Everflow Eastern Partners 10-K 25 Mar 22 2021 FY Annual report Financial data

Document And Entity Information

Document And Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2021	Mar. 10, 2022	Jun. 30, 2021
Document Information [Line Items]
Entity Central Index Key	0000868082
Entity Registrant Name	EVERFLOW EASTERN PARTNERS LP
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2021
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2021
Document Transition Report	false
Entity File Number	0-19279
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	34-1659910
Entity Address, Address Line One	585 West Main Street
Entity Address, City or Town	Canfield
Entity Address, State or Province	OH
Entity Address, Postal Zip Code	44406
City Area Code	330
Local Phone Number	533-2692
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	true
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	false
Entity Shell Company	false
Entity Public Float			$ 0
Entity Common Stock, Shares Outstanding		5,334,473
Auditor Name	Maloney + Novotny LLC
Auditor Location	Cleveland, OH
Auditor Firm ID	320

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($)	Dec. 31, 2021	Dec. 31, 2020
CURRENT ASSETS
Cash and equivalents	$ 12,404,205	$ 10,249,207
Investments	22,382,137	20,372,652
Production accounts receivable	1,846,726	815,419
Other	51,095	79,950
Total current assets	36,684,163	31,517,228
PROPERTY AND EQUIPMENT
Proved properties (successful efforts accounting method)	136,173,678	142,912,812
Pipeline and support equipment	527,916	719,988
Corporate and other	2,112,889	2,093,989
Gross property and equipment	138,814,483	145,726,789
Less accumulated depreciation, depletion, amortization and write down	132,008,249	138,424,885
Net property and equipment	6,806,234	7,301,904
OTHER ASSETS	210,699	131,863
TOTAL ASSETS	43,701,096	38,950,995
CURRENT LIABILITIES
Accounts payable	2,205,736	2,470,720
Accrued expenses	980,881	1,575,935
Total current liabilities	3,186,617	4,046,655
DEFERRED INCOME TAXES	0	27,900
OPERATIONAL ADVANCES	2,855,680	2,653,099
ASSET RETIREMENT OBLIGATIONS	14,340,671	14,564,400
COMMITMENTS AND CONTINGENCIES	0	0
LIMITED PARTNERS' EQUITY, SUBJECT TO REPURCHASE RIGHT
Authorized - 8,000,000 Units Issued and outstanding - 5,334,473 and 5,441,928 Units, respectively	23,028,472	17,442,684
GENERAL PARTNER'S EQUITY	289,656	216,257
Total partners' equity	23,318,128	17,658,941
TOTAL LIABILITIES AND PARTNERS' EQUITY	$ 43,701,096	$ 38,950,995

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parentheticals) - shares	Dec. 31, 2021	Dec. 31, 2020
Limited partner's equity, units authorized (in shares)	8,000,000	8,000,000
Limited partner's equity, units issued (in shares)	5,334,473	5,441,928
Limited partner's equity, units outstanding (in shares)	5,334,473	5,441,928

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
REVENUES
Total revenues	$ 9,641,441	$ 3,824,550
DIRECT COST OF REVENUES
Production costs	2,294,111	1,955,265
Well management and operating	342,627	244,474
Depreciation, depletion and amortization	369,120	970,115
Accretion expense	212,410	243,468
Total direct cost of revenues	3,218,268	3,413,322
GENERAL AND ADMINISTRATIVE EXPENSE	2,081,245	2,024,011
Total cost of revenues	5,299,513	5,437,333
INCOME (LOSS) FROM OPERATIONS	4,341,928	(1,612,783)
OTHER INCOME
Investment income	12,285	273,419
Gain on disposal of property and equipment	906,026	1,067,994
Forgiveness of loan	326,932	0
Total other income	1,245,243	1,341,413
INCOME (LOSS) BEFORE INCOME TAXES	5,587,171	(271,370)
INCOME TAX BENEFIT
Current	0	50,300
Deferred	110,700	17,800
Total income tax benefit	110,700	68,100
NET INCOME (LOSS)	5,697,871	(203,270)
Allocation of Partnership Net Income (Loss):
Limited Partners	5,627,789	(200,806)
General Partner	70,082	(2,464)
NET INCOME (LOSS)	$ 5,697,871	$ (203,270)
Net income (loss) per unit (in dollars per share)	$ 1.04	$ (0.04)
Oil and Gas [Member]
REVENUES
Total revenues	$ 9,067,189	$ 3,413,680
Oil and Gas Service [Member]
REVENUES
Total revenues	569,670	405,560
Product and Service, Other [Member]
REVENUES
Total revenues	$ 4,582	$ 5,310

