The unrealized gains on the Fund's investments in federal agency mortgage-backed securities were the result of fluctuations in market interest rates. The contractual cash flows of those investments are guaranteed by an agency of the U.S. government. Unrealized gains or losses on available-for-sale debt securities are reported in other comprehensive income until realized.

For all investments, interest income is accrued as earned and amortization of premium or discount, if any, is included in interest income. Interest earned on the account will become part of the salvage fund. There are no restrictions on withdrawals from the salvage fund.

Asset Retirement Obligations

For oil and gas properties, there are obligations to perform removal and remediation activities when the properties are retired. Upon the determination that a property is either proved or dry, a retirement obligation is incurred. The Fund recognizes the fair value of a liability for an asset retirement obligation in the period incurred.incurred based on expected future cash outflows required to satisfy the obligation discounted at the Fund’s credit-adjusted risk-free rate. Plug and abandonment costs associated with unsuccessful projects are expensed as dry-hole costs. Annually, or more frequently if an event occurs that would dictate a change in assumptions or estimates underlying the obligations, the Fund reassesses its asset retirement obligations to determine whether any revisions to the obligations are necessary. The Fund maintains a salvage fund to provide for the funding of future asset retirement obligations.

Revenue Recognition

Oil and gas revenues are recognized at the point when control of oil and natural gas is transferred to the customers. Natural gas liquid sales are included within gas sales. The Fund’s oil and natural gas generally isare sold to its customers at prevailing market prices based on an index in which the prices are published, adjusted for pricing differentials, quality of oil and pipeline allowances. Under the Fund’s oil and natural gas contracts, each unit of oil and natural gas represents a separate performance obligation; therefore, future volumes are wholly unsatisfied and the transaction price related to the remaining performance obligations is the variable index-based price attributable to each unit of oil and natural gas that is transferred to the customer. The Fund invoices customers once its performance obligations have been satisfied, at which point the payment is unconditional. Accordingly, the Fund’s oil and natural gas contracts do not give rise to contract assets or liabilities. The receivables related to the Fund’s oil and gas revenue are included within “Production receivable” on the Fund’s balance sheets.

Other revenue is generated from the Fund’s production handling, gathering and operating services agreement with an affiliated entity and other third parties. The Fund simply earns a fee for its services and recognizes these fees as revenue at the time its performance obligations are satisfied as the control of oil and natural gas is never transferred to the Fund, thus there are no unsatisfied performance obligations. The Fund’s project operator performs joint interest billing once the performance obligations have been satisfied, at which point the payment is unconditional. Accordingly, the Fund’s production handling, gathering and operating services agreement with an affiliated entity and other third parties does not give rise to contract assets or liabilities. The receivables related to the Fund’s proportionate share of revenue from an affiliate are included within “Due from affiliate” on the Fund’s balance sheets. The receivables related to the Fund’s proportionate share of revenue from third parties are presented as a reduction from “Due to operator” on the Fund’s balance sheets. The receivables are settled by issuance of a non-cash credit from the Beta Project operator to the Fund when the operator performs the joint interest billing of the lease operating expenses due from the Fund.

The Fund also has an estimation process for revenue and related accruals, and any identified difference between its revenue estimates and actual revenue havehas not been significant. ForDuring each of the period ending March 31,three and six months ended June 30, 2019 and 2018, revenue recognized from performance obligations satisfied in previous periods iswas not significant.

Impairment of Long-Lived Assets

The Fund reviews the carrying value of its oil and gas properties for impairment whenever events and circumstances indicate that the recorded carrying value of the assets may not be recoverable. Impairments are determined by comparing estimated future net undiscounted cash flows to the carrying value of the assets at the time of the review. If the carrying value exceeds the estimated future net undiscounted cash flows, the carrying value of the asset is written down to fair value, which is determined using valuation techniques that include both market and income approaches and use Level 3 inputs. The fair value determinations require considerable judgment and are sensitive to change. Different pricing assumptions, reserve estimates or discount rates could result in a different calculated impairment.

There were no impairments of oil and gas properties during each of the three and six months ended March 31,June 30, 2019 and 2018. Fluctuations in oil and natural gas commodity prices may impact the fair value of the Fund’s oil and gas properties. If oil and natural gas commodity prices decline, even if only for a short period of time, it is possible that impairments of oil and gas properties will occur.

