PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

RIDGEWOOD ENERGY S 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 S 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 S 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 S 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 S FUND, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

1.Organization and Summary of Significant Accounting Policies

Organization

The Ridgewood Energy S Fund, LLC (the “Fund”), a Delaware limited liability company, was formed on December 19, 2005 and operates pursuant to a limited liability company agreement (the “LLC Agreement”) dated as of February 1, 2006 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 4 and 5.4.

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, 20192020 financial statements and notes thereto included in the Fund’s Annual Report on Form 10-K (“20192020 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, 2019,2020, 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 20192020 Annual Report. There have been no significant changes to the Fund’s significant accounting policies during the three and ninesix months ended SeptemberJune 30, 2020.2021.

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, salvage fund, due to operators, accrued expenses and long-term debt and other current liabilities.debt. Except for long-term debt, 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:

On May 26, 2021, the Fund entered into a settlement agreement and release with the operator of West Cameron 75, which fully absolves the Fund from its asset retirement obligation for this well. In addition, the Fund also entered into an abandonment and escrow agreement with the well’s operator wherein the Fund will deposit into an escrow account its share of the plug and abandonment costs beginning June 2021 through January 2022. As a result, the Fund relieved the related asset retirement obligation totaling $0.3 million and the remaining balance of such liability is recorded within “Due to operators” on its balance sheet as of June 30, 2021.

During the six months ended June 30, 2021, the Fund recorded depletion expense totaling $0.1 million, which 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. Naturalcustomers in accordance with Accounting Standard Codification Topic 606, Revenue from Contracts with Customers. Revenues from the sale of natural gas liquid sales are included within gas sales.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 an affiliated entityentities 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 an affiliated entityentities and other third parties does not give rise to contract assets or liabilities. The receivables related to the Fund’s proportionate share of revenue from an affiliateaffiliates 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 ninesix months ended SeptemberJune 30, 20202021 and 2019,2020, 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 propertiesAllowance for impairment whenever events and circumstances indicate that the recorded carrying value of the oil and gas properties may not be recoverable. Impairments are determined 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 written down to fair value, which is determined using valuation techniques that include both market and income approaches and use Level 3 inputs. The fair value determinations require considerable judgment and are sensitive to change. Different pricing assumptions, reserve estimates or discount rates could result in a different calculated impairment.

During first half of 2020, there had been a significant fluctuation in oil and natural gas commodity prices primarily due to the Coronavirus (“COVID-19”) pandemic. 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. The Fund is unable to predict the amount of future reserve revisions at this time, however, if oil and natural gas commodity prices are further impacted by the COVID-19 pandemic, it is possible that impairments of oil and gas properties will occur.

During third quarter 2020, the Beta Project experienced negative oil and natural gas reserves revisions primarily due to well performance and a steeper than anticipated production decline curve. As a result, the Fund determined that it had a triggering event requiring the Fund to evaluate recoverability of the Beta Project. The Fund performed an asset recoverability assessment for the Beta Project as of September 30, 2020 and based on this assessment, the Fund determined the Beta Project was not impaired during the three and nine months ended September 30, 2020. There were no impairments during the three and nine months ended September 30, 2019.

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 adopted this accounting guidance on January 1, 2020 and the adoption did not have a material impact on the Fund’s financial statements.

In June 2016, the FASB issued accounting guidance on measurement of credit losses, which introduces, among other things, a new expected loss impairment model that applies to most financial assets measured at amortized cost and certain other instruments including trade and other receivables and other financial assets. Under the new accounting guidance, entities are required to estimate expected credit loss over the life of financial assets and record an allowance against the asset’s amortized cost basis to present the financial asset at the amount expected to be collected. The estimate of expected credit losses will require entities to incorporate considerations of historical information, current information and reasonable and supportable forecasts. The accounting guidance and the most recent update issued in February 2020 are effective for the Fund in the first quarter of 2023 with early adoption permitted. The Fund early adopted this accounting guidance and related updates prospectively on January 1, 2020 and the adoption did not result in a cumulative adjustment to retained earnings on January 1, 2020. 

