Document and Entity Information
Document and Entity Information | 3 Months Ended |
Mar. 31, 2018shares | |
Document And Entity Information [Abstract] | |
Document Type | 10-Q |
Amendment Flag | false |
Document Period End Date | Mar. 31, 2018 |
Document Fiscal Year Focus | 2,018 |
Document Fiscal Period Focus | Q1 |
Entity Registrant Name | DGOC Series 18C LP |
Entity Central Index Key | 1,711,736 |
Current Fiscal Year End Date | --12-31 |
Entity Filer Category | Smaller Reporting Company |
Entity Common Stock, Shares Outstanding | 0 |
CONDENSED BALANCE SHEETS
CONDENSED BALANCE SHEETS - USD ($) | Mar. 31, 2018 | Dec. 31, 2017 |
Current assets: | ||
Cash | $ 0 | $ 0 |
Accounts receivable trade–affiliate | 1,534,800 | 1,325,700 |
Total current assets | 1,534,800 | 1,325,700 |
Natural gas properties, net | 28,273,600 | 28,788,400 |
Long-term asset retirement receivable-affiliate | 365,200 | 317,800 |
Total assets | 30,173,600 | 30,431,900 |
Current liabilities: | ||
Accrued liabilities | 29,000 | 28,900 |
Total current liabilities | 29,000 | 28,900 |
Asset retirement obligations | 2,807,700 | 2,773,200 |
Commitments and contingencies (Note 4) | ||
Partners’ capital: | ||
Managing general partner’s interest | 2,461,000 | 2,426,400 |
Limited partners’ interest (22,928.90 units) | 24,875,900 | 25,203,400 |
Total partners’ capital | 27,336,900 | 27,629,800 |
Total liabilities and partners’ capital | $ 30,173,600 | $ 30,431,900 |
CONDENSED BALANCE SHEETS (Paren
CONDENSED BALANCE SHEETS (Parenthetical) - shares | Mar. 31, 2018 | Mar. 31, 2017 |
Statement of Financial Position [Abstract] | ||
Limited partners' units | 22,928.90 | 22,928.90 |
CONDENSED STATEMENTS OF OPERATI
CONDENSED STATEMENTS OF OPERATIONS - USD ($) | 3 Months Ended | |
Mar. 31, 2018 | Mar. 31, 2017 | |
REVENUES | ||
Natural gas | $ 1,570,700 | $ 2,012,800 |
Total revenues | 1,570,700 | 2,012,800 |
COSTS AND EXPENSES | ||
Production | 560,000 | 567,300 |
Depletion | 514,800 | 537,700 |
Accretion of asset retirement obligations | 34,500 | 39,100 |
General and administrative | 40,700 | 32,100 |
Total costs and expenses | 1,150,000 | 1,176,200 |
Net income | 420,700 | 836,600 |
Allocation of net income: | ||
Managing general partner | 233,800 | 338,500 |
Limited partners | $ 186,900 | $ 498,100 |
Net income per limited partnership unit (in dollars per share) | $ 8 | $ 22 |
CONDENSED STATEMENT OF CHANGES
CONDENSED STATEMENT OF CHANGES IN PARTNERS' CAPITAL - 3 months ended Mar. 31, 2018 - USD ($) | Total | Managing General Partner | Limited Partners |
Beginning balance at Dec. 31, 2017 | $ 27,629,800 | $ 2,426,400 | $ 25,203,400 |
Participation in revenues, costs and expenses: | |||
Net production revenues | 1,010,700 | 300,200 | 710,500 |
Depletion | (514,800) | (45,400) | (469,400) |
Accretion of asset retirement obligations | (34,500) | (9,600) | (24,900) |
General and administrative | (40,700) | (11,400) | (29,300) |
Net income | 420,700 | 233,800 | 186,900 |
Distributions to partners | (713,600) | (199,200) | (514,400) |
Ending balance at Mar. 31, 2018 | $ 27,336,900 | $ 2,461,000 | $ 24,875,900 |
CONDENSED STATEMENTS OF CASH FL
CONDENSED STATEMENTS OF CASH FLOWS - USD ($) | 3 Months Ended | |
Mar. 31, 2018 | Mar. 31, 2017 | |
Cash flows from operating activities: | ||
Net income | $ 420,700 | $ 836,600 |
Adjustments to reconcile net income to net cash provided by operating activities: | ||
Depletion | 514,800 | 537,700 |
Accretion of asset retirement obligations | 34,500 | 39,100 |
Changes in operating assets and liabilities: | ||
Increase in accounts receivable trade-affiliate | (209,100) | (592,900) |
Increase in asset retirement receivable-affiliate | (47,400) | (15,600) |
Increase (decrease) in accrued liabilities | 100 | (5,400) |
Net cash provided by operating activities | 713,600 | 799,500 |
Cash flows from investing activities: | ||
Net cash provided by investing activities | 0 | 0 |
Cash flows from financing activities: | ||
Distributions to partners | (713,600) | (582,200) |
Net cash used in financing activities | (713,600) | (582,200) |
Net change in cash | 0 | 217,300 |
Cash at beginning of period | 0 | 249,000 |
Cash at end of period | $ 0 | $ 466,300 |
Description of Business
Description of Business | 3 Months Ended |
Mar. 31, 2018 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
