10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

ý	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended June 30, 2016

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, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer	☐	Accelerated filer	☐
Non-accelerated filer (Do not check if a smaller reporting company)	☐	Smaller reporting company	☒

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

 Yes ☐     No ☒

As of August 9, 2016 the Fund had 207.7026 shares of LLC Membership Interest outstanding.

Table of Contents

			PAGE
PART I - FINANCIAL INFORMATION
Item 1.	Financial Statements		1
		Unaudited Condensed Balance Sheets as of June 30, 2016 and December 31, 2015	1
		Unaudited Condensed Statements of Operations and Comprehensive Loss for the three and six months ended June 30, 2016 and 2015	2
		Unaudited Condensed Statements of Cash Flows for the six months ended June 30, 2016 and 2015	3
		Notes to Unaudited Condensed Financial Statements	4
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		10
Item 3.	Quantitative and Qualitative Disclosures About Market Risk		16
Item 4.	Controls and Procedures		16
PART II - OTHER INFORMATION
Item 1.	Legal Proceedings		16
Item 1A.	Risk Factors		16
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		16
Item 3.	Defaults Upon Senior Securities		16
Item 4.	Mine Safety Disclosures		16
Item 5.	Other Information		16
Item 6.	Exhibits		17
	SIGNATURES		17

PART I – FINANCIAL INFORMATION

ITEM 1.  FINANCIAL STATEMENTS

RIDGEWOOD ENERGY A-1 FUND, LLC

UNAUDITED CONDENSED BALANCE SHEETS

(in thousands, except share data)

	June 30, 2016			December 31, 2015
Assets
Current assets:
Cash and cash equivalents	$	460		$	1,444
Salvage fund		474			474
Production receivable		21			7
Total current assets		955			1,925
Salvage fund		1,313			1,310
Oil and gas properties:
Proved properties		17,001			15,754
Less:  accumulated depletion and amortization		(2,989	)		(2,958	)
Total oil and gas properties, net		14,012			12,796
Total assets	$	16,280		$	16,031
Liabilities and Members' Capital
Current liabilities:
Due to operators	$	390		$	153
Accrued expenses		470			215
Current portion of long-term borrowings		247			-
Asset retirement obligations		474			474
Total current liabilities		1,581			842
Long-term borrowings		2,470			2,656
Asset retirement obligations		1,645			1,645
Other liabilities		-			127
Total liabilities		5,696			5,270
Commitments and contingencies (Note 4)
Members' capital:
Manager:
Distributions		(5,058	)		(5,058	)
Retained earnings		5,075			5,097
Manager's total		17			39
Shareholders:
Capital contributions (250 shares authorized;
207.7026 issued and outstanding)		41,143			41,143
Syndication costs		(4,804	)		(4,804	)
Distributions		(35,427	)		(35,427	)
Retained earnings		9,651			9,807
Shareholders' total		10,563			10,719
Accumulated other comprehensive income		4			3
Total members' capital		10,584			10,761
Total liabilities and members' capital	$	16,280		$	16,031

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 June 30,						Six months ended June 30,
	2016			2015			2016			2015
Revenue
Oil and gas revenue	$	138		$	201		$	156		$	339
Expenses
Depletion and amortization		24			606			31			633
Management fees to affiliate (Note 2)		95			95			190			190
Operating expenses		28			131			43			211
General and administrative expenses		39			35			73			70
Total expenses		186			867			337			1,104
Loss from operations		(48	)		(666	)		(181	)		(765	)
Interest income		2			3			3			6
Net loss		(46	)		(663	)		(178	)		(759	)
Other comprehensive income (loss)
Unrealized gain (loss) on marketable securities		1			(1	)		1			(1	)
Total comprehensive loss	$	(45	)	$	(664	)	$	(177	)	$	(760	)
Manager Interest
Net loss	$	(2	)	$	(3	)	$	(22	)	$	(13	)
Shareholder Interest
Net loss	$	(44	)	$	(660	)	$	(156	)	$	(746	)
Net loss per share	$	(207	)	$	(3,174	)	$	(750	)	$	(3,591	)

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)

	Six months ended June 30,
	2016			2015
Cash flows from operating activities
Net loss	$	(178	)	$	(759	)
Adjustments to reconcile net loss to net cash
used in operating activities:
Depletion and amortization		31			633
Accretion expense		-			83
Changes in assets and liabilities:
(Increase) decrease in production receivable		(34	)		59
Decrease in other current assets		-			21
Increase (decrease) in due to operators		10			(98	)
Increase in accrued expenses		23			18
Net cash used in operating activities		(148	)		(43	)
Cash flows from investing activities
Capital expenditures for oil and gas properties		(834	)		(1,355	)
Investments in salvage fund		(2	)		(3	)
Net cash used in investing activities		(836	)		(1,358	)
Cash flows from financing activities
Long-term borrowings		-			1,100
Distributions		-			(89	)
Net cash provided by financing activities		-			1,011
Net decrease in cash and cash equivalents		(984	)		(390	)
Cash and cash equivalents, beginning of period		1,444			5,045
Cash and cash equivalents, end of period	$	460		$	4,655

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. 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 Fund operations. Such services include, without limitation, the administration of shareholder accounts, shareholder relations and the preparation, review and dissemination of tax and other financial information.  In addition, the Manager provides office space, equipment and facilities and other services necessary for Fund operations.  The Manager also engages and manages the contractual relations with unaffiliated custodians, depositories, accountants, attorneys, broker-dealers, corporate fiduciaries, insurers, banks and others as required.  See Notes 2, 3 and 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 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, 2015 financial statements and notes thereto included in the Fund’s Annual Report on Form 10-K 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, 2015, but does not include all 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, net property balances, determination of proved reserves, impairment of long-lived assets and asset retirement obligations.  Actual results may differ from those estimates.