Credit Losses

The Fund is exposed to credit losses through the salessale 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 COVID-19Coronavirus (“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

During 2019,The Fund reviews the Fund, as well as other funds managed by the Manager that invested in the Beta Project, elected not to participate in the drillingcarrying value of the 8th well proposed by Walter Oil and Gas Corporation. As a result, the Fund was due reimbursement for a portion of the cost relating to the slot on the Beta Project platform that was utilized by the other third-party working interest owners for the 8th well. On July 17, 2019, the Fund and the other third-party working interest owners in the Beta Project agreed to a reimbursement to the Fund of $0.5 million, which was recorded as a reduction toits 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 six months ended June 30, 2021 and 2020. 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 six months ended June 30, 2021 or 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 balance sheet as of September 30, 2019 and presented as “Reimbursement from operator for capital expenditures” in the investing section of the Fund’s statement of cash flows for the nine months ended September 30, 2019. The amount received was utilized by the Fund to repay a portion of the long-term debt outstanding under its Credit Agreement as defined below in Note 4. There was no such reimbursement during the nine months ended September 30, 2020.financial statements.

2. 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 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. Effective April 1, 2020, the Manager waived its management fee for the remaining life of the Fund. Upon the waiver of the management fee, the Fund began recording costs, totaling $20 thousand per quarter, representing reimbursements to the Manager, related to services provided by the Manager for accounting and investor relations. Such costs are included on the statements of operations within general and administrative expenses. Management reimbursement costs during the three and ninesix months ended SeptemberJune 30, 20202021 were $20 thousand and $40 thousand, respectively. Management reimbursement costs during the three months ended June 30, 2020 were $20 thousand. Management fees during the ninesix months ended SeptemberJune 30, 2020 were $0.1 million. Management fees during the three and nine months ended September 30, 2019 were $0.1 million and $0.4 million, respectively.

The Manager is also entitled to receive 15% of the cash distributions from operations made by the Fund. Distributions paid to the Manager during each of the three and six months ended June 30, 2021 were $9 thousand. The Fund did not pay distributions during the three months ended SeptemberJune 30, 2020. Distributions paid to the Manager during the ninesix months ended SeptemberJune 30, 2020 were $14 thousand. Distributions paid to the Manager during the three and nine months ended September 30, 2019 were $33 thousand and $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 parties 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”), and other third-party working interest owners in the Claiborne Project. On September 23, 2020, a third-party working interest owner of the Claiborne Project executed a consent letter to assign the rights to the services under the PHA to Ridgewood Rattlesnake, LLC, a wholly-owned entity of Ridgewood Energy Oil & Gas Fund III, L.P. (“Institutional Fund III”). Institutional Fund II is an entityand Institutional Fund III are entities that isare managed by the Fund’s Manager. During the three and ninesix months ended SeptemberJune 30, 2021, the Fund earned $38 thousand and $0.1 million, respectively, representing its proportionate share of the production handling fees earned from Institutional Fund II and Institutional Fund III, which is included within “Other revenue” on the Fund’s statements of operations. During the three and six months ended June 30, 2020, the Fund earned $27$14 thousand and $0.1 million,$26 thousand, respectively, representing its proportionate share of the production handling fees earned from Institutional Fund II, which is included within “Other revenue” on the Fund’s statements of operations. During the three and nine months ended September 30, 2019, the Fund earned $15 thousand and $49 thousand, respectively, representing its proportionate share of the production handling fees earned from Institutional Fund II. As of SeptemberJune 30, 20202021 and December 31, 2019,2020, the Fund’s receivables of $17$24 thousand and $15$19 thousand, respectively, related to the Fund’s proportionate share of revenue from Institutional Fund II and Institutional Fund III 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

