Energy Resources 12 10-Q 13 Nov 24 2024 Q3 Quarterly report Financial data

Cover

Cover - shares	9 Months Ended
	Sep. 30, 2024	Nov. 13, 2024
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Transition Report	false
Entity Interactive Data Current	Yes
Amendment Flag	false
Document Period End Date	Sep. 30, 2024
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	Q3
Entity Information [Line Items]
Entity Registrant Name	Energy Resources 12, L.P.
Entity Central Index Key	0001696088
Entity File Number	000-55916
Entity Tax Identification Number	81-4805237
Entity Incorporation, State or Country Code	DE
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Shell Company	false
Entity Filer Category	Non-accelerated Filer
Entity Small Business	true
Entity Emerging Growth Company	false
Entity Contact Personnel [Line Items]
Entity Address, Address Line One	120 W 3rd Street, Suite 220
Entity Address, City or Town	Fort Worth
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	76102
Entity Phone Fax Numbers [Line Items]
City Area Code	817
Local Phone Number	882-9192
Entity Listings [Line Items]
Title of 12(b) Security	None
Entity Common Stock, Shares Outstanding		11,031,579

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($)	Sep. 30, 2024	Dec. 31, 2023
Assets
Cash and cash equivalents	$ 1,113,971	$ 1,455,619
Accounts receivable and other current assets	6,212,970	4,472,150
Total Current Assets	7,326,941	5,927,769
Oil and natural gas properties, successful efforts method, net of accumulated depreciation, depletion and amortization of $96,994,167 and $83,340,469, respectively	159,957,522	171,101,264
Other assets, net	33,191	0
Total Assets	167,317,654	177,029,033
Liabilities
Accounts payable and accrued expenses	2,680,962	3,058,704
Total Current Liabilities	2,680,962	3,058,704
Revolving credit facility	4,600,000	0
Asset retirement obligations	756,909	729,315
Total Liabilities	8,037,871	3,788,019
Partners’ Equity
Limited partners' interest (11,031,579 common units issued and outstanding, respectively)	159,279,998	173,241,229
General partner's interest	(215)	(215)
Total Partners’ Equity	159,279,783	173,241,014
Total Liabilities and Partners’ Equity	$ 167,317,654	$ 177,029,033

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parentheticals) - USD ($)	Sep. 30, 2024	Dec. 31, 2023
Statement of Financial Position [Abstract]
Oil and natural gas properties, successful efforts method, accumulated depreciation, depletion and amortization (in Dollars)	$ 96,994,167	$ 83,340,469
Limited partners' interest, common units issued	11,031,579	11,031,579
Limited partners' interest, common units outstanding	11,031,579	11,031,579

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Revenues
Oil	$ 8,992,141	$ 10,658,915	$ 24,338,597	$ 33,442,031
Natural gas	335,444	664,351	1,092,348	2,174,598
Natural gas liquids	903,465	842,740	2,568,514	2,669,273
Total revenue	10,231,050	12,166,006	27,999,459	38,285,902
Operating costs and expenses
Production expenses	4,468,955	5,445,066	13,554,913	15,679,551
Production taxes	730,560	1,052,564	2,276,482	3,235,632
General and administrative expenses	496,225	531,401	1,672,911	1,744,178
Depreciation, depletion, amortization and accretion	5,213,055	4,578,247	13,677,565	13,655,624
Total operating costs and expenses	10,908,795	11,607,278	31,181,871	34,314,985
Operating income (loss)	(677,745)	558,728	(3,182,412)	3,970,917
Interest income (expense), net	(104,612)	21,516	(140,976)	247,270
Total other income (expense), net	(104,612)	21,516	(140,976)	247,270
Net income (loss)	$ (782,357)	$ 580,244	$ (3,323,388)	$ 4,218,187
Basic and diluted net income (loss) per common unit (in Dollars per share)	$ (0.07)	$ 0.05	$ (0.3)	$ 0.38
Weighted average common units outstanding - basic and diluted (in Shares)	11,031,579	11,031,579	11,031,579	11,031,579

Consolidated Statements of Part

Consolidated Statements of Partners' Equity - USD ($)	Total	Limited Partner [Member]	General Partner [Member]
Balance at Dec. 31, 2022	$ 202,034,461	$ 202,034,676	$ (215)
Balance (in Shares) at Dec. 31, 2022		11,031,579
Distributions declared and paid to common units	(3,850,473)	$ (3,850,473)
Net income (loss)	3,193,772	3,193,772
Balance at Mar. 31, 2023	201,377,760	$ 201,377,975	(215)
Balance (in Shares) at Mar. 31, 2023		11,031,579
Balance at Dec. 31, 2022	202,034,461	$ 202,034,676	(215)
Balance (in Shares) at Dec. 31, 2022		11,031,579
Distributions declared and paid to common units	(28,887,547)
Net income (loss)	4,218,187
Balance at Sep. 30, 2023	177,365,246	$ 177,365,461	(215)
Balance (in Shares) at Sep. 30, 2023		11,031,579
Balance at Mar. 31, 2023	201,377,760	$ 201,377,975	(215)
Balance (in Shares) at Mar. 31, 2023		11,031,579
Distributions declared and paid to common units	(21,501,000)	$ (21,501,000)
Adjustment to state tax withholding for limited partners	145	145
Net income (loss)	444,171	444,171
Balance at Jun. 30, 2023	180,321,076	$ 180,321,291	(215)
Balance (in Shares) at Jun. 30, 2023		11,031,579
Distributions declared and paid to common units	(3,536,074)	$ (3,536,074)
Net income (loss)	580,244	580,244
Balance at Sep. 30, 2023	177,365,246	$ 177,365,461	(215)
Balance (in Shares) at Sep. 30, 2023		11,031,579
Balance at Dec. 31, 2023	$ 173,241,014	$ 173,241,229	(215)
Balance (in Shares) at Dec. 31, 2023	11,031,579	11,031,579
Distributions declared and paid to common units	$ (3,536,073)	$ (3,536,073)
Adjustment to state tax withholding for limited partners	(29,623)	(29,623)
Net income (loss)	(1,113,467)	(1,113,467)
Balance at Mar. 31, 2024	168,561,851	$ 168,562,066	(215)
Balance (in Shares) at Mar. 31, 2024		11,031,579
Balance at Dec. 31, 2023	$ 173,241,014	$ 173,241,229	(215)
Balance (in Shares) at Dec. 31, 2023	11,031,579	11,031,579
Distributions declared and paid to common units	$ (10,608,220)
Net income (loss)	(3,323,388)
Balance at Sep. 30, 2024	$ 159,279,783	$ 159,279,998	(215)
Balance (in Shares) at Sep. 30, 2024	11,031,579	11,031,579
Balance at Mar. 31, 2024	$ 168,561,851	$ 168,562,066	(215)
Balance (in Shares) at Mar. 31, 2024		11,031,579
Distributions declared and paid to common units	(3,536,073)	$ (3,536,073)
Net income (loss)	(1,427,564)	(1,427,564)
Balance at Jun. 30, 2024	163,598,214	$ 163,598,429	(215)
Balance (in Shares) at Jun. 30, 2024		11,031,579
Distributions declared and paid to common units	(3,536,074)	$ (3,536,074)
Net income (loss)	(782,357)	(782,357)
Balance at Sep. 30, 2024	$ 159,279,783	$ 159,279,998	$ (215)
Balance (in Shares) at Sep. 30, 2024	11,031,579	11,031,579