Fair Value Measurements

The fair value measurement guidance provides a hierarchy that prioritizes and defines the types of inputs used to measure fair value. The fair value hierarchy gives the highest priority to Level 1 inputs, which consists of unadjusted quoted prices for identical instruments in active markets. Level 2 inputs consist of quoted prices for similar instruments.  Level 3 inputs are unobservable inputs and include situations where there is little, if any, market activity for the instrument; hence, these inputs have the lowest priority.  Mortgage-backed securities are recorded based on Level 2 inputs, as such instruments trade in over-the-counter markets.

4

Cash and Cash Equivalents

All highly liquid investments with maturities, when purchased, of three months or less, are considered cash equivalents. These balances, as well as cash on hand, are included in “Cash and cash equivalents” on the balance sheet. As of June 30, 2016, the Fund had no cash equivalents. At times, deposits may be in excess of federally insured limits, which are $250 thousand per insured financial institution.  As of June 30, 2016, the Fund’s bank balances were maintained in uninsured bank accounts at Wells Fargo Bank, N.A.

Salvage Fund

The Fund deposits in a separate interest-bearing account, or salvage fund, money to provide for the dismantling and removal of 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 June 30, 2016 and December 31, 2015, 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.

			Gross
	Amortized		Unrealized		Fair
	Cost		Gains		Value
	(in thousands)
Government National Mortgage Association security (GNMA July 2041)
June 30, 2016	$	74	$	4	$	78
December 31, 2015	$	75	$	3	$	78

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.

Debt Discounts and Deferred Financing Costs

Debt discounts and deferred financing costs include lender fees and other costs of acquiring debt (see Note 3. “Credit Agreement – Beta Project Financing”) such as the conveyance of override royalty interests related to the Beta Project.  These costs are deferred and amortized over the term of the debt period or until the redemption of the debt. During the first quarter of 2016, the Fund adopted the accounting guidance issued in April 2015 related to the presentation of debt issuance costs on the balance sheet as a direct reduction from the carrying amount of the debt liability, rather than as an asset. As a result, the unamortized debt discounts and deferred financing costs of $0.2 million as of June 30, 2016 and December 31, 2015 are presented as a reduction of “Long-term borrowings” on the balance sheets. Amortization expense was $31 thousand during each of the three months ended June 30, 2016 and 2015. Amortization expense was $0.1 million during each of the six months ended June 30, 2016 and 2015.  During the period of asset construction, amortization expense, as a component of interest, is capitalized and included on the balance sheet within “Oil and gas properties”.

Oil and Gas Properties

The Fund invests in oil and gas properties, which are operated by unaffiliated entities that are responsible for drilling, administering and producing activities pursuant to the terms of the applicable operating agreements with working interest owners. The Fund’s portion of exploration, drilling, operating and capital equipment expenditures is billed by operators.

Exploration, development and acquisition costs are accounted for using the successful efforts method. Costs of acquiring unproved and proved oil and natural gas leasehold acreage, including lease bonuses, brokers’ fees and other related costs are capitalized. Costs of drilling and equipping productive wells and related production facilities are capitalized.  The costs of exploratory wells are capitalized pending determination of whether proved reserves have been found. If proved commercial reserves are not found, exploratory well costs are expensed as dry-hole costs.  At times, the Fund receives adjustments to certain wells from their respective operators upon review and audit of the wells’ costs.  Interest costs related to the Credit Agreement (see Note 3. “Credit Agreement – Beta Project Financing”) are capitalized during the period of asset construction.  Annual lease rentals and exploration expenses are expensed as incurred.  All costs related to production activity and workover efforts are expensed as incurred.

5

Once a well has been determined to be fully depleted or upon the sale, retirement or abandonment of a property, the cost and related accumulated depletion and amortization, if any, is eliminated from the property accounts, and the resultant gain or loss is recognized.

As of June 30, 2016 and December 31, 2015, amounts recorded in due to operators totaling $0.3 million and $0.1 million, respectively, related to capital expenditures for oil and gas properties.

Advances to Operators for Working Interests and Expenditures

The Fund may be required to advance its share of the estimated succeeding month’s expenditures to the operator for its oil and gas properties. As the costs are incurred, the advances are reclassified to proved properties.

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 of a property to be 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.  As indicated above, the Fund maintains a salvage fund to provide for the funding of asset retirement obligations.