Recent Accounting Pronouncements

In August 2018, the Financial Accounting Standards Board (“FASB”) issued accounting guidance on fair value measurement, which adds, among other things, disclosure requirements for the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. This accounting guidance is effective for the Fund in the first quarter 2020 with early adoption permitted. The Fund does not expect this accounting guidance will have a material impact on its financial statements upon adoption.

In February 2016, the FASB issued accounting guidance on leases as amended on January 2018 and July 2018, which requires an entity to recognize all lease assets and liabilities with a term greater than one year on the balance sheet, disclose key quantitative and qualitative information about leasing arrangements, and permits an entity not to evaluate existing or expired land easements that were not previously assessed under the existing lease guidance. The accounting guidance does not apply to leases of mineral rights to explore for or use of oil and natural gas. The accounting guidance was effective for the Fund beginning January 1, 2019. Although the Fund, as a non-operator, does not enter into lease agreements to support its operations, the Fund completed its evaluation of existing contracts that may have a lease impact and embedded lease features to determine the contracts to which the new guidance applies. Based on this evaluation, the Fund determined its existing contracts did not meet the definition of leases under the new accounting guidance and therefore, did not qualify for lease accounting.

Pursuant to the terms of the LLC Agreement, the Manager is entitled to receive an annual management fee, payable monthly, of 2.5% of total capital contributions, net of cumulative dry-hole and related well costs incurred by the Fund, however, the Manager is permitted to waive the management fee at its own discretion. Therefore, the management fee may be temporarily waived to accommodate the Fund’s short-term commitments. Management fees during each of the three and six months ended March 31,June 30, 2019 and 2018 were $0.1 million.million and $0.2 million, respectively.

The Manager is also entitled to receive 15% of the cash distributions from operations made by the Fund. Distributions paid to the Manager during each of the three and six months ended March 31,June 30, 2019 were $0.1 million. The Fund did not pay distributions during the three and six months ended March 31,June 30, 2018.

The Fund utilizes Beta Sales and Transport, LLC, a wholly-owned subsidiary of the Manager, to facilitate the transportation and sale of oil and natural gas produced from the Beta Project.

During 2016, the Fund and other third-party working interest owners in the Beta Project entered into a production handling, gathering and operating services agreement (“PHA”) with Ridgewood Claiborne, LLC, a wholly-owned entity of Ridgewood Energy Oil & Gas Fund II, L.P. (“Institutional Fund II”), and other third-party working interest owners in the Claiborne Project. Institutional Fund II is an entity that is managed by the Fund’s Manager. During the three and six months ended March 31,June 30, 2019, the Fund earned $15$16 thousand and $31 thousand, respectively, representing its proportionate share of the production handling fees earned from Institutional Fund II, which is included within “Other revenue” on the Fund’s statements of operations. There were no such amounts recorded during the three and six months ended March 31,June 30, 2018. As of March 31,June 30, 2019 and December 31, 2018, the Fund’s receivables of $15$16 thousand and $0.1 million, respectively, related to the Fund’s proportionate share of revenue from Institutional Fund II are included within “Due from affiliate” on the Fund’s balance sheets. The receivables are settled by issuance of a non-cash credit from the Beta Project operator to the Fund on behalf of the Claiborne Project working interest owners when the operator performs the joint interest billing of the lease operating expenses due from the Fund. The revenue received from the PHA will be utilized by the Fund to repay a portion of the long-term debt outstanding under its credit agreement until the loan is repaid in full, in no event later than December 31, 2022.

At times, short-term payables and receivables, which do not bear interest, arise from transactions with affiliates in the ordinary course of business.

The Fund has working interest ownership in certain oil and natural gas projects, which are also owned by other entities that are likewise managed by the Manager.

As of March 31,June 30, 2019 and December 31, 2018, the Fund had outstanding borrowings of $3.0$2.8 million and $3.2 million, respectively, under its credit agreement dated November 27, 2012, as amended on September 30, 2016, September 15, 2017, June 1, 2018 and August 10, 2018 (the “Credit Agreement”). As of March 31,June 30, 2019, the estimated fair value of the debt was $3.0$2.8 million.

