PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

RIDGEWOOD ENERGY A-1 FUND, LLC

UNAUDITED CONDENSED BALANCE SHEETS

(in thousands, except share data)

The accompanying notes are an integral part of these unaudited condensed financial statements.

Table of Contents

RIDGEWOOD ENERGY A-1 FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF OPERATIONS

(in thousands, except per share data)

The accompanying notes are an integral part of these unaudited condensed financial statements.

Table of Contents

RIDGEWOOD ENERGY A-1 FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF CHANGES

IN MEMBERS’ CAPITAL

(in thousands, except share data)

The accompanying notes are an integral part of these unaudited condensed financial statements.

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RIDGEWOOD ENERGY A-1 FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF CASH FLOWS

(in thousands)

The accompanying notes are an integral part of these unaudited condensed financial statements.

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RIDGEWOOD ENERGY A-1 FUND, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

1.

Organization

The Ridgewood Energy A-1 Fund, LLC (the “Fund”), a Delaware limited liability company, was formed on February 3, 2009 and operates pursuant to a limited liability company agreement (the “LLC Agreement”) dated as of March 2, 2009 by and among Ridgewood Energy Corporation (the “Manager”) and the shareholders of the Fund, which addresses matters such as the authority and voting rights of the Manager and shareholders, capitalization, transferability of membership interests, participation in costs and revenues, distribution of assets and dissolution and winding up. The Fund was organized to primarily acquire interests in oil and gas properties located in the United States offshore waters of Texas, Louisiana and Alabama in the Gulf of Mexico.

The Manager 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. Such services include, without limitation, the administration of shareholder accounts, shareholder relations, the preparation, review and dissemination of tax and other financial information and the management of the Fund’s investments in projects. In addition, the Manager provides office space, equipment and facilities and other services necessary for the Fund’s operations. The Manager also engages and manages contractual relations with unaffiliated custodians, depositories, accountants, attorneys, corporate fiduciaries, insurers, banks and others as required. See Notes 2 3 and 4.3.

Basis of Presentation

These unaudited interim condensed financial statements have been prepared by the Fund’s management in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and in the opinion of management, contain all adjustments (consisting of only normal recurring adjustments) necessary to present fairly the Fund’s financial position, results of operations, changes in members’ capital and cash flows for the periods presented. Certain information and note disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted in these unaudited interim condensed financial statements. The financial position, results of operations, changes in members’ capital and cash flows for the periods presented herein are not necessarily indicative of future financial results. These unaudited interim condensed financial statements should be read in conjunction with the Fund’s December 31, 20202021 financial statements and notes thereto included in the Fund’s Annual Report on Form 10-K (“20202021 Annual Report”) filed with the Securities and Exchange Commission (“SEC”). The year-end condensed balance sheet data was derived from audited financial statements for the year ended December 31, 2020,2021, but does not include all annual disclosures required by GAAP.

Use of Estimates

The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenue and expense during the reporting period. On an ongoing basis, management reviews its estimates, including those related to the fair value of financial instruments, depletion and amortization, determination of proved reserves, impairment of long-lived assets and asset retirement obligations. Actual results may differ from those estimates.

Summary of Significant Accounting Policies

The Fund has provided discussion of significant accounting policies in Note 1 of “Notes to Financial Statements” – “Organization and Summary of Significant Accounting Policies” contained in Item 8. “Financial Statements and Supplementary Data” within its 20202021 Annual Report. There have been no significant changes to the Fund’s significant accounting policies during the three and nine months ended September 30, 2021.2022.

Fair Value Measurements

The Fund follows the accounting guidance for fair value measurement for measuring fair value of assets and liabilities in its financial statements. The Fund’s financial assets and liabilities consist of cash and cash equivalents, salvage fund, production receivable, due from affiliate, other current assets, due to operators and accrued expenses and long-term debt. Except for long-term debt, theexpenses. The carrying amounts of these financial assets and liabilities approximate fair value due to their short-term nature.