Consolidated Statements of Pa_2

Consolidated Statements of Partners' Equity (Parentheticals) - $ / shares	3 Months Ended
	Sep. 30, 2024	Jun. 30, 2024	Mar. 31, 2024	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023
General Partner [Member]
Distributions declared and paid per unit	$ 0.320541	$ 0.320541	$ 0.320541	$ 0.320541	$ 1.949041	$ 0.349041

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Cash flow from operating activities:
Net income (loss)	$ (782,357)	$ 580,244	$ (3,323,388)	$ 4,218,187
Adjustments to reconcile net income to cash from operating activities:
Depreciation, depletion, amortization and accretion	5,213,055	4,578,247	13,677,565	13,655,624
Changes in operating assets and liabilities:
Accounts receivable and other current assets			(1,627,972)	3,515,485
Accounts payable and accrued expenses			(695,898)	263,986
Net cash flow provided by operating activities			8,030,307	21,653,282
Cash flow from investing activities:
Additions to oil and natural gas properties			(2,217,695)	(7,811,549)
Net cash flow used in investing activities			(2,217,695)	(7,811,549)
Cash flow from financing activities:
Cash paid for loan costs			(146,040)	0
Proceeds from revolving credit facility			4,600,000	0
Distributions paid to limited partners	(3,536,074)	(3,536,074)	(10,608,220)	(28,887,547)
Net cash flow used in financing activities			(6,154,260)	(28,887,547)
Decrease in cash and cash equivalents			(341,648)	(15,045,814)
Cash and cash equivalents, beginning of period			1,455,619	18,442,414
Cash and cash equivalents, end of period	$ 1,113,971	$ 3,396,600	1,113,971	3,396,600
Interest paid			76,008	0
Supplemental non-cash information:
Accrued capital expenditures related to additions to oil and natural gas properties			$ 717,017	$ 3,452,324

Partnership Organization

Partnership Organization	9 Months Ended
	Sep. 30, 2024
Accounting Policies [Abstract]
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]	Note 1. Partnership Organization Energy Resources 12, L.P. (together with its wholly-owned subsidiary, the “Partnership”) is a Delaware limited partnership formed to acquire producing and non-producing oil and natural gas properties onshore in the United States and to develop those properties. The initial capitalization of the Partnership of $1,000 occurred on December 30, 2016. The Partnership completed its best-efforts offering in October 2019 with a total of approximately 11.0 million common units sold for gross proceeds of $218.0 million and proceeds net of offering costs of $204.3 million. As of September 30, 2024, the Partnership owned an approximate 5% non-operated working interest in 445 producing wells, predominantly in McKenzie, Dunn, McLean and Mountrail counties of North Dakota (collectively, the “Bakken Assets”). The Partnership also owns an estimated approximate 1% non-operated working interest in 4 wells in various stages of the drilling and completion process, and possible future development locations in the Bakken Assets. The Bakken Assets, which are a part of the Bakken shale formation in the Greater Williston Basin, are operated by 13 third-party operators on behalf of the Partnership and other working interest owners. The general partner of the Partnership is Energy Resources 12 GP, LLC (the “General Partner”). The General Partner manages and controls the business affairs of the Partnership. The Partnership’s fiscal year ends on December 31.