The Credit Agreement bears interest at 8.75% compounded monthly. Principal and interest payments are based on the fixed percentage of the Fund’s Net Revenue, as defined in the Credit Agreement. As of March 31, 2019, the Fund’s fixed percentage is 30%, which was based on the Fund’s ratio of outstanding debt to working interest ownership in the Beta Project determined on September 1, 2018 as scheduled in the Credit Agreement. Beginning on April 1, 2019 and each April 1^st thereafter, the Fund’s fixed percentage will beis the greater of (i) 30% or (ii) the Fixed Reassessment Percentage, as defined in the Credit Agreement. The Fixed Reassessment Percentage is determined annually beginning April 1, 2019 and each April 1^st thereafter, and will beis based on the Fund’s ratio of its outstanding debt as of the reassessment date relative to 80% of third-party reserve engineer’s proved plus probable future undiscounted cash flows attributable to the Beta Project through the maturity of the loan. As of April 1, 2019, the Fixed Reassessment PercentageFund’s fixed percentage was determined to be 30%. The loan may be prepaid by the Fund without premium or penalty. Pursuant to the Credit Agreement, the Fund also agreed to convey a fixed percentage of 10.81% overriding royalty interest in its working interest in the Beta Project to the lenders, which will become payable to the lenders on January 1, 2023.

As of March 31,June 30, 2019 and December 31, 2018, the unamortized debt discounts related to the Credit Agreement of $14$13 thousand and $15 thousand, respectively, were presented as a reduction of “Long-term borrowings” on the Fund’s balance sheets. Amortization expense during the three and six months ended March 31,June 30, 2019 of $1 thousand and $2 thousand, respectively, was included on the Fund’s statements of operations within “Interest expense, net”. There were no such amounts recorded during the three and six months ended March 31,June 30, 2018. As of March 31,June 30, 2019 and December 31, 2018, there were no accrued interest costs outstanding. Interest costs incurred during each of the three and six months ended March 31,June 30, 2019 and 2018 of $0.1 million were included on the Fund’s statements of operations within “Interest expense, net”. Interest costs incurred during the three and six months ended June 30, 2018 of $0.1 million and $0.3 million, respectively, were included on the Fund’s statements of operations within “Interest expense, net”.

The Credit Agreement contains customary covenants, with which the Fund was in compliance as of March 31,June 30, 2019 and December 31, 2018.

Capital Commitments

As of March 31,June 30, 2019, the Fund’s estimated capital commitments related to its oil and gas properties were $2.8$2.7 million (which include asset retirement obligations for the Fund’s projects of $1.9 million), of which $0.1 million is expected to be spent during the next twelve months. Future results of operations and cash flows are dependent on the continued successful development and the related production of oil and gas revenues from the Beta Project.

Based upon its current cash position and its current reserve estimates, the Fund expects cash flow from operations to be sufficient to cover its commitments, borrowing repayments and ongoing operations. Reserve estimates are projections based on engineering data that cannot be measured with precision, require substantial judgment, and are subject to frequent revision. However, if cash flow from operations is not sufficient to meet the Fund’s commitments, the Manager will temporarily waive all or a portion of the management fee as well as provide short-term financing to accommodate the Fund’s short-term commitments if needed.

Environmental and Governmental Regulations

Many aspects of the oil and gas industry are subject to federal, state and local environmental laws and regulations. The Manager and operators of the Fund’s properties are continually taking action they believe appropriate to satisfy applicable federal, state and local environmental regulations. However, due to the significant public and governmental interest in environmental matters related to those activities, the Manager cannot predict the effects of possible future legislation, rule changes, or governmental or private claims. As of March 31,June 30, 2019 and December 31, 2018, there were no known environmental contingencies that required adjustment to, or disclosure in, the Fund’s financial statements.

Oil and gas industry legislation and administrative regulations are periodically changed for a variety of political, economic, and other reasons. Any such future laws and regulations could result in increased compliance costs or additional operating restrictions, which could have a material adverse effect on the Fund’s operating results and cash flows. It is not possible at this time to predict whether such legislation or regulation, if proposed, will be adopted as initially written, if at all, or how legislation or new regulation that may be adopted would impact the Fund’s business.

