Everflow Eastern Partners 10-K 27 Mar 19 2018 FY Annual report Financial data

Document And Entity Information

Document And Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2018	Mar. 10, 2019	Jun. 30, 2018
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 Common Stock, Shares Outstanding (in shares)		5,549,355
Entity Public Float			$ 4,320,927
Entity Shell Company	false
Document Type	10-K
Document Period End Date	Dec. 31, 2018
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	FY
Amendment Flag	false

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($)	Dec. 31, 2018	Dec. 31, 2017
CURRENT ASSETS
Cash and equivalents	$ 12,566,868	$ 11,883,725
Investments	17,064,136	13,207,778
Production accounts receivable	1,661,669	1,189,524
Other	64,681	60,725
Total current assets	31,357,354	26,341,752
PROPERTY AND EQUIPMENT
Proved properties (successful efforts accounting method)	175,062,777	179,141,990
Pipeline and support equipment	762,440	682,135
Corporate and other	2,094,423	2,127,423
Gross property and equipment	177,919,640	181,951,548
Less accumulated depreciation, depletion, amortization and write down	168,754,778	172,431,241
Net property and equipment	9,164,862	9,520,307
OTHER ASSETS	125,796	136,290
TOTAL ASSETS	40,648,012	35,998,349
CURRENT LIABILITIES
Accounts payable	1,869,885	1,958,042
Accrued expenses	1,084,347	1,624,205
Total current liabilities	2,954,232	3,582,247
DEFERRED INCOME TAXES	40,700	37,700
OPERATIONAL ADVANCES	2,135,632	1,513,924
ASSET RETIREMENT OBLIGATIONS	16,807,486	16,591,270
COMMITMENTS AND CONTINGENCIES
LIMITED PARTNERS' EQUITY, SUBJECT TO REPURCHASE RIGHT
Authorized - 8,000,000 Units issued and outstanding - 5,549,355 and 5,587,616 Units, respectively	18,486,440	14,103,844
GENERAL PARTNER'S EQUITY	223,522	169,364
Total partners' equity	18,709,962	14,273,208
TOTAL LIABILITIES AND PARTNERS' EQUITY	$ 40,648,012	$ 35,998,349

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parentheticals) - shares	Dec. 31, 2018	Dec. 31, 2017
Limited partner's equity, units authorized (in shares)	8,000,000	8,000,000
Limited partner's equity, units issued (in shares)	5,549,355	5,587,616
Limited partner's equity, units outstanding (in shares)	5,549,355	5,587,616

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
REVENUES
Total revenues	$ 10,104,664	$ 7,660,939
DIRECT COST OF REVENUES
Production costs	3,256,946	2,160,029
Well management and operating	320,962	299,581
Depreciation, depletion and amortization	637,642	940,143
Accretion expense	313,641	355,127
Total direct cost of revenues	4,529,191	3,754,880
GENERAL AND ADMINISTRATIVE EXPENSE	2,250,442	2,264,424
Total cost of revenues	6,779,633	6,019,304
INCOME FROM OPERATIONS	3,325,031	1,641,635
OTHER INCOME
Interest and dividend income	393,810	146,710
Gain on disposal of property and equipment	644,898	80,368
Gain on sale of other assets	15,164	175,612
Total other income	1,053,872	402,690
INCOME BEFORE INCOME TAXES	4,378,903	2,044,325
INCOME TAX EXPENSE (BENEFIT)
Current	(65,060)	5,000
Deferred	3,000	(36,300)
Total income tax benefit	(62,060)	(31,300)
NET INCOME	4,440,963	2,075,625
Allocation of Partnership Net Income:
Limited Partners	4,388,088	2,050,996
General Partner	52,875	24,629
Net income	$ 4,440,963	$ 2,075,625
Net income per unit (in dollars per share)	$ 0.79	$ 0.37
Oil and Gas [Member]
REVENUES
Total revenues	$ 9,547,117	$ 7,086,476
Oil and Gas Service [Member]
REVENUES
Total revenues	551,498	512,043
Product and Service, Other [Member]
REVENUES
Total revenues	$ 6,049	$ 62,420