Consolidated Statements of Part

Consolidated Statements of Partners' Equity	USD ($)
PARTNERS' EQUITY – BEGINNING OF YEAR at Dec. 31, 2019	$ 19,296,121
Net income (loss)	(203,270)
Cash distributions ($0.25 per unit in 2020)	(1,390,016)
Repurchase of Units	(69,694)
Options exercised	25,800
PARTNERS' EQUITY – END OF YEAR at Dec. 31, 2020	17,658,941
Net income (loss)	5,697,871
Cash distributions ($0.25 per unit in 2020)	0
Repurchase of Units	(49,484)
Options exercised	10,800
PARTNERS' EQUITY – END OF YEAR at Dec. 31, 2021	$ 23,318,128

Consolidated Statements of Pa_2

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

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	$ 5,697,871	$ (203,270)
Adjustments to reconcile to net cash provided by operating activities:
Depreciation, depletion and amortization	443,908	1,043,892
Accretion expense	212,410	243,468
Unrealized (gain) loss on investments	87,396	(403)
Gain on disposal of property and equipment	(906,026)	(1,067,994)
Forgiveness of loan	(326,932)	0
Deferred income taxes	(110,700)	(17,800)
Changes in assets and liabilities:
Production accounts receivable	(1,031,307)	393,215
Other current assets	28,855	(71,800)
Other assets	3,964	(239)
Accounts payable	(264,984)	(31,422)
Accrued expenses	(39,027)	(130,709)
Operational advances	202,581	189,414
Total adjustments	(1,699,862)	549,622
Net cash provided by operating activities	3,998,009	346,352
CASH FLOWS FROM INVESTING ACTIVITIES
Purchase of investments	(2,096,881)	(264,669)
Purchase of property and equipment	(142,154)	(117,890)
Proceeds from disposal of property and equipment	434,708	104,269
Settlement of disposal of property and equipment	0	(468,934)
Net cash used in investing activities	(1,804,327)	(747,224)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from loan	0	326,932
Distributions	0	(1,390,016)
Repurchase of Units	(49,484)	(69,694)
Proceeds from options exercised	10,800	25,800
Net cash used in financing activities	(38,684)	(1,106,978)
NET CHANGE IN CASH AND EQUIVALENTS	2,154,998	(1,507,850)
CASH AND EQUIVALENTS AT BEGINNING OF YEAR	10,249,207	11,757,057
CASH AND EQUIVALENTS AT END OF YEAR	$ 12,404,205	$ 10,249,207

