UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

ýQUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 For the quarterly period ended March 31, 20172018
or

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 For the transition period from _______________________to____________________________


Commission File No. 000-53895

Ridgewood Energy A-1 Fund, LLC
(Exact name of registrant as specified in its charter)

Delaware
(State or other jurisdiction of
incorporation or organization)
 
01-0921132
(I.R.S. Employer
Identification No.)

14 Philips Parkway, Montvale, NJ  07645
(Address of principal executive offices) (Zip code)

(800) 942-5550
(Registrant’s telephone number, including area code)

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 ☒   No

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).   Yes ☒     No

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 Securities Exchange Act of 1934.

Large accelerated filerAccelerated filer
Non-accelerated filer
(Do not check if a smaller reporting company)
Smaller reporting company
Emerging growth company

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 Securities Exchange Act of 1934.

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Securities Exchange Act of 1934).  Yes     No ☒

As of May 10, 2017 the Fund had11, 2018 there were 207.7026 shares of LLC Membership Interest outstanding.
 


 
Table of Contents

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PART I - FINANCIAL INFORMATION 
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PART II - OTHER INFORMATION 
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PART I – FINANCIAL INFORMATION

ITEM 1.  FINANCIAL STATEMENTS

RIDGEWOOD ENERGY A-1 FUND, LLC
UNAUDITED CONDENSED BALANCE SHEETS
(in thousands, except share data)

 March 31, 2017  December 31, 2016  March 31, 2018  December 31, 2017 
Assets            
Current assets:            
Cash and cash equivalents $3,634  $3,458  $2,267  $2,423 
Salvage fund  69   266   310   1,191 
Production receivable  283   324   408   491 
Other current assets  27   119   29   52 
Total current assets  4,013   4,167   3,014   4,157 
Salvage fund  1,483   1,286   1,281   355 
Oil and gas properties:                
Proved properties  18,772   18,056   21,111   20,498 
Less: accumulated depletion and amortization  (4,884)  (3,804)  (8,350)  (7,391)
Total oil and gas properties, net  13,888   14,252   12,761   13,107 
Total assets $19,384  $19,705  $17,056  $17,619 
                
Liabilities and Members' Capital                
Current liabilities:                
Due to operators $827  $462  $293  $609 
Accrued expenses  595   566   57   54 
Current portion of long-term borrowings  926   690   1,566   1,566 
Asset retirement obligations  69   266   310   1,191 
Other current liabilities  40   40 
Total current liabilities  2,417   1,984   2,266   3,460 
Long-term borrowings  6,248   6,453   5,392   5,639 
Asset retirement obligations  1,417   1,409   1,095   210 
Other liabilities  40   40 
Total liabilities  10,122   9,886   8,753   9,309 
Commitments and contingencies (Note 4)        
Commitments and contingencies (Note 5)        
Members' capital:                
Manager:                
Distributions  (5,058)  (5,058)  (5,058)  (5,058)
Retained earnings  5,195   5,117   5,638   5,484 
Manager's total  137   59   580   426 
Shareholders:                
Capital contributions (250 shares authorized;                
207.7026 issued and outstanding)  41,143   41,143   41,143   41,143 
Syndication costs  (4,804)  (4,804)  (4,804)  (4,804)
Distributions  (35,427)  (35,427)  (35,427)  (35,427)
Retained earnings  8,210   8,845   6,810   6,970 
Shareholders' total  9,122   9,757   7,722   7,882 
Accumulated other comprehensive income  3   3   1   2 
Total members' capital  9,262   9,819   8,303   8,310 
Total liabilities and members' capital $19,384  $19,705  $17,056  $17,619 

The accompanying notes are an integral part of these unaudited condensed financial statements.
 
1

 
RIDGEWOOD ENERGY A-1 FUND, LLC
UNAUDITED CONDENSED STATEMENTS OF OPERATIONS
AND COMPREHENSIVE LOSS
 (in thousands, except per share data)

    Three months ended March 31, 
  2018  2017 
Revenue      
Oil and gas revenue $1,366  $911 
Expenses        
Depletion and amortization  959   958 
Management fees to affiliate (Note 3)  93   94 
Operating expenses  132   189 
General and administrative expenses  46   42 
Total expenses  1,230   1,283 
Income (loss) from operations  136   (372)
Interest expense, net  (142)  (185)
Net loss  (6)  (557)
Other comprehensive loss        
Unrealized loss on marketable securities  (1)  - 
Total comprehensive loss $(7) $(557)
         
Manager Interest        
Net income $154  $78 
         
Shareholder Interest        
Net loss $(160) $(635)
Net loss per share $(773) $(3,053)

    Three months ended March 31, 
  2017  2016 
Revenue      
Oil and gas revenue $911  $18 
Expenses        
Depletion and amortization  958   7 
Management fees to affiliate (Note 2)  94   95 
Operating expenses  189   15 
General and administrative expenses  42   34 
Total expenses  1,283   151 
Loss from operations  (372)  (133)
Interest (expense) income, net  (185)  1 
Net loss  (557)  (132)
Other comprehensive income  -   - 
Total comprehensive loss $(557) $(132)
         
Manager Interest        
Net income (loss) $78  $(20)
         
Shareholder Interest        
Net loss $(635) $(112)
Net loss per share $(3,053) $(543)
The accompanying notes are an integral part of these unaudited condensed financial statements.
 