Consolidated Statements of Part

Consolidated Statements of Partners' Equity	USD ($)
PARTNERS' EQUITY – BEGINNING OF YEAR at Dec. 31, 2016	$ 12,197,583
Net income	2,075,625
Repurchase of Units
Options exercised
PARTNERS' EQUITY – END OF YEAR at Dec. 31, 2017	14,273,208
Net income	4,440,963
Repurchase of Units	(7,509)
Options exercised	3,300
PARTNERS' EQUITY – END OF YEAR at Dec. 31, 2018	$ 18,709,962

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 4,440,963	$ 2,075,625
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	715,399	1,026,172
Accretion expense	313,641	355,127
Gain on disposal of property and equipment	(644,898)	(80,368)
Gain on sale of other assets	(15,164)	(175,612)
Deferred income taxes	3,000	(36,300)
Changes in assets and liabilities:
Production accounts receivable	(472,145)	(171,212)
Other current assets	(47,831)	25,606
Other assets	824	(13,740)
Accounts payable	(88,157)	254,601
Accrued expenses	12,903	(124,549)
Operational advances	621,708	460,342
Total adjustments	399,280	1,520,067
Net cash provided by operating activities	4,840,243	3,595,692
CASH FLOWS FROM INVESTING ACTIVITIES
Purchase of investments	(3,856,358)	(3,127,170)
Payments received on notes receivables from employees	46,870	52,203
Advances disbursed to employees	(3,700)	(11,900)
Purchase of property and equipment	(405,623)	(221,108)
Proceeds from disposal of property and equipment	40,381	128,281
Proceeds from sale of other assets	25,539	242,862
Net cash used in investing activities	(4,152,891)	(2,936,832)
CASH FLOWS FROM FINANCING ACTIVITIES
Repurchase of Units	(7,509)
Proceeds from options exercised	3,300
Net cash used in financing activities	(4,209)
NET CHANGE IN CASH AND EQUIVALENTS	683,143	658,860
CASH AND EQUIVALENTS AT BEGINNING OF YEAR	11,883,725	11,224,865
CASH AND EQUIVALENTS AT END OF YEAR	12,566,868	11,883,725
Supplemental disclosures of cash flow information:
Cash paid during the year for income taxes	$ 3,650	$ 5,499

Note 1 - Organization and Summa

Note 1 - Organization and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2018
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 are Everflow Management Corporation ("EMC"); two one 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 and notes 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, $2,135,632 $1,513,924 December 31, 2018 2017, 5 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 1. 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 $595,163 $889,794 2018 2017, 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 2018 2017. Additions to proved properties in 2017 2 1.G 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 $42,479 $50,349 December 31, 2018 2017, $77,757 $86,029 December 31, 2018 2017, 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 $650,200 $54,900 2018 2017, The schedule below is a reconciliation of the Company's liability for the years ended December 31: 2018 2017 Beginning of period $ 17,366,270 $ 17,124,630 Liabilities incurred - 877 Liabilities settled (676,425 ) (114,364 ) Accretion expense 313,641 355,127 End of period $ 17,003,486 $ 17,366,270 H. Revenue Recognition – As further described in Note 1.K., 2014 09 January 1, 2018. 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, 2018; December 31, 2018. 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, 2018 2017. The Company 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 Earnings per limited partner Unit have been computed based on the weighted average number of Units outstanding during each year presented. Average outstanding Units for earnings per Unit calculations amount to 5,568,486 5,587,616 2018 2017, K. New Accounting Standards – In May 2014, No. 2014 09, 606 2014 09” 2014 09 2014 09 2014 09, 2015 14, December 31, 2017 ( 2014 09 January 1, 2018. no not no 2014 09 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 L. 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, 2018
Notes to Financial Statements
Accounts Payable and Accrued Liabilities Disclosure [Text Block]	N ote 2. Current Liabilities The Company's accounts payable and accrued expenses consist of the following at December 31: 2018 2017 Accounts Payable: Production and related other $ 1,522,106 $ 1,615,606 Other 299,150 295,507 Joint venture partner deposits 48,629 46,929 Total accounts payable $ 1,869,885 $ 1,958,042 Accrued Expenses: Current portion of asset retirement obligations $ 196,000 $ 775,000 Payroll and retirement plan contributions 692,083 664,384 Drilling 106,100 106,100 Other 55,100 45,600 Federal, state and local taxes 35,064 33,121 Total accrued expenses $ 1,084,347 $ 1,624,205