Syndication Costs

Syndication costs are direct costs incurred by the Fund in connection with the offering of the Fund’s shares, including professional fees, selling expenses and administrative costs payable to the Manager, an affiliate of the Manager and unaffiliated broker-dealers, which are reflected on the Fund’s balance sheet as a reduction of shareholders’ capital.

Revenue Recognition and Imbalances

Oil and gas revenues are recognized when oil and gas is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and collectability of the revenue is reasonably assured.  The Fund uses the sales method of accounting for gas production imbalances.  The volumes of gas sold may differ from the volumes to which the Fund is entitled based on its interests in the properties.  These differences create imbalances that are recognized as a liability only when the properties’ estimated remaining reserves net to the Fund will not be sufficient to enable the underproduced owner to recoup its entitled share through production.  The Fund’s recorded liability, if any, would be reflected in other liabilities.  No receivables are recorded for those wells where the Fund has taken less than its share of production.

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 of oil and natural gas prices, it is reasonably possible that the Fund’s estimate of discounted future net cash flows from proved oil and natural gas reserves could change in the near term.

Significant declines in oil and natural gas prices since fourth quarter 2014 have impacted the fair value of the Fund’s oil and gas properties. If oil and natural gas prices continue to decline, even if only for a short period of time, it is possible that impairments of oil and gas properties will occur.

Depletion and Amortization

Depletion and amortization of the cost of proved oil and gas properties are calculated using the units-of-production method.  Proved developed reserves are used as the base for depleting capitalized costs associated with successful exploratory well costs, development costs and related facilities. The sum of proved developed and proved undeveloped reserves is used as the base for depleting or amortizing leasehold acquisition costs.  During the three and six months ended June 30, 2015, the Fund recorded $0.6 million of depletion expense related to adjustments to asset retirement obligations for fully depleted properties.

6

Income Taxes

No provision is made for income taxes in the financial statements.  The Fund is a limited liability company, and as such, the Fund’s income or loss is passed through and included in the tax returns of the Fund’s shareholders.  The Fund files U.S. Federal and State tax returns and the 2013 through 2015 tax returns remain open for examination by tax authorities.

Income and Expense Allocation

Profits and losses are allocated to shareholders and the Manager in accordance with the LLC Agreement.

Distributions

Distributions to shareholders are allocated in proportion to the number of shares held.  The Manager determines whether available cash from operations, as defined in the LLC Agreement, will be distributed. Such distributions are allocated 85% to the shareholders and 15% to the Manager, as required by the LLC Agreement.

Available cash from dispositions, as defined in the LLC Agreement, will be paid 99% to shareholders and 1% to the Manager until the shareholders have received total distributions equal to their capital contributions. After shareholders have received distributions equal to their capital contributions, 85% of available cash from dispositions will be distributed to shareholders and 15% to the Manager.

Recent Accounting Pronouncements

In April 2015, the Financial Accounting Standards Board (“FASB”) issued accounting guidance related to the presentation of debt issuance costs on the balance sheet as a direct reduction from the carrying amount of the debt liability, consistent with debt discounts, rather than as an asset.  Amortization of debt issuance costs will continue to be reported as interest expense.  In August 2015, the FASB issued accounting guidance related to the presentation and subsequent measurement of debt issuance costs associated with line-of-credit arrangements which clarifies that companies may continue to present unamortized debt issuance costs associated with line of credit arrangements as an asset.  These pronouncements are effective for fiscal years, and interim periods within those years, beginning after December 15, 2015, with early adoption permitted.  The Fund adopted the accounting guidance in first quarter 2016, resulting in a one-time reclassification of $0.2 million of unamortized debt discounts and deferred financing costs from "Other assets" to "Long-term borrowings" on the balance sheet as of December 31, 2015. Long-term borrowings are presented net of $0.2 million of unamortized debt discounts and deferred financing costs as of June 30, 2016. The adoption of these pronouncements did not impact the Fund’s results of operations or cash flows.

In 2014, the FASB issued accounting guidance on revenue recognition, which provides for a single five-step model to be applied to all revenue contracts with customers. In 2015, the FASB issued a deferral of the effective date of the guidance to 2018, with early adoption permitted in 2017. In May 2016, the FASB issued final amendments which provided narrow scope improvements and practical expedients related to the implementation of the guidance. The Fund is currently evaluating the impact of this guidance on its financial statements.

2. Related Parties

Pursuant to the terms of the LLC Agreement, the Manager renders management, administrative and advisory services to the Fund.  For such services, the Manager is entitled to 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.  Management fees during each of the three and six months ended June 30, 2016 and 2015 were $0.1 million and $0.2 million, respectively.

The Manager is entitled to receive a 15% interest in cash distributions from operations made by the Fund.  The Fund did not pay distributions during the three and six months ended June 30, 2016 and during the three months ended June 30, 2015. Distributions paid to the Manager during the six months ended June 30, 2015 were $13 thousand.

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

None of the amounts paid to the Manager have been derived as a result of arm’s length negotiations.