The Fund’s long-term debt is valued using an income approach and classified as Level 3 in the fair value hierarchy. The fair value of long-term debt is estimated by discounting future cash payments of principal and interest to a present value amount using a market yield for debt instruments with similar terms, maturities and credit ratings. The Fund also applies the provisions of the fair value measurement accounting guidance to its non-financial assets and liabilities, such as oil and gas properties and asset retirement obligations, on a non-recurring basis.

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 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. The following table presents changes in asset retirement obligations for the following periods:

During the nine months ended September 30, 2021, the Fund recorded credits to depletion expense totaling $0.3 million primarily related to an adjustment to the asset retirement obligation for a fully depleted property.

Revenue Recognition

Oil and gas revenues from contracts with customers are recognized at the point when control of oil and natural gas is transferred to the customers in accordance with Accounting Standard Codification Topic 606, Revenue from Contracts with Customers. Revenues from the sale of natural gas liquid are included within gas revenues. The Fund’s oil and natural gas generally are 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 affiliated entities and other third parties. The Fund 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 affiliated entities 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 affiliates 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. However, if applying the joint interest billing credit results in a net credit balance due to the Fund, the Beta Project operator remits such balance in cash to 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 has not been significant. During each of the three and nine months ended September 30, 20212022 and 2020,2021, revenue recognized from performance obligations satisfied in previous periods was not significant.

Allowance for Credit Losses

The Fund is exposed to credit losses through the sale of oil and natural gas to customers. However, the Fund only sells to a small number of major oil and gas companies that have investment-grade credit ratings. Based on historical collection experience, current and future economic and market conditions and a review of the current status of customers' production receivables, the Fund has not recorded an expected loss allowance as there are no past due receivable balances or projected credit losses. The Fund considered the current and expected future economic and market conditions surrounding the Coronavirus (“COVID-19”) pandemic and determined based on the composition of its customer base, there was no related credit loss impact.

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 its oil and gas properties may not be recoverable. Recoverability is evaluated by comparing estimated future net undiscounted cash flows to the carrying value of the oil and gas properties at the time of the review. If the carrying value exceeds the estimated future net undiscounted cash flows, the carrying value of the oil and gas properties is impaired, and written down to fair value. Fair value 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, estimates of oil and natural gas reserves and future development costs or discount rates could result in a significant impact on the amount of impairment.

There were no impairments of oil and gas properties during each of the three and nine months ended September 30, 20212022 and 2020.2021. Fluctuations in oil and natural gas commodity prices may impact the fair value of the Fund’s oil and gas properties. In addition, significant declines in oil and natural gas commodity prices could reduce the quantities of reserves that are commercially recoverable, which could result in impairment.

Recent Accounting Pronouncements

The Fund has considered recent accounting pronouncements issued during the nine months ended September 30, 2021 or2022 and through the filing of this report, and the Fund has not identified new standards that it believes will have an impact on the Fund’s financial statements.

2.

Pursuant to the terms of the LLC Agreement, the Manager is entitled to receive an annual management fee, payable monthly, of 2.5%2.5% of total capital contributions, net of cumulative dry-hole well costs incurred by the Fund and fully depleted project investments, however, the Manager is permitted to waive all or a portion of the management fee at its own discretion. Therefore, all or a portion of the management fee may be temporarily waived to accommodate the Fund’s short-term commitments. Management fees during each of the three and nine months ended September 30, 2022 and 2021 and 2020 were $0.1$0.1 million and $0.2$0.2 million, respectively.

The Manager is also entitled to receive 15%15% of the cash distributions from operations made by the Fund. Distributions paid to the Manager during the three and nine months ended September 30, 20212022 were $44 thousand$0.2 million and $0.1$0.5 million, respectively. Distributions paid to the Manager during the three and nine months ended September 30, 20202021 were $8$44 thousand and $0.1$0.1 million, respectively.