Note 3 - Partners' Equity

Note 3 - Partners' Equity	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Partners' Capital Notes Disclosure [Text Block]	N ote 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% 2019 December 31, 2018 $1.50 $0.30 April 2019. In June 2018, 68,261 $0.11 not 2017 2016 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. In June 2018, 30,000 not 2017. 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 5,549,355 June 2018. no December 31, 2018 2017

Note 4 - Retirement Plan

Note 4 - Retirement Plan	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Pension and Other Postretirement Benefits Disclosure [Text Block]	Note 4 . Retirement Plan The Company has a defined contribution plan pursuant to Section 401 $193,200 $194,400 December 31, 2018 2017,

Note 5 - Related Party Transact

Note 5 - Related Party Transactions	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Related Party Transactions Disclosure [Text Block]	Note 5 . Related Party Transactions The Company's Officers, Directors, affiliates and certain employees have frequently participated, and will likely continue to participate in the future, as working interest owners in wells in which the Company has an interest. Frequently, the Company has loaned the funds necessary for certain employees to participate in the drilling and development of such wells. Initial terms of the unsecured loans call for repayment of all principal and accrued interest at the end of four not four Employees remain obligated for the entire loan amount regardless of a dry-hole event or otherwise insufficient production. The loans carry no no 5.50% December 31, 2018. In accordance with the Sarbanes-Oxley Act of 2002, not 2002. December 31, 2018 December 2017 December 2018. December 31, 2017 three December 2011 December 2017. December 31, 2017 two $5,000 $46,700 December 31, 2018 2017, The Company collects and holds operational advances from employees, including officers and directors, who own working interests in wells of which the Company operates (see Note 1 $307,800 $180,300 December 31, 2018 2017,

Note 6 - Business Segments, Ris

Note 6 - Business Segments, Risks and Major Customers	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Segment Reporting Disclosure [Text Block]	N ote 6 . 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 66% 73% 2018 2017, 71% 83% 2018 2017, two December 31, 2018 2017. Natural Gas Purchaser 2018 2017 Dominion Field Services, Inc. ("Dominion") 43 % 44 % Interstate Gas Supply, Inc. ("IGS") 3 12 46 % 56 % As of December 31, 2018, 610 30 70% 76% 2018 2017, Substantially all of the Company’s crude oil production from operated wells is purchased by Ergon Oil Purchasing, Inc. (“Ergon Oil”). 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, 2018 2017. 2019. not third may The Company has multiple contracts with Dominion Field Services (“Dominion”) which obligate Dominion 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 450,000 January 2019 March 2019 $4.35

Note 7 - Commitments and Contin

Note 7 - Commitments and Contingencies	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Commitments and Contingencies Disclosure [Text Block]	Note 7 . Commitments and Contingencies The Company has natural gas delivery commitments to the Gas Purchasers (see Note 6 may may 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