The Fund has working interest ownership in certain projects to acquire and develop oil and natural gas projects with other entities that are likewise managed by the Manager.

7

3. Credit Agreement – Beta Project Financing

In November 2012, the Fund entered into a credit agreement (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, collectively “Lenders”) that provides for an aggregate loan commitment to the Fund of approximately $8.3 million (“Loan”), to provide capital toward the funding of the Fund’s share of development costs on the Beta Project. Except in cases of fraud and breach of certain representations, the Loan is non-recourse to the Fund’s other assets and secured solely by the Fund’s interests in the Beta Project. Certain other funds managed by Ridgewood (“Ridgewood Funds”, and when used with the Fund the “Ridgewood Participating Funds”) have also executed the Credit Agreement. Pursuant to the Credit Agreement, each Ridgewood Participating Fund has a separate loan commitment from the Lenders and amounts borrowed are not joint and several obligations. Each of the Ridgewood Participating Funds’ borrowings is secured solely by its separate interest in the Beta Project. Therefore, the Fund is liable for the repayment of its Loan and is not liable to the Lenders to repay any loan made to any other Ridgewood Funds. The Manager serves as the manager for each of the Ridgewood Participating Funds.

The Fund anticipates it will borrow approximately $8.3 million over the development period of the Beta Project. The Loan bears interest at 8% compounded annually and accrues only on Loan proceeds as they are drawn. Principal and interest will not be payable until such time that initial production has commenced for the Beta Project, which commenced production in third quarter 2016.  At that time, if certain revenue production levels are met, principal and interest will be repaid at a monthly rate of 1.25% of the Fund’s total principal outstanding at the date the Beta Project commences production for the first seven months of production, and a monthly rate of 4.5% of the Fund’s total principal outstanding at the date the Beta Project commences production thereafter until the Loan is repaid in full, in no event later than December 31, 2020.  The Loan may be prepaid by the Fund without premium or penalty.

As of June 30, 2016 and December 31, 2015, the Fund had borrowings of $2.9 million under the Credit Agreement. During the first quarter of 2016, the Fund adopted the accounting guidance issued in April 2015 related to the presentation of debt issuance costs on the balance sheet as a direct reduction from the carrying amount of the debt liability, rather than as an asset. As a result, the unamortized debt discounts and deferred financing costs of $0.2 million as of June 30, 2016 and December 31, 2015 are presented as a reduction of “Long-term borrowings” on the balance sheets.  As of June 30, 2016 and December 31, 2015, interest costs of $0.4 million and $0.3 million, respectively, were capitalized and included on the balance sheet within “Oil and gas properties”.  Such amounts are accrued on the balance sheet within “Accrued expenses” as of June 30, 2016 and “Accrued expenses” and “Other liabilities” as of December 31, 2015.

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 Credit Agreement contains customary covenants, for which the Fund believes it was in compliance as of June 30, 2016 and December 31, 2015.

4. Commitments and Contingencies

Capital Commitments

The Fund has entered into multiple agreements for the acquisition, drilling and development of its oil and gas properties. The estimated capital expenditures associated with these agreements vary depending on the stage of development on a property-by-property basis.  As of June 30, 2016, the Fund had one property, the Beta Project, for which additional development costs must be incurred in order to commence production. The Fund currently expects to spend an additional $4.5 million (which includes asset retirement obligations) related to the development of the Beta Project, which the Fund anticipates will include the development of four wells with related platform and pipeline infrastructure. During third quarter 2016, one well in the Beta Project commenced production.

As of June 30, 2016, the Fund’s estimated capital commitments related to its oil and gas properties were $6.3 million (which include asset retirement obligations for the Fund’s projects of $2.7 million and projected interest costs of $21 thousand for the Beta Project), of which $3.3 million is expected to be spent during the next twelve months. These expected capital commitments exceed available working capital and salvage fund by $5.2 million as of June 30, 2016.  The Fund has entered into the Credit Agreement to provide capital for funding of the Beta Project.  See Note 3. “Credit Agreement – Beta Project Financing” for additional information.

Based upon its current cash position, its current reserve estimates and its current development plan of the Beta Project, the Fund expects cash flow from operations and borrowings to be sufficient to cover its commitments, as well as 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 capital commitments, the Manager will take action, which may include adjusting its management fee temporarily to accommodate the Fund’s short-term capital commitments.

8

Environmental Considerations

The exploration for and development of oil and natural gas involves the extraction, production and transportation of materials which, under certain conditions, can be hazardous or cause environmental pollution problems.  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 and do not currently anticipate that compliance with federal, state and local environmental regulations will have a material adverse effect upon capital expenditures, results of operations or the competitive position of the Fund in the oil and gas industry.  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 June 30, 2016 and December 31, 2015, there were no known environmental contingencies that required adjustment to, or disclosure in, the Fund’s financial statements.

During the past several years, the United States Congress, as well as certain regulatory agencies with jurisdiction over the Fund’s business, have considered or proposed legislation or regulation relating to the upstream oil and gas industry both onshore and offshore.  If any such proposals were to be enacted or adopted they could potentially materially impact the Fund’s operations.  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. 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.

