UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

or

Commission File No. 000-53591

Ridgewood Energy X Fund, LLC

(Exact name of registrant as specified in its charter)

14 Philips Parkway, Montvale, NJ  07645

(Address of principal executive offices) (Zip code)

(800) 942-5550

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act: None

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes  ☒   xNo ☐o

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).   Yes ☒x     No ☐o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes☐   YesoNo ☒x

As of November 9, 2018August 6, 2019, there were 477.8874 shares of LLC Membership Interest outstanding.

Table of Contents

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

RIDGEWOOD ENERGY X FUND, LLC

UNAUDITED CONDENSED BALANCE SHEETS

(in thousands, except share data)

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

RIDGEWOOD ENERGY X 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.

RIDGEWOOD ENERGY X 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.

RIDGEWOOD ENERGY X FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF CASH FLOWS

(in thousands)

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

RIDGEWOOD ENERGY X FUND, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

1.       Organization and Summary of Significant Accounting Policies

Organization

The Ridgewood Energy X Fund, LLC (the “Fund”), a Delaware limited liability company, was formed on August 30, 2007 and operates pursuant to a limited liability company agreement (the “LLC Agreement”) dated as of January 2, 2008 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 32 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, financial position,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, 20172018 financial statements and notes thereto included in the Fund’s Annual Report on Form 10-K (“20172018 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, 2017,2018, 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, the Manager 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 20172018 Annual Report. There have been no significant changes to the Fund’s significant accounting policies during the three and ninesix months ended SeptemberJune 30, 2018, except as noted below for investment in Delta House and revenue recognition. See Note 2. “Revenue Recognition” for discussion of the Fund’s updated accounting policies related to revenue recognition for revenue from contracts with customers.2019.

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 instruments consist of cash and cash equivalents, salvage fund, production receivable, other current assets, investment in Delta House, due to operators and accrued expenses. Except for investment in Delta House, the carrying amounts of these instruments approximate fair value due to their short-term nature. The Fund’s salvage fund is a separate interest-bearing account that has no restrictions on withdrawals, therefore its carrying amount approximates fair value.

The Fund’s investment in Delta House is valued using the measurement alternative for investment in other entities (see “InvestmentInvestment in Delta House”House below for additional information). 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.

Investment in Delta House

The Fund has investments in Delta House Oil and Gas Lateral, LLC and Delta House FPS, LLC (collectively “Delta House”), legal entities that own interests in a deepwater floating production system operated by LLOG Exploration Offshore, L.L.C. Upon adoption of the new accounting guidance on financial instruments on January 1, 2018, the Fund electedThe investment in Delta House is valued using the measurement alternative to record the investment in Delta House at cost, less impairment and plus or minus subsequent adjustments for observable price changes with change in basis reported in current earnings. At each reporting period, the Fund reviews its investment in Delta House to evaluate whether the investment is impaired. Losses on investments, including impairments, are classified as non-operating losses in the Fund’s statements of operations. During each of the three and ninesix months ended SeptemberJune 30, 20182019 and 2017,2018, there were no impairments of the Fund’s investment in Delta House.

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

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 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.

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 ninethree and six months ended SeptemberJune 30, 2017, the Fund recorded credits to depletion expense totaling $0.3 million related to an adjustment to the asset retirement obligation for a fully depleted property.2019 and 2018, revenue recognized from performance obligations satisfied in previous periods was 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 estimated fair value, which is determined using a valuation techniquetechniques that considersinclude both market and income approaches and usesuse 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 ninesix months ended SeptemberJune 30, 20182019 and 2017.2018. 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 JanuaryFebruary 2016, the FASB issued accounting guidance on financial instruments,leases as amended in Februaryon 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 requires, among other things, companies to measure investments in other entities, except those accounted forwere not previously assessed under the equity method, at fair valueexisting lease guidance. The accounting guidance does not apply to leases of mineral rights to explore for or use of oil and recognize any changes in fair value in net income unless an election is made to record the investment at cost, less impairment and plus or minus subsequent adjustments for observable price changes with change in basis reported in current earnings. This pronouncementnatural gas. The accounting guidance was effective for the Fund in first quarter of 2018 and early adoption was not permitted. The amendments are effective in third quarter of 2018, however early adoption is permitted. The Fund adopted the accounting guidance onbeginning January 1, 2018, as well as the amendments issued in February 2018 in third quarter of 2018, and it did not have an impact on the Fund’s investment in other entities (see “Investment in Delta House” above).