2

 
RIDGEWOOD ENERGY A-1 FUND, LLC
UNAUDITED CONDENSED STATEMENTS OF CASH FLOWS
(in thousands)

  Three months ended March 31, 
  2018  2017 
       
Cash flows from operating activities      
Net loss $(6) $(557)
Adjustments to reconcile net loss to net cash        
  provided by operating activities:        
Depletion and amortization  959   958 
Accretion expense  4   7 
Amortization of debt discounts and deferred financing costs  -   31 
Changes in assets and liabilities:        
Decrease in production receivable  83   41 
Decrease in other current assets  23   92 
(Decrease) increase in due to operators  (16)  56 
Increase in accrued expenses  3   137 
Settlement of asset retirement obligation  -   (74)
Net cash provided by operating activities  1,050   691 
         
Cash flows from investing activities        
Capital expenditures for oil and gas properties  (913)  (515)
Increase in salvage fund  (46)  - 
Net cash used in investing activities  (959)  (515)
         
Cash flows from financing activities        
Repayment of long-term borrowings  (247)  - 
Net cash used in financing activities  (247)  - 
         
Net (decrease) increase in cash and cash equivalents  (156)  176 
Cash and cash equivalents, beginning of period  2,423   3,458 
Cash and cash equivalents, end of period $2,267  $3,634 
         
Supplemental disclosure of cash flow information        
Cash paid for interest, net of amounts capitalized $144  $- 
         
Supplemental disclosure of non-cash investing activities        
Due to operators for accrued capital expenditures for
oil and gas properties
 $200  $725 
    Three months ended March 31, 
  2017  2016 
       
Cash flows from operating activities      
Net loss $(557) $(132)
Adjustments to reconcile net loss to net cash        
provided by (used in) operating activities:        
Depletion and amortization  958   7 
Accretion expense  7   - 
Amortization of debt discounts and deferred financing costs  31   - 
Changes in assets and liabilities:        
Decrease in production receivable  41   - 
Decrease in other current assets  92   - 
Increase in due to operators  56   17 
Increase (decrease) in accrued expenses  137   (17)
Settlement of asset retirement obligations  (74)  - 
Net cash provided by (used in) operating activities  691   (125)
         
Cash flows from investing activities        
Capital expenditures for oil and gas properties  (515)  (215)
Increase in salvage fund  -   (1)
Net cash used in investing activities  (515)  (216)
         
Cash flows from financing activities  -   - 
         
Net increase (decrease) in cash and cash equivalents  176   (341)
Cash and cash equivalents, beginning of period  3,458   1,444 
Cash and cash equivalents, end of period $3,634  $1,103 
         
Supplemental disclosure of non-cash investing activities        
Due to operators for capital expenditures for
oil and gas properties
 $725  $216 

The accompanying notes are an integral part of these unaudited condensed financial statements.
 
3

 
RIDGEWOOD ENERGY A-1 FUND, LLC
NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

1.          
1.Organization and Summary of Significant Accounting Policies

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

The Manager has direct and exclusive control over the management of the Fund’s operations.  With respect to project investments, the Manager locates potential projects, conducts due diligence, and negotiates and completes the transactions.  The Manager performs, or arranges for the performance of, the management, advisory and administrative services required for Fundthe 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 Fund 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 4.5.

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 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 results of operations, financial position, 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, 20162017 financial statements and notes thereto included in the Fund’s Annual Report on Form 10-K (“20162017 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, 2016,2017, 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 20162017 Annual Report. There have been no significant changes to the Fund’s significant accounting policies during the three months ended March 31, 2017.2018, except as noted below for revenue recognition. See Note 2. “Impact of New Revenue Standard Adoption” for discussion of the Fund’s updated accounting policies related to revenue recognition for revenue from contracts with customers.

Salvage Fund
The Fund deposits cash in a separate interest-bearing account, or salvage fund, cash to provide for the fundingdismantling and removal of asset retirement obligations.production platforms and facilities and plugging and abandoning its wells at the end of their useful lives in accordance with applicable federal and state laws and regulations. As of March 31, 20172018 and December 31, 2016,2017, the Fund had investments in federal agency mortgage-backed securities as detailed in the following table, which are classified as available for sale.  Available-for-sale securities are carried in the financial statements at fair value. Mortgage-backed securities within the salvage fund are recorded based on Level 2 inputs, as such instruments trade in over-the-counter markets.markets and the inputs are consistent with the Level 2 definition.
 