DESCRIPTION OF BUSINESS | DESCRIPTION OF BUSINESS DGOC Series 18(C), L.P. (the "Partnership") is a Delaware limited partnership, formed on July 6, 2017 and includes the Appalachian-based assets that were previously included within Atlas Resources Public 18-2009(C), L.P. ("Predecessor Partnership") that was formed on June 9, 2009 and was then managed by Atlas Resources, LLC ("Atlas" or "Previous MGP"). DGOC Partnership Holdings, LLC now serves as its Managing General Partner (“DGOC Holdings” or the “MGP”) and certain affiliates of the MGP serving as our Operator ("Operator"). DGOC Holdings is an indirect subsidiary of Diversified Gas & Oil, PLC (“Diversified”; AIM: DGOC). Unless the context otherwise requires, references below to “the Partnership,” “we,” “us,” “our” and “our company”, refer to DGOC Series 18(C), L.P. The Partnership has drilled and currently operates wells located in Pennsylvania and Tennessee. We have no employees and rely on our MGP to staff and manage our operations, which in turn, relied on Atlas Energy Group, LLC, Titan’s parent company, for administrative services through a Transition Services Agreement ("TSA") effective through December 31, 2017. Since the expiration of the TSA, staffing is provided by an affiliate of Diversified. The Partnership’s operating cash flows are generated from its wells, which produce natural gas. Produced natural gas is then delivered to market through third-party gas gathering systems. The Partnership intends to produce its wells until they are sold, depleted or become uneconomical to produce, at which time they will be plugged and abandoned. The Partnership does not expect to drill additional wells and expects no additional funds will be required for drilling. The economic viability of the Partnership’s production is based on a variety of factors including proved developed reserves that it can expect to recover through existing wells with existing equipment and operating methods or in which the cost of additional required extraction equipment is relatively minor compared to the cost of a new well; and through currently installed extraction equipment and related infrastructure which is operational at the time of the reserves estimate (if the extraction is by means not involving drilling, completing or reworking a well). There are numerous uncertainties inherent in estimating quantities of proven reserves and in projecting future net revenues. The prices at which the Partnership’s natural gas will be sold are uncertain and the Partnership is not guaranteed a specific price for the sale of its production. Changes in natural gas prices have a significant impact on the Partnership’s cash flow and the value of its reserves. Lower natural gas prices may, in addition to decreasing the Partnership’s revenues, also reduce the amount of natural gas that the Partnership can produce economically. Liquidity and Capital Resources The Partnership is generally limited to the amount of funds generated by the cash flow from its operations to fund its obligations and make distributions, if any, to its partners. Prices for natural gas began to decline significantly during the fourth quarter of 2014 and continue to remain low, on a relative basis, in 2018. These lower commodity prices negatively impact the Partnership’s revenues, earnings and cash flows. In addition, low commodity prices place downward pressure on the Partnership’s proved natural gas reserves as some volumes in the later years of the life of the well become uneconomic to produce at the lower prices. The MGP continues to implement various cost saving measures to reduce the Partnership’s operating and general and administrative costs, including renegotiating contracts with contractors, suppliers and service providers, and deferring and/or eliminating discretionary costs. The MGP will continue to be strategic in managing the Partnership’s cost structure and, in turn, liquidity to meet its operating needs. To the extent commodity prices remain low or decline further, or the Partnership experiences other disruptions in the industry, the Partnership’s ability to fund its operations and make distributions may be further impacted, and could result in the liquidation of the Partnership’s operations. |
Summary of Significant Accounti
Summary of Significant Accounting Policies | 3 Months Ended |
Mar. 31, 2018 | |
Accounting Policies [Abstract] | |
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES These condensed financial statements are unaudited, but in the opinion of management, reflect all adjustments necessary for a fair presentation of results for the interim periods presented. All adjustments are of a normal recurring nature unless disclosed otherwise. Interim period results are not necessarily indicative of results to be expected for the full year. These condensed financial statements have been prepared in accordance with rules of the Securities and Exchange Commission (“SEC”) and do not include all the information and disclosures required by accounting principles generally accepted in the United States (“GAAP”) for complete financial statements. They should be read in conjunction with the financial statements for the year ended December 31, 2017 and notes thereto included in our 2017 Annual Report on Form 10-K, which include a summary of the significant accounting policies. Use of Estimates The preparation of the Partnership’s condensed financial statements in conformity with U.S. GAAP