As of SeptemberJune 30, 20202021 and December 31, 2019,2020, the Fund had outstanding borrowings of $1.7$0.9 million and $2.0$1.5 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 SeptemberJune 30, 2020,2021, the estimated fair value of the debt was $1.6$0.9 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 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 each 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, 2020,2021, the Fund’s fixed percentage was determined to be 30%49%. 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 13.34% 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 SeptemberJune 30, 20202021 and December 31, 2019,2020, the unamortized debt discounts related to the loan of $9$6 thousand and $12$8 thousand, respectively, were presented as a reduction of “Long-term borrowings”long-term borrowings on the Fund’s balance sheets. Amortization expense during the three and ninesix months ended SeptemberJune 30, 2020 of $1 thousand and $3 thousand, respectively, was included on the Fund’s statements of operations within “Interest expense, net”. Amortization expense during the three and nine months ended September 30, 20192021 of $1 thousand and $2 thousand, respectively, was included on the Fund’s statements of operations within “Interest expense, net”. Amortization expense during each of the three and six months ended June 30, 2020 of $1 thousand was included on the Fund’s statements of operations within “Interest expense, net”. As of SeptemberJune 30, 20202021 and December 31, 2019,2020, there were no00no accrued interest costs outstanding. Interest costs incurred during the three and ninesix months ended SeptemberJune 30, 20202021 of $39$26 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 ninesix months ended SeptemberJune 30, 20192020 of $0.1 million$40 thousand and $0.2$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 SeptemberJune 30, 20202021 and December 31, 2019.2020.

4.Commitments and Contingencies

Capital Commitments

As of SeptemberJune 30, 2020,2021, the Fund’s estimated capital commitments related to its oil and gas properties were $2.0$1.9 million (which include asset retirement obligations for the Fund’s projects of $1.1$0.9 million), of which $0.6$0.1 million is expected to be spent during the next twelve months primarily related to the recompletion work for the Beta Project and the settlement of asset retirement obligations for certain of the Fund’s projects.Project. Future results of operations and cash flows are dependent on the relatedrevenues from production and sale of oil and gas revenues from the Beta Project.

Based upon its current cash position, salvage fund and its current reserve estimates, the Fund expects cash flow from operations to be sufficient to cover its commitments, borrowing repayments and ongoing operations. Reserve estimates are projections based on engineering data that cannot be measured with precision, require substantial judgment, and are subject to frequent revision. However, if cash flow from operations is not sufficient to meet the Fund’s commitments, the Manager will provide short-term financingmay temporarily suspend distributions to accommodate the Fund’s short-term commitments if needed.

Impact from COVID-19

The extent of the impact of the COVID-19 pandemic on the Fund’sremains a global health crisis and continues to cause uncertainty in financial position, results of operations and cash flows will depend on future developments, including the duration and spread of the pandemic and related advisories and restrictions and the impact of COVID-19 on oil and natural gas commodity prices, financial markets and the overall economy, all of which are highly uncertain and cannot be predicted. Lower oil and gas prices may reduce the amount of oil and gas products which can be economically produced. Although themarkets. The ultimate extent of the impact of the COVID-19 pandemic and resulting market disruption to the Fund’s operating results and cash flows iscontinue 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 projects.  With the continued uncertainty,Beta Project. However, because the Fund has electedowns the Beta Project with little debt and the project is a long-lived asset that is expected to conserve capital for unforeseen expensesproduce over many years with relatively low operating costs, the Fund believes that it is positioned to weather this period of uncertainty and to temporarily suspend distributions.volatility from the COVID-19 pandemic. If oil and natural gas commodity prices and the overall global economy, including financial markets and/or the overall economytherein, 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 maywill be materially adversely affected, which could significantly affect the Fund’s liquidity development of oil and gas 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.

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, 20202021 and December 31, 2019,2020, 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 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 June 22, 2017, the BOEM announced that the implementation timeline extension will remain in effect pending the completion of the review of NTL 2016-N01. As of SeptemberJune 30, 2020,2021, the BOEM has not lifted its suspension of the implementation of NTL 2016-N01. The impact of NTL 2016-N01, 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.