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.

The Fund and other third-party working interest owners in the Beta Project are partiesis a party to 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”),affiliated entities and other third-party working interest owners in the Claiborne Project. On September 23, 2020,May 12, 2022, a third-party working interest owner executed an assignment and bill of the Claiborne Project executed a consent lettersale agreement to assign the rights to the services under the PHA to Ridgewood Rattlesnake,Institutional IV Prospective Leases, LLC, a wholly-owned entity of Ridgewood Energy Oil & Gas Fund III,IV, L.P. (“Institutional Fund III”IV”). As a result of the assignment, Ridgewood Institutional IV Prospective Leases, LLC, as a working interest owner in the Claiborne Project, became party to the Claiborne Project’s PHA with entities that own the Beta Project production facility. Institutional Fund II and Institutional Fund III are entitiesIV is an entity that areis managed by the Fund’s Manager. Under the terms of the PHA, the Claiborne Project producers have agreed to pay the Beta Project owners a fixed production handling fee for each barrel of oil and mcf of natural gas processed through the Beta Project production facility. During the three and nine months ended September 30, 2021,2022, the Fund earned $22 $30 thousand and $0.1$0.1 million, respectively, representing its proportionate share of the production handling fees earned from Institutional Fund II and Institutional Fund III,affiliates, which isare included within “Other revenue” on the Fund’s statements of operations. During the three and nine months ended September 30, 2020,2021, the Fund earned $25 $22 thousand and $49 thousand,$0.1 million, respectively, representing its proportionate share of the production handling fees earned from Institutional Fund II,affiliates, which isare included within “Other revenue” on the Fund’s statements of operations. As of September 30, 20212022 and December 31, 2020,2021, the Fund’s receivablesreceivable of $11 $21 thousand and $18$19 thousand, respectively, related to the Fund’s proportionate share of revenue from Institutional Fund II and Institutional Fund IIIaffiliates 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. However, if applying the joint interest billing credit results in a net credit balance due to the Fund, the Beta Project operator remits such balance in cash to the Fund. The revenue received from the PHA is utilized by the Fund to repay a portion of the long-term debt outstanding under its Credit Agreement (defined below) 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.

3. Credit Agreement – Beta Project Financing
 

Capital Commitments

As of September 30, 2021 and December 31, 2020, the Fund had outstanding borrowings of $0.4 million and $1.4 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 September 30, 2021, the estimated fair value of the debt was $0.4 million.

Borrowings under the Credit Agreement bear 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. Beginning on April 1, 2019 and each April 1st thereafter, the Fund’s fixed percentage is 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 1st thereafter, and is 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 of December 31, 2022. As of April 1, 2021, the Fund’s fixed percentage was determined to be 51%. 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 September 30, 2021 and December 31, 2020, the unamortized debt discounts related to the loan of $4 thousand and $7 thousand, respectively, were presented as a reduction of long-term borrowings on the Fund’s balance sheets. Amortization expense during each of the three and nine months ended September 30, 2021 and 2020 of $1 thousand and $3 thousand, respectively, was included on the Fund’s statements of operations within “Interest expense, net”. As of September 30, 2021 and December 31, 2020, there were 00no accrued interest costs outstanding. Interest costs incurred during the three and nine months ended September 30, 2021 of $16 thousand and $0.1 million, respectively, were included on the Fund’s statements of operations within “Interest expense, net”. Interest costs incurred during the three and nine months ended September 30, 2020 of $37 thousand and $0.1 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 September 30, 2021 and December 31, 2020.

4.Commitments and Contingencies

Capital Commitments

As of September 30, 2021,2022, the Fund’s estimated capital commitments related to its oil and gas properties were $2.5$2.1 million (which include asset retirement obligations for the Fund’s projects of $1.4$1.4 million), of which $0.6$0.6 million is expected to be spent during the next twelve months related to the recompletion work for the Beta Project and the settlement of asset retirement obligations for certain of the Fund’s projects.months. Future results of operations and cash flows are dependent on the planned recompletion costs of and revenues from production and sale of oil and gas from the Beta Project.