requires the MGP to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities that exist at the date of the Partnership’s condensed financial statements, as well as the reported amounts of revenues and costs and expenses during the reporting periods. The Partnership’s condensed financial statements are based on a number of significant estimates, including the revenue and expense accruals, depletion, impairments and the probability of forecasted transactions. The natural gas industry principally conducts its business by processing actual transactions as many as 60 days after the month of delivery. Consequently, the most recent two months’ financial results were recorded using estimated volumes and contract market prices . Actual results could differ from those estimates. Natural Gas Properties The following is a summary of natural gas properties at the dates indicated: March 31, December 31, Change 2018 2017 $ % Proved properties: Leasehold interests $ 1,660,400 $ 1,660,400 $ — — % Wells and related equipment 210,127,800 210,127,800 — — % Total natural gas properties 211,788,200 211,788,200 — — % Accumulated depletion and impairment (183,514,600 ) (182,999,800 ) (514,800 ) — % Natural gas properties, net $ 28,273,600 $ 28,788,400 $ (514,800 ) (2 )% We review our natural gas producing properties for impairment whenever events or changes in circumstances indicate that the carrying amount of such properties may not be recoverable. The review of the Partnership’s natural gas properties is done on a field-by-field basis by determining if the historical cost of proved properties less the applicable accumulated depletion and impairment is less than the estimated expected undiscounted future cash flows including salvage. If the carrying value exceeds the expected future cash flows, an impairment loss is recognized for the difference between the estimated fair market value and the carrying value of the assets. Events or changes in circumstances that would indicate the need for impairment testing include, among other factors: operating losses; unused capacity; market value declines; technological developments resulting in obsolescence; changes in demand for products manufactured by others utilizing our services or for our products; changes in competition and competitive practices; uncertainties associated with the United States and world economies; changes in the expected level of environmental capital, operating or remediation expenditures; and changes in governmental regulations or actions. There was no triggering event in the first quarter of 2018 that would cause us to believe the value of natural gas producing properties should be impaired. Recently Adopted Accounting Standards In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). The standard requires an entity to identify all customer contracts and their corresponding performance obligations, determine the transaction price and its allocation, at the entity level, and to recognize revenue upon fulfillment of the performance obligation. ASU 2014-09 replaces most of the existing revenue recognition requirements in GAAP. The Partnership adopted the standard on January 1, 2018 using the modified retrospective method as of the adoption date. The new standard did not have a material impact on the Partnership's Financial Statements other than requiring new disclosures. Revenue Recognition The Partnership sells natural gas under multiple purchaser contracts. The Partnership’s performance obligation, to the customer, includes the production and sale of natural gas at multiple delivery points. The sales contracts are based on blended rate pricing provisions with fixed and variable components. The fixed component is well defined, under each purchaser contract, and is tied to base production levels. The variable component is generally tied to a regional market index and is received for anything in excess of the base production levels outlined under each customer contract. Under certain agreements, the Partnership’s natural gas sales are delivered to midstream processing entities and DGOC Partnership Holdings, LLC is in control of the gas asset at all points of sale to the purchaser(s). The gathering fees charged, by the midstream processing agents, are paid at the gross rate, by the Partnership as production costs which is consistent with prior reporting periods. The Partnership recognizes revenue and related accounts receivable in the month the performance obligation has been met. However; the settlement statements may not be received from the purchaser for 30-90 days after the production is delivered. As a result, DGOC Partnership Holdings, LLC is required to estimate and accrue for the current month’s revenue using well defined processes that have historically demonstrated close proximities to actual payments. The current revenue accruals have existing internal controls and are evaluated, for accuracy, on a regular basis. Revenues from the production of natural gas, in which the Partnership has an interest with other producers, are recognized on the basis of its percentage ownership of working interest and/or overriding royalty. The MGP and its affiliates perform all administrative and management functions for the Partnership, including billing revenues and paying expenses. |