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2024
Accounting Policies [Abstract]
Significant Accounting Policies [Text Block]	Note 2. Summary of Significant Accounting Policies Basis of Presentation The accompanying unaudited financial statements have been prepared in accordance with the instructions for Article 10 of SEC Regulation S-X. Accordingly, they do not include all of the information required by generally accepted accounting principles (“GAAP”) in the United States for complete financial statements. In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation have been included. These unaudited financial statements should be read in conjunction with the Partnership’s audited December 31, 2023 financial statements included in its 2023 Annual Report on Form 10-K. Operating results for the three and nine months ended September 30, 2024 are not necessarily indicative of the results that may be expected for the twelve-month period ending December 31, 2024. Cash and Cash Equivalents Cash and cash equivalents consist of highly liquid investments with original maturities of three months or less. The fair market value of cash and cash equivalents approximates their carrying value. Cash balances may at times exceed federal depository insurance limits. Use of Estimates The preparation of financial statements in conformity with United States GAAP requires management to make estimates and assumptions that affect the reported amounts in the consolidated financial statements and accompanying notes. Actual results could differ from those estimates. Revenue Recognition The Partnership is bound by a joint operating agreement with the operator of each of its producing wells. Under the joint operating agreement, the Partnership’s proportionate share of production is marketed at the discretion of the operators. The Partnership typically satisfies its performance obligations upon transfer of control of its products and records the related revenue in the month production is delivered to the purchaser. As the Partnership does not operate its properties, it receives actual oil, natural gas, and NGL sales volumes and prices, net of costs incurred by the operators, two to three months after the date production is delivered by the operator. At the end of each month when the performance obligation is satisfied, the variable consideration can be reasonably estimated and amounts due from the Partnership’s operators are accrued in Accounts Receivable and other current assets in the consolidated balance sheets. Variances between the Partnership’s estimated revenue and actual payments are recorded in the month the payment is received; differences have been and are insignificant. As a result, the variable consideration is not constrained. The Partnership has elected to utilize the practical expedient in ASC 606 that states the Partnership is not required to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Each delivery of product represents a separate performance obligation; therefore, future volumes are wholly unsatisfied, and disclosure of the transaction price allocated to remaining performance obligations is not required. Virtually all of the Partnership’s contracts’ pricing provisions are tied to a market index, with certain adjustments based on, among other factors, whether a well delivers to a gathering or transmission line, quality of oil, natural gas and natural gas liquids and prevailing supply and demand conditions, so that prices fluctuate to remain competitive with other available suppliers. Accounts Receivable and Concentration of Credit Risk Substantially all of the Partnership’s accounts receivable are due from the operators of the Partnership’s oil and natural gas properties in North Dakota (the operators have accounts receivable from purchasers of oil, natural gas and NGLs). Oil, natural gas and NGL sales receivables are generally unsecured. This industry and location concentration has the potential to impact the Partnership’s overall exposure to credit risk, in that the purchasers of the Partnership’s oil, natural gas and NGLs and the operators of the properties in which the Partnership has an interest may be similarly affected by changes in economic, industry or other conditions. At September 30, 2024 and December 31, 2023, the Partnership did not reserve for bad debt expense, as all amounts are deemed collectible and the Partnership’s operators do not have a history of non-payment. For the quarter ended September 30, 2024, approximately 93% of the Partnership’s total revenue was generated through sales by four of its 13 operators, respectively. All oil and natural gas producing activities of the Partnership are in North Dakota and represent substantially all of the business activities of the Partnership. Income Tax The Partnership is taxed as a partnership for federal and state income tax purposes. Typically, the Partnership has not recorded a provision for income taxes since the liability for such taxes is that of each of the partners rather than the Partnership. In mid-2022, the Partnership was contacted by the state of North Dakota, which asserted that the Partnership has an obligation to make tax payments on behalf of certain non-resident partners. In accordance with its settlements with the state of North Dakota, the Partnership has made payments of (i) approximately $365,000 (approximately $0.033 per common unit) in May 2023 for tax year 2021; (ii) approximately $532,000 (approximately $0.048 per common unit) in April 2024 for tax year 2022; and (iii) approximately $142,000 (approximately $0.013 per common unit) in April 2024 for tax year 2023. The Partnership’s income tax returns are subject to examination by the federal and state taxing authorities, and changes, if any, could adjust the individual income tax of the partners. The Partnership has evaluated whether any material tax position taken will more likely than not be sustained upon examination by the appropriate taxing authority and believes that all such material tax positions taken are supportable by existing laws and related interpretations. Fair Value of Other Financial Instruments The carrying value of the Partnership’s other financial instruments, including cash and cash equivalents, accounts receivable, accounts payable and accrued expenses, reflect these items’ cost, which approximates fair value based on the timing of the anticipated cash flows, current market conditions and short-term maturity of these instruments. Net Income (Loss) Per Common Unit Basic net income (loss) per common unit is computed as net income (loss) divided by the weighted average number of common units outstanding during the period. Diluted net income (loss) per common unit is calculated after giving effect to all potential common units that were dilutive and outstanding for the period. There were no common units with a dilutive effect for the three and nine months ended September 30, 2024 and 2023. As a result, basic and diluted outstanding common units were the same. The Incentive Distribution Rights, as defined below, are not included in net income (loss) per common unit until such time that it is probable Payout (as discussed in Note 6) will occur.

Oil and Gas Investments

Oil and Gas Investments	9 Months Ended
	Sep. 30, 2024
Oil and Gas Disclosure [Abstract]
Oil and Gas, Property and Equipment [Text Block]	Note 3. Oil and Gas Investments On February 1, 2018, the Partnership completed its first purchase (“Acquisition No. 1”) in the Bakken Assets for approximately $90.5 million, including all closing costs and assumed liabilities. On August 31, 2018, the Partnership completed its second purchase of an additional non-operated working interest in the Bakken Assets for approximately $81.3 million, including all closing costs and assumed liabilities. As of September 30, 2024, the Partnership’s ownership of the Bakken Assets consisted of an approximate 5% non-operated working interest in 445 producing wells, and an estimated approximate 1% non-operated working interest in 4 wells in various stages of the drilling and completion process. From September 1, 2017, the effective date of Acquisition No. 1, to September 30, 2024, the Partnership has participated in the drilling of 247 wells, of which 241 have been completed as of September 30, 2024. The Partnership incurred approximately $2.5 million and $9.1 million in capital drilling and completion costs for the nine-month periods ended September 30, 2024 and 2023, respectively. The Partnership anticipates less than $1 million of capital expenditures will be incurred to complete the 4 wells in process as of September 30, 2024. Estimated capital expenditures to complete these 4 wells could be significantly different from amounts actually invested, and the timing of these expenditures is difficult to estimate.

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2024
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation Disclosure [Text Block]	Note 4. Asset Retirement Obligations The Partnership records an asset retirement obligation (“ARO”) and capitalizes the asset retirement costs in oil and natural gas properties in the period in which the ARO is incurred based upon the fair value of an obligation to perform site reclamation, dismantle facilities or plug and abandon wells. After recording these amounts, the ARO is accreted to its future estimated value using an assumed cost of funds and the additional capitalized costs are depreciated on a unit-of-production basis. Inherent in the present value calculation are numerous assumptions and judgments including the ultimate settlement amounts, inflation factors, credit-adjusted discount rates, timing of settlement and changes in the legal, regulatory, environmental and political environments. To the extent future revisions of these assumptions impact the present value of the existing ARO, a corresponding adjustment is made to the oil and natural gas property balance. The changes in the aggregate ARO are as follows: 2024 2023 Balance at January 1 $ 729,315 $ 695,889 Well additions 3,726 3,415 Accretion 23,868 22,293 Revisions - - Balance at September 30 $ 756,909 $ 721,597