4


     Gross    
  Amortized  Unrealized  Fair 
  Cost  Gains  Value 
  (in thousands) 
Government National Mortgage Association security (GNMA July 2041)    
   March 31, 2017 $59  $3  $62 
   December 31, 2016 $64  $3  $67 
     Gross    
  Amortized  Unrealized  Fair 
  Cost  Gains  Value 
  (in thousands) 
Government National Mortgage Association security (GNMA July 2041)    
March 31, 2018 $46  $1  $47 
December 31, 2017 $46  $2  $48 

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

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

Asset Retirement Obligations
For oil and gas properties, there are obligations to perform removal and remediation activities when the properties are retired. Upon the determination that a property is either proved or dry, a retirement obligation is incurred. The Fund recognizes the fair value of a liability for an asset retirement obligation in the period incurred.  Plug and abandonment costs associated with unsuccessful projects are expensed as dry-hole costs.  At least bi-annually,Bi-annually, or more frequently if an event occurs that would dictate a change in assumptions or estimates underlying the obligations, the Fund reassesses all of its asset retirement obligations to determine whether any revisions to the obligations are necessary.  The following table presents changes in asset retirement obligations during the three months ended March 31, 20172018 and 2016.2017.

 2017  2016  2018  2017 
 (in thousands)  (in thousands) 
Balance, beginning of period $1,675  $2,119  $1,401  $1,675 
Liabilities settled  (74)  -   -   (74)
Accretion expense  7   -   4   7 
Revision of estimates  (122)  -   -   (122)
Balance, end of period $1,486  $2,119  $1,405  $1,486 

During the three months ended March 31, 2017, the Fund recorded credits to depletion expense totaling $0.1 million related to an adjustment to the asset retirement obligation for a fully depleted property. The Fund maintains a salvage fund to provide for the funding of future asset retirement obligations.

Impairment of Long-Lived Assets
The Fund reviews the carrying value of its oil and gas properties annually and when management determines that events and circumstances indicate that the recorded carrying value of properties may not be recoverable.  Impairments are determined by comparing estimated future net undiscounted cash flows to the carrying value at the time of the review.  If the carrying value exceeds the estimated future net undiscounted cash flows, the carrying value of the asset is written down to fair value, which is determined using estimated future net discounted cash flows from the asset.  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.  Given the volatility
There were no impairments of oil and natural gas prices, it is reasonably possible thatproperties during each of the Fund’s estimate of discounted future net cash flows from proved oilthree months ended March 31, 2018 and natural gas reserves could change in the near term.

2017. Fluctuations in oil and natural gas prices may impact the fair value of the Fund’s oil and gas properties. If oil and natural gas prices decline, even if only for a short period of time, it is possible that impairments of oil and gas properties will occur.
 
5


Recent Accounting Pronouncements
In May 2014, the Financial Accounting Standards Board (“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 guidanceNew 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 recognition standard.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 guidance.New Revenue Standard.  The accounting guidanceNew Revenue Standard may be applied either retrospectively or through the use of a modified-retrospective method. Based onUnder the New Revenue Standard, the revenue associated with the Fund’s initial assessmentexisting 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. “Impact of New Revenue Standard Adoption” 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.Impact of New Revenue Standard Adoption

The Fund adopted the New Revenue Standard on January 1, 2018 using the modified retrospective method to all new contracts entered into after January 1, 2018 and all existing contracts for which all of the revenues has not been recognized under the previous revenue guidance as of December 31, 2017. Although the Fund did not identify changes to its revenue recognition that resulted in a cumulative adjustment to retained earnings on January 1, 2018, the adoption of the 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.

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 currently does not expect it will have a material impact on its resultssells oil and natural gas under two types of operations or cash flowsagreements, which are common in the period after adoption. 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 accounting guidance,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. For those contracts where the Fund concluded that it is the principal and the ultimate third-party purchaser is the customer, the Fund recognizes revenue is recognizedon 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 suchexpense within operating expenses in the statements of operations.
6

The Fund expectsassesses the applicationperformance 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 that are both 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 accounting guidancebenefits 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. However, uncertainty related to the oil and gas prices is resolved daily or monthly. Payments are received in the month following 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 generally represents separate performance obligations, therefore, future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required.