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 Outer Continental Shelf 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. The Fund is not able to evaluate the impact of the proposed new rule on its operations or financial condition until the final rule is issued.

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 S 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 that1995. 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, 2019.2020.

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 well costs incurred by the Fund and fully depleted project investments. Effective April 1, 2020, the Manager waived its management fee for the remaining life of the Fund. Upon the waiver of the management fee, the Fund began recording costs related to services provided by the Manager for accounting and investor relations. 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 Developments

In March 2020, the World Health Organization recognizedcategorized the novel strainoutbreak of coronavirus (“COVID-19”)COVID-19 as a global pandemic, which resulted in a significant drop in oil demand caused by lockdown measures and industrial slowdown around 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. Although on April 12, 2020, OPEC and Russia agreed to reduce production by approximately 9.7 million barrels per day in May and June 2020, the COVID-19 pandemic, the initial oil price war and significant oil demand destruction as a result of world-wide government ordered lock-downs pushed oilOil prices decreased to their lowest level duringin April 2020 as compared to the past several years.years as a result of the initial oil price war and significant decreases 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 stabilized and strengthened with oil prices gradually rising. On June 6, 2020,rising throughout 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 measures and the rollout of COVID-19 vaccines, market-driven supply cutbacks in the upstream oil sector globally 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 Russia agreed to extend the production cut of approximately 9.7 million barrels per day through the end of July 2020 and maintainnon-OPEC countries in supporting a production cut of 7.7 million barrels per day from August 2020 through the end of the year.balanced global oil supply.

Although theThe ultimate extent of the impact of the COVID-19 pandemic and resulting market disruption to the Fund’s operating results and cash flows iscontinue 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 projects.  With the continued uncertainty, the Fund has elected to conserve capital for unforeseen expenses and to temporarily suspend distributions.Beta Project. However, because 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. However, ifIf 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 maywill be materially adversely impacted,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.

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. During first half of 2020, oil and natural gas commodity prices experienced significant volatility primarily attributable to the COVID-19 pandemic. The Fund anticipates price cyclicality in its planning and believes it is well positioned to withstand price volatility. The Fund will continue to closely manage and coordinate its capital spending estimates within its expected cash flows to provide for future development costs of 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 ninesix months ended SeptemberJune 30, 20202021 and 20192020 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 ninesix months ended SeptemberJune 30, 20202021 and 2019,2020, 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 ninesix months ended SeptemberJune 30, 20202021 and 2019.2020. Natural gas liquid sales are included within gas sales.

The decreases in the number of wells producing and production days and gas sales volumes noted in the table above table were primarily attributable to West Cameron 75,Main Pass 275, which was shut-in in May 2020 due to the low-price environment and reached the end of its productive life during firstsecond quarter 2020. In addition, as a result of the Fund’s withdrawal from the operating agreement effective October 9, 2019, the Fund did not receive its share of revenue since fourth quarter 2019.2021. The decreases in oil and gas sales volumevolumes noted in the table above were primarily related to the Beta Project, aswhich is experiencing a resultnatural decline in production coupled with the shut-in of curtailmentone of productionits wells during May 2020second quarter 2021 due to the low-price environment coupled with storm-related safety shut-ins due to the active storm systems passing through the Gulf of Mexico during third quarter 2020.recompletion work. See additional discussion in “Business Update” section above.

Oil and Gas Revenue. Oil and gas revenue during the three months ended SeptemberJune 30, 20202021 was $0.5$0.9 million, a decreasean increase of $0.5$0.6 million from the three months ended SeptemberJune 30, 2019.2020. The decreaseincrease was primarily attributable to decreased sales volume totaling $0.2 million coupled with decreasedincreased oil prices totaling $0.2 million.and gas prices.

Oil and gas revenue during the ninesix months ended SeptemberJune 30, 20202021 was $1.5$1.6 million, a decreasean increase of $1.4$0.6 million from the ninesix months ended SeptemberJune 30, 2019.2020. The decreaseincrease was attributable to decreasedincreased oil and gas prices totaling $0.9$0.7 million coupled withpartially offset by decreased sales volume totaling $0.4$0.2 million.

