member] | Building and Building Improvements [Member]
Property, Plant and Equipment, Useful Life (Year)			39 years
Maximum [Member]
Actual Processing Time for Sales Transaction (Day)		90 days
Maximum [Member] | Pipeline and Support Equipment [Member]
Property, Plant and Equipment, Useful Life (Year)			15 years
Maximum [Member] | Other Corporate Equipment [Member]
Property, Plant and Equipment, Useful Life (Year)			7 years
Maximum [Member] | Building and Building Improvements [Member]
Property, Plant and Equipment, Useful Life (Year)			40 years

Note 1 - Organization and Sum_4

Note 1 - Organization and Summary of Significant Accounting Policies - Reconciliation of Company's Asset Retirement Obligations (Details) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Beginning of period	$ 17,221,632	$ 17,003,486
Liabilities incurred	2,860	3,745
Liabilities settled	(2,472,560)	(58,622)
Accretion expense	243,468	273,023
End of period	$ 14,995,400	$ 17,221,632

Note 2 - Current Liabilities (D

Note 2 - Current Liabilities (Details Textual) - USD ($)	1 Months Ended
	Feb. 28, 2021	Dec. 31, 2020	Apr. 30, 2020	Dec. 31, 2019
Other Short-term Borrowings		$ 326,932
Paycheck Protection Program CARES Act [Member]
Other Short-term Borrowings			$ 326,932
Paycheck Protection Program CARES Act [Member] | Subsequent Event [Member]
Debt Instrument, Decrease, Forgiveness	$ 326,932

Note 2 - Current Liabilities -

Note 2 - Current Liabilities - Components of Accounts Payable and Accrued (Details) - USD ($)	Dec. 31, 2020	Dec. 31, 2019
Accounts Payable:
Production and related other	$ 1,638,704	$ 1,768,723
Property and equipment disposal	468,934
Other	300,440	304,488
Joint venture partner deposits	62,642	63,379
Total accounts payable	2,470,720	2,136,590
Accrued Expenses:
Payroll and retirement plan contributions	652,530	651,856
Current portion of asset retirement obligations	431,000	581,000
Paycheck Protection Program loan	326,932
Drilling	96,419	96,419
Federal, state and local taxes	36,154	35,917
Other	32,900	60,300
Total accrued expenses	$ 1,575,935	$ 1,425,492

Note 3 - Partners' Equity (Deta

Note 3 - Partners' Equity (Details Textual) - $ / shares	1 Months Ended			2 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2021	Dec. 31, 2020	Dec. 31, 2019
Maximum percentage of units to be repurchased					10.00%
Percentage of Adjusted Book Value of Company Allocable to the Repurchase Right Per Unit					66.00%
Minimum Percentage of Outstanding Units Tendered to Use Prorated Method for Calculating Actual Number of Units Acquired					10.00%
Net Repurchase Price of Partner Unit (in dollars per share)	$ 0.86	$ 1.50	$ 0.11
Partners' Capital Account, Units, Treasury Units Purchased (in shares)	81,039	86,388	68,261
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross (in shares)	30,000	30,000	30,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period (in shares)	30,000	30,000	30,000
Limited Partners' Capital Account, Units Outstanding (in shares)	5,441,928	5,492,967	5,549,355		5,441,928	5,492,967
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number, Ending Balance (in shares)					0	0
Forecast [Member]
Net Repurchase Price of Partner Unit (in dollars per share)				$ 0.36

Note 4 - Retirement Plan (Detai

Note 4 - Retirement Plan (Details Textual) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 187,300	$ 190,900

Note 5 - Business Segments, R_2

Note 5 - Business Segments, Risks and Major Customers (Details Textual)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Gas Purchasers [Member]
Gas, Productive Well, Number of Wells, Gross	570
Product Concentration Risk [Member] | Revenue, Product and Service Benchmark [Member] | Product, Natural Gas [Member]
Concentration Risk, Percentage	64.00%	69.00%
Number of Major Customers	1	1
Product Concentration Risk [Member] | Revenue, Product and Service Benchmark [Member] | Crude Oil and Natural Gas from Operated Wells [Member]
Concentration Risk, Percentage	80.00%	79.00%
Product Concentration Risk [Member] | Natural Gas Sales [Member] | Gas Purchasers [Member]
Concentration Risk, Percentage	45.00%	50.00%
Customer Concentration Risk [Member] | Natural Gas Sales from Operated Wells [Member] | Gas Purchasers [Member]
Concentration Risk, Percentage	70.00%	71.00%