Insurance Coverage

The Fund is subject to all risks inherent in the exploration for and development of oil and natural gas. 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 funds managed by the Manager.  Claims made by other funds managed by the Manager can reduce or eliminate insurance for the Fund.

9

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 US 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 conditions affecting the pricing and production of oil and natural gas, the cost and availability of equipment, and changes in 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

The discussion and analysis of the Fund’s financial condition and results of operations are based upon the Fund’s financial statements, which have been prepared in conformity with accounting principles generally accepted in the United States of America (“GAAP”).  In preparing these financial statements, the Fund is required to make certain estimates, judgments and assumptions. These estimates, judgments and assumptions affect the reported amounts of the Fund’s assets and liabilities, including the disclosure of contingent assets and liabilities, at the date of the financial statements and the reported amounts of its revenues and expenses during the periods presented.  The Fund evaluates these estimates and assumptions on an ongoing basis. The Fund bases its estimates and assumptions on historical experience and on various other factors that the Fund believes to be reasonable at the time the estimates and assumptions are made. However, future events and actual results may differ from these estimates and assumptions and such differences may have a material impact on the results of operations, financial position or cash flows. 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 the Fund’s significant accounting policies. No changes have been made to the Fund’s critical accounting policies and estimates disclosed in its 2015 Annual Report on Form 10-K.

Overview of the Fund’s Business

The Fund is a Delaware limited liability company formed on February 3, 2009 to primarily 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 exploratory or development oil and natural gas projects.  Distributions to shareholders are made in accordance with the Fund’s limited liability company agreement (the “LLC Agreement”). The Fund does not expect in the future to investigate or invest in any additional projects other than those in which it currently has a working interest. The Fund’s remaining capital has been fully allocated to complete such projects.

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 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.

10

Commodity Price Changes

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

Since fourth quarter 2014, there has been a significant decline in oil and natural gas prices.  See “Results of Operations” under this Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Quarterly Report for more information on the average oil and natural gas prices received by the Fund during the three and six months ended June 30, 2016 and 2015 and the effect of such decreased average prices on the Fund’s results of operations.  If oil and natural gas prices continue to decline, even if only for a short period of time, the Fund’s results of operations and liquidity will continue to be adversely impacted.

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

· 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 price of foreign imports of 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 availability of alternate fuel sources.

Business Update

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

11

		Total Spent		Total
	Working	through		Fund
Project	Interest	June 30, 2016		Budget		Status
		(in thousands)
Producing Properties
Beta Project	2.0%	$	13,445	$	17,935	The Beta Project is expected to include the development of four wells.  Well #1 commenced production during third quarter 2016.  Well #2, which is currently drilling, is expected to commence production in fourth quarter 2016.  Wells #3 and #4 are expected to commence production in 2017. The Fund expects to spend $3.6 million for additional development costs and $0.9 million for asset retirement obligations.
Liberty Project	2.0%	$	3,004	$	3,505	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 recompletion is planned for 2017 at an estimated cost of $0.1 million.  The Fund expects to spend $0.4 million for asset retirement obligations.

Results of Operations

The following table summarizes the Fund’s results of operations during the three and six months ended June 30, 2016 and 2015, 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 June 30,						Six months ended June 30,
	2016			2015			2016			2015
	(in thousands)
Revenue
Oil and gas revenue	$	138		$	201		$	156		$	339
Expenses
Depletion and amortization		24			606			31			633
Management fees to affiliate		95			95			190			190
Operating expenses		28			131			43			211
General and administrative expenses		39			35			73			70
Total expenses		186			867			337			1,104
Loss from operations		(48	)		(666	)		(181	)		(765	)
Interest income		2			3			3			6
Net loss		(46	)		(663	)		(178	)		(759	)
Other comprehensive income (loss)
Unrealized gain (loss) on marketable securities		1			(1	)		1			(1	)
Total comprehensive loss	$	(45	)	$	(664	)	$	(177	)	$	(760	)

12

Overview.The following table provides information related to the Fund’s oil and gas production and oil and gas revenue during the three and six months ended June 30, 2016 and 2015.  Natural gas liquid (“NGL”) sales are included within gas sales.

	Three months ended June 30,				Six months ended June 30,
	2016		2015		2016		2015
Number of wells producing		1		1		1		1
Total number of production days		55		85		73		171
Oil sales (in thousands of barrels)		2		3		2		6
Average oil price per barrel	$	42	$	58	$	39	$	52
Gas sales (in thousands of mcfs)		4		8		6		15
Average gas price per mcf	$	1.65	$	2.40	$	1.50	$	2.30

The decreases noted in the above table were attributable to the Liberty Project, which has been shut-in for the majority of 2016.  See additional discussion in “Business Update” section above.