Certain Relationships and Relat
Certain Relationships and Related Party Transactions | 3 Months Ended |
Mar. 31, 2018 | |
Related Party Transactions [Abstract] | |
CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS | CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS The Partnership has entered into the following significant transactions with the MGP and its affiliates as provided under its Partnership Agreement. Administrative costs, which are included in general and administrative expenses in the Partnership’s condensed statements of operations, are payable at $75 per well per month. Monthly well supervision fees, which are included in production expenses in the Partnership’s condensed statements of operations, are payable at $975 per well per month for Marcellus wells and for all other wells a fee of $392 is charged per well per month for operating and maintaining the wells. Well supervision fees are proportionately reduced to the extent the Partnership does not acquire 100% of the working interest in a well. Transportation fees are included in production expenses in the Partnership’s condensed statements of operations and are generally payable at 16% of the natural gas sales price or $0.35 per Mcf, whichever is greater. Direct costs, which are included in production and general administrative expenses in the Partnership’s condensed statements of operations, are payable to the MGP and its affiliates as reimbursement for all costs expended on the Partnership’s behalf. The following table provides information with respect to these costs and the periods incurred: Three Months Ended Change 2018 2017* $ % Administrative fees $ 13,600 $ 13,600 $ — — % Supervision fees 177,400 177,400 $ — — % Transportation fees 255,500 274,900 $ (19,400 ) (7 )% Direct costs 154,200 133,500 $ 20,700 16 % Total $ 600,700 $ 599,400 $ 1,300 — % * Amounts paid to the Previous MGP. The MGP and its affiliates perform all administrative and management functions for the Partnership, including billing revenues and paying expenses. Accounts receivable trade-affiliate on the Partnership’s balance sheets includes the net production revenues due from the MGP. |
Commitments and Contingencies
Commitments and Contingencies | 3 Months Ended |
Mar. 31, 2018 | |
Commitments and Contingencies Disclosure [Abstract] | |
COMMITMENTS AND CONTINGENCIES | COMMITMENTS AND CONTINGENCIES General Commitments Subject to certain conditions, investor partners may present their interests for purchase by the MGP. The purchase price is calculated by the MGP in accordance with the terms of the partnership agreement. The MGP is not obligated to purchase more than 5% of the total outstanding units in any calendar year. In the event that the MGP is unable to obtain the necessary funds, it may suspend its purchase obligation. Beginning one year after each of the Partnership’s wells has been placed into production, the MGP, as Operator, may retain $200 per month per well to cover estimated future plugging and abandonment costs. As of March 31, 2018 , the Operator has withheld $365,200 of net production revenue for future plugging and abandonment costs. Environmental risk is inherent to natural gas operations, and we and our affiliates may be, at times, subject to potential environmental remediation liability. We manage this environmental risk through appropriate environmental policies and practices to minimize any impact our operations may have on the environment. To the extent that we are unable to recover payment for environmental liabilities from insurance or other potentially responsible parties, we will be responsible for payment of liabilities arising from environmental incidents associated with the operating activities of our natural gas operations. Legal Proceedings The Partnership and affiliates of the MGP and their subsidiaries are party to various routine legal proceedings arising out of the ordinary course of its business. The MGP believes that none of these actions, individually or in the aggregate, will have a material adverse effect on the Partnership’s or the MGP’s financial condition or results of operations. |
Summary of Significant Accoun11
Summary of Significant Accounting Policies (Policies) | 3 Months Ended |
Mar. 31, 2018 | |
Accounting Policies [Abstract] | |