Debt

Debt	9 Months Ended
	Sep. 30, 2024
Debt Disclosure [Abstract]
Debt Disclosure [Text Block]	Note 5. Debt On May 2, 2024, the Partnership and its wholly-owned subsidiary, as borrowers, entered into a loan agreement (“Loan Agreement”) with BancFirst (the “Lender”), which provides for a revolving credit facility (“Credit Facility”) with an approved maximum credit amount (“Maximum Credit Amount”) of $20 million, subject to borrowing base restrictions. The Partnership paid one-time commitment and setup fees totaling $100,000 at closing. Total loan costs were approximately $146,000, which were capitalized and will be amortized through the maturity date. The maturity date is March 1, 2026. The Partnership is also subject to an additional fee of 0.50% on any incremental increase to the borrowing base. The Partnership is required to pay an unused facility fee of 0.25% on the unused portion of the Credit Facility, based on borrowings outstanding during a quarter. Under the Loan Agreement, the initial, and current, borrowing base is $10 million. The borrowing base is subject to redetermination semi-annually, on March 1 and September 1, based upon the Lender’s analysis of the Partnership’s proven oil and natural gas reserves. The Lender is also permitted to cause the borrowing base to be redetermined up to two times during a 12-month period. Outstanding borrowings under the Credit Facility cannot exceed the lesser of the borrowing base or the Maximum Credit Amount at any time. The interest rate is equal to the Wall Street Journal Prime Rate plus 0.50%, with a floor of 4.50%. Any further advances under the Credit Facility are to be used to fund capital expenditures for the development of the Partnership’s undrilled acreage. Under the terms of the Loan Agreement, the Partnership may make voluntary prepayments, in whole or in part, at any time with no penalty. The Credit Facility is secured by a mortgage and first lien position on at least 80% of the Partnership’s producing wells. In addition, the Partnership is not required to maintain a risk management program to manage the commodity price risk of the Partnership’s future oil and gas production. However, if the Partnership does elect to speculatively trade and hedge future oil and natural gas production, hedged volumes may not exceed 85% of the Partnership’s anticipated future production. The Credit Facility contains prepayment requirements, customary affirmative and negative covenants and events of default. Certain of the financial covenants include: ● A minimum ratio of trailing 12-month EBITDAX to debt service coverage of 1.20 to 1.0 ● A minimum ratio of current assets to current liabilities of 1.00 to 1.00 The Partnership is permitted to make distributions to its limited partners so long as the Partnership is in compliance with its debt service coverage ratio and no other event of default has occurred. At September 30, 2024, the outstanding balance on the BF Credit Facility was approximately $4.6 million, and the interest rate was 8.50%. The Partnership was in compliance with all covenants as of September 30, 2024. At September 30, 2024, the outstanding balance on the Credit Facility approximated the fair market value of the Credit Facility. The Partnership estimated the fair value of its credit facility by discounting the future cash flows of the instrument at estimated market rates consistent with the maturity of a debt obligation with similar credit terms and credit characteristics, which are Level 3 inputs under the fair value hierarchy. Market rates take into consideration general market conditions and maturity.

Capital Contribution and Partne

Capital Contribution and Partners' Equity	9 Months Ended
	Sep. 30, 2024
Partners' Capital Notes [Abstract]
Partners' Capital Notes Disclosure [Text Block]	Note 6. Capital Contribution and Partners Equity At inception, the General Partner and organizational limited partner made initial capital contributions totaling $1,000 to the Partnership. Upon closing of the minimum offering, the organizational limited partner withdrew its initial capital contribution of $990, the General Partner received Incentive Distribution Rights (defined below), and has been reimbursed for its documented third-party out-of-pocket expenses incurred in organizing the Partnership and offering the common units. The Partnership completed its best-efforts offering of common units as of the close of business on October 24, 2019. As of the conclusion of the offering, the Partnership had completed the sale of approximately 11.0 million common units for total gross proceeds of $218.0 million and proceeds net of offering costs of $204.3 million. Under the agreement with David Lerner Associates, Inc. (the “Managing Dealer”), the Managing Dealer received a total of 6% in selling commissions and a marketing expense allowance based on gross proceeds of the common units sold. The Managing Dealer also has Dealer Manager Incentive Fees (defined below) where the Managing Dealer could receive distributions up to an additional 4% of gross proceeds of the common units sold in the Partnership’s best-efforts offering as outlined in the prospectus based on the performance of the Partnership. Based on the common units sold in the best-efforts offering, the Dealer Manager Incentive Fees are approximately $8.7 million, subject to Payout (defined below). Prior to “Payout,” which is defined below, all of the distributions made by the Partnership, if any, will be paid to the holders of common units. Accordingly, the Partnership will not make any distributions with respect to the Incentive Distribution Rights or the Dealer Manager Incentive Fees to the Managing Dealer until Payout occurs. The Agreement of Limited Partnership of the Partnership (the “Partnership Agreement”) provides that “Payout”, which is defined below, occurs on the day when the aggregate amount distributed with respect to each of the common units equals $20.00 plus the Payout Accrual. The Partnership Agreement defines “Payout Accrual” as 7% per annum simple interest accrued monthly until paid on the Net Investment Amount outstanding from time to time. The Partnership Agreement defines Net Investment Amount initially as $20.00 per common unit, regardless of the amount paid for the common unit. If at any time the Partnership distributes to holders of common units more than the Payout Accrual, the amount the Partnership distributes in excess of the Payout Accrual will reduce the Net Investment Amount. In June 2023, the General Partner declared and paid a special distribution to return $1.60 per common unit of capital to holders of Partnership common units. As described in Income Tax in Note 2. Summary of Significant Accounting Policies, in May 2023 and April 2024, the Partnership paid total withholding taxes of approximately $0.09 per common unit to the state of North Dakota on behalf of its limited partners related to tax years 2021, 2022 and 2023. These withholding tax payments, along with the $1.60 per common unit special distribution to holders of its common units in June 2023, have reduced the Net Investment Amount described above by an approximate total of $1.69 per common unit. All distributions made by the Partnership after Payout, which may include all or a portion of the proceeds of the sale of all or substantially all of the Partnership’s assets, will be made as follows: ● First, (i) to the Record Holders of the Incentive Distribution Rights, 30%; (ii) to the Managing Dealer, the “Dealer Manager Incentive Fees”, 30%, until such time as the Managing Dealer receives 4% of the gross proceeds of the common units sold; and (iii) to the Record Holders of outstanding common units, 40%, pro rata based on their percentage interest. ● Thereafter, (i) to the Record Holders of the Incentive Distribution Rights, 60%; and (ii) to the Record Holders of outstanding common units, 40%, pro rata based on their percentage interest. All items of income, gain, loss and deduction will be allocated to each Partner’s capital account in a manner generally consistent with the distribution procedures outlined above. For the three and nine months ended September 30, 2024, the Partnership paid distributions of $0.320541 and $0.961623 per common unit, or $3.5 million and $10.6 million, respectively. For the three and nine months ended September 30, 2023, the Partnership paid distributions of $0.320541 and $2.618623 per common unit, or $3.5 million and $28.9 million, respectively.