Oil and Gas Revenue.   Oil and gas revenue during the three months ended June 30, 2016 was $0.1 million, a decrease of $0.1 million from the three months ended June 30, 2015.  Oil and gas revenue during the six months ended June 30, 2016 was $0.2 million, a decrease of $0.2 million from the six months ended June 30, 2015.  The decreases were primarily attributable to decreased sales volume.  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 June 30, 2016 was $24 thousand, a decrease of $0.6 million from the three months ended June 30, 2015.  Depletion and amortization during the six months ended June 30, 2016 was $31 thousand, a decrease of $0.6 million from the six months ended June 30, 2015. The decreases were primarily attributable to adjustments to asset retirement obligations related to fully depleted properties totaling $0.6 million, which were recorded in second quarter 2015.

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.

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

	Three months ended June 30,				Six months ended June 30,
	2016		2015		2016		2015
	(in thousands)
Lease operating expense	$	7	$	33	$	25	$	122
Insurance expense		14		15		15		23
Accretion expense and other		7		83		3		66
	$	28	$	131	$	43	$	211

Lease operating 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. Accretion expense related to the asset retirement obligations established for the Fund’s proved properties.

The average production cost, which includes lease operating expense and insurance expense, was $9.09 per barrel of oil equivalent (“BOE”) and $12.97 per BOE during the three and six months ended June 30, 2016, respectively, compared to $10.77 per BOE and $17.11 per BOE during the three and six months ended June 30, 2015, respectively.  The decrease in the six months ended June 30, 2016 was primarily attributable to costs incurred by the Fund during 2015 for wells that were no longer producing.

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.

13

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

Unrealized Gain (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 used in operating activities during the six months ended June 30, 2016 were $0.1 million, related to management fees of $0.2 million and general and administrative expenses of $0.1 million, partially offset by revenue received of $0.1 million.

Cash flows used in operating activities during the six months ended June 30, 2015 were $43 thousand, related to operating expenses of $0.2 million, management fees of $0.2 million and general and administrative expenses of $31 thousand, partially offset by revenue received of $0.4 million.

Investing Cash Flows

Cash flows used in investing activities during the six months ended June 30, 2016 were $0.8 million, primarily related to capital expenditures for oil and gas properties.

Cash flows used in investing activities during the six months ended June 30, 2015 were $1.4 million, primarily related to capital expenditures for oil and gas properties.

Financing Cash Flows

There were no cash flows from financing activities during the six months ended June 30, 2016.

Cash flows provided by financing activities during the six months ended June 30, 2015 were $1.0 million, related to proceeds from long-term borrowings of $1.1 million, partially offset by manager and shareholder distributions totaling $0.1 million.

Estimated Capital Expenditures

Capital Commitments

The Fund has entered into multiple agreements for the acquisition, drilling and development of its oil and gas properties. The estimated capital expenditures associated with these agreements vary depending on the stage of development on a property-by-property basis. As of June 30, 2016, the Fund had one property, the Beta Project, for which additional development costs must be incurred in order to commence production. The Fund currently expects to spend an additional $4.5 million (which includes asset retirement obligations) related to the development of the Beta Project, which the Fund anticipates will include the development of four wells with related platform and pipeline infrastructure.  During third quarter 2016, one well in the Beta Project commenced production. 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 number of projects in which the Fund could invest was limited, and each unsuccessful project the Fund experienced exhausted its capital and reduced its ability to generate revenue.

Liquidity Needs

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

As of June 30, 2016, the Fund’s estimated capital commitments related to its oil and gas properties were $6.3 million (which include asset retirement obligations for the Fund’s projects of $2.7 million and projected interest costs of $21 thousand for the Beta Project), of which $3.3 million is expected to be spent during the next twelve months. These expected capital commitments exceed available working capital and salvage fund by $5.2 million as of June 30, 2016. The Fund has entered into a credit agreement to provide capital for the Beta Project.  See “Credit Agreement” below for additional information.

14

Based upon its current cash position, its current reserve estimates and its current development plan of the Beta Project, the Fund expects cash flow from operations and borrowings to be sufficient to cover its commitments, as well as 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 capital commitments, the Manager will take action, which may include adjusting its management fee temporarily to accommodate the Fund’s short-term capital commitments.

The Manager is entitled to receive an annual management fee from the Fund regardless of the Fund’s profitability in that year.

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 will be impacted in the future, by amounts reserved to provide for its ongoing development costs, debt service costs, and funding its estimated asset retirement obligations.

Credit Agreement

In November 2012, the Fund entered into a credit agreement (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), that provides 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 June 30, 2016 and December 31, 2015, the Fund had borrowed $2.9 million under the Credit Agreement. During the first quarter of 2016, the Fund adopted the accounting guidance issued in April 2015 related to the presentation of debt issuance costs on the balance sheet as a direct reduction from the carrying amount of the debt liability, rather than as an asset. As a result, the unamortized debt discounts and deferred financing costs of $0.2 million as of June 30, 2016 and December 31, 2015 are presented as a reduction of “Long-term borrowings” on the balance sheets.   Principal and interest amounts are contracted to be repaid upon the onset of production of the Beta Project, which commenced in the third quarter 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 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 June 30, 2016 and December 31, 2015.

Off-Balance Sheet Arrangements

The Fund had no off-balance sheet arrangements as of June 30, 2016 and December 31, 2015 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 June 30, 2016 and December 31, 2015, 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 June 30, 2016.