Note 1 - Organization and Summa

Note 1 - Organization and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2021
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. At December 31, 2021, three one September 1990 nor 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 days after the month of delivery of its product. Consequently, accounts receivable from production and crude oil and natural gas sales are recorded using estimated production volumes and market or contract prices. Differences between estimated and actual amounts are recorded in subsequent periods’ financial results. As is typical in the oil and gas industry, a significant portion of the Company's accounts receivable from production and crude oil and natural gas sales consists of unbilled receivables. Oil and gas reserve quantities are utilized in the calculation of depreciation, depletion and amortization and the impairment of crude oil and natural gas properties and also impact the timing and costs associated with asset retirement obligations. The Company's estimates, especially those related to oil and gas reserves, could change in the near term and could significantly impact the Company's results of operations and financial position. 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, December 31, 2021 2020, December 31, 2021 2020, 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 $300,390 and $903,226 during 2021 2020, 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 2021 2020. 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 to 15 years, other corporate equipment - 3 to 7 years, building and improvements - 39 to 40 years). Depreciation on pipeline and support equipment amounted to $68,730 and $66,889 for the years ended December 31, 2021 2020, December 31, 2021 2020, 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 $687,200 and $1,009,200 of gains associated with non-cash settlements of asset retirement obligations during 2021 2020. The schedule below is a reconciliation of the Company's liability for the years ended December 31: 2021 2020 Beginning of period $ 14,995,400 $ 17,221,632 Liabilities incurred - 2,860 Liabilities settled (745,139 ) (2,472,560 ) Accretion expense 212,410 243,468 End of period $ 14,462,671 $ 14,995,400 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 sales 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, 2021 2020, December 31, 2021 2020, 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 material gas imbalances at December 31, 2021 2020. 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, recorded with other 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, percentage depletion and general business 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% of revenues and costs were allocated to the Unitholders (the limited partners) and 1% of revenues and costs were allocated to the general partner. Such allocation has changed and 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. New Accounting Standards – The Company has reviewed all 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

Note 2 - Current Liabilities

Note 2 - Current Liabilities	12 Months Ended
	Dec. 31, 2021
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: 2021 2020 Accounts Payable: Production and related other $ 1,833,366 $ 1,638,704 Other 309,728 300,440 Joint venture partner deposits 62,642 62,642 Property and equipment disposal - 468,934 Total accounts payable $ 2,205,736 $ 2,470,720 Accrued Expenses: Payroll and retirement plan contributions $ 671,031 $ 652,530 Current portion of asset retirement obligations 122,000 431,000 Other 151,860 129,319 Federal, state and local taxes 35,990 36,154 Paycheck Protection Program loan - 326,932 Total accrued expenses $ 980,881 $ 1,575,935 In March 2020, June 2020. April 2020, 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, 2021
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% of the then outstanding Units, to the extent Unitholders offer Units to Everflow for repurchase pursuant to the Repurchase Right. The Repurchase Right entitles any Unitholder, between May 1 June 30 December 31 2022 December 31, 2021 April 2022. In June 2021, June 2020, June 2019, 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 options to officers and certain key employees in June 2021, 2020 2019, 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 5,334,473, 5,441,928 and 5,492,967 outstanding Units following the Company’s repurchase of Units and issuance of options in June 2021, 2020 2019, December 31, 2021 2020

Note 4 - Retirement Plan

Note 4 - Retirement Plan	12 Months Ended
	Dec. 31, 2021
Notes to Financial Statements
Retirement Benefits [Text Block]	Note 4. Retirement Plan The Company has a defined contribution plan pursuant to Section 401 December 31, 2021 2020,

Note 5 - Business Segments, Ris

Note 5 - Business Segments, Risks and Major Customers	12 Months Ended
	Dec. 31, 2021
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 74% and 64% of total crude oil and natural gas sales in 2021 2020, 2021 2020, one December 31, 2021 2020 2021 2020, As of December 31, 2021, 2021 2020, 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, 2021 2020. 2022. not third may