Note 8 - Supplemental Informati

Note 8 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited)	12 Months Ended
	Dec. 31, 2018
Notes to Financial Statements
Oil and Gas Exploration and Production Industries Disclosures [Text Block]	Note 8 . 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, 2018 2017 Proved oil and gas properties $ 175,062,777 $ 179,141,990 Pipeline and support equipment 762,440 682,135 Gross capitalized costs 175,825,217 179,824,125 Accumulated depreciation, depletion, amortization and write down 167,611,775 171,337,190 Net capitalized costs $ 8,213,442 $ 8,486,935 COSTS INCURRED IN OIL AND GAS PRODUCING ACTIVITIES Years ended December 31, 2018 2017 Property acquisition costs $ 49,855 $ 11,045 Development costs 277,899 192,284 The Company had no 2018 2017. RESULTS OF OPERATIONS FOR OIL AND GAS PRODUCING ACTIVITIES Years ended December 31, 2018 2017 Crude oil and natural gas sales $ 9,547,117 $ 7,086,476 Production costs (3,256,946 ) (2,160,029 ) Depreciation, depletion and amortization (637,642 ) (940,143 ) Accretion expense (313,641 ) (355,127 ) Results of operations before income tax benefit 5,338,888 3,631,177 Income tax benefit (60,000 ) (30,000 ) Results of operations for oil and gas producing activities (excluding corporate overhead and financing costs) $ 5,398,888 $ 3,661,177 Income tax expense was computed using statutory tax rates and reflects permanent differences that are reflected in the Company's consolidated income tax expense for the year. ESTIMATED QUANTITIES OF PROVED OIL AND GAS RESERVES Oil Gas (BBLS) (MCF) Balance, January 1, 2017 244,000 5,280,000 Extensions, discoveries and other additions 8,000 17,000 Production (40,000 ) (1,904,000 ) Revision of previous estimates 78,000 7,851,000 Balance, December 31, 2017 290,000 11,244,000 Production (55,000 ) (2,301,000 ) Revision of previous estimates 151,000 7,415,000 Balance, December 31, 2018 386,000 16,358,000 The Company has not 100 December 31, 2018 2017, $33,300 $35,700 December 31, 2018 2017, STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS December 31, 2018 2017 (Thousands of Dollars) Future cash inflows from sales of oil and gas $ 67,050 $ 37,232 Future production and development costs (36,575 ) (22,716 ) Future asset retirement obligations, net of salvage (15,871 ) (16,360 ) Future income tax expense (321 ) (132 ) Future net cash flows 14,283 (1,976 ) Effect of discounting future net cash flows at 10% per annum (9,839 ) (3,078 ) Standardized measure of discounted future net cash flows $ 4,444 $ (5,054 ) CHANGES IN THE STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS Years Ended December 31, 2018 2017 (Thousands of Dollars) Balance, beginning of year $ (5,054 ) $ (9,924 ) Extensions, discoveries and other additions - 197 Revision of quantity estimates 8,543 4,031 Sales of crude oil and natural gas, net of production costs (6,290 ) (4,926 ) Net change in income taxes (112 ) (20 ) Net changes in prices and production costs 4,096 2,478 Accretion of discount (505 ) (992 ) Other 3,766 4,102 Balance, end of year $ 4,444 $ (5,054 ) 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 $2.63 $2.09 December 31, 2018 2017, $62.12 $47.48 December 31, 2018 2017,