BOEM Notice to Lessees on Supplemental Bonding

On July 14, 2016, the Bureau of Ocean Energy Management (“BOEM”) issued a Notice to Lessees (“NTL”) that discontinued and materially replaced existing policies and procedures regarding financial security (i.e. supplemental bonding) for decommissioning obligations of lessees of federal oil and gas leases and owners of pipeline rights-of-way, rights-of use and easements on the Outer Continental Shelf (“Lessees”).  Generally, the NTL (i) ended the practice of excusing Lessees from providing such additional security where co-lessees had sufficient financial strength to meet such decommissioning obligations, (ii) established new criteria for determining financial strength and additional security requirements of such Lessees, (iii) provided acceptable forms of such additional security and (iv) replaced the waiver system with one of self-insurance. The rule became effective as of September 12, 2016; however on January 6, 2017, the BOEM announced that it was suspending the implementation timeline for six months in certain circumstances. On June 22, 2017, the BOEM announced that the implementation timeline extension will remain in effect pending the completion of its review of the NTL. As of March 31,June 30, 2019, the BOEM has not completed its review nor has the NTL been enforced.  The impact of the NTL, if enforced without change or amendment, may require the Fund to fully secure all of its potential abandonment liabilities to the BOEM’s satisfaction using one or more of the enumerated methods for doing so.  Potentially this could increase costs to the Fund if the Fund is required to obtain additional supplemental bonding, fund escrow accounts or obtain letters of credit.

Insurance Coverage

The Fund is subject to all risks inherent in the oil and natural gas business. Insurance coverage as is customary for entities engaged in similar operations is maintained, but losses may occur from uninsurable risks or amounts in excess of existing insurance coverage. The occurrence of an event that is not insured or not fully insured could have a material adverse impact upon earnings and financial position. Moreover, insurance is obtained as a package covering all of the entities managed by the Manager. Depending on the extent, nature and payment of claims made by the Fund or other entities managed by the Manager, yearly insurance coverage may be exhausted and become insufficient to cover a claim by the Fund in a given year.

The Fund as well as other funds managed by the Manager that invested in the Beta Project elected not to participate in the drilling of the 8th well proposed by Walter Oil and Gas Corporation.  As a result, the Fund is due reimbursement for a portion of the cost relating to the slot on the Beta Project platform that was utilized by the other third-party working interest partners for the 8th well.  On July 17, 2019, the Fund as well as the other funds managed by the Manager and the other third-party working interest owners in the Beta Project agreed to a reimbursement to the Fund of $0.5 million, which will be recorded as a reduction to oil and gas properties in the third quarter 2019.  The amount received will be utilized by the Fund to repay a portion of the long-term debt outstanding under the Credit Agreement.

ITEM 2.               MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Cautionary Statement Regarding Forward-Looking Statements

Certain statements in this Quarterly Report on Form 10-Q (“Quarterly Report”) and the documents Ridgewood Energy A-1 Fund, LLC (the “Fund”) has incorporated by reference into this Quarterly Report, other than purely historical information, including estimates, projections, statements relating to the Fund’s business plans, strategies, objectives and expected operating results, and the assumptions upon which those statements are based, are “forward-looking statements” within the meaning of the U.S. Private Securities Litigation Reform Act of 1995 that are based on current expectations and assumptions and are subject to risks and uncertainties that may cause actual results to differ materially from the forward-looking statements. You are therefore cautioned against relying on any such forward-looking statements. Forward-looking statements can generally be identified by words such as “believe,” “project,” “expect,” “anticipate,” “estimate,” “intend,” “strategy,” “plan,” “target,” “pursue,” “may,” “will,” “will likely result,” and similar expressions and references to future periods. Examples of events that could cause actual results to differ materially from historical results or those anticipated include weather conditions, such as hurricanes, changes in market and other conditions affecting the pricing, production and demand of oil and natural gas, the cost and availability of equipment, and changes in domestic and foreign governmental regulations. Examples of forward-looking statements made herein include statements regarding projects, investments, insurance, capital expenditures and liquidity. Forward-looking statements made in this document speak only as of the date on which they are made. The Fund undertakes no obligation to update or revise publicly any forward-looking statements, whether as a result of new information, future events or otherwise, except as required by law.