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 existing contractscustomers. However, settlement statements for residue gas and NGLs sales may not be received for 30 to be generally consistent with its current revenue recognition model. The Fund will continue the evaluation of the provisions of this accounting guidance, as well as new or emerging interpretations, as it relates to new contracts the Fund receives and in particular as it relates to disclosure requirements through60 days after the date of adoption, whichproduction is currently expecteddelivered. As a result, the Fund is required to estimate the amount of production delivered to the purchaser and the price that will be January 1, 2018.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 existing internal controls for its revenue estimation process and related accruals, and any identified difference between its revenue estimates and actual revenue historically have not been significant.

2.          
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. In addition, pursuant to the terms of the LLC Agreement,Fund, however, the Manager is also permitted to waive the management fee at its own discretion. SuchTherefore, the management fee may be temporarily waived to accommodate the Fund’s short-term capital commitments. Management fees during each of the three months ended March 31, 20172018 and 20162017 were $0.1 million.
 
The Manager is also entitled to receive a 15% interest inof the cash distributions from operations made by the Fund.  The Fund did not pay distributions during the three months ended March 31, 20172018 and 2016.2017.
 
None of the amounts paid to the Manager have been derived as a result of arm’s length negotiations.
In 2016, theThe Fund entered into a master agreement withutilizes Beta Sales and Transport, LLC, a wholly ownedwholly-owned subsidiary of the Manager, to facilitate the transportation and sale of oil and natural gas produced from the Beta Project. The Fund has provided discussion of this agreement in Note 2 of “Notes to Financial Statements” – “Related Parties” contained in Item 8. “Financial Statements and Supplementary Data” within its 2016 Annual Report.

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 projects to acquire and develop oil and natural gas projects, which are also owned by other entities that are likewise managed by the Manager.

3.
4.Credit Agreement – Beta Project Financing

As of March 31, 20172018 and December 31, 2016,2017, the Fund had borrowings of $7.3$7.0 million and $7.2 million, respectively, under the credit agreement. The loan bears interest at 8% compounded annually.  Principal and interest are repaid at the lesser of (i) athe monthly ratefixed amount of 1.25% ofapproximately $0.1 million or the Fund’s total principal outstanding as of July 31, 2016 for the first seven months beginning October 2016, and increases to a monthly rate of 4.5% thereafter until the loan is repaid in full, and (ii) debt serviceDebt Service Cap amount as defined in the credit agreement, in no event later than December 31, 2020.  The loan may be prepaid by the Fund without premium or penalty. As of December 31, 2016, in accordance with the terms of the credit agreement, there are no additional borrowings available to the Fund.

TheThere were no unamortized debt discounts and deferred financing costs of $0.1 million as of March 31, 20172018 and December 31, 2016 are presented as a reduction2017. Amortization expense of “Long-term borrowings” on the balance sheets.  Amortization expenseunamortized debt discounts and deferred financing costs during the three months ended March 31, 2017 of $31 thousand was expensed and is included on the statements of operations within “Interest (expense) income,expense, net”. Amortization expenseThere were no such amounts recorded during the three months ended March 31, 20162018.
7

 
As of March 31, 20172018 and December 31, 2016,2017, there were no accrued interest costs of $0.5 million were included on the balance sheets within “Accrued expenses”.outstanding. Interest costs incurred during the three months ended March 31, 2018 and 2017 of $0.1 million and $0.2 million, respectively, were expensed and are included on the statements of operations within “Interest (expense) income,expense, net”. Interest costs incurred during the three months ended March 31, 2016 of $0.1 million were capitalized and included on the balance sheet within “Oil and gas properties”. During the three months ended March 31, 2017, the Fund made interest payments on the loan of $0.1 million, which related to capitalized interest costs. Such amounts are included within cash flows from investing activities on the statements of cash flows.
 
6


As additional consideration to the lenders, the Fund has agreed to convey an overriding royalty interest (“ORRI”) in its working interest in the Beta Project to the lenders.  The Fund’s share of the lenders’ aggregate ORRI is directly proportionate to its level of borrowing as a percentage of total borrowings of all the other participating funds managed by the Manager. Such ORRI will not accrue or become payable to the lenders until after the loan is repaid in full.  The credit agreement contains customary covenants, with which the Fund was in compliance as of March 31, 20172018 and December 31, 2016.2017.

4.          
5.Commitments and Contingencies

Capital Commitments
As of March 31, 2017,2018, the Fund’s estimated capital commitments related to its oil and gas properties were $3.8$4.0 million (which include asset retirement obligations for the Fund’s projects of $2.3$2.1 million), of which $1.3$1.6 million is expected to be spent during the next twelve months, primarily related to the completion of the final phasecontinued development of the Beta Project.Project and the settlement of asset retirement obligations for certain of the Fund’s projects.  As a result of continued development of the Beta Project as well as borrowing repayments, the Fund has experienced negative cash flows during the three months ended March 31, 2018. Future results of operations and cash flows are dependent on the continued successful development and the related production of oil and gas revenues from the Beta Project.