Significant Accounting Policies

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2018
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 are Everflow Management Corporation ("EMC"); two one 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 and notes 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, $2,135,632 $1,513,924 December 31, 2018 2017, 5
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 1.
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 $595,163 $889,794 2018 2017, 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 2018 2017. Additions to proved properties in 2017 2 1.G 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 $42,479 $50,349 December 31, 2018 2017, $77,757 $86,029 December 31, 2018 2017, 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 $650,200 $54,900 2018 2017, The schedule below is a reconciliation of the Company's liability for the years ended December 31: 2018 2017 Beginning of period $ 17,366,270 $ 17,124,630 Liabilities incurred - 877 Liabilities settled (676,425 ) (114,364 ) Accretion expense 313,641 355,127 End of period $ 17,003,486 $ 17,366,270
Revenue from Contract with Customer [Policy Text Block]	H. Revenue Recognition – As further described in Note 1.K., 2014 09 January 1, 2018. 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, 2018; December 31, 2018. 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, 2018 2017. The Company 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 Earnings per limited partner Unit have been computed based on the weighted average number of Units outstanding during each year presented. Average outstanding Units for earnings per Unit calculations amount to 5,568,486 5,587,616 2018 2017,
New Accounting Pronouncements, Policy [Policy Text Block]	K. New Accounting Standards – In May 2014, No. 2014 09, 606 2014 09” 2014 09 2014 09 2014 09, 2015 14, December 31, 2017 ( 2014 09 January 1, 2018. no not no 2014 09 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, Policy [Policy Text Block]	L. 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, 2018
Notes Tables
Schedule of Asset Retirement Obligations [Table Text Block]	2018 2017 Beginning of period $ 17,366,270 $ 17,124,630 Liabilities incurred - 877 Liabilities settled (676,425 ) (114,364 ) Accretion expense 313,641 355,127 End of period $ 17,003,486 $ 17,366,270

Note 2 - Current Liabilities (T

Note 2 - Current Liabilities (Tables)	12 Months Ended
	Dec. 31, 2018
Notes Tables
Schedule of Accounts Payable and Accrued Liabilities [Table Text Block]	2018 2017 Accounts Payable: Production and related other $ 1,522,106 $ 1,615,606 Other 299,150 295,507 Joint venture partner deposits 48,629 46,929 Total accounts payable $ 1,869,885 $ 1,958,042 Accrued Expenses: Current portion of asset retirement obligations $ 196,000 $ 775,000 Payroll and retirement plan contributions 692,083 664,384 Drilling 106,100 106,100 Other 55,100 45,600 Federal, state and local taxes 35,064 33,121 Total accrued expenses $ 1,084,347 $ 1,624,205

Note 6 - Business Segments, R_2

Note 6 - Business Segments, Risks and Major Customers (Tables)	12 Months Ended
	Dec. 31, 2018
Notes Tables
Schedule of Revenue by Major Customers by Reporting Segments [Table Text Block]	Natural Gas Purchaser 2018 2017 Dominion Field Services, Inc. ("Dominion") 43 % 44 % Interstate Gas Supply, Inc. ("IGS") 3 12 46 % 56 %

Note 8 - Supplemental Informa_2

Note 8 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2018
Notes Tables
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]	Years ended December 31, 2018 2017 Proved oil and gas properties $ 175,062,777 $ 179,141,990 Pipeline and support equipment 762,440 682,135 Gross capitalized costs 175,825,217 179,824,125 Accumulated depreciation, depletion, amortization and write down 167,611,775 171,337,190 Net capitalized costs $ 8,213,442 $ 8,486,935
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure [Table Text Block]	Years ended December 31, 2018 2017 Property acquisition costs $ 49,855 $ 11,045 Development costs 277,899 192,284
Results of Operations for Oil and Gas Producing Activities Disclosure [Table Text Block]	Years ended December 31, 2018 2017 Crude oil and natural gas sales $ 9,547,117 $ 7,086,476 Production costs (3,256,946 ) (2,160,029 ) Depreciation, depletion and amortization (637,642 ) (940,143 ) Accretion expense (313,641 ) (355,127 ) Results of operations before income tax benefit 5,338,888 3,631,177 Income tax benefit (60,000 ) (30,000 ) Results of operations for oil and gas producing activities (excluding corporate overhead and financing costs) $ 5,398,888 $ 3,661,177
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Table Text Block]	Oil Gas (BBLS) (MCF) Balance, January 1, 2017 244,000 5,280,000 Extensions, discoveries and other additions 8,000 17,000 Production (40,000 ) (1,904,000 ) Revision of previous estimates 78,000 7,851,000 Balance, December 31, 2017 290,000 11,244,000 Production (55,000 ) (2,301,000 ) Revision of previous estimates 151,000 7,415,000 Balance, December 31, 2018 386,000 16,358,000
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure [Table Text Block]	December 31, 2018 2017 (Thousands of Dollars) Future cash inflows from sales of oil and gas $ 67,050 $ 37,232 Future production and development costs (36,575 ) (22,716 ) Future asset retirement obligations, net of salvage (15,871 ) (16,360 ) Future income tax expense (321 ) (132 ) Future net cash flows 14,283 (1,976 ) Effect of discounting future net cash flows at 10% per annum (9,839 ) (3,078 ) Standardized measure of discounted future net cash flows $ 4,444 $ (5,054 )
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows [Table Text Block]	Years Ended December 31, 2018 2017 (Thousands of Dollars) Balance, beginning of year $ (5,054 ) $ (9,924 ) Extensions, discoveries and other additions - 197 Revision of quantity estimates 8,543 4,031 Sales of crude oil and natural gas, net of production costs (6,290 ) (4,926 ) Net change in income taxes (112 ) (20 ) Net changes in prices and production costs 4,096 2,478 Accretion of discount (505 ) (992 ) Other 3,766 4,102 Balance, end of year $ 4,444 $ (5,054 )