Related Parties

Related Parties	9 Months Ended
	Sep. 30, 2024
Related Party Transactions [Abstract]
Related Party Transactions Disclosure [Text Block]	Note 7. Related Parties The Class A voting members of the General Partner are affiliates of Glade M. Knight, Chairman and Chief Executive Officer and David S. McKenney, Chief Financial Officer. Messrs. Knight and McKenney are also the Chief Executive Officer and Chief Financial Officer of Energy 11 GP, LLC, the general partner of Energy 11, L.P. (“Energy 11”), a limited partnership that also invests in producing and non-producing oil and gas properties on-shore in the United States. The Partnership has, and is expected to continue to engage in, significant transactions with related parties. These transactions cannot be construed to be at arm’s length and the results of the Partnership’s operations may be different than if conducted with non-related parties. The General Partner’s Board of Directors oversees and reviews the Partnership’s related party relationships and is required to approve any significant modifications to any existing related party transactions, as well as any new significant related party transactions. The Partnership will reimburse the General Partner for any costs incurred by the General Partner for certain expenses, which include costs for organizing the Partnership, costs incurred in the offering of the common units and general and administrative costs. The Partnership also agreed to pay the General Partner an advisory fee to manage the day-to-day affairs of the Partnership, including serving as an investment advisor and consultant in connection with the acquisition, development, operation and disposition of oil and gas properties and other assets of the Partnership. In accordance with the Partnership Agreement, subsequent to the Partnership’s first asset purchase, which occurred on February 1, 2018, the Partnership is required to pay quarterly an annual fee of 0.5% of the total gross equity proceeds raised by the Partnership in its best-efforts offering. The management fee that has been or will be paid to the General Partner for the three and nine months ended September 30, 2024 and 2023 was approximately $273,000 and $818,000, respectively, and is included in General and administrative expenses on the consolidated statements of operations. At September 30, 2024, the management fee of approximately $273,000 for the third quarter of 2024 is included in Accounts payable and accrued expenses in the consolidated balance sheets. For the three and nine months ended September 30, 2024, approximately $74,000 and $227,000 of general and administrative costs, respectively, were incurred by a member of the General Partner and have been or will be reimbursed by the Partnership. At September 30, 2024, approximately $74,000 was due to a member of the General Partner and is included in Accounts payable and accrued expenses in the consolidated balance sheets. For the three and nine months ended September 30, 2023, approximately $68,000 and $174,000 of general and administrative costs were incurred by a member of the General Partner and have been or will be reimbursed by the Partnership. On December 1, 2020, the Partnership entered into an Administrative Services Agreement (the “ASA”) with Regional Energy Investors, L.P. d/b/a Regional Energy Management (the “Administrator”) and Energy 11, whereby the Administrator was to provide administrative, operating and professional services necessary and useful to the Partnership. The Administrator also was to assist the General Partner with the day-to-day operations of the Partnership. The Administrator is owned by entities that are controlled by Anthony F. Keating, III and Michael J. Mallick, former Class B members of the General Partner and the former Co-Chief Operating Officers of Energy 11’s general partner. The ASA became effective January 1, 2021. On April 5, 2023, the Partnership and Energy 11 entered into an agreement (the “Agreement”) with Messrs. Knight, McKenney, Keating and Mallick and various affiliates of each, including the Administrator. Pursuant to the Agreement, the ASA was terminated effective immediately, subject to a 60-day transition period to transition the services being provided by the Administrator to Partnership and Energy 11 management. All Administrator costs and expenses were accumulated (based on actual costs incurred with no mark-up or profit to the Administrator) and approved by the Partnership prior to reimbursement. Costs and expenses reimbursed under the ASA included, but were not limited to, employee wages and benefits – including the former president of Energy 11’s general partner, who was paid as an employee of the Administrator, rent for office space and network and information technology support. Other expenses, such as business travel costs and accounting, legal or banking services, were not incurred by the Administrator on behalf of the Partnership without prior express written consent of the Partnership. Costs and expenses attributable to the services performed by the Administrator under the ASA have been reimbursed by the Partnership. For the nine months ended September 30, 2023, approximately $162,000 of costs and expenses subject to the ASA were reimbursed by the Partnership to the Administrator. Also pursuant to the Agreement, the affiliates of Messrs. Keating and Mallick sold (i) their Class B Unit interests in the General Partner; (ii) all interests in the general partner of Energy 11; (iii) all common unit interests in Energy 11; and (iv) all Class B Unit interests in Energy 11 to an affiliate of Mr. Knight and withdrew as members of General Partner and the general partner of Energy 11. Prior to the execution of the Agreement, the General Partner had agreed to pay one-half of its annual management fee to the Administrator in exchange for the services to be provided under the ASA. Therefore, one-half of the management fee for the three months ended March 31, 2023 described above was paid by the General Partner to the Administrator.