Based upon its current cash position, salvage fund and its current reservereserves estimates, the Fund expects cash flow from operations to be sufficient to cover its commitments borrowing repayments and ongoing operations. ReserveReserves 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 may temporarily suspend distributions to accommodate the Fund’s short-term commitments if needed.

Impact from COVID-19current market conditions

The COVID-19 pandemic remainsoil and gas market, and the global economy in general, is subject to sources of uncertainty relating to: (i) further escalation in the Russia-Ukraine conflict, which could result in a major oil supply disruption; (ii) a prolonged high inflationary environment, which could result in a deep global health crisisrecession; and continuesthe (iii) fluctuations in the value of the U.S. Dollar against other major world currencies, particularly the significant devaluation of the Euro, Pound, Yen and Yuan against the U.S. Dollar recently, has added to cause uncertaintythe volatility in the oil market as nearly all oil globally is transacted in U.S. Dollars. The impact of these matters on global financial and commodity markets. The ultimate extent of the impact of the COVID-19 pandemicmarkets and resulting market disruption to the Fund’s operating results and cash flows continue to be unknown and unpredictable. Although, oil and natural gas commodity prices have improved from historic lows in 2020, the period of low oil and natural gas commodity prices during 2020 negatively impacted cash flow generated by the Fund’s Beta Project. However, becausetheir corresponding effect on the Fund owns the Beta Project with little debt and the project is a long-lived asset that is expected to produce over many years with relatively low operating costs, the Fund believes that it is positioned to weather this period of uncertainty and volatility from the COVID-19 pandemic. If oil and natural gas commodity prices and the overall global economy, including financial markets therein, are further adversely impacted by the COVID-19 pandemic for a prolonged period, the Fund, its operators and other working interest partners’ financial performance results will be materially adversely affected, which could significantly affect the Fund’s liquidity and expected operating results. It is likely that estimates of oil and gas products that can be economically produced will be reduced, which increases the likelihood of future impairments and higher depletion rates.remains uncertain.

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 September 30, 20212022 and December 31, 2020,2021, 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 Supplemental Financial Assurance Requirements

On July 14, 2016, the Bureau of Ocean Energy Management (“BOEM”) issued a Notice to Lessees (“NTL 2016-N01”) 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, NTL 2016-N01 (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 May 1, 2017, the Secretary of the U.S. Department of the Interior (“Interior”) directed the BOEM to complete a review of NTL 2016-N01, to provide a report to certain Interior personnel describing the results of the review and options for revising or rescinding NTL 2016-N01, and to keep the implementation timeline extension in effect pending the completion of the review of NTL 2016-N01 by the identified Interior personnel. 

On October 16, 2020, BOEM and the Bureau of Safety and Environmental Enforcement published a proposed new rule at 85 FR 65904 on Risk, Management, Financial Assurance and Loss Prevention, addressing the streamlining of evaluation criteria when determining whether oil, gas and sulfur leases, right-of-use and easement grant holders, and pipeline right-of-way grant holders may be required to provide bonds or other security above the prescribed amounts for base bonds to ensure compliance with the Lessees’ obligations, primarily decommissioning obligations. The proposed rule was significantly less stringent with respect to financial assurance than NTL 2016-N01. To date, the BOEM is not currently implementing NTL 2016-N01 and its status is uncertain. uncertain, but has indicated that it is reviewing the proposed rule.