Note 1 - Organization and Sum_3

Note 1 - Organization and Summary of Significant Accounting Policies (Details Textual)	12 Months Ended
	Dec. 31, 2018USD ($)shares	Dec. 31, 2017USD ($)shares
General Partner, Assets	$ 0
General Partner, Operations	0
Cash and Equivalents Maturity Period	90 days
Contract with Customer, Liability, Noncurrent	$ 2,135,632	$ 1,513,924
Depletion, Depreciation and Amortization on Proved Properties	595,163	889,794
Impairment of Oil and Gas Properties	0	0
Settlement of Asset Retirement Obligations Through Noncash Payments, Amount	$ 650,200	$ 54,900
Number of Uncertain Tax Positions	0
Weighted Average Limited Partnership Units Outstanding, Basic | shares	5,568,486	5,587,616
General Partner, Liabilities	$ 0
Gas Balancing Payable		$ 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%
Pipeline and Support Equipment [Member]
Depreciation, Total	$ 42,479	50,349
Other Corporate Property [Member]
Depreciation, Total	$ 77,757	$ 86,029
Minimum [Member]
Actual Processing Time for Sales Transaction	60 days
Minimum [Member] | Pipeline and Support Equipment [Member]
Property, Plant and Equipment, Useful Life	10 years
Minimum [Member] | Other Corporate Equipment [Member]
Property, Plant and Equipment, Useful Life	3 years
Minimum [Member] | Building and Building Improvements [Member]
Property, Plant and Equipment, Useful Life	39 years
Maximum [Member]
Actual Processing Time for Sales Transaction	90 days
Maximum [Member] | Pipeline and Support Equipment [Member]
Property, Plant and Equipment, Useful Life	15 years
Maximum [Member] | Other Corporate Equipment [Member]
Property, Plant and Equipment, Useful Life	7 years
Maximum [Member] | Building and Building Improvements [Member]
Property, Plant and Equipment, Useful Life	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, 2018	Dec. 31, 2017
Beginning of period	$ 17,366,270	$ 17,124,630
Liabilities incurred		877
Liabilities settled	(676,425)	(114,364)
Accretion expense	313,641	355,127
End of period	$ 17,003,486	$ 17,366,270

Note 2 - Current Liabilities -

Note 2 - Current Liabilities - Components of Accounts Payable and Accrued (Details) - USD ($)	Dec. 31, 2018	Dec. 31, 2017
Accounts Payable:
Production and related other	$ 1,522,106	$ 1,615,606
Other	299,150	295,507
Joint venture partner deposits	48,629	46,929
Total accounts payable	1,869,885	1,958,042
Accrued Expenses:
Current portion of asset retirement obligations	196,000	775,000
Payroll and retirement plan contributions	692,083	664,384
Drilling	106,100	106,100
Other	55,100	45,600
Federal, state and local taxes	35,064	33,121
Total accrued expenses	$ 1,084,347	$ 1,624,205