In May 2014, the FASB issued accounting guidance on revenue recognition (“New Revenue Standard”), which provides for a single five-step model to be applied to all revenue contracts with customers. In July 2015, the FASB issued a deferral of the effective date of the New Revenue Standard to 2018, with early adoption permitted in 2017. In March 2016, the FASB issued accounting guidance, which clarifies the implementation guidance on principal versus agent considerations in the New Revenue Standard. In April 2016, the FASB issued guidance on identifying performance obligations and licensing and in May 2016, the FASB issued final amendments which provided narrow scope improvements and practical expedients related to the implementation of the New Revenue Standard. The New Revenue Standard may be applied either retrospectively or through the use of a modified-retrospective method. Under the New Revenue Standard, the revenue associated with the Fund’s existing contracts will be recognized in the period that control of the related commodity is transferred to the customer, which is generally consistent with the Fund’s previous revenue recognition model. The Fund adopted the New Revenue Standard using the modified retrospective method on January 1, 2018. See Note 2. “Revenue Recognition” for the required disclosures related to the impact of adopting this guidance and a discussion of the Fund’s updated policies related to revenue recognition for revenue from contracts with customers.

2.       Revenue Recognition

The Fund adopted the New Revenue Standard on January 1, 2018 using the modified retrospective method for all new contracts entered into after January 1, 2018 and all existing contracts for which revenues have not been recognized under the previous revenue guidance as of December 31, 2017.2019. 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 identify changes to its revenue recognition that resulted in a cumulative adjustment to retained earnings on January 1, 2018,meet the adoptiondefinition of leases under the new accounting guidance resulted in enhanced disclosures related to revenue recognition policies, the Fund’s performance obligations and significant judgments used in applying the New Revenue Standard.therefore, did not qualify for lease accounting.

Revenue from Contracts with Customers

Oil and gas revenues are recognized at the point when control of oil and natural gas is transferred to the customers. Natural gas liquid (“NGL”) sales are included within gas sales. The Fund’s oil and natural gas generally is sold to its customers at prevailing market prices based on an index in which the prices are published, adjusted for pricing differentials, quality of the oil and pipeline allowances.

Oil and Gas Revenue

Generally, the Fund sells oil and natural gas under two types of agreements, which are common in the oil and gas industry. In the first type of agreement, or a netback agreement, the Fund receives a price, net of pricing differentials as well as transportation expense incurred by the customer, and the Fund records revenue at the wellhead at the net price received where control transfers to the customer. In the second type of agreement, the Fund delivers oil and natural gas to the customer at a contractually agreed-upon delivery point where the customer takes control. The Fund pays a third-party to transport the oil and natural gas and receives a specific market price from the customer net of pricing adjustments. The Fund records the transportation expense within operating expenses in the statements of operations.

Under the Fund’s natural gas processing contracts, the Fund delivers natural gas to a midstream processing company at the inlet of the midstream processing company’s facility. The midstream processing company gathers and processes the natural gas and remits the proceeds to the Fund for the sale of NGLs. In this type of arrangement, the Fund evaluates whether it is the principal or agent in the transaction. The Fund concluded that it is the principal and the ultimate third-party purchaser is the customer, therefore, the Fund recognizes revenue on a gross basis, with transportation, gathering and processing fees recorded as an expense within operating expenses in the statements of operations.

In certain instances, the Fund may elect to take its residue gas and NGLs in-kind at the tailgate of the midstream company’s processing plant and subsequently market such volumes. Through its marketing process, the Fund delivers the residue gas and NGLs to the ultimate third-party customer at a contractually agreed-upon delivery point and receives a specified market price from the customer. In this arrangement, the Fund recognizes revenue when control transfers to the customer at the delivery point based on the market price received from the customer. The transportation, gathering and processing fees are recorded as expense within operating expenses in the statements of operations.

The Fund assesses the performance obligations promised in its oil and natural gas contracts based on each unit of oil and natural gas that will be transferred to its customer because each unit is capable of being distinct. The Fund satisfies its performance obligation when control transfers at a point in time when its customer is able to direct the use of, and obtain substantially all of the benefits from, the oil and natural gas delivered. Under each of the Fund’s oil and natural gas contracts, contract prices are variable and based on an index in which the prices are published, which fluctuate as a result of related industry variables, adjusted for pricing differentials, quality of the oil and pipeline allowances. The use of index-based pricing with predictable differentials reduces the level of uncertainty related to oil and gas prices. Additionally, any variable consideration is not constrained. Payments are received in the month following the oil and natural gas production month. Adjustments that occur after delivery, such as quality bank adjustments, are reflected in revenue in the month payments are received.

Transaction price allocated to remaining performance obligations

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.

Contract balances

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 under the New Revenue Standard. The receivables related to the Fund’s oil and gas revenue are included within “Production receivable” on the balance sheets.