There has been no change in the Fund’s internal control over financial reporting that occurred during the three months ended June 30, 2016 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.

ITEM 5. OTHER INFORMATION

None.

16

ITEM 6. EXHIBITS

EXHIBIT NUMBER	TITLE OF EXHIBIT	METHOD OF FILING
31.1	Certification of Robert E. Swanson, Chief Executive Officer of the Fund, pursuant to Exchange Act Rule 13a-14(a)	Filed herewith
31.2	Certification of Kathleen P. McSherry, Executive Vice President and Chief Financial Officer of the Fund, pursuant to Exchange Act Rule 13a-14(a)	Filed herewith
32	Certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, signed by Robert E. Swanson, Chief Executive Officer of the Fund and Kathleen P. McSherry, Executive Vice President and Chief Financial Officer of the Fund	Filed herewith
101.INS	XBRL Instance Document	Filed herewith
101.SCH	XBRL Taxonomy Extension Schema	Filed herewith
101.CAL	XBRL Taxonomy Extension Calculation Linkbase	Filed herewith
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document	Filed herewith
101.LAB	XBRL Taxonomy Extension Label Linkbase	Filed herewith
101.PRE	XBRL Taxonomy Extension Presentation Linkbase	Filed herewith

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:	August 9, 2016	By:	/s/	ROBERT E. SWANSON
			Name:	Robert E. Swanson
			Title:	Chief Executive Officer
				(Principal Executive Officer)
Dated:	August 9, 2016	By:	/s/	KATHLEEN P. MCSHERRY
			Name:	Kathleen P. McSherry
			Title:	Executive Vice President and Chief Financial Officer
				(Principal Financial and Accounting Officer)

17

EX-31.1

EXHIBIT 31.1

CERTIFICATION

I, Robert E. Swanson, certify that:

1.          I have reviewed this Quarterly Report on Form 10-Q of Ridgewood Energy A-1 Fund, LLC;

2.          Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.          Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.          The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a – 15(e) and 15d – 15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a – 15(f) and 15d – 15(f)) for the registrant and have:

(a)  Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)  Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)  Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)  Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.          The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)  All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)  Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Dated:	August 9, 2016
/s/	ROBERT E. SWANSON
Name:	Robert E. Swanson
Title:	Chief Executive Officer
	(Principal Executive Officer)

EX-31.2

EXHIBIT 31.2

CERTIFICATION

I, Kathleen P. McSherry, certify that:

1.          I have reviewed this Quarterly Report on Form 10-Q of Ridgewood Energy A-1 Fund, LLC;

2.          Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.          Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.          The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a – 15(e) and 15d – 15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a – 15(f) and 15d – 15(f)) for the registrant and have:

(a)  Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)  Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)  Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)  Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.          The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)  All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)  Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Dated:	August 9, 2016
/s/	KATHLEEN P. MCSHERRY
Name:	Kathleen P. McSherry
Title:	Executive Vice President and Chief Financial Officer
	(Principal Financial and Accounting Officer)

EX-32

EXHIBIT 32

CERTIFICATIONS PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with this Quarterly Report on Form 10-Q of the Ridgewood Energy A-1 Fund, LLC (the “Fund”) for the period ended June 30, 2016, as filed with the Securities and Exchange Commission on the date hereof, (the “Report”), each of the undersigned officers of the Fund hereby certifies, pursuant to 18 U.S.C. (section) 1350, as adopted pursuant to (section) 906 of the Sarbanes-Oxley Act of 2002, that to the best of their knowledge:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Fund.

Dated:	August 9, 2016
		/s/	ROBERT E. SWANSON
		Name:	Robert E. Swanson
		Title:	Chief Executive Officer
			(Principal Executive Officer)
Dated:	August 9, 2016
		/s/	KATHLEEN P. MCSHERRY
		Name:	Kathleen P. McSherry
		Title:	Executive Vice President and Chief Financial Officer
			(Principal Financial and Accounting Officer)

A signed original of this written statement or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement has been provided to the Fund and will be retained by the Fund and furnished to the Securities and Exchange Commission or its staff upon request. The foregoing certification is being furnished solely pursuant to 18 U.S.C. Section 1350 and is not being filed as part of this report or as a separate disclosure document.

XML

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2016	Aug. 09, 2016
Document And Entity Information Abstract
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016
Entity Registrant Name	RIDGEWOOD ENERGY A-1 FUND LLC
Entity Central Index Key	0001457919
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
Entity Filer Category	Smaller Reporting Company
Entity Common Stock, Shares Outstanding		207.7026