Note 3 - Partners' Equity (Deta

Note 3 - Partners' Equity (Details Textual) - $ / shares	1 Months Ended	4 Months Ended	6 Months Ended	12 Months Ended
	Jun. 30, 2018	Apr. 30, 2019	Jun. 30, 2019	Dec. 31, 2018	Dec. 31, 2017
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	$ 0.11
Partners' Capital Account, Units, Treasury Units Purchased				68,261
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross				30,000
Limited Partners' Capital Account, Units Outstanding				5,549,355	5,587,616
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number, Ending Balance				0	0
Scenario, Forecast [Member]
Net Repurchase Price of Partner Unit			$ 1.50
Partners Equity Interim Distributions		$ 0.30

Note 4 - Retirement Plan (Detai

Note 4 - Retirement Plan (Details Textual) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 193,200	$ 194,400

Note 5 - Related Party Transa_2

Note 5 - Related Party Transactions (Details Textual)	12 Months Ended
	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Related Party Deposit Liabilities	$ 307,800	$ 180,300
Employee [Member]
Term of Employee Receivables	4 years
Loan Forgiveness Provisions	0
Loans Forgiven	0
Related Party Transaction, Rate	5.50%
Number of Employees to Whom Loans have been Extended	1	3
Subsequent Addenda		2
Due from Employees	$ 5,000	$ 46,700

Note 6 - Business Segments, R_3

Note 6 - Business Segments, Risks and Major Customers (Details Textual)	12 Months Ended
	Dec. 31, 2018$ / Mcf	Dec. 31, 2017
Oil and Gas Delivery Commitments and Contracts, Significant Supplies Dedicated or Contracted to Entity	450,000
Oil and Gas Delivery Commitments and Contracts, Fixed Price	4.35
Dominion Field Services, Inc. [Member]
Productive Gas Wells, Number of Wells, Gross	610
Interstate Gas Supply, Inc. [Member]
Productive Gas Wells, Number of Wells, Gross	30
Product Concentration Risk [Member] | Sales Revenue, Product Line [Member] | Product, Natural Gas [Member]
Concentration Risk, Percentage	66.00%	73.00%
Product Concentration Risk [Member] | Sales Revenue, Product Line [Member] | Crude Oil and Natural Gas from Operated Wells [Member]
Concentration Risk, Percentage	71.00%	83.00%
Customer Concentration Risk [Member] | Sales Revenue, Product Line [Member] | Product, Natural Gas [Member]
Number of Major Customers	2	2
Customer Concentration Risk [Member] | Natural Gas Sales from Operated Wells [Member] | Gas Purchasers [Member]
Concentration Risk, Percentage	70.00%	76.00%

Note 6 - Business Segments, R_4

Note 6 - Business Segments, Risks and Major Customers - Table of Natural Gas Sales to Significant Purchasers as a Percentage of Consolidated Crude Oil and Natural Gas Sale (Details) - Customer Concentration Risk [Member] - Natural Gas Sales [Member]	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Concentration Risk, Percentage	46.00%	56.00%
Dominion Field Services, Inc. [Member]
Concentration Risk, Percentage	43.00%	44.00%
Interstate Gas Supply, Inc. [Member]
Concentration Risk, Percentage	3.00%	12.00%

Note 8 - Supplemental Informa_3

Note 8 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) (Details Textual)	12 Months Ended
	Dec. 31, 2018USD ($)a$ / Mcf$ / bbl	Dec. 31, 2017USD ($)a$ / Mcf$ / bbl
Costs Incurred, Acquisition of Oil and Gas Properties with Proved Reserves	$ 0	$ 0
Proved Undeveloped Carrying Cost	$ 33,300	$ 35,700
Discount Rate Standardized Measure	10.00%
Estimate of Proved Reserves Natural Gas Price | $ / Mcf	2.63	2.09
Estimate of Proved Reserves Crude Oil Price | $ / bbl	62.12	47.48
Maximum [Member]
Gas and Oil Area, Undeveloped, Net | a	100	100