Note 6 - Commitments and Contin

Note 6 - Commitments and Contingencies	12 Months Ended
	Dec. 31, 2021
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. The Company may January 2022 March 2023 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, 2021
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, 2021 2020 Proved oil and gas properties $ 136,173,678 $ 142,912,812 Pipeline and support equipment 527,916 719,988 Gross capitalized costs 136,701,594 143,632,800 Accumulated depreciation, depletion, amortization and write down 130,777,683 137,211,641 Net capitalized costs $ 5,923,911 $ 6,421,159 The Company had no 2021 2020. no 2021 2020. RESULTS OF OPERATIONS FOR OIL AND GAS PRODUCING ACTIVITIES Years ended December 31, 2021 2020 Crude oil and natural gas sales $ 9,067,189 $ 3,413,680 Production costs (2,294,111 ) (1,955,265 ) Depreciation, depletion and amortization (369,120 ) (970,115 ) Accretion expense (212,410 ) (243,468 ) Results of operations before income tax benefit 6,191,548 244,832 Income tax benefit 110,000 70,000 Results of operations for oil and gas producing activities (excluding corporate overhead and financing costs) $ 6,301,548 $ 314,832 Income tax benefit was computed using statutory tax rates and reflects permanent differences that are reflected in the Company's consolidated income tax benefit for the year. ESTIMATED QUANTITIES OF PROVED OIL AND GAS RESERVES Oil Gas (BBLS) (MCF) Balance, January 1, 2020 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 Production (36,000 ) (2,053,000 ) Revision of previous estimates 137,000 12,448,000 Balance, December 31, 2021 336,000 16,145,000 The Company has not December 31, 2021 2020, December 31, 2021 2020, STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS December 31, 2021 2020 (Thousands of Dollars) Future cash inflows from sales of oil and gas $ 68,661 $ 16,918 Future production and development costs (37,790 ) (11,227 ) Future asset retirement obligations, net of salvage (13,227 ) (13,879 ) Future income tax expense (363 ) (42 ) Future net cash flows 17,281 (8,230 ) Effect of discounting future net cash flows at 10% per annum (10,505 ) (334 ) Standardized measure of discounted future net cash flows $ 6,776 $ (8,564 ) CHANGES IN THE STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS Years Ended December 31, 2021 2020 (Thousands of Dollars) Balance, beginning of year $ (8,564 ) $ (2,502 ) Revision of quantity estimates 12,040 (1,337 ) Sales of crude oil and natural gas, net of production costs (6,773 ) (1,458 ) Net change in income taxes (194 ) 79 Net changes in prices and production costs 5,394 (7,748 ) Accretion of discount (856 ) (250 ) Other 5,729 4,652 Balance, end of year $ 6,776 $ (8,564 ) 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% rate. 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 $2.94 and $1.46 per MCF at December 31, 2021 2020, December 31, 2021 2020,

Significant Accounting Policies

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2021
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. At December 31, 2021, three one September 1990 nor 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 days after the month of delivery of its product. Consequently, accounts receivable from production and crude oil and natural gas sales are recorded using estimated production volumes and market or contract prices. Differences between estimated and actual amounts are recorded in subsequent periods’ financial results. As is typical in the oil and gas industry, a significant portion of the Company's accounts receivable from production and crude oil and natural gas sales consists of unbilled receivables. Oil and gas reserve quantities are utilized in the calculation of depreciation, depletion and amortization and the impairment of crude oil and natural gas properties and also impact the timing and costs associated with asset retirement obligations. The Company's estimates, especially those related to oil and gas reserves, could change in the near term and could significantly impact the Company's results of operations and financial position.
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, December 31, 2021 2020, December 31, 2021 2020,
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 $300,390 and $903,226 during 2021 2020, 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 2021 2020. 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 to 15 years, other corporate equipment - 3 to 7 years, building and improvements - 39 to 40 years). Depreciation on pipeline and support equipment amounted to $68,730 and $66,889 for the years ended December 31, 2021 2020, December 31, 2021 2020, 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 $687,200 and $1,009,200 of gains associated with non-cash settlements of asset retirement obligations during 2021 2020. The schedule below is a reconciliation of the Company's liability for the years ended December 31: 2021 2020 Beginning of period $ 14,995,400 $ 17,221,632 Liabilities incurred - 2,860 Liabilities settled (745,139 ) (2,472,560 ) Accretion expense 212,410 243,468 End of period $ 14,462,671 $ 14,995,400
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 sales 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, 2021 2020, December 31, 2021 2020, 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 material gas imbalances at December 31, 2021 2020. 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, recorded with other 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, percentage depletion and general business 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% of revenues and costs were allocated to the Unitholders (the limited partners) and 1% of revenues and costs were allocated to the general partner. Such allocation has changed and 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.
New Accounting Pronouncements, Policy [Policy Text Block]	K. New Accounting Standards – The Company has reviewed all 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