Prior period performance obligations

The Fund records oil and gas revenue in the month production is delivered to its customers. However, settlement statements for residue gas and NGLs sales may not be received for 30 to 60 days after the date production is delivered. As a result, the Fund is required to estimate the amount of production delivered to the purchaser and the price that will be received for the sale of the residue gas and NGLs. The Fund records the differences between its estimates and the actual amounts received in the month that the payment is received from the customer. The Fund has an estimation process for revenue and related accruals, and any identified difference between its revenue estimates and actual revenue historically have not been significant. There was no material revenue recognized in the current period from performance obligations satisfied in previous periods.

3.       Related Parties

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 ninesix months ended SeptemberJune 30, 20182019 and 20172018 were $0.3 million and $0.8$0.5 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 the three and ninesix months ended SeptemberJune 30, 20182019 were $0.2$0.1 million and $0.5$0.2 million, respectively. Distributions paid to the Manager during the three and ninesix months ended SeptemberJune 30, 20172018 were $0.1 million and $0.3 million, respectively.

The Fund utilizes DH 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 Diller and Marmalard projects.

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.

4.       Commitments and Contingencies

Capital Commitments

As of SeptemberJune 30, 2018,2019, the Fund’s estimated capital commitments related to its oil and gas properties were $4.5$4.4 million (which include asset retirement obligations for the Fund’s projects of $1.6 million), of which $0.9$1.6 million is expected to be spent during the next twelve months.

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 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.

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 SeptemberJune 30, 20182019 and December 31, 2017,2018, 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 new 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 new 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 new NTL. The Fund, as well as other industry participants, are working withAs of June 30, 2019, the BOEM has not completed its operators and working interest partners to determine and agree uponreview nor has the correct level of decommissioning obligations to which they may be liable and the manner in which such obligations will be secured.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.

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 X 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, 2017, except for the revenue recognition for revenue from contracts with customers. See Note 2 of “Notes to Unaudited Condensed Financial Statements” - “Revenue Recognition” contained in Item 1. “Financial Statements” within Part I of this Quarterly Report for adiscussion of the Fund’s updated accounting policies on revenue recognition upon adoption of the related new standard.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.

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 continueswill continue to conserveclosely manage and coordinate its capital spending estimates within its expected cash flows to provide for the additionalfuture development costs for the Diller and Marmalardof 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 ninesix months ended SeptemberJune 30, 20182019 and 20172018 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 ninesix months ended SeptemberJune 30, 20182019 and 2017,2018, 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.

OverviewOverview.. The following table provides information related to the Fund’s oil and natural gas production and oil and gas revenue during the three and ninesix months ended SeptemberJune 30, 20182019 and 2017.2018. Natural gas liquid (“NGL”) sales are included within gas sales.

The production-related decreasesincreases in the above table were primarily related to the extended shut-ins of two wells in the Marmalard Project, which were shut-in during first half of 2018 due to replacement of well jumpers, during the first half of 2018, coupled with the Diller Project,and Liberty projects, which waswere shut-in periodically during second quarter 2018 due to hydrate issues.2018. These decreasesincreases were partially offset by decreases from the other two wells in the Marmalard Project, which experienced shut-ins during first half of 2019 due to mechanical issues. The decreases in oil and gas sales volumes during the six months ended June 30, 2019 were primarily related to the Liberty Project, which experienced increaseda decrease in production as a result of recompletion work in thirda shut-in during first quarter 2017.2019 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 SeptemberJune 30, 20182019 was $2.6$1.6 million, an increase of $1.0$0.3 million from the three months ended SeptemberJune 30, 2017.2018. The increase was attributable to increased sales volume totaling $0.4 million, partially offset by decreased oil and gas prices totaling $0.8 million coupled with increased sales volume totaling $0.2$0.1 million.

Oil and gas revenue during the ninesix months ended SeptemberJune 30, 20182019 was $5.8$2.9 million, an increasea decrease of $0.9$0.3 million from the ninesix months ended SeptemberJune 30, 2017.2018. The increasedecrease was attributable to increaseddecreased oil and gas prices totaling $1.5$0.2 million partially offset bycoupled with decreased sales volume totaling $0.6$0.1 million.

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

Depletion and Amortization. Depletion and amortization during the three months ended SeptemberJune 30, 20182019 was $0.2 million, an increase of $27 thousand from the three months ended June 30, 2018. The increase was primarily attributable to an increase in production volumes.

Depletion and amortization during the six months ended June 30, 2019 was $0.3 million, a decrease of $0.1$0.2 million from the threesix months ended SeptemberJune 30, 2017.2018. The decrease was attributable to a decrease in the average depletion rate totaling $0.2$0.1 million partially offset by an increase in production volumes totaling $0.1 million.