Notwithstanding the uncertain status of NTL 2016-N01, BOEM had continued under existing law to review supplemental financial assurance requirements relative to sole liability properties (i.e., properties in which only one company is liable for decommissioning).  However, on August 18, 2021, the BOEM issued a Note to Stakeholders in which the BOEM stated that it was expanding its financial assurance efforts beyond sole liability projects to include “supplemental financial assurance of certain high-risk, non-sole liability properties” (those properties with more than one company potentially liable for decommissioning costs). The BOEM identified (i) inactive properties, (ii) those with less than five years of production left, and (iii) those with damaged infrastructure, as being high-risk, non-sole liability properties and for which supplemental financial assurance may be required.   The BOEM may require the Fund to fully secure all of its potential abandonment liabilities, which potentially could increase costs to the Fund.

On October 16, 2020, BOEM and the Bureau of Safety and Environmental Enforcement published a proposed new rule at 85 FR 65904 on Risk, Management, Financial Assurance and Loss Prevention, addressing the streamlining of evaluation criteria when determining whether oil, gas and sulfur leases, right-of-use and easement grant holders, and pipeline right-of-way grant holders may be required to provide bonds or other security above the prescribed amounts for base bonds to ensure compliance with the Lessees’ obligations, primarily decommissioning obligations. The proposed rule was significantly less stringent with respect to financial assurance than NTL 2016-N01. To date, however, Interior has not issued a final rule but has indicated that it is reviewing the proposed rule. The Fund is not able to evaluate the impact of the proposed new rule on its operations or financial condition until a final rule is issued or some other definitive action is taken by the Interior or BOEM. As of September 30, 2022, the Fund has fully funded in a separate interest-bearing account, or salvage fund, its proportionate share of the estimated decommissioning liabilities for its projects. The Fund will continue to reassess its estimated decommissioning liabilities and reserve for additional funding as necessary.  

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.

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. Such forward-looking statements 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 the impact on the Fund’s business and operations of the ongoing Coronavirus (“COVID-19”) pandemic and any other future widespread health emergencies or public health crises such as pandemics and epidemics, 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, 2020.2021.

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 receive 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 well costs incurred by the Fund and fully depleted project investments. 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.

Recent DevelopmentsMarket Conditions

In March 2020,The oil and gas market, and the World Health Organization categorizedglobal economy in general, is subject to sources of uncertainty relating to: (i) further escalation in the outbreak of COVID-19 as a global pandemic,Russia-Ukraine conflict, which resultedcould result in a major oil supply disruption; (ii) prolonged high inflationary environment, which could result in a deep global recession; and the (iii) fluctuations in the value of the U.S. Dollar against other major world currencies, particularly the significant drop in oil demand caused by lockdown measuresdevaluation of the Euro, Pound, Yen and industrial slowdown aroundYuan against the world. In addition, in March 2020, the failure of an alliance between the Saudi Arabia-led Organization of Petroleum Exporting Countries (“OPEC”) and Russia to reach an agreement on oil production volumes resulted in an oil “price war” and caused oil prices to collapse. Oil prices decreased to their lowest level in April 2020 as comparedU.S. Dollar recently, has added to the past several years as a result of the initial oil price war and significant decreasesvolatility in oil demand caused by world-wide government-ordered lock-downs. On April 12, 2020, and throughout 2020, OPEC and Russia agreed and implemented oil production cuts to stabilize the oil market. Since then, the oil market has stabilizedas nearly all oil globally is transacted in U.S. Dollars. While the current outlook for oil and strengthened with oilgas commodity prices gradually rising throughoutis favorable, different outcomes of these issues would have different impacts on global economic growth and the performance of financial markets during the rest of 2020. Oil prices have continued to strengthen into 2021 supported by a slow recovery in demand with the easing of lock-down measures2022 and the rollout of COVID-19 vaccines, market-driven supply cutbacks in the upstream oil sector globallyFund, its operators and the effective ongoing supply-side management by OPEC. Looking ahead, these factors indicate a balanced market by the second half of 2021. However, uncertainty still exists depending on actions taken by OPEC and non-OPEC countries in supporting a balanced global oil supply.