Note 1 - Organization and Sum_2

Note 1 - Organization and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2021
Notes Tables
Schedule of Asset Retirement Obligations [Table Text Block]	2021 2020 Beginning of period $ 14,995,400 $ 17,221,632 Liabilities incurred - 2,860 Liabilities settled (745,139 ) (2,472,560 ) Accretion expense 212,410 243,468 End of period $ 14,462,671 $ 14,995,400

Note 2 - Current Liabilities (T

Note 2 - Current Liabilities (Tables)	12 Months Ended
	Dec. 31, 2021
Notes Tables
Schedule of Accounts Payable and Accrued Liabilities [Table Text Block]	2021 2020 Accounts Payable: Production and related other $ 1,833,366 $ 1,638,704 Other 309,728 300,440 Joint venture partner deposits 62,642 62,642 Property and equipment disposal - 468,934 Total accounts payable $ 2,205,736 $ 2,470,720 Accrued Expenses: Payroll and retirement plan contributions $ 671,031 $ 652,530 Current portion of asset retirement obligations 122,000 431,000 Other 151,860 129,319 Federal, state and local taxes 35,990 36,154 Paycheck Protection Program loan - 326,932 Total accrued expenses $ 980,881 $ 1,575,935

Note 7 - Supplemental Informa_2

Note 7 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2021
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, 2021 2020 Proved oil and gas properties $ 136,173,678 $ 142,912,812 Pipeline and support equipment 527,916 719,988 Gross capitalized costs 136,701,594 143,632,800 Accumulated depreciation, depletion, amortization and write down 130,777,683 137,211,641 Net capitalized costs $ 5,923,911 $ 6,421,159
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, 2021 2020 Crude oil and natural gas sales $ 9,067,189 $ 3,413,680 Production costs (2,294,111 ) (1,955,265 ) Depreciation, depletion and amortization (369,120 ) (970,115 ) Accretion expense (212,410 ) (243,468 ) Results of operations before income tax benefit 6,191,548 244,832 Income tax benefit 110,000 70,000 Results of operations for oil and gas producing activities (excluding corporate overhead and financing costs) $ 6,301,548 $ 314,832
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, 2020 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 Production (36,000 ) (2,053,000 ) Revision of previous estimates 137,000 12,448,000 Balance, December 31, 2021 336,000 16,145,000
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, 2021 2020 (Thousands of Dollars) Future cash inflows from sales of oil and gas $ 68,661 $ 16,918 Future production and development costs (37,790 ) (11,227 ) Future asset retirement obligations, net of salvage (13,227 ) (13,879 ) Future income tax expense (363 ) (42 ) Future net cash flows 17,281 (8,230 ) Effect of discounting future net cash flows at 10% per annum (10,505 ) (334 ) Standardized measure of discounted future net cash flows $ 6,776 $ (8,564 )
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, 2021 2020 (Thousands of Dollars) Balance, beginning of year $ (8,564 ) $ (2,502 ) Revision of quantity estimates 12,040 (1,337 ) Sales of crude oil and natural gas, net of production costs (6,773 ) (1,458 ) Net change in income taxes (194 ) 79 Net changes in prices and production costs 5,394 (7,748 ) Accretion of discount (856 ) (250 ) Other 5,729 4,652 Balance, end of year $ 6,776 $ (8,564 )