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

Environmental and Governmental Regulations
Many aspects of the oil and gas industry are subject to federal, state and local environmental laws and regulations. The Manager and operators of the Fund’s properties are continually taking action they believe appropriate to satisfy applicable federal, state and local environmental regulations. However, due to the significant public and governmental interest in environmental matters related to those activities, the Manager cannot predict the effects of possible future legislation, rule changes, or governmental or private claims. As of March 31, 20172018 and December 31, 2016,2017, 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 with the BOEM, its operators and working interest partners to determine and agree upon the correct level of decommissioning obligations to which they may be liable and the manner in which such obligations will be secured.  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.
 
78


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 fundsentities managed by the Manager.  Depending on the extent, nature and payment of claims made by the Fund or other fundsentities managed by the Manager, yearly insurance coverage may be exhausted and become insufficient to cover a claim by the Fund in a given year.
 
89

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

Cautionary Statement Regarding Forward-Looking Statements

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

Critical Accounting Policies and Estimates

There were no changes to the Fund’s critical accounting policies and estimates from those disclosed in its Annual Report on Form 10-K for the year ended December 31, 2016.2017, except for the revenue recognition for revenue from contracts with customers. See Note 2 of “Notes to Unaudited Condensed Financial Statements” - “Impact of New Revenue Standard Adoption” contained in Item 1. “Financial Statements” within Part I of this Quarterly Report for a discussion of the Fund’s updated accounting policies on revenue recognition upon adoption of the related new standard.

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” or “Ridgewood Energy”) 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.  ReductionsDeclines 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.  Significant declines in prices couldrecoverable and result in non-cash charges to earnings due to impairment.

During fourth quarter 2014, there was a significant decline in oilOil and natural gas commodity prices which continued into mid-year 2016 when oil and gas commodity prices beganhave been subject to show improvement that has continued through first quarter 2017.significant fluctuations during the past several years. The Fund plans foranticipates price cyclicality in its planning and believes it is well positioned to withstand such price volatility. Despite operating in a sustained lowervolatile oil and natural gas commodity price environment, the Fund continued to advance the development of the Beta Project. During the second half of 2016, Beta Project, well #1 and well #2which commenced production and during second quarter 2017, Beta Project well #3 began producing.in 2016. The Fund has suspended distributions and continues to conserve cash to completeprovide for the final phasecontinued development of the Beta Project as budgeted.Project.  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 months ended March 31, 20172018 and 20162017 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 continue to be adversely impacted.
9


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:

·weather conditions;
·economic conditions, including demand for petroleum-based products;
·actions by OPEC, the Organization of Petroleum Exporting Countries;
·political instability in the Middle East and other major oil and gas producing regions;
·governmental regulations, both domestic and foreign;
·domestic and foreign tax policy;
·the pace adopted by foreign governments for the exploration, development, and production of their national reserves;
·the supply and price of foreign oil and gas;
·the cost of exploring for, producing and delivering oil and gas;
·the discovery rate of new oil and gas reserves;
·the rate of decline of existing and new oil and gas reserves;
·available pipeline and other oil and gas transportation capacity;
·the ability of oil and gas companies to raise capital;
·the overall supply and demand for oil and gas; and
·the price and availability of alternate fuel sources.

Business Update

Information regarding the Fund’s current projects, all of which are located in the United States offshore waters ofin 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.
 
1011

 
    Total Spent  Total      Total Spent  Total  
 Working  through  Fund   Working  through  Fund  
Project Interest  March 31, 2017  Budget Status Interest  March 31, 2018  Budget Status
    (in thousands)      (in thousands)  
Producing Properties                          
Beta Project  2.0% $15,502  $17,978 
The Beta Project is expected to include the development of four wells.  Well #1 commenced production during third quarter 2016.  Well #2 commenced production during fourth quarter 2016.  Well #3  commenced production during second quarter 2017. Well #4 began drilling operations in second quarter 2017 and is expected to commence production in the latter part of 2017. The Fund expects to spend $1.6 million for additional development costs and $0.9 million for asset retirement obligations.
 2.0%  $17,925  $20,781 The Beta Project is expected to include the development of six wells.  Wells #1 and #2 commenced production in 2016.  Wells #3  and #4 commenced production in second  quarter 2017 and  third quarter 2017, respectively. Well #5 commenced production in first quarter 2018. Well #6, which began drilling in second quarter 2018, is expected to commence production in fourth quarter 2018. The Fund expects to spend $2.0 million for additional development costs and $0.9 million for asset retirement obligations.
Liberty Project  2.0% $3,004  $3,445 The Liberty Project, a single-well project, commenced production in 2010.  After various shut-ins in late-2015 and early-2016, due to third-party facilities' repair and maintenance activities, the well resumed production in early-May 2016.  A smart recompletion is planned for 2018 with no costs to the Fund.  The Fund expects to spend $0.4 million for asset retirement obligations. 2.0%  $3,004  $3,268 The Liberty Project, a single-well project, commenced production in 2010.  The well, which was shut-in in late-June 2017 due to gas dehydration unit work resumed production in late-September 2017.  The Fund expects to spend $0.3 million for asset retirement obligations.
 