Subsequent Events

Subsequent Events	9 Months Ended
	Sep. 30, 2024
Subsequent Events [Abstract]
Subsequent Events [Text Block]	Note 8. Subsequent Events In October 2024, the Partnership declared and paid $1.1 million, or $0.098628 per outstanding common unit, in distributions to its holders of common units.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($)	3 Months Ended						9 Months Ended
	Sep. 30, 2024	Jun. 30, 2024	Mar. 31, 2024	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Sep. 30, 2024	Sep. 30, 2023
Pay vs Performance Disclosure
Net Income (Loss)	$ (782,357)	$ (1,427,564)	$ (1,113,467)	$ 580,244	$ 444,171	$ 3,193,772	$ (3,323,388)	$ 4,218,187

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
	Sep. 30, 2024
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

Accounting Policies, by Policy

Accounting Policies, by Policy (Policies)	9 Months Ended
	Sep. 30, 2024
Accounting Policies [Abstract]
Basis of Accounting, Policy [Policy Text Block]	Basis of Presentation The accompanying unaudited financial statements have been prepared in accordance with the instructions for Article 10 of SEC Regulation S-X. Accordingly, they do not include all of the information required by generally accepted accounting principles (“GAAP”) in the United States for complete financial statements. In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation have been included. These unaudited financial statements should be read in conjunction with the Partnership’s audited December 31, 2023 financial statements included in its 2023 Annual Report on Form 10-K. Operating results for the three and nine months ended September 30, 2024 are not necessarily indicative of the results that may be expected for the twelve-month period ending December 31, 2024.
Cash and Cash Equivalents, Policy [Policy Text Block]	Cash and Cash Equivalents Cash and cash equivalents consist of highly liquid investments with original maturities of three months or less. The fair market value of cash and cash equivalents approximates their carrying value. Cash balances may at times exceed federal depository insurance limits.
Use of Estimates, Policy [Policy Text Block]	Use of Estimates The preparation of financial statements in conformity with United States GAAP requires management to make estimates and assumptions that affect the reported amounts in the consolidated financial statements and accompanying notes. Actual results could differ from those estimates.
Revenue [Policy Text Block]	Revenue Recognition The Partnership is bound by a joint operating agreement with the operator of each of its producing wells. Under the joint operating agreement, the Partnership’s proportionate share of production is marketed at the discretion of the operators. The Partnership typically satisfies its performance obligations upon transfer of control of its products and records the related revenue in the month production is delivered to the purchaser. As the Partnership does not operate its properties, it receives actual oil, natural gas, and NGL sales volumes and prices, net of costs incurred by the operators, two to three months after the date production is delivered by the operator. At the end of each month when the performance obligation is satisfied, the variable consideration can be reasonably estimated and amounts due from the Partnership’s operators are accrued in Accounts Receivable and other current assets in the consolidated balance sheets. Variances between the Partnership’s estimated revenue and actual payments are recorded in the month the payment is received; differences have been and are insignificant. As a result, the variable consideration is not constrained. The Partnership has elected to utilize the practical expedient in ASC 606 that states the Partnership is not required to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Each delivery of product represents a separate performance obligation; therefore, future volumes are wholly unsatisfied, and disclosure of the transaction price allocated to remaining performance obligations is not required. Virtually all of the Partnership’s contracts’ pricing provisions are tied to a market index, with certain adjustments based on, among other factors, whether a well delivers to a gathering or transmission line, quality of oil, natural gas and natural gas liquids and prevailing supply and demand conditions, so that prices fluctuate to remain competitive with other available suppliers.
Concentration Risk, Credit Risk, Policy [Policy Text Block]	Accounts Receivable and Concentration of Credit Risk Substantially all of the Partnership’s accounts receivable are due from the operators of the Partnership’s oil and natural gas properties in North Dakota (the operators have accounts receivable from purchasers of oil, natural gas and NGLs). Oil, natural gas and NGL sales receivables are generally unsecured. This industry and location concentration has the potential to impact the Partnership’s overall exposure to credit risk, in that the purchasers of the Partnership’s oil, natural gas and NGLs and the operators of the properties in which the Partnership has an interest may be similarly affected by changes in economic, industry or other conditions. At September 30, 2024 and December 31, 2023, the Partnership did not reserve for bad debt expense, as all amounts are deemed collectible and the Partnership’s operators do not have a history of non-payment. For the quarter ended September 30, 2024, approximately 93% of the Partnership’s total revenue was generated through sales by four of its 13 operators, respectively. All oil and natural gas producing activities of the Partnership are in North Dakota and represent substantially all of the business activities of the Partnership.
Income Tax, Policy [Policy Text Block]	Income Tax The Partnership is taxed as a partnership for federal and state income tax purposes. Typically, the Partnership has not recorded a provision for income taxes since the liability for such taxes is that of each of the partners rather than the Partnership. In mid-2022, the Partnership was contacted by the state of North Dakota, which asserted that the Partnership has an obligation to make tax payments on behalf of certain non-resident partners. In accordance with its settlements with the state of North Dakota, the Partnership has made payments of (i) approximately $365,000 (approximately $0.033 per common unit) in May 2023 for tax year 2021; (ii) approximately $532,000 (approximately $0.048 per common unit) in April 2024 for tax year 2022; and (iii) approximately $142,000 (approximately $0.013 per common unit) in April 2024 for tax year 2023. The Partnership’s income tax returns are subject to examination by the federal and state taxing authorities, and changes, if any, could adjust the individual income tax of the partners. The Partnership has evaluated whether any material tax position taken will more likely than not be sustained upon examination by the appropriate taxing authority and believes that all such material tax positions taken are supportable by existing laws and related interpretations.
Fair Value of Financial Instruments, Policy [Policy Text Block]	Fair Value of Other Financial Instruments The carrying value of the Partnership’s other financial instruments, including cash and cash equivalents, accounts receivable, accounts payable and accrued expenses, reflect these items’ cost, which approximates fair value based on the timing of the anticipated cash flows, current market conditions and short-term maturity of these instruments.
Earnings Per Share, Policy [Policy Text Block]	Net Income (Loss) Per Common Unit Basic net income (loss) per common unit is computed as net income (loss) divided by the weighted average number of common units outstanding during the period. Diluted net income (loss) per common unit is calculated after giving effect to all potential common units that were dilutive and outstanding for the period. There were no common units with a dilutive effect for the three and nine months ended September 30, 2024 and 2023. As a result, basic and diluted outstanding common units were the same. The Incentive Distribution Rights, as defined below, are not included in net income (loss) per common unit until such time that it is probable Payout (as discussed in Note 6) will occur.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2024
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Asset Retirement Obligations [Table Text Block]	The Partnership records an asset retirement obligation (“ARO”) and capitalizes the asset retirement costs in oil and natural gas properties in the period in which the ARO is incurred based upon the fair value of an obligation to perform site reclamation, dismantle facilities or plug and abandon wells. After recording these amounts, the ARO is accreted to its future estimated value using an assumed cost of funds and the additional capitalized costs are depreciated on a unit-of-production basis. Inherent in the present value calculation are numerous assumptions and judgments including the ultimate settlement amounts, inflation factors, credit-adjusted discount rates, timing of settlement and changes in the legal, regulatory, environmental and political environments. To the extent future revisions of these assumptions impact the present value of the existing ARO, a corresponding adjustment is made to the oil and natural gas property balance. The changes in the aggregate ARO are as follows: 2024 2023 Balance at January 1 $ 729,315 $ 695,889 Well additions 3,726 3,415 Accretion 23,868 22,293 Revisions - - Balance at September 30 $ 756,909 $ 721,597