Note 1 - Organization and Sum_3

Note 1 - Organization and Summary of Significant Accounting Policies (Details Textual)	12 Months Ended
	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)
General Partner, Assets	$ 0
General Partner, Operations	0
Cash and Equivalents Maturity Period (Month)	3 months
OPERATIONAL ADVANCES	$ 2,855,680	$ 2,653,099
Depletion, Depreciation and Amortization on Proved Properties	300,390	903,226
Impairment of Oil and Gas Properties	0	0
Noncash Settlements of Asset Retirement Obligations	687,200	1,009,200
Gas Balancing Payable	$ 0	0
Number of Uncertain Tax Positions	0
Limited Partner [Member]
Initial Percentage of Revenue and Cost Allocation	99.00%
General Partner [Member]
Initial Percentage of Revenue and Cost Allocation	1.00%
General Partner, Liabilities	$ 0
Pipeline and Support Equipment [Member]
Depreciation, Total	68,730	66,889
Other Corporate Equipment [Member]
Depreciation, Total	74,788	73,777
Employee [Member]
Related Party Deposit Liabilities	$ 825,300	$ 720,200
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, 2021	Dec. 31, 2020
Beginning of period	$ 14,995,400	$ 17,221,632
Liabilities incurred	0	2,860
Liabilities settled	(745,139)	(2,472,560)
Accretion expense	212,410	243,468
End of period	$ 14,462,671	$ 14,995,400

Note 2 - Current Liabilities (D

Note 2 - Current Liabilities (Details Textual) - USD ($)	1 Months Ended
	Feb. 28, 2021	Dec. 31, 2021	Dec. 31, 2020	Apr. 30, 2020
Other Short-term Borrowings		$ 0	$ 326,932
Paycheck Protection Program CARES Act [Member]
Other Short-term Borrowings				$ 326,932
Debt Instrument, Decrease, Forgiveness	$ 326,932

Note 2 - Current Liabilities -

Note 2 - Current Liabilities - Components of Accounts Payable and Accrued (Details) - USD ($)	Dec. 31, 2021	Dec. 31, 2020
Accounts Payable:
Production and related other	$ 1,833,366	$ 1,638,704
Other	309,728	300,440
Joint venture partner deposits	62,642	62,642
Property and equipment disposal	0	468,934
Total accounts payable	2,205,736	2,470,720
Accrued Expenses:
Payroll and retirement plan contributions	671,031	652,530
Current portion of asset retirement obligations	122,000	431,000
Other	151,860	129,319
Federal, state and local taxes	35,990	36,154
Paycheck Protection Program loan	0	326,932
Total accrued expenses	$ 980,881	$ 1,575,935

Note 3 - Partners' Equity (Deta

Note 3 - Partners' Equity (Details Textual) - $ / shares	1 Months Ended
	Apr. 30, 2022	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2021	Dec. 31, 2020
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)		$ 0.36	$ 0.86	$ 1.50
Partners' Capital Account, Units, Treasury Units Purchased (in shares)		137,455	81,039	86,388
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross (in shares)		30,000	30,000	30,000
Limited Partners' Capital Account, Units Outstanding (in shares)		5,334,473	5,441,928	5,492,967	5,334,473	5,441,928
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number, Ending Balance (in shares)					0	0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period (in shares)		30,000	30,000	30,000
Forecast [Member]
Net Repurchase Price of Partner Unit (in dollars per share)	$ 2.51
Partners' Capital Account, Distribution Per Unit of Limited Partner Interest (in dollars per share)	$ 0.50

Note 4 - Retirement Plan (Detai

Note 4 - Retirement Plan (Details Textual) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 207,900	$ 187,300

Note 5 - Business Segments, R_2

Note 5 - Business Segments, Risks and Major Customers (Details Textual)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Gas Purchasers [Member]
Gas, Productive Well, Number of Wells, Gross	580
Product Concentration Risk [Member] | Revenue, Product and Service Benchmark [Member] | Product, Natural Gas [Member]
Concentration Risk, Percentage	74.00%	64.00%
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	88.00%	80.00%
Product Concentration Risk [Member] | Natural Gas Sales [Member] | Gas Purchasers [Member]
Concentration Risk, Percentage	61.00%	45.00%
Product Concentration Risk [Member] | Natural Gas Sales from Operated Wells [Member] | Gas Purchasers [Member]
Concentration Risk, Percentage	82.00%
Customer Concentration Risk [Member] | Natural Gas Sales from Operated Wells [Member] | Gas Purchasers [Member]
Concentration Risk, Percentage		70.00%
Customer Concentration Risk [Member] | Crude Oil and Natural Gas from Operated Wells [Member] | Product, Oil Purchaser [Member]
Number of Major Customers	1