Note 8 - Supplemental Informa_4

Note 8 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) - Capitalized Costs Relating to Oil and Gas Producing Activities (Details) - USD ($)	Dec. 31, 2018	Dec. 31, 2017
Proved oil and gas properties	$ 175,062,777	$ 179,141,990
Pipeline and support equipment	762,440	682,135
Gross capitalized costs	175,825,217	179,824,125
Accumulated depreciation, depletion, amortization and write down	167,611,775	171,337,190
Net capitalized costs	$ 8,213,442	$ 8,486,935

Note 8 - Supplemental Informa_5

Note 8 - 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, 2018	Dec. 31, 2017
Property acquisition costs	$ 49,855	$ 11,045
Development costs	$ 277,899	$ 192,284

Note 8 - Supplemental Informa_6

Note 8 - 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, 2018	Dec. 31, 2017
Crude oil and natural gas sales	$ 9,547,117	$ 7,086,476
Production costs	(3,256,946)	(2,160,029)
Depreciation, depletion and amortization	(637,642)	(940,143)
Accretion expense	(313,641)	(355,127)
Results of operations before income tax benefit	5,338,888	3,631,177
Income tax benefit	(60,000)	(30,000)
Results of operations for oil and gas producing activities (excluding corporate overhead and financing costs)	$ 5,398,888	$ 3,661,177

Note 8 - Supplemental Informa_7

Note 8 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) - Estimated Quantities of Proved Oil and Gas Reserves (Details)	12 Months Ended
	Dec. 31, 2018bblMMcf	Dec. 31, 2017bblMMcf
Oil [Member]
Beginning Balance (Barrel of Oil) | bbl	290,000	244,000
Extensions, discoveries and other additions (Barrel of Oil) | bbl		8,000
Production (Barrel of Oil) | bbl	(55,000)	(40,000)
Revision of previous estimates (Barrel of Oil) | bbl	151,000	78,000
Ending Balance (Barrel of Oil) | bbl	386,000	290,000
Natural Gas [Member]
Beginning Balance (Barrel of Oil) | MMcf	11,244,000	5,280,000
Extensions, discoveries and other additions (Barrel of Oil) | MMcf		17,000
Production (Barrel of Oil) | MMcf	(2,301,000)	(1,904,000)
Revision of previous estimates (Barrel of Oil) | MMcf	7,415,000	7,851,000
Ending Balance (Barrel of Oil) | MMcf	16,358,000	11,244,000

Note 8 - Supplemental Informa_8

Note 8 - Supplemental Information Relating to Oil and Gas Producing Activities (Unaudited) - Standardized Measure of Discounted Future Net Cash Flows (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Future cash inflows from sales of oil and gas	$ 67,050	$ 37,232
Future production and development costs	(36,575)	(22,716)
Future asset retirement obligations, net of salvage	(15,871)	(16,360)
Future income tax expense	(321)	(132)
Future net cash flows	14,283	(1,976)
Effect of discounting future net cash flows at 10% per annum	(9,839)	(3,078)
Standardized measure of discounted future net cash flows	$ 4,444	$ (5,054)	$ (9,924)

Note 8 - Supplemental Informa_9

Note 8 - 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, 2018	Dec. 31, 2017
Balance, beginning of year	$ (5,054)	$ (9,924)
Extensions, discoveries and other additions		197
Revision of quantity estimates	8,543	4,031
Sales of crude oil and natural gas, net of production costs	(6,290)	(4,926)
Net change in income taxes	(112)	(20)
Net changes in prices and production costs	4,096	2,478
Accretion of discount	(505)	(992)
Other	3,766	4,102
Balance, end of year	$ 4,444	$ (5,054)