The ultimate extent of the impact of the COVID-19 pandemic and resulting market disruption toother working interest partners’ financial performance results may be materially adversely affected, which could affect the Fund’s operating results and cash flows continue to be unknown and unpredictable. Although,liquidity, development of oil and natural gas commodity prices have improved from historic lows in 2020, the period of low oilproperties and natural gas commodity prices during 2020 negatively impacted cash flow generated by the Beta Project.expected operating results. However, because the Fund owns the Beta Project with littleno debt and the project is a long-lived asset that is expected to produce over many years with relatively low operating costs, the Fund believes that it is positioned to weather this period of uncertainty and volatility fromin the COVID-19 pandemic. If oil and natural gas commodity prices and the overall global economy, including financial markets therein, are further adversely impacted by the COVID-19 pandemic for a prolonged period, the Fund, its operators and other working interest partners’ financial performance results will be materially adversely affected, which could significantly affect the Fund’s liquidity and expected operating results. It is likely that estimates of oil and gas products that can be economically produced will be reduced, which increases the likelihood of future impairments and higher depletion rates.market.

Commodity Price Changes

Changes in oil and natural gas commodity prices may significantly affect liquidity and expected operating results. DeclinesSignificant 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.impairment and higher depletion rates.

Oil and natural gas commodity prices have been subject to significant fluctuationsvolatility most recently due to the issues impacting market conditions described above. Although volatile, the overall trend for the crude oil market has been favorable during the past several years. During first half of 2020, oil and natural gas commodity prices experienced significant volatility primarily attributable tonine months ended September 30, 2022, which positively impacted cash flow generated by the COVID-19 pandemic.Fund’s Beta Project. 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 developmentthe costs ofassociated with the well recompletions for the Beta Project, 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 nine months ended September 30, 20212022 and 20202021 and the effect of such average prices on the Fund’s results of operations. If oil and natural gas commodity prices are further adversely impacted by the COVID-19 pandemic for a prolonged period, the Fund’s results of operations and liquidity will be materially 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 nine months ended September 30, 20212022 and 2020,2021, 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 nine months ended September 30, 20212022 and 2020.2021. Natural gas liquid sales are included within gas sales.

The decreaseproduction related increases noted in the numbertable above were primarily attributable to the Beta Project, which experienced significant periods of shut-ins during 2021 compared to 2022 due to well recompletion during May 2021 to September 2021 and storm-related safety shut-in during third quarter 2021. In addition, the Beta Project experienced increases in production rates during 2022 compared to 2021 from two of the project’s wells, which were recompleted and have been producing from new reservoir sands. The increase in gas sales volumes during the nine months ended September 30, 2021 related to the Liberty Project, which reached the end of its productive life during first quarter 2020. The decreases2022 was partially offset by lower gas production rates from one other well in production days and oil and gas volumes noted in the table above were primarily related to the Beta Project, as a result of the shut-in of production from one of the project’s wells since May 2021 due to recompletion work coupled with thewhich is experiencing natural decline in production from the other wells. The recompleted well returned to production in late-September 2021. In addition, the decreases during the nine months ended September 30, 2021 were also attributable to the Liberty Project, which reached the end of its productive life during first quarter 2020.production. See additional discussion in “Business Update” section above.

Oil and Gas Revenue. Oil and gas revenue during the three months ended September 30, 20212022 was $0.6$1.6 million, an increase of $0.2$1.0 million from the three months ended September 30, 2020.2021. The increase was attributable to increased sales volume totaling $0.6 million coupled with increased oil and gas prices totaling $0.3 million, partially offset by decreased sales volume totaling $0.1$0.4 million.

Oil and gas revenue during the nine months ended September 30, 20212022 was $2.1$4.3 million, an increase of $0.6$2.2 million from the nine months ended September 30, 2020.2021. The increase was attributable to increased oil and gas prices totaling $0.9$1.5 million partially offset by decreasedcoupled with increased sales volume totaling $0.3$0.7 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 affiliated entities and other third parties.