Critical Accounting Policies and Estimates

There were no changes to the Fund’s critical accounting policies and estimates from those disclosed in its Annual Report on Form 10-K for the year ended December 31, 2018.2018.

Overview of the Fund’s Business

The Fund was organized primarily to acquire interests in oil and natural gas properties located in the United States offshore waters of Texas, Louisiana and Alabama in the Gulf of Mexico. The Fund’s primary investment objective is to generate cash flow for distribution to its shareholders by generating returns across a portfolio of oil and natural gas projects. Distributions to shareholders are made in accordance with the Fund’s limited liability company agreement (the “LLC Agreement”).

Ridgewood Energy Corporation (the “Manager”) is the Manager, and as such, has direct and exclusive control over the management of the Fund’s operations. The Manager performs, or arranges for the performance of, the management, advisory and administrative services required for the Fund’s operations. As compensation for its services, the Manager is entitled to an annual management fee, payable monthly, equal to 2.5% of the total capital contributions made by the Fund’s shareholders, net of cumulative dry-hole and related well costs incurred by the Fund. The Fund does not currently, nor is there any plan to, operate any project in which the Fund participates. The Manager enters into operating agreements with third-party operators for the management of all exploration, development and producing operations, as appropriate. The Manager also participates in distributions.

Subsequent Event

The Fund as well as other funds managed by the Manager that invested in the Beta Project elected not to participate in the drilling of the 8th well proposed by Walter Oil and Gas Corporation.  As a result, the Fund is due reimbursement for a portion of the cost relating to the slot on the Beta Project platform that was utilized by the other third-party working interest partners for the 8th well.  On July 17, 2019, the Fund as well as the other funds managed by the Manager and the other third-party working interest owners in the Beta Project agreed to a reimbursement to the Fund of $0.5 million, which will be recorded as a reduction to oil and gas properties in the third quarter 2019.  The amount received will be utilized by the Fund to repay a portion of the long-term debt outstanding under the credit agreement.

Commodity Price Changes

Changes in oil and natural gas commodity prices may significantly affect liquidity and expected operating results. Declines in oil and natural gas commodity prices not only reduce revenues and profits but could also reduce the quantities of reserves that are commercially recoverable and result in non-cash charges to earnings due to impairment.

Oil and natural gas commodity prices have been subject to significant fluctuations during the past several years. The Fund anticipates price cyclicality in its planning and believes it is well positioned to withstand price volatility. The Fund will continue to closely manage and coordinate its capital spending estimates within its expected cash flows to provide for future development costs of its producing projects, as budgeted. See “Results of Operations” under this Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Quarterly Report for more information on the average oil and natural gas prices received by the Fund during the three and six months ended March 31,June 30, 2019 and 2018 and the effect of such average prices on the Fund’s results of operations. If oil and natural gas commodity prices decline, even if only for a short period of time, the Fund’s results of operations and liquidity will be adversely impacted.

Market pricing for oil and natural gas is volatile and is likely to continue to be volatile in the future. This volatility is caused by numerous factors and market conditions that the Fund cannot control or influence. Therefore, it is impossible to predict the future price of oil and natural gas with any certainty. Factors affecting market pricing for oil and natural gas include:

Business Update

Information regarding the Fund’s current projects, all of which are located in the United States offshore waters in the Gulf of Mexico, is provided in the following table. See “Liquidity Needs” under this Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Quarterly Report for information regarding the funding of the Fund’s capital commitments.

Results of Operations

The following table summarizes the Fund’s results of operations during the three and six months ended March 31,June 30, 2019 and 2018, and should be read in conjunction with the Fund’s financial statements and notes thereto included within Item 1. “Financial Statements” in Part I of this Quarterly Report.

Overview. The following table provides information related to the Fund’s oil and natural gas production and oil and gas revenue during the three and six months ended March 31,June 30, 2019 and 2018. Natural gas liquid sales are included within gas sales.

The increases in the number of wells producing and production days were primarily related to the commencement of production of two wells in the Beta Project, one well during third quarter 2018 and one well during first quarter 2019. The decreases in oil and gas sales volumes were primarily related to the Beta and Liberty projects. The decrease in the Beta Project production was primarily related to the partial sale of working interest in the projectBeta Project during third quarter 2018 coupled with periodic shut-ins during first quarterhalf of 2019 due to certain drilling and completion operations performed at the project’s production facility. The Liberty Project experienced a decrease in production as a result of a shut-in during first quarter 2019 due to mechanical work. See additional discussion in “Business Update” section above.