Partnership Organization (Detai

Partnership Organization (Details) shares in Millions		9 Months Ended	25 Months Ended
	Dec. 30, 2016 USD ($)	Sep. 30, 2024	Oct. 24, 2019 USD ($) shares
Partnership Organization (Details) [Line Items]
Limited Liability Company or Limited Partnership, Business, Formation State	Delaware
Partners' Capital Account, Contributions (in Dollars)	$ 1,000
Number of Operators		13
Bakken Assets [Member]
Partnership Organization (Details) [Line Items]
Number of Operators		13
Best-Efforts Offering [Member]
Partnership Organization (Details) [Line Items]
Partners' Capital Account, Units, Sale of Units (in Shares) | shares			11
Proceeds from Issuance of Common Limited Partners Units (in Dollars)			$ 218,000,000
Proceeds, Net of Offering Costs, from Issuance of Common Limited Partners Units (in Dollars)			$ 204,300,000
Non-operated Completed Wells [Member] | Bakken Assets [Member]
Partnership Organization (Details) [Line Items]
Gas and Oil Area Developed, Net		5%
Oil, Productive Well, Number of Wells, Net		445
Non-operated Wells in the Process of Drilling [Member] | Bakken Assets [Member]
Partnership Organization (Details) [Line Items]
Gas and Oil Area Developed, Net		1%
Oil and Gas, Present Activity, Well in Process of Being Drilled, Number		4

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Details) - USD ($)	1 Months Ended		9 Months Ended
	Apr. 30, 2024	May 31, 2023	Sep. 30, 2024
Summary of Significant Accounting Policies (Details) [Line Items]
Number of Operators			13
Customer Concentration Risk [Member] | Five Operators [Member] | Revenue Benchmark [Member]
Summary of Significant Accounting Policies (Details) [Line Items]
Concentration Risk, Percentage			93%
Number of Operators			4
Tax Year 2021 [Member]
Summary of Significant Accounting Policies (Details) [Line Items]
Distribution Withholding Tax To Limited Partner Per Common Unit		$ 0.09
Tax Year 2021 [Member] | State and Local Jurisdiction [Member]
Summary of Significant Accounting Policies (Details) [Line Items]
Estimated State Tax Withholding For Limited Partners		$ 365,000
Distribution Withholding Tax To Limited Partner Per Common Unit		$ 0.033
Tax Year 2022 [Member]
Summary of Significant Accounting Policies (Details) [Line Items]
Distribution Withholding Tax To Limited Partner Per Common Unit	$ 0.09
Tax Year 2022 [Member] | State and Local Jurisdiction [Member]
Summary of Significant Accounting Policies (Details) [Line Items]
Estimated State Tax Withholding For Limited Partners	$ 532,000
Distribution Withholding Tax To Limited Partner Per Common Unit	$ 0.048
Tax Year 2023 [Member]
Summary of Significant Accounting Policies (Details) [Line Items]
Distribution Withholding Tax To Limited Partner Per Common Unit	$ 0.09
Tax Year 2023 [Member] | State and Local Jurisdiction [Member]
Summary of Significant Accounting Policies (Details) [Line Items]
Estimated State Tax Withholding For Limited Partners	$ 142,000
Distribution Withholding Tax To Limited Partner Per Common Unit	$ 0.013

Oil and Gas Investments (Detail

Oil and Gas Investments (Details) - Bakken Assets [Member] $ in Millions			9 Months Ended		85 Months Ended
	Aug. 31, 2018 USD ($)	Feb. 01, 2018 USD ($)	Sep. 30, 2024 USD ($)	Sep. 30, 2023 USD ($)	Sep. 30, 2024
Acquisition No. 1 [Member]
Oil and Gas Investments (Details) [Line Items]
Business Combination, Consideration Transferred (in Dollars)		$ 90.5
Wells Drilled					247
Oil and Gas, Development Well Drilled, Net Productive, Number					241
Oil and Gas, Cost Incurred, Development Cost (in Dollars)			$ 2.5	$ 9.1
Capital Expenditures Drilling and Completion of Wells (in Dollars)			$ 1
Acquisition No. 2 [Member]
Oil and Gas Investments (Details) [Line Items]
Business Combination, Consideration Transferred (in Dollars)	$ 81.3
Non-operated Completed Wells [Member]
Oil and Gas Investments (Details) [Line Items]
Gas and Oil Area Developed, Net			5%
Oil, Productive Well, Number of Wells, Net			445		445
Non-operated Wells in the Process of Drilling [Member]
Oil and Gas Investments (Details) [Line Items]
Gas and Oil Area Developed, Net			1%
Oil, Productive Well, Number of Wells, Net			4		4

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - Schedule of Asset Retirement Obligations - USD ($)	9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023
Schedule Of Asset Retirement Obligations Abstract
Balance	$ 729,315	$ 695,889
Well additions	3,726	3,415
Accretion	23,868	22,293
Revisions	0	0
Balance	$ 756,909	$ 721,597

Debt (Details)