Depletion and Amortization. Depletion and amortization during the three months ended September 30, 20212022 was $0.2$0.5 million, a decreasean increase of $0.2$0.3 million from the three months ended September 30, 2020.2021. The decreaseincrease was primarily attributable to an increase in production volumes totaling $0.5 million and an adjustment to the asset retirement obligation related to a fully depleted property totaling $0.3 million during third quarter 2021, coupled with a decrease in production volumes totaling $0.1 million, partially offset by an increasea decrease in the average depletion rate totaling $0.2$0.5 million.

Depletion and amortization during the nine months ended September 30, 20212022 was $1.4$1.5 million, an increase of $0.2$0.1 million from the nine months ended September 30, 2020.2021. The increase was primarily attributable to an increase in the average depletion rateproduction volumes totaling $0.7$0.6 million partially offset byand an adjustment to the asset retirement obligation related to a fully depleted property totaling $0.3 million during third quarter 2021, coupled withpartially offset by a decrease in production volumesthe average depletion rate totaling $0.2$0.9 million.

The increasesdecreases in the average depletion rates were primarily attributable to the changes in reserves estimates provided annually by the Fund’s independent petroleum engineers coupled with the higher cost of reserves from the Beta Project primarily due to the recompletion costs incurred for one of the project’s wells during 2021.engineers.

See “Overview” above for certain factors that impact the depletion and amortization volume and rate variances. Reserves estimates may also be impacted by significant declines in oil and natural gas commodity prices due to the COVID-19 pandemic, which could result in higher depletion rates.

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 ($7.947.39 per barrel of oil equivalent or “BOE”) and $0.4 million ($7.33 per BOE) during the three and nine months ended September 30, 2022, respectively, compared to $0.1 million ($7.94 per BOE) and $0.3 million ($6.96 per BOE) during the three and nine months ended September 30, 2021, respectively, compared to $0.1 million ($8.25 per BOE) and $0.4 million ($8.17 per BOE) during the three and nine months ended September 30, 2020, respectively.

Production costs and production costs per BOE were relatively consistent during the three months ended September 30, 2021 compared to the three months ended September 30, 2020. The decreases in production costs and production costs per BOE during the nine months ended September 30, 20212022 compared to the three and nine months ended September 30, 2020 were primarily attributable to decreased oil and natural gas production from the Beta Project as a result of natural decline in production. In addition, the decreases were also attributable to the Liberty Project, which reached the end of its productive life during first quarter 2020.2021.

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 well costs incurred by the Fund and fully depleted project investments, is paid monthly to the Manager. All or a portion of such fee may be temporarily waived by the Manager to accommodate the Fund’s short-term commitments.

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, NetIncome (Expense). . Interest expense, net isDuring the three and nine months ended September 30, 2022, interest income (expense) was comprised of interest income earned on cash and cash equivalents and salvage fund. During the three and nine months ended September 30, 2021, interest income (expense) was 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.borrowings.  The Fund fully repaid its loan related to the Beta Project as of December 31, 2021.

Capital Resources and Liquidity

Operating Cash Flows

Cash flows provided by operating activities during the nine months ended September 30, 2022 were $3.7 million, primarily related to revenue received of $4.4 million, partially offset by operating expenses of $0.4 million, management fees of $0.2 million and general and administrative expenses of $0.1 million.

Cash flows provided by operating activities during the nine months ended September 30, 2021 were $1.6 million, related to revenue received of $2.6 million, partially offset by the settlement of asset retirement obligations of $0.3 million, operating expenses of $0.3 million, management fees of $0.2 million, general and administrative expenses of $0.1 million and interest payments of $0.1 million.