Depletion and amortization during the nine months ended September 30, 2018 was $0.8 million, a decrease of $0.2 million from the nine months ended September 30, 2017. The decrease was attributable to a decrease in the average depletion rate totaling $0.4 million coupled with a decrease in production volumes totaling $0.1 million. These decreases were partially offset by an adjustment to the asset retirement obligation related to a fully depleted property totaling $0.3 million, which was recorded in first quarter 2017.

$0.1 million. The decreasesdecrease in the average depletion rates wererate was primarily attributable to lower cost of reserves from the Diller and Marmalard projects. Liberty Project.

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.

Workover expense represents costs to restore or stimulate production of existing reserves. During the three and six months ended June 30, 2019, workover expense primarily related to remediation work for mechanical issues in the Marmalard Project. 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. 

Production costs, which include lease operating expense, transportation and processing expense and insurance expense, were $0.3 million ($10.13 per barrel of oil equivalent or “BOE”) and $0.6 million ($10.80 per BOE) during the three and six months ended June 30, 2019, respectively, compared to $0.3 million ($11.57 per BOE) and $0.6 million ($9.56 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 decrease in production cost per BOE during the three months ended June 30, 2019 compared to the three months ended June 30, 2018 was a result of increased production volumes from the Diller and Liberty projects, which were shut-in periodically during second quarter 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 certain fixed costs associated with the Diller and Marmalard projects, which were shut-in periodically during first half of 2019 due to mechanical issues. 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 properties. Insurance expense represents premiums related to the Fund’s properties, 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.

The average production cost, which includes lease operating expense, transportation and processing expense and insurance expense, was $9.43 per barrel of oil equivalent (“BOE”) and $9.47 per BOE during the three and nine months ended September 30, 2018, respectively, compared to $9.90 per BOE and $9.60 per BOE during the three and nine months ended September 30, 2017, respectively. The average production cost per BOE remained relatively consistent.

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.

Dividend Income.  Dividend income is related to the Fund’s investment in Delta House.

Interest Income. Interest income is comprised of interest earned on cash and cash equivalents and salvage fund.

Capital Resources and Liquidity

Operating Cash Flows

Cash flows provided by operating activities during the ninesix months ended SeptemberJune 30, 20182019 were $3.7$1.2 million, primarily related to revenue received of $5.7$2.8 million, partially offset by operating expenses of $1.0 million, management fees of $0.8$0.5 million and general and administrative expenses of $0.1 million.

Cash flows provided by operating activities during the ninesix months ended SeptemberJune 30, 20172018 were $2.4$2.2 million, primarily related to revenue received of $4.8$3.5 million, partially offset by operating expenses of $1.3$0.7 million, management fees of $0.8 million, the settlement of an asset retirement obligation of $0.2$0.5 million and general and administrative expenses of $0.1 million.

Investing Cash Flows

Cash flows provided byused in investing activities during the ninesix months ended SeptemberJune 30, 20182019 were $1.7$0.1 million, primarily related to proceeds from salvage fund of $1.9 million, partially offset by capital expenditures for oil and gas properties, inclusive of $0.2 million.advances.

Cash flows provided by investing activities during the ninesix months ended SeptemberJune 30, 20172018 were $0.2 million, primarily related to proceeds from salvage fund.$4 thousand.

Financing Cash Flows

Cash flows used in financing activities during the ninesix months ended SeptemberJune 30, 20182019 were $3.0$1.6 million, related to manager and shareholder distributions.

Cash flows used in financing activities during the ninesix months ended SeptemberJune 30, 20172018 were $2.1$2.0 million, related to manager and shareholder distributions.

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. The Fund’s remaining 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 and capital expenditures for its oil and gas properties. Such needs are funded utilizing operating income and existing cash on-hand. 

As of SeptemberJune 30, 2018,2019, the Fund’s estimated capital commitments related to its oil and gas properties were $4.5$4.4 million (which include asset retirement obligations for the Fund’s projects of $1.6 million), of which $0.9$1.6 million is expected to be spent during the next twelve months.

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 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.

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 future capital required to develop the Diller and Marmalard projects, distributions may be impacted by amounts reserved to provide for their development costs and funding their estimated asset retirement obligations.

Off-Balance Sheet Arrangements

The Fund had no off-balance sheet arrangements as of SeptemberJune 30, 20182019 and December 31, 20172018 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 SeptemberJune 30, 20182019 and December 31, 2017,2018, other than those discussed in “Estimated Capital Expenditures” 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 adiscussiona 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 SeptemberJune 30, 2018.2019.

There has been no change in the Fund’s internal control over financial reporting that occurred during the three months ended SeptemberJune 30, 20182019 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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