Results of Operations

The following table summarizes the Fund’s results of operations during the three months ended March 31, 20172018 and 2016,2017, 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.

 Three months ended March 31,  Three months ended March 31, 
 2017  2016  2018  2017 
 (in thousands)  (in thousands) 
Revenue            
Oil and gas revenue $911  $18  $1,366  $911 
Expenses                
Depletion and amortization  958   7   959   958 
Management fees to affiliate  94   95   93   94 
Operating expenses  189   15   132   189 
General and administrative expenses  42   34   46   42 
Total expenses  1,283   151   1,230   1,283 
Loss from operations  (372)  (133)
Interest (expense) income, net  (185)  1 
Income (loss) from operations  136   (372)
Interest expense, net  (142)  (185)
Net loss $(557) $(132)  (6)  (557)
Other comprehensive loss        
Unrealized loss on marketable securities  (1)  - 
Total comprehensive loss $(7) $(557)
 
1112


Overview.  The following table provides information related to the Fund’s oil and natural gas production and oil and gas revenue during the three months ended March 31, 20172018 and 2016.2017.  Natural gas liquid (“NGL”) sales are included within gas sales.

 Three months ended March 31,  Three months ended March 31, 
 2017  2016  2018  2017 
Number of wells producing  3   1   6   3 
Total number of production days  260   18   432   260 
Oil sales (in thousands of barrels)  19   1   21   19 
Average oil price per barrel $44  $30  $60  $44 
Gas sales (in thousands of mcfs)  23   1   29   23 
Average gas price per mcf $3.25  $0.83  $3.50  $3.25 

The increases notedproduction-related changes in the above table were primarily related to the commencement of production of twothree additional wells in the Beta Project during the second half of 2016 coupled with the Liberty Project, which had been shut-in duringexperienced increased production as a result of flowing the early part of 2016.project’s current zone with the behind-pipe zone in third quarter 2017.  See additional discussion in “Business Update” section above.

Oil and Gas Revenue.   Generally, the Fund sells oil, gas and NGLs under two types of agreements, which are common in the oil and gas industry. In a netback agreement, the Fund receives a price, net of transportation expense incurred by the purchaser, and the Fund records revenue at the net price received. In the second type of agreement, the Fund pays transportation expense directly, and transportation expense is included within operating expenses in the statements of operations.

Oil and gas revenue during the three months ended March 31, 20172018 was $0.9$1.4 million, an increase of $0.9$0.5 million from the three months ended March 31, 2016.2017. The increase was attributable to increased sales volume totaling $0.6 million coupled with increased oil and gas prices totaling $0.3 million coupled with increased sales volume totaling $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 March 31, 20172018 was $1.0 million, an increase of $1.0 million$1 thousand from the three months ended March 31, 2016.2017.  The increase was attributable to an increase in the average depletion rate totaling $0.8 million coupled with an increase in production volumes totaling $0.2 million partially offset bycoupled with an adjustment to the asset retirement obligation related to a fully depleted property totaling $0.1 million, which was recorded in first quarter 2017.  These increases were partially offset by a decrease in the average depletion rate totaling $0.3 million.  The increasedecrease in the average depletion rate was primarily attributable to the onset of production of three additional wells in the Beta 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.
 
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 capital commitments.
 
Operating Expenses.  Operating expenses represent costs specifically identifiable or allocable to the Fund’s wells, as detailed in the following table.

  Three months ended March 31, 
  2018  2017 
  (in thousands) 
Lease operating expense $92  $132 
Insurance expense  23   24 
Transportation and processing expense  8   5 
Accretion expense  4   7 
Workover expense and other  5   21 
  $132  $189 
  Three months ended March 31, 
  2017  2016 
  (in thousands) 
Lease operating expense $137  $18 
Insurance expense  24   1 
Workover expense  15   - 
Accretion expense and other  13   (4)
  $189  $15 

Lease operating expense which includesand transportation and processing expense, relates 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. During the three months ended March 31, 2017, workover expense relates to the Beta Project.  Accretion expense relates to the asset retirement obligations established for the Fund’s provedoil and gas properties.
12

existing reserves.