Oil and Gas Revenue. Oil and gas revenue during the three months ended March 31,June 30, 2019 was $0.9$1.0 million, a decrease of $0.5$0.2 million from the three months ended March 31,June 30, 2018. The decrease was primarily attributable to decreased sales volume.

Oil and gas revenue during the six months ended June 30, 2019 was $1.9 million, a decrease of $0.7 million from the six months ended June 30, 2018. The decrease was attributable to decreased sales volume totaling $0.7 million coupled with decreased oil and gas prices totaling $0.1 million.

See “Overview” above for factors that impact the oil and gas revenue volume and rate variances.

Other Revenue.Other revenue is generated from the Fund’s production handling, gathering and operating services agreement with an affiliated entity and other third parties. There were no such amounts recorded during the three and six months ended March 31,June 30, 2018.

Depletion and Amortization. Depletion and amortization during the three months ended March 31,June 30, 2019 was $0.5 million, a decrease of $0.5 million from the three months ended March 31,June 30, 2018. The decrease was attributable to a decrease in the average depletion rate totaling $0.3 million coupled with a decrease in production volumes totaling $0.2 million.

Depletion and amortization during the six months ended June 30, 2019 was $1.0 million, a decrease of $1.0 million from the six months ended June 30, 2018. The decrease was attributable to a decrease in production volumes totaling $0.3$0.5 million coupled with a decrease in the average depletion rate totaling $0.2$0.4 million.

The decreasedecreases in the average depletion rate wasrates were primarily attributable to lower cost of reserves from the Fund’s producing projects. Depletion and amortization was also impacted by the partial sale of working interest in the Beta Project during third quarter 2018.

See “Overview” above for certain factors that impact the depletion and amortization volume and rate variances. Depletion and amortization rates may also be impacted by changes in reserve estimates provided annually by the Fund’s independent petroleum engineers.

Operating Expenses. Operating expenses represent costs specifically identifiable or allocable to the Fund’s wells, as detailed in the following table.

Lease operating expense and transportation and processing expense relate to the Fund’s producing projects. Insurance expense represents premiums related to the Fund’s projects, which vary depending upon the number of wells producing or drilling. Workover expense represents costs to restore or stimulate production of existing reserves. Accretion expense relates to the asset retirement obligations established for the Fund’s oil and gas properties.

Production costs, which include lease operating expense, transportation and processing expense and insurance expense, were $0.1 million ($6.48 per barrel of oil equivalent or “BOE”) and $0.3 million ($7.04 per BOE) during the three and six months ended June 30, 2019, respectively, compared to $0.2 million ($6.26 per BOE) and $0.3 million ($5.39 per BOE) during the three and six months ended June 30, 2018, respectively. Production costs remained relatively consistent during the three and six months ended June 30, 2019 compared to the three and six months ended June 30, 2018. The increase in production costs per BOE during the six months ended June 30, 2019 compared to the six months ended June 30, 2018 was primarily due to the impact of ongoing costs for the Beta Project, which experienced decreased production volumes due to periodic shut-ins during first half of 2019. See “Overview” above for factors that impact oil and natural gas production.

Management Fees to Affiliate. An annual management fee, totaling 2.5% of total capital contributions, net of cumulative dry-hole and related well costs incurred by the Fund, is paid monthly to the Manager. Such fee may be temporarily waived by the Manager to accommodate the Fund’s short-term commitments.

Operating Expenses. Operating expenses represent costs specifically identifiable or allocable to the Fund’s wells, as detailed in the following table.

Lease operating expense and transportation and processing expense relate to the Fund’s producing projects. Insurance expense represents premiums related to the Fund’s projects, which vary depending upon the number of wells producing or drilling. Accretion expense relates to the asset retirement obligations established for the Fund’s oil and gas properties. Workover expense represents costs to restore or stimulate production of existing reserves.