Note 6 - Commitments and Cont_2

Note 6 - Commitments and Contingencies (Details Textual)	Dec. 31, 2021$ / Mcf
Oil and Gas, Delivery Commitment, Supply Dedicated or Contracted	625,000
Oil and Gas Delivery Commitments and Contracts, Fixed Price (in USD per Millions Cubic Feet)	4

Note 7 - Supplemental Informa_3

Note 7 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) (Details Textual)	12 Months Ended
	Dec. 31, 2021USD ($)a$ / Mcf$ / bbl	Dec. 31, 2020USD ($)a$ / Mcf$ / bbl
Costs Incurred, Acquisition of Oil and Gas Properties with Proved Reserves	$ 0	$ 0
Costs Incurred, Acquisition of Oil and Gas Properties, Total	0	0
Proved Undeveloped Carrying Cost	$ 33,300	$ 33,300
Discount Rate Standardized Measure	10.00%
Estimate of Proved Reserves Natural Gas Price (in USD per Millions Cubic Feet) | $ / Mcf	2.94	1.46
Estimate of Proved Reserves Crude Oil Price (in USD per Barrel of Oil) | $ / bbl	63.16	36.30
Costs Incurred, Development Costs	$ 0	$ 0
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, 2021	Dec. 31, 2020
Proved oil and gas properties	$ 136,173,678	$ 142,912,812
Pipeline and support equipment	527,916	719,988
Gross capitalized costs	136,701,594	143,632,800
Accumulated depreciation, depletion, amortization and write down	130,777,683	137,211,641
Net capitalized costs	$ 5,923,911	$ 6,421,159

Note 7 - Supplemental Informa_5

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, 2021	Dec. 31, 2020
Crude oil and natural gas sales	$ 9,067,189	$ 3,413,680
Production costs	(2,294,111)	(1,955,265)
Depreciation, depletion and amortization	(369,120)	(970,115)
Accretion expense	(212,410)	(243,468)
Results of operations before income tax benefit	6,191,548	244,832
Income tax benefit	110,000	70,000
Results of operations for oil and gas producing activities (excluding corporate overhead and financing costs)	$ 6,301,548	$ 314,832

Note 7 - Supplemental Informa_6

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, 2021bblMcf	Dec. 31, 2020bblMcf
Oil [Member]
Beginning Balance | bbl	235,000	329,000
Production | bbl	(36,000)	(31,000)
Revision of previous estimates | bbl	137,000	(63,000)
Ending Balance | bbl	336,000	235,000
Natural Gas [Member]
Beginning Balance | Mcf	5,750,000	13,035,000
Production | Mcf	(2,053,000)	(1,185,000)
Revision of previous estimates | Mcf	12,448,000	(6,100,000)
Ending Balance | Mcf	16,145,000	5,750,000

Note 7 - Supplemental Informa_7

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, 2021	Dec. 31, 2020	Dec. 31, 2019
Future cash inflows from sales of oil and gas	$ 68,661	$ 16,918
Future production and development costs	(37,790)	(11,227)
Future asset retirement obligations, net of salvage	(13,227)	(13,879)
Future income tax expense	(363)	(42)
Future net cash flows	17,281	(8,230)
Effect of discounting future net cash flows at 10% per annum	(10,505)	(334)
Standardized measure of discounted future net cash flows	$ 6,776	$ (8,564)	$ (2,502)

Note 7 - Supplemental Informa_8

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, 2021	Dec. 31, 2020
Balance, beginning of year	$ (8,564)	$ (2,502)
Revision of quantity estimates	12,040	(1,337)
Sales of crude oil and natural gas, net of production costs	(6,773)	(1,458)
Net change in income taxes	(194)	79
Net changes in prices and production costs	5,394	(7,748)
Accretion of discount	(856)	(250)
Other	5,729	4,652
Balance, end of year	$ 6,776	$ (8,564)