The average production cost, which includes lease operating expense, transportation and processing expense and insurance expense, was $7.17$4.72 per barrel of oil equivalent (“BOE”) during the three months ended March 31, 2017,2018, compared to $25.57$7.17 per BOE during the three months ended March 31, 2016.2017. The decrease was primarily attributable to the LibertyBeta Project, which had higher cost per BOE in 2016 due to costs incurred as a result of third-party facilities’ repair and maintenance activities during first quarter 2016.  In addition, the Beta Project experiencedhas lower cost per BOE as a resultcompared to other projects due to the processing of production during the first quarter 2017.  As the Beta Project volumes are produced through its own standalone production facility, thefacility. The production costs per BOE may decline over time as throughput increases from the project or other projects expected to tie-in to the facility.

13

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

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

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

Capital Resources and Liquidity

Operating Cash Flows
Cash flows provided by operating activities during the three months ended March 31, 2018 were $1.1 million, primarily related to revenue received of $1.4 million, partially offset by interest payments of $0.1 million, operating expenses of $0.1 million and management fees of $0.1 million.

Cash flows provided by operating activities during the three months ended March 31, 2017 were $0.7 million, primarily related to revenue received of $1.0 million, partially offset by management fees of $0.1 million, the settlement of an asset retirement obligation of $0.1 million and general and administrative expenses of $0.1 million.

Investing Cash Flows
Cash flows used in operatinginvesting activities during the three months ended March 31, 20162018 were $0.1$1.0 million, primarily related to management fees of $0.1 millioncapital expenditures for oil and general and administrative expenses of $0.1 million, partially offset by revenue received of $18 thousand.gas properties.

Investing Cash Flows
Cash flows used in investing activities during the three months ended March 31, 2017 were $0.5 million, related to capital expenditures for oil and gas properties.

Financing Cash Flows
Cash flows used in investingfinancing activities during the three months ended March 31, 20162018 were $0.2 million, primarily related to capital expenditures for oil and gas properties.the repayment of long-term borrowings.

Financing Cash Flows
There were no cash flows from financing activities during the three months ended March 31, 2017 and 2016.2017.

Estimated Capital Expenditures

Capital Commitments
The Fund has entered into multiple agreementsexpenditures for the acquisition, drilling and development of its oil and gas properties.properties have been funded with the capital raised by the Fund in its private placement offering and through debt financing.  The estimatedFund’s remaining capital expenditures associated with these agreements vary depending onhas been fully allocated to its projects. As a result, the stage of development onFund will not invest in any new projects and will limit its investment activities, if any, to those projects in which it currently has a property-by-property basis.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.

Capital expenditures for oil and gas properties have been funded with the capital raised by the Fund in its private placement offering, and in certain circumstances, through debt financing.  The Fund’s remaining capital has been fully allocated to complete 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.

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.
13


As of March 31, 2017,2018, the Fund’s estimated capital commitments related to its oil and gas properties were $3.8$4.0 million (which include asset retirement obligations for the Fund’s projects of $2.3$2.1 million), of which $1.3$1.6 million is expected to be spent during the next twelve months, primarily related to the completion of the final phasecontinued development of the Beta Project.Project and the settlement of asset retirement obligations for certain of the Fund’s projects. As a result of continued development of the Beta Project as well as borrowing repayments, the Fund has experienced negative cash flows during the three months ended March 31, 2018.  Future results of operations and cash flows are dependent on the continued successful development and the related production of oil and gas revenues from the Beta Project. Based upon its current cash position and its current reserve estimates, the Fund expects cash flow from operations to be sufficient to cover its commitments, borrowing repayments as well asand ongoing operations. Reserve estimates are projections based on engineering data that cannot be measured with precision, require substantial judgment, and are subject to frequent revision. However, if cash flow from operations is not sufficient to meet the Fund’s commitments, the Manager will temporarily waive all or a portion of the management fee as well as provide short-term financing to accommodate the Fund’s short-term commitments if needed.

14

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. Such fee may be temporarily waived by the Manager to accommodate the Fund’s short-term capital commitments.

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

Credit Agreement
In November 2012, the Fund entered into a credit agreement (as amended on September 30, 2016 and September 15, 2017, the “Credit Agreement”) with Rahr Energy Investments LLC, as administrative agent and lender (and any other banks or financial institutions that may in the future become a party thereto)thereto, collectively “Lenders”), that providesprovided for an aggregate loan commitment to the Fund of approximately $8.3 million to provide capital toward the funding of the Fund’s share of development costs on the Beta Project. As of March 31, 20172018 and December 31, 2016,2017, the Fund had borrowed $7.3borrowings of $7.0 million and $7.2 million, respectively, under the Credit Agreement.  As of December 31, 2016, in accordance with the terms of the Credit Agreement, there will be no additional borrowings available.