Use of Estimates | Use of Estimates The preparation of the Partnership’s condensed financial statements in conformity with U.S. GAAP requires the MGP to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities that exist at the date of the Partnership’s condensed financial statements, as well as the reported amounts of revenues and costs and expenses during the reporting periods. The Partnership’s condensed financial statements are based on a number of significant estimates, including the revenue and expense accruals, depletion, impairments and the probability of forecasted transactions. The natural gas industry principally conducts its business by processing actual transactions as many as 60 days after the month of delivery. Consequently, the most recent two months’ financial results were recorded using estimated volumes and contract market prices . Actual results could differ from those estimates. |
Natural Gas Properties | We review our natural gas producing properties for impairment whenever events or changes in circumstances indicate that the carrying amount of such properties may not be recoverable. The review of the Partnership’s natural gas properties is done on a field-by-field basis by determining if the historical cost of proved properties less the applicable accumulated depletion and impairment is less than the estimated expected undiscounted future cash flows including salvage. If the carrying value exceeds the expected future cash flows, an impairment loss is recognized for the difference between the estimated fair market value and the carrying value of the assets. Events or changes in circumstances that would indicate the need for impairment testing include, among other factors: operating losses; unused capacity; market value declines; technological developments resulting in obsolescence; changes in demand for products manufactured by others utilizing our services or for our products; changes in competition and competitive practices; uncertainties associated with the United States and world economies; changes in the expected level of environmental capital, operating or remediation expenditures; and changes in governmental regulations or actions. |
Recently Adopted Accounting Standards | Recently Adopted Accounting Standards In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). The standard requires an entity to identify all customer contracts and their corresponding performance obligations, determine the transaction price and its allocation, at the entity level, and to recognize revenue upon fulfillment of the performance obligation. ASU 2014-09 replaces most of the existing revenue recognition requirements in GAAP. The Partnership adopted the standard on January 1, 2018 using the modified retrospective method as of the adoption date. The new standard did not have a material impact on the Partnership's Financial Statements other than requiring new disclosures. |
Revenue Recognition | Revenue Recognition The Partnership sells natural gas under multiple purchaser contracts. The Partnership’s performance obligation, to the customer, includes the production and sale of natural gas at multiple delivery points. The sales contracts are based on blended rate pricing provisions with fixed and variable components. The fixed component is well defined, under each purchaser contract, and is tied to base production levels. The variable component is generally tied to a regional market index and is received for anything in excess of the base production levels outlined under each customer contract. Under certain agreements, the Partnership’s natural gas sales are delivered to midstream processing entities and DGOC Partnership Holdings, LLC is in control of the gas asset at all points of sale to the purchaser(s). The gathering fees charged, by the midstream processing agents, are paid at the gross rate, by the Partnership as production costs which is consistent with prior reporting periods. The Partnership recognizes revenue and related accounts receivable in the month the performance obligation has been met. However; the settlement statements may not be received from the purchaser for 30-90 days after the production is delivered. As a result, DGOC Partnership Holdings, LLC is required to estimate and accrue for the current month’s revenue using well defined processes that have historically demonstrated close proximities to actual payments. The current revenue accruals have existing internal controls and are evaluated, for accuracy, on a regular basis. Revenues from the production of natural gas, in which the Partnership has an interest with other producers, are recognized on the basis of its percentage ownership of working interest and/or overriding royalty. The MGP and its affiliates perform all administrative and management functions for the Partnership, including billing revenues and paying expenses. |
Summary of Significant Accoun12
Summary of Significant Accounting Policies (Tables) | 3 Months Ended |
Mar. 31, 2018 | |
Accounting Policies [Abstract] | |