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

Other Revenue. Other revenue is generated from the Fund’s production handling, gathering and operating services agreement with an affiliated entityentities and other third parties.

Depletion and Amortization. Depletion and amortization during the three months ended SeptemberJune 30, 20202021 was $0.4$0.7 million, a decreasean increase of $0.2$0.3 million from the three months ended SeptemberJune 30, 2019.2020. The decreaseincrease was primarily attributable to a decreasean increase in production volumes.the average depletion rate.

Depletion and amortization during the ninesix months ended SeptemberJune 30, 20202021 was $1.4 million, a decreasean increase of $0.3$0.5 million from the ninesix months ended SeptemberJune 30, 2019.2020. The decreaseincrease was attributable to an increase in the average depletion rate totaling $0.5 million and an adjustment to the asset retirement obligation related to a fully depleted property totaling $0.1 million during the six months ended June 30, 2021, partially offset by a decrease in production volumes totaling $0.2 million coupled with a decrease$0.1 million.

The increases in the average depletion rate totaling $0.1 million.rates were primarily attributable to the changes in reserves estimates provided annually by the Fund’s independent petroleum engineers.

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. 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. Workover expense represents costs to restore or stimulate production of existing reserves. 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. The credit in lease operating expense noted in the table above was primarily due to an adjustment related to West Cameron 75 as a result of the final settlement of outstanding lease operating expense, which the Fund was obligated to pay pursuant to that settlement agreement and release executed on May 26, 2021.

Production costs, which include lease operating expense, transportation and processing expense and insurance expense, were $0.1 million$22 thousand ($7.191.45 per barrel of oil equivalent or “BOE”) and $0.6$0.2 million ($13.655.81 per BOE) during the three and ninesix months ended SeptemberJune 30, 2020,2021, respectively, compared to $0.1$0.2 million ($3.4013.60 per BOE) and $0.6 million ($9.5616.12 per BOE) during the three and ninesix months ended SeptemberJune 30, 2019,2020, respectively.

ProductionThe decreases in production costs were relatively consistent during the three and nine months ended September 30, 2020 compared to the three and nine months ended September 30, 2019. The increases in production costs per BOE during the three and ninesix months ended SeptemberJune 30, 20202021 compared to the three and ninesix months ended SeptemberJune 30, 20192020 were primarily due to decreased oil production from the Beta Project as a result of curtailment of production during May 2020 dueattributable to the low-price environment coupled with storm-related safety shut-ins due to the active storm systems passing through the Gulfimpact of Mexico during third quarter 2020. The increase in production costs per BOE during the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 was also due to the lease operating expense incurred during first quarter 2020 related to West Cameron 75, which the Fund was obligated to pay after withdrawal from the joint operating agreement in fourth quarter 2019.2019 coupled with an adjustment to the lease operating expense recorded during second quarter 2021 described above. The decreases were also attributable to decreased oil and natural gas production from the Beta Project as a result of natural decline in production. 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, was paid monthly to the Manager. Effective April 1, 2020, the Manager waived its management fee for the remaining life of the Fund.

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. Management reimbursement costs related to services provided by the Manager for accounting and investor relations are also included within general and administrative expenses.

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

Capital Resources and Liquidity

Operating Cash Flows

Cash flows provided by operating activities during the ninesix months ended SeptemberJune 30, 20202021 were $0.3$1.3 million, primarily related to revenue received of $1.6$1.8 million, partially offset by operating expenses of $0.7$0.2 million, general and administrative expenses of $0.2$0.1 million, interest payments of $0.1 million and the payment of $0.1 million related to the Fund’s proportionate share of the plug and abandonment for a fully depleted property pursuant to the settlement agreement and release executed on May 26, 2021 with the well’s operator.