Debt (Details) - USD ($)		9 Months Ended
	May 02, 2024	Sep. 30, 2024
Debt (Details) [Line Items]
Debt Instrument, Fee	The Partnership paid one-time commitment and setup fees totaling $100,000 at closing. Total loan costs were approximately $146,000, which were capitalized and will be amortized through the maturity date. The maturity date is March 1, 2026. The Partnership is also subject to an additional fee of 0.50% on any incremental increase to the borrowing base. The Partnership is required to pay an unused facility fee of 0.25% on the unused portion of the Credit Facility, based on borrowings outstanding during a quarter.
Line of Credit Facility, Borrowing Capacity, Description	the initial, and current, borrowing base is $10 million. The borrowing base is subject to redetermination semi-annually, on March 1 and September 1, based upon the Lender’s analysis of the Partnership’s proven oil and natural gas reserves.
Line of Credit Facility, Fair Value of Amount Outstanding		$ 4,600,000
Line of Credit Facility, Interest Rate During Period		8.50%
Revolving Credit Facility [Member]
Debt (Details) [Line Items]
Debt Instrument, Face Amount	$ 20,000,000
Debt Issuance Costs, Gross	$ 146,000
Line of Credit Facility, Expiration Date	Mar. 01, 2026
Line of Credit Facility, Commitment Fee Percentage	0.25%
Debt Instrument, Basis Spread on Variable Rate	0.50%
Debt instrument minimum interest rate	4.50%
Line of Credit Facility, Collateral	The Credit Facility is secured by a mortgage and first lien position on at least 80% of the Partnership’s producing wells.
Line of Credit Facility, Covenant Compliance		The Partnership is permitted to make distributions to its limited partners so long as the Partnership is in compliance with its debt service coverage ratio and no other event of default has occurred.

Capital Contribution and Part_2

Capital Contribution and Partners' Equity (Details) - USD ($) $ / shares in Units, shares in Millions

1 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

25 Months Ended

Dec. 30, 2016

Apr. 30, 2024

Jun. 30, 2023

May 31, 2023

Sep. 30, 2024

Jun. 30, 2024

Mar. 31, 2024

Sep. 30, 2023

Jun. 30, 2023

Mar. 31, 2023

Sep. 30, 2024

Sep. 30, 2023

Dec. 31, 2017

Oct. 24, 2019

Capital Contribution and Partners' Equity (Details) [Line Items]

Partners' Capital Account, Contributions

$ 1,000

Partners' Capital Account, Return of Contribution Upon Minimum Offering

$ 990

Partners' Capital Account, Description of Units Sold

Under the agreement with David Lerner Associates, Inc. (the “Managing Dealer”), the Managing Dealer received a total of 6% in selling commissions and a marketing expense allowance based on gross proceeds of the common units sold. The Managing Dealer also has Dealer Manager Incentive Fees (defined below) where the Managing Dealer could receive distributions up to an additional 4% of gross proceeds of the common units sold in the Partnership’s best-efforts offering as outlined in the prospectus based on the performance of the Partnership.

Managing Dealer, Selling Commissions, Percentage

6%

Managing Dealer, Maximum Contingent Incentive Fee on Gross Proceeds, Percentage

4%

Managing Dealer, Maximum Contingent Incentive Fee on Gross Proceeds

$ 8,700,000

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$ 1.69

$ 0.320541

$ 0.320541

$ 0.961623

$ 2.618623

Distribution Made to Limited Partner, Cash Distributions Paid

$ 3,536,074

$ 3,536,073

$ 3,536,073

$ 3,536,074

$ 21,501,000

$ 3,850,473

$ 10,608,220

$ 28,887,547

Best-Efforts Offering [Member]

Capital Contribution and Partners' Equity (Details) [Line Items]

Partners' Capital Account, Units, Sale of Units

11

Proceeds from Issuance of Common Limited Partners Units

$ 218,000,000

Proceeds, Net of Offering Costs, from Issuance of Common Limited Partners Units

$ 204,300,000

Tax Year 2021 [Member]

Capital Contribution and Partners' Equity (Details) [Line Items]

Distribution Withholding Tax To Limited Partner Per Common Unit

$ 0.09

Tax Year 2022 [Member]

Capital Contribution and Partners' Equity (Details) [Line Items]

Distribution Withholding Tax To Limited Partner Per Common Unit

$ 0.09

Tax Year 2023 [Member]

Capital Contribution and Partners' Equity (Details) [Line Items]

Distribution Withholding Tax To Limited Partner Per Common Unit

$ 0.09

Return of Capital [Member]

Capital Contribution and Partners' Equity (Details) [Line Items]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$ 1.6

Related Parties (Details)

Related Parties (Details) - USD ($)	3 Months Ended			9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Mar. 31, 2023	Sep. 30, 2024	Sep. 30, 2023
Related Parties (Details) [Line Items]
Related Party Transaction, Description of Transaction				subsequent to the Partnership’s first asset purchase, which occurred on February 1, 2018, the Partnership is required to pay quarterly an annual fee of 0.5% of the total gross equity proceeds raised by the Partnership in its best-efforts offering.
General Partner [Member]
Related Parties (Details) [Line Items]
Selling, General and Administrative Expense	$ 74,000	$ 68,000		$ 227,000	$ 174,000
Affiliated Entity [Member]
Related Parties (Details) [Line Items]
Selling, General and Administrative Expense					$ 162,000
Administrative Service Agreement [Member]
Related Parties (Details) [Line Items]
Related Party, Administrative Service Agreement			the execution of the Agreement, the General Partner had agreed to pay one-half of its annual management fee to the Administrator in exchange for the services to be provided under the ASA
Management Fee [Member] | General Partner [Member]
Related Parties (Details) [Line Items]
Selling, General and Administrative Expense	273,000			818,000
Management Fee [Member] | General Partner [Member]
Related Parties (Details) [Line Items]
Other Liabilities, Current	273,000			273,000
General and Administrative Expense [Member] | General Partner [Member]
Related Parties (Details) [Line Items]
Other Liabilities, Current	$ 74,000			$ 74,000

Subsequent Events (Details)

Subsequent Events (Details) - Subsequent Event [Member] $ / shares in Units, $ in Millions	1 Months Ended
	Oct. 31, 2024 USD ($) $ / shares
Subsequent Events (Details) [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid | $	$ 1.1
Distribution Made to Limited Partner, Distributions Paid, Per Unit | $ / shares	$ 0.098628