Note 7 - Supplemental Informa_3

Note 7 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) (Details Textual)	12 Months Ended
	Dec. 31, 2020USD ($)a$ / Mcf$ / bbl	Dec. 31, 2019USD ($)a$ / Mcf$ / bbl
Costs Incurred, Acquisition of Oil and Gas Properties with Proved Reserves	$ 0	$ 0
Proved Undeveloped Carrying Cost		$ 33,300
Discount Rate Standardized Measure	10.00%
Estimate of Proved Reserves Natural Gas Price (in USD per Millions Cubic Feet) | $ / Mcf	1.46	2.17
Estimate of Proved Reserves Crude Oil Price (in USD per Barrel of Oil) | $ / bbl	36.3	52.14
Maximum [Member]
Oil and Gas, Undeveloped Acreage, Net (Acre) | a	100	100

Note 7 - Supplemental Informa_4

Note 7 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) - Capitalized Costs Relating to Oil and Gas Producing Activities (Details) - USD ($)	Dec. 31, 2020	Dec. 31, 2019
Proved oil and gas properties	$ 142,912,812	$ 174,633,910
Pipeline and support equipment	719,988	791,756
Gross capitalized costs	143,632,800	175,425,666
Accumulated depreciation, depletion, amortization and write down	137,211,641	167,541,207
Net capitalized costs	$ 6,421,159	$ 7,884,459

Note 7 - Supplemental Informa_5

Note 7 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) - Costs Incurred in Oil and Gas Producing Activities (Details) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Property acquisition costs		$ 23,018
Development costs		$ 125,071

Note 7 - Supplemental Informa_6

Note 7 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) - Results of Operations for Oil and Gas Producing Activities (Details) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Crude oil and natural gas sales	$ 3,413,680	$ 7,298,279
Production costs	(1,955,265)	(2,612,507)
Depreciation, depletion and amortization	(970,115)	(600,180)
Accretion expense	(243,468)	(273,023)
Results of operations before income tax expense (benefit)	244,832	3,812,569
Income tax expense (benefit)	(70,000)	30,000
Results of operations for oil and gas producing activities (excluding corporate overhead and financing costs)	$ 314,832	$ 3,782,569

Note 7 - Supplemental Informa_7

Note 7 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) - Estimated Quantities of Proved Oil and Gas Reserves (Details)	12 Months Ended
	Dec. 31, 2020bblMcf	Dec. 31, 2019bblMcf
Oil [Member]
Beginning Balance | bbl	329,000	386,000
Extensions, discoveries and other additions | bbl		20,000
Production | bbl	(31,000)	(42,000)
Revision of previous estimates | bbl	(63,000)	(35,000)
Ending Balance | bbl	235,000	329,000
Natural Gas [Member]
Beginning Balance | Mcf	13,035,000	16,358,000
Extensions, discoveries and other additions | Mcf		95,000
Production | Mcf	(1,185,000)	(1,840,000)
Revision of previous estimates | Mcf	(6,100,000)	(1,578,000)
Ending Balance | Mcf	5,750,000	13,035,000

Note 7 - Supplemental Informa_8

Note 7 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) - Standardized Measure of Discounted Future Net Cash Flows (Details) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Future cash inflows from sales of oil and gas	$ 16,918	$ 45,488
Future production and development costs	(11,227)	(26,931)
Future asset retirement obligations, net of salvage	(13,879)	(15,828)
Future income tax expense	(42)	(170)
Future net cash flows	(8,230)	2,559
Effect of discounting future net cash flows at 10% per annum	(334)	(5,061)
Standardized measure of discounted future net cash flows	$ (8,564)	$ (2,502)	$ 4,444

Note 7 - Supplemental Informa_9

Note 7 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) - Changes in the Standardized Measure of Discounted Future Net Cash Flows (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Balance, beginning of year	$ (2,502)	$ 4,444
Extensions, discoveries and other additions		551
Revision of quantity estimates	(1,337)	(1,650)
Sales of crude oil and natural gas, net of production costs	(1,458)	(4,686)
Net change in income taxes	79	88
Net changes in prices and production costs	(7,748)	(5,161)
Accretion of discount	(250)	444
Other	4,652	3,468
Balance, end of year	$ (8,564)	$ (2,502)