The loan bears interest at 8% compounded annually. PrincipalMonthly principal and interest payments are repaid at the lesser of (i) athe monthly ratefixed amount of 1.25% ofapproximately $0.1 million or the Fund’s total principal outstandingDebt Service Cap amount, as of July 31, 2016 fordefined in the first seven months beginning October 2016, and increases to a monthly rate of 4.5% thereafterCredit Agreement, until the loan is repaid in full, and (ii) debt service amount as defined in the Credit Agreement, in no event later than December 31, 2020. The Fund expects operating income from the Beta Project to be sufficient to cover the principal and interest payments required under the Credit Agreement. The loan may be prepaid by the Fund without premium or penalty.

As additional consideration to the lenders,Lenders, the Fund has agreed to convey an overriding royalty interest (“ORRI”) in its working interest in the Beta Project to the lenders.Lenders.  The Fund’s share of the lender’sLenders’ aggregate ORRI is directly proportionate to its level of borrowing as a percentage of total borrowings of all the other participating funds managed by the Manager. Such ORRI will not accrue or become payable to the lendersLenders until after the loanLoan is repaid in full.

Unamortized debt discounts and deferred financing costs of $0.1 million as of March 31, 2017 and December 31, 2016 are presented as a reduction of “Long-term borrowings” on the balance sheets.

Principal and interest amounts are contracted to be repaid beginning October 2016, over a period not to extend beyond December 31, 2020.  The Fund expects operating income from the Beta Project will be sufficient to cover the principal and interest payments required under the Credit Agreement.  See Note 3 of “Notes to Unaudited Condensed Financial Statements” – “Credit Agreement – Beta Project Financing” contained in Item 1. “Financial Statements” within Part I of this Quarterly Report for more information regarding the Credit Agreement.

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, warrants and covenants, insolvency and change of control. Upon the occurrence of a default, in some cases following a notice and cure period, the lendersLenders under the Credit Agreement may accelerate the maturity of the loan and require full and immediate repayment of all borrowings under the Credit Agreement. The Fund believes it is in compliance with all covenants under the Credit Agreement as of March 31, 20172018 and December 31, 2016.
 
Off-Balance Sheet Arrangements

The Fund had no off-balance sheet arrangements as of March 31, 20172018 and December 31, 20162017 and does not anticipate the use of such arrangements in the future.

Contractual Obligations

The Fund enters into participation and joint operating agreements with operators.  On behalf of the Fund, an operator enters into various contractual commitments pertaining to exploration, development and production activities.  The Fund does not negotiate such contracts.  No contractual obligations exist as of March 31, 20172018 and December 31, 2016,2017, other than those discussed in “Estimated Capital Expenditures” and “Liquidity Needs – Credit Agreement” above.

15

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.
 
ITEM 3.QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Not required.

ITEM 4.CONTROLS AND PROCEDURES

In accordance with Rules 13a-15 and 15d-15 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), the Fund’s management, including its Chief Executive Officer and Chief Financial Officer, evaluated the effectiveness of the Fund’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this report.  Based on that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the Fund’s disclosure controls and procedures were effective as of March 31, 2017.2018.

There has been no change in the Fund’s internal control over financial reporting that occurred during the three months ended March 31, 20172018 that has materially affected, or is reasonably likely to materially affect, the Fund’s internal control over financial reporting.

PART II – OTHER INFORMATION

ITEM 1.LEGAL PROCEEDINGS

None.

ITEM 1A.RISK FACTORS

Not required.

ITEM 2.UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

None.

ITEM 3.DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4.MINE SAFETY DISCLOSURES

None.
15


ITEM 5.OTHER INFORMATION

None.

16

ITEM 6.EXHIBITS

EXHIBIT
NUMBER
TITLE OF EXHIBIT
METHOD OF FILING
   
31.1Filed herewith
   
31.2Filed herewith
   
32Filed herewith
   
101.INSXBRL Instance DocumentFiled herewith
   
101.SCHXBRL Taxonomy Extension SchemaFiled herewith
   
101.CALXBRL Taxonomy Extension Calculation LinkbaseFiled herewith
   
101.DEFXBRL Taxonomy Extension Definition Linkbase DocumentFiled herewith
   
101.LABXBRL Taxonomy Extension Label LinkbaseFiled herewith
   
101.PREXBRL Taxonomy Extension Presentation LinkbaseFiled herewith

16

 
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.


      
RIDGEWOOD ENERGY A-1 FUND, LLC
Dated:May 10, 201711, 2018By:/s/  ROBERT E. SWANSON
   Name:  Robert E. Swanson
   Title:  Chief Executive Officer
      (Principal Executive Officer)
       
       
Dated:May 10, 201711, 2018By:/s/  KATHLEEN P. MCSHERRY
   Name:  Kathleen P. McSherry
   Title:  Executive Vice President and Chief Financial Officer
      
(Principal Financial and Accounting Officer)
 
 
17