Investing Cash Flows

Cash flows provided by operatingused in investing activities during the nine months ended September 30, 20202022 were $0.5 million, primarily related to revenue receivedcapital expenditures for oil and gas properties of $1.7 million, partially offset by operating expenses of $0.5 million, management fees of $0.2 million, payment of $0.2 million related to the Fund’s proportionate share of a settlement for litigation between the Beta Project’s operator and a third-party, general and administrative expenses of $0.1$0.4 million and interest paymentsinvestments in salvage fund of $0.1 million.

Investing Cash Flows

Cash flows used in investing activities during the nine months ended September 30, 2021 were $0.2 million, related to capital expenditures for oil and gas properties of $0.3 million and investments in salvage fund of $0.1 million, partially offset by proceeds from the salvage fund of $0.3 million.

Financing Cash Flows

Cash flows used in investingfinancing activities during the nine months ended September 30, 20202022 were $0.1$3.7 million, primarily related to investments in the salvage fund.manager and shareholder distributions.

Financing Cash Flows

Cash flows used in financing activities during the nine months ended September 30, 2021 were $1.6 million, related to the repayments of long-term borrowings of $1.0 million and manager and shareholder distributions of $0.6 million.

Cash flows used in financing activities during the nine months ended September 30, 2020 were $0.7 million, related to the repayments of long-term borrowings of $0.3 million and manager and shareholder distributions of $0.3 million.

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. Such investment activities, which include estimated capital spending on planned well recompletions for the Beta Project, are expected to be funded from cash flows from operations and existing cash-on-hand and not from equity, debt or off-balance sheet financing arrangements.

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 and long-term liquidity needs are to fund its operations and capital expenditures for its oil and gas properties and borrowing repayments.properties. Such needs are funded utilizing operating income and existing cash on-hand.

As of September 30, 2021,2022, the Fund’s estimated capital commitments related to its oil and gas properties were $2.5$2.1 million (which include asset retirement obligations for the Fund’s projects of $1.4 million), of which $0.6 million is expected to be spent during the next twelve months related to the recompletion work for the Beta Project and the settlement of asset retirement obligations for certain of the Fund’s projects.months. Future results of operations and cash flows are dependent on planned recompletion costs of and revenues from production and sale of oil and gas from the Beta Project. In addition, cash flow from operations may be impacted by fluctuations in oil and natural gas commodity prices.

Based upon its current cash position, salvage fund and its current reservereserves estimates, the Fund expects cash flow from operations to be sufficient to cover its commitments borrowing repayments and ongoing operations. ReserveReserves 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 may temporarily suspend distributions 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 all or a portion of 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. However, distributions may be impacted by amounts reserved to provideof future capital required for the borrowing repaymentscosts associated with the well recompletions for the Credit Agreement (defined below) andBeta Project, as budgeted, as well as the funding of estimated asset retirement obligations. Distributions may also be impacted by fluctuations in oil and natural gas commodity prices.

Credit Agreement

As of September 30, 2021 and December 31, 2020, the Fund had outstanding borrowings of $0.4 million and $1.4 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”).

Borrowings under the Credit Agreement bear 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. Beginning on April 1, 2019 and each April 1^st thereafter, the Fund’s fixed percentage is 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 is 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 of December 31, 2022. As of April 1, 2021, the Fund’s fixed percentage was determined to be 51%. 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, warranties 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 is in compliance with all covenants under the Credit Agreement as of September 30, 2021 and December 31, 2020.

Off-Balance Sheet Arrangements

The Fund had no off-balance sheet arrangements as of September 30, 2021 and December 31, 2020 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 September 30, 20212022 and December 31, 2020,2021, other than those discussed in “Estimated Capital“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 September 30, 2021.2022.

There has been no change in the Fund’s internal control over financial reporting that occurred during the three months ended September 30, 20212022 that has materially affected, or is reasonably likely to materially affect, the Fund’s internal control over financial reporting. The Fund has not experienced any material impact to internal control over financial reporting due to the COVID-19 pandemic.