Production costs, which include lease operating expense, transportation and processing expense and insurance expense, were $0.1 million ($7.70 per barrel of oil equivalent or “BOE”) during the three months ended March 31, 2019, compared to $0.1 million ($4.72 per BOE) during the three months ended March 31, 2018. Although production costs remained relatively consistent during first quarter 2019 compared to first quarter 2018, the production costs per BOE increased primarily due to the impact of ongoing costs for the Beta Project, which experienced decreased production volumes due to periodic shut-ins during first quarter 2019. See “Overview” above for factors that impact oil and natural gas production.

General and Administrative Expenses. General and administrative expenses represent costs specifically identifiable or allocable to the Fund, such as accounting and professional fees and insurance expenses.

Interest Expense, Net. Interest expense, net is comprised of interest expense and amortization of debt discounts related to the Fund’s long-term borrowings (see “Liquidity Needs -Credit Agreement” below for additional information), and interest income earned on cash and cash equivalents and salvage fund.

Unrealized LossGain (Loss) on Marketable Securities.The Fund has available-for-sale investments within its salvage fund in federal agency mortgage-backed securities. Available-for-sale debt securities are carried in the financial statements at fair value and unrealized gains and losses related to the securities’ changes in fair value are recorded in other comprehensive income until realized.

Capital Resources and Liquidity

Operating Cash Flows

Cash flows provided by operating activities during the threesix months ended March 31,June 30, 2019 were $0.6$1.2 million, primarily related to revenue received of $0.9$1.9 million, partially offset by operating expenses of $0.1$0.2 million, management fees of $0.1$0.2 million, and interest payments of $0.1 million and general and administrative expenses of $0.1 million.

Cash flows provided by operating activities during the threesix months ended March 31,June 30, 2018 were $1.1$1.8 million, primarily related to revenue received of $1.4$2.7 million, partially offset by interest payments of $0.1$0.3 million, operating expenses of $0.1$0.3 million, management fees of $0.2 million and management feesgeneral and administrative expenses of $0.1 million.

Investing Cash Flows

Cash flows used in investing activities during the threesix months ended March 31,June 30, 2019 were $0.3$0.5 million, primarily related to capital expenditures for oil and gas properties.properties of $0.4 million and investments in salvage fund of $0.1 million.

Cash flows used in investing activities during the threesix months ended March 31,June 30, 2018 were $1.0$1.2 million, primarily related to capital expenditures for oil and gas properties.properties of $1.1 million and investments in salvage fund of $0.1 million.

Financing Cash Flows

Cash flows used in financing activities during the threesix months ended March 31,June 30, 2019 were $0.7$1.3 million, related to manager and shareholder distributions of $0.5$0.9 million and the repayments of long-term borrowings of $0.2$0.4 million.

Cash flows used in financing activities during the threesix months ended March 31,June 30, 2018 were $0.2$0.5 million, related to the repayment of long-term borrowings.

Estimated Capital Expenditures

Capital expenditures for oil and gas properties have been funded with the capital raised by the Fund in its private placement offering and through debt financing. The Fund’s capital has been fully allocated to its projects. As a result, the Fund will not invest in any new projects and will limit its investment activities, if any, to those projects in which it currently has a working interest. See “Business Update” under this Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Quarterly Report for information regarding the Fund’s current projects. See “Liquidity Needs” below for additional information.

Liquidity Needs

The Fund’s primary short-term liquidity needs are to fund its operations, capital expenditures for its oil and gas properties and borrowing repayments. Such needs are funded utilizing operating income and existing cash on-hand.

As of March 31,June 30, 2019, the Fund’s estimated capital commitments related to its oil and gas properties were $2.8$2.7 million (which include asset retirement obligations for the Fund’s projects of $1.9 million), of which $0.1 million is expected to be spent during the next twelve months. Future results of operations and cash flows are dependent on the continued successful development and the related production of oil and gas revenues from the Beta Project.

Based upon its current cash position and its current reserve estimates, the Fund expects cash flow from operations to be sufficient to cover its commitments, borrowing repayments and ongoing operations. Reserve estimates are projections based on engineering data that cannot be measured with precision, require substantial judgment, and are subject to frequent revision. However, if cash flow from operations is not sufficient to meet the Fund’s commitments, the Manager will temporarily waive all or a portion of the management fee as well as provide short-term financing to accommodate the Fund’s short-term commitments if needed.