Summary of Gas Properties | The following is a summary of natural gas properties at the dates indicated: March 31, December 31, Change 2018 2017 $ % Proved properties: Leasehold interests $ 1,660,400 $ 1,660,400 $ — — % Wells and related equipment 210,127,800 210,127,800 — — % Total natural gas properties 211,788,200 211,788,200 — — % Accumulated depletion and impairment (183,514,600 ) (182,999,800 ) (514,800 ) — % Natural gas properties, net $ 28,273,600 $ 28,788,400 $ (514,800 ) (2 )% |
Certain Relationships and Rel13
Certain Relationships and Related Party Transactions (Tables) | 3 Months Ended |
Mar. 31, 2018 | |
Related Party Transactions [Abstract] | |
Certain Relationships and Related Party Transactions | The following table provides information with respect to these costs and the periods incurred: Three Months Ended Change 2018 2017* $ % Administrative fees $ 13,600 $ 13,600 $ — — % Supervision fees 177,400 177,400 $ — — % Transportation fees 255,500 274,900 $ (19,400 ) (7 )% Direct costs 154,200 133,500 $ 20,700 16 % Total $ 600,700 $ 599,400 $ 1,300 — % * Amounts paid to the Previous MGP. |
Summary of Significant Accoun14
Summary of Significant Accounting Policies - Summary of Gas and Oil Properties (Details) - USD ($) | 3 Months Ended | |
Mar. 31, 2018 | Dec. 31, 2017 | |
Property, Plant and Equipment [Line Items] | ||
Natural gas properties | $ 211,788,200 | $ 211,788,200 |
Accumulated depletion and impairment | (183,514,600) | (182,999,800) |
Natural gas properties, net | 28,273,600 | 28,788,400 |
Natural gas properties, $ change | 0 | |
Accumulated depletion and impairment, $ change | (514,800) | |
Natural gas properties, net, $ change | $ (514,800) | |
Natural gas properties, % change | 0.00% | |
Accumulated depletion and impairment, % change | 0.00% | |
Natural gas properties, net, % change | (2.00%) | |
Leasehold interests | ||
Property, Plant and Equipment [Line Items] | ||
Natural gas properties | $ 1,660,400 | 1,660,400 |
Natural gas properties, $ change | $ 0 | |
Natural gas properties, % change | 0.00% | |
Wells and related equipment | ||
Property, Plant and Equipment [Line Items] | ||
Natural gas properties | $ 210,127,800 | $ 210,127,800 |
Natural gas properties, $ change | $ 0 | |
Natural gas properties, % change | 0.00% |
Certain Relationships and Rel15
Certain Relationships and Related Party Transactions (Details) - MGP and Affiliates | 3 Months Ended |
Mar. 31, 2018USD ($)$ / mo | |
General and administrative expenses | |
Related Party Transaction [Line Items] | |
Monthly administrative costs per well | 75 |
Production | |
Related Party Transaction [Line Items] | |
Transportation fee rate as percentage of natural gas sales price | 16.00% |
Transportation fees (USD per Mcf) | $ | $ 0.35 |
Production | Marcellus wells | |
Related Party Transaction [Line Items] | |
Monthly supervision fees per well | 975 |
Production | Other Wells | |
Related Party Transaction [Line Items] | |
Monthly supervision fees per well | 392 |
Certain Relationships and Rel16
Certain Relationships and Related Party Transactions - Costs and the Periods Incurred (Details) - MGP and Affiliates - USD ($) | 3 Months Ended | |
Mar. 31, 2018 | Mar. 31, 2017 | |
Related Party Transaction [Line Items] | ||
Related party transaction, expenses from transactions with related party | $ 600,700 | $ 599,400 |
Related party transactions, $ change | $ 1,300 | |
Related party transactions, % change | 0.00% | |
Administrative fees | ||
Related Party Transaction [Line Items] | ||
Related party transaction, expenses from transactions with related party | $ 13,600 | 13,600 |
Related party transactions, $ change | $ 0 | |
Related party transactions, % change | 0.00% | |
Supervision fees | ||
Related Party Transaction [Line Items] | ||
Related party transaction, expenses from transactions with related party | $ 177,400 | 177,400 |
Related party transactions, $ change | $ 0 | |
Related party transactions, % change | 0.00% | |
Transportation fees | ||
Related Party Transaction [Line Items] | ||
Related party transaction, expenses from transactions with related party | $ 255,500 | 274,900 |
Related party transactions, $ change | $ (19,400) | |
Related party transactions, % change | (7.00%) | |
Direct costs | ||
Related Party Transaction [Line Items] | ||
Related party transaction, expenses from transactions with related party | $ 154,200 | $ 133,500 |
Related party transactions, $ change | $ 20,700 | |
Related party transactions, % change | 16.00% |
Commitments and Contingencies (
Commitments and Contingencies (Details) | 3 Months Ended |
Mar. 31, 2018USD ($)$ / mo | |
Commitments and Contingencies Disclosure [Abstract] | |
Investor partners ownership interest presented for purchase by the MGP, maximum percentage | 5.00% |
Operator fee per well to cover estimated future plugging and abandonment costs, monthly | $ / mo | 200 |
Net production revenue for future plugging and abandonment costs | $ | $ 365,200 |