Cash flows provided by operating activities during the six months ended June 30, 2020 were $0.1 million, primarily related to revenue received of $1.1 million, partially offset by operating expenses of $0.5 million, the 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, management fees of $0.1 million, and interest payments of $0.1 million.

Cash flows provided by operating activities during the nine months ended September 30, 2019 were $1.8 million, primarily related to revenue received of $3.3 million, partially offset by operating expenses of $0.7 million, management fees of $0.4 million, interest payments of $0.2 million and general and administrative expenses of $0.2$0.1 million and interest payments of $0.1 million.

Investing Cash Flows

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

Cash flows used in investing activities during the six months ended June 30, 2020 were $0.1 million, primarily related to investments in salvage fund.

Cash flows provided by investing activities during the nine months ended September 30, 2019 were $0.3 million, related to the reimbursement received from operator for capital expenditures of $0.5 million and proceeds from the salvage fund of $0.3 million, partially offset by capital expenditures for oil and gas properties of $0.4 million. The reimbursement received from operator for capital expenditures related to a portion of the cost of the Beta Project platform slot that was utilized by the other third-party working interest owners for the project’s 8th well. The Fund as well as other funds managed by the Manager that invested in the Beta Project elected not to participate in the drilling of the 8th well proposed by the Beta Project operator.

Financing Cash Flows

Cash flows used in financing activities during the ninesix months ended SeptemberJune 30, 20202021 were $0.5$0.7 million, related to the repayments of long-term borrowings of $0.4$0.6 million and manager and shareholder distributions of $0.1 million.

Cash flows used in financing activities during the ninesix months ended SeptemberJune 30, 20192020 were $1.8$0.3 million, related to the repayments of long-term borrowings of $1.2$0.2 million and manager and shareholder distributions of $0.6$0.1 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. See “Business Update” under this Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Quarterly Report for information regarding the Fund’s current projects. See “Liquidity Needs” below for additional information.

Liquidity Needs

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

As of SeptemberJune 30, 2020,2021, the Fund’s estimated capital commitments related to its oil and gas properties were $2.0$1.9 million (which include asset retirement obligations for the Fund’s projects of $1.1$0.9 million), of which $0.6$0.1 million is expected to be spent during the next twelve months primarily related to the recompletion work for the Beta Project and the settlement of asset retirement obligations for certain of the Fund’s projects.Project. Future results of operations and cash flows are dependent on the relatedrevenues from production and sale of oil and gas revenues from the Beta Project.

Based upon its current cash position, salvage fund and its current reserve estimates, the Fund expects cash flow from operations to be sufficient to cover its commitments, borrowing repayments and ongoing operations. Reserve estimates are projections based on engineering data that cannot be measured with precision, require substantial judgment, and are subject to frequent revision. However, if cash flow from operations is not sufficient to meet the Fund’s commitments, the Manager will provide short-term financingmay temporarily suspend distributions to accommodate the Fund’s short-term commitments if needed.

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 provide for the borrowing repayments for the Credit Agreement (defined below) and funding of estimated asset retirement obligations. Distributions may also be impacted by fluctuations in oil and natural gas commodity prices due to the COVID-19 pandemic.prices.

Credit Agreement

As of SeptemberJune 30, 20202021 and December 31, 2019,2020, the Fund had outstanding borrowings of $1.7$0.9 million and $2.0$1.5 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, 2020,2021, the Fund’s fixed percentage was determined to be 30%49%. The loan may be prepaid by the Fund without premium or penalty. The Credit Agreement also provides for a fixed percentage of 13.34% 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 believes it is in compliance with all covenants under the Credit Agreement as of SeptemberJune 30, 20202021 and December 31, 2019.2020.

Off-Balance Sheet Arrangements

The Fund had no off-balance sheet arrangements as of SeptemberJune 30, 20202021 and December 31, 20192020 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, 20202021 and December 31, 2019,2020, other than those discussed in “Estimated Capital Expenditures” and “Liquidity Needs – Credit Agreement” above.

Recent Accounting Pronouncements

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

Not required.