The Manager is entitled to receive an annual management fee from the Fund regardless of the Fund’s profitability in that year. However, pursuant to the terms of the LLC Agreement, the Manager is also permitted to waive the management fee at its own discretion.

Distributions, if any, are funded from available cash from operations, as defined in the LLC Agreement, and the frequency and amount are within the Manager’s discretion. Due to the significant capital required to develop the Beta Project, distributions have been impacted, and may be impacted in the future, by amounts reserved to provide for its ongoing development costs, borrowing repayments and funding its estimated asset retirement obligations.

Credit Agreement

As of March 31,June 30, 2019 and December 31, 2018, the Fund had outstanding borrowings of $3.0$2.8 million and $3.2 million, respectively, under its credit agreement dated November 27, 2012, as amended on September 30, 2016, September 15, 2017, June 1, 2018 and August 10, 2018 (the “Credit Agreement”).

The Credit Agreement bears interest at 8.75% compounded monthly. Principal and interest payments are based on the fixed percentage of the Fund’s Net Revenue, as defined in the Credit Agreement. The Fund’s fixed percentage is 30%, which was based on the Fund’s ratio of outstanding debt to working interest ownership in the Beta Project determined on September 1, 2018, as scheduled in the Credit Agreement. Beginning on April 1, 2019 and each April 1^st thereafter, the Fund’s fixed percentage will beis the greater of (i) 30% or (ii) the Fixed Reassessment Percentage, as defined in the Credit Agreement. The Fixed Reassessment Percentage is determined annually beginning April 1, 2019 and every April 1^st thereafter, and will beis based on the Fund’s ratio of its outstanding debt as of the reassessment date relative to 80% of third-party reserve engineer’s proved plus probable future undiscounted cash flows attributable to the Beta Project through the maturity of the loan. As of April 1, 2019, the Fixed Reassessment PercentageFund’s fixed percentage was determined to be 30%. The loan may be prepaid by the Fund without premium or penalty. The Credit Agreement also provides for a fixed percentage of 10.81% overriding royalty interest to the lenders, which will become payable to the lenders in January 2023.

The Credit Agreement contains customary negative covenants including covenants that limit the Fund’s ability to, among other things, grant liens, change the nature of its business, or merge into or consolidate with other persons. The events which constitute events of default are also customary for credit facilities of this nature and include payment defaults, breaches of representations, warrantswarranties and covenants, insolvency and change of control. Upon the occurrence of a default, in some cases following a notice and cure period, the lenders under the Credit Agreement may accelerate the maturity of the loan and require full and immediate repayment of all borrowings under the Credit Agreement. The Fund believes it is in compliance with all covenants under the Credit Agreement as of March 31,June 30, 2019 and December 31, 2018.

Off-Balance Sheet Arrangements

The Fund had no off-balance sheet arrangements as of March 31,June 30, 2019 and December 31, 2018 and does not anticipate the use of such arrangements in the future.

Contractual Obligations

The Fund enters into participation and joint operating agreements with operators. On behalf of the Fund, an operator enters into various contractual commitments pertaining to exploration, development and production activities. The Fund does not negotiate such contracts. No contractual obligations exist as of March 31,June 30, 2019 and December 31, 2018, other than those discussed in “Estimated Capital Expenditures” and “Liquidity Needs –Credit Agreement” above.

Recent Accounting Pronouncements

See Note 1 of “Notes to Unaudited Condensed Financial Statements” - “Organization and Summary of Significant Accounting Policies” contained in Item 1. “Financial Statements” within Part I of this Quarterly Report for a discussion of recent accounting pronouncements.

Not required.

In accordance with Rules 13a-15 and 15d-15 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), the Fund’s management, including its Chief Executive Officer and Chief Financial Officer, evaluated the effectiveness of the Fund’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this report. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the Fund’s disclosure controls and procedures were effective as of March 31,June 30, 2019.

There has been no change in the Fund’s internal control over financial reporting that occurred during the three months ended March 31,June 30, 2019 that has materially affected, or is reasonably likely to materially affect, the Fund’s internal control over financial reporting.

PART II – OTHER INFORMATION

None.

Not required.

None.

None.

None.

None.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

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