XML

UNAUDITED CONDENSED BALANCE SHEETS - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 460	$ 1,444
Salvage fund	474	474
Production receivable	21	7
Total current assets	955	1,925
Salvage fund	1,313	1,310
Oil and gas properties:
Proved properties	17,001	15,754
Less: accumulated depletion and amortization	(2,989)	(2,958)
Total oil and gas properties, net	14,012	12,796
Total assets	16,280	16,031
Current liabilities:
Due to operators	390	153
Accrued expenses	470	215
Current portion of long-term borrowings	247
Asset retirement obligations	474	474
Total current liabilities	1,581	842
Long-term borrowings	2,470	2,656
Asset retirement obligations	1,645	1,645
Other liabilities		127
Total liabilities	5,696	5,270
Commitments and contingencies (Note 4)
Members' capital:
Distributions	(5,058)	(5,058)
Retained earnings	5,075	5,097
Manager's total	17	39
Capital contributions (250 shares authorized; 207.7026 issued and outstanding)	41,143	41,143
Syndication costs	(4,804)	(4,804)
Distributions	(35,427)	(35,427)
Retained earnings	9,651	9,807
Shareholders' total	10,563	10,719
Accumulated other comprehensive income	4	3
Total members' capital	10,584	10,761
Total liabilities and members' capital	$ 16,280	$ 16,031

XML

UNAUDITED CONDENSED BALANCE SHEETS (Parenthetical) - shares	Jun. 30, 2016	Dec. 31, 2015
Statement of Financial Position [Abstract]
Shares authorized	250	250
Shares issued	207.7026	207.7026
Shares outstanding	207.7026	207.7026

XML

UNAUDITED CONDENSED STATEMENTS OF OPERATIONS AND COMPREHENSIVE LOSS - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Revenue
Oil and gas revenue	$ 138	$ 201	$ 156	$ 339
Expenses
Depletion and amortization	24	606	31	633
Management fees to affiliate (Note 2)	95	95	190	190
Operating expenses	28	131	43	211
General and administrative expenses	39	35	73	70
Total expenses	186	867	337	1,104
Loss from operations	(48)	(666)	(181)	(765)
Interest income	2	3	3	6
Net loss	(46)	(663)	(178)	(759)
Other comprehensive income (loss)
Unrealized gain (loss) on marketable securities	1	(1)	1	(1)
Total comprehensive loss	(45)	(664)	(177)	(760)
Manager Interest
Net loss	(2)	(3)	(22)	(13)
Shareholder Interest
Net loss	$ (44)	$ (660)	$ (156)	$ (746)
Net loss per share	$ (207)	$ (3,174)	$ (750)	$ (3,591)

XML

UNAUDITED CONDENSED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Cash flows from operating activities
Net loss	$ (178)	$ (759)
Adjustments to reconcile net loss to net cash used in operating activities:
Depletion and amortization	31	633
Accretion expense		83
Changes in assets and liabilities:
Increase (decrease) in production receivable	(34)	59
Decrease in other current assets		21
Increase (decrease) in due to operators	10	(98)
Increase in accrued expenses	23	18
Net cash used in operating activities	(148)	(43)
Cash flows from investing activities
Capital expenditures for oil and gas properties	(834)	(1,355)
Investments in salvage fund	(2)	(3)
Net cash used in investing activities	(836)	(1,358)
Cash flows from financing activities
Long-term borrowings		1,100
Distributions		(89)
Net cash provided by financing activities		1,011
Net decrease in cash and cash equivalents	(984)	(390)
Cash and cash equivalents, beginning of period	1,444	5,045
Cash and cash equivalents, end of period	$ 460	$ 4,655

XML

Organization and Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization and Summary of Significant Accounting Policies

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 Fund operations. Such services include, without limitation, the administration of shareholder accounts, shareholder relations and the preparation, review and dissemination of tax and other financial information.  In addition, the Manager provides office space, equipment and facilities and other services necessary for Fund operations.  The Manager also engages and manages the contractual relations with unaffiliated custodians, depositories, accountants, attorneys, broker-dealers, corporate fiduciaries, insurers, banks and others as required.  See Notes 2, 3 and 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 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, 2015 financial statements and notes thereto included in the Fund’s Annual Report on Form 10-K 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, 2015, but does not include all 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, net property balances, determination of proved reserves, impairment of long-lived assets and asset retirement obligations.  Actual results may differ from those estimates.

Fair Value Measurements

The fair value measurement guidance provides a hierarchy that prioritizes and defines the types of inputs used to measure fair value. The fair value hierarchy gives the highest priority to Level 1 inputs, which consists of unadjusted quoted prices for identical instruments in active markets. Level 2 inputs consist of quoted prices for similar instruments.  Level 3 inputs are unobservable inputs and include situations where there is little, if any, market activity for the instrument; hence, these inputs have the lowest priority.  Mortgage-backed securities are recorded based on Level 2 inputs, as such instruments trade in over-the-counter markets.

Cash and Cash Equivalents

All highly liquid investments with maturities, when purchased, of three months or less, are considered cash equivalents. These balances, as well as cash on hand, are included in “Cash and cash equivalents” on the balance sheet. As of June 30, 2016, the Fund had no cash equivalents. At times, deposits may be in excess of federally insured limits, which are $250 thousand per insured financial institution.  As of June 30, 2016, the Fund’s bank balances were maintained in uninsured bank accounts at Wells Fargo Bank, N.A.

Salvage Fund

The Fund deposits in a separate interest-bearing account, or salvage fund, money to provide for the dismantling and removal of 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 June 30, 2016 and December 31, 2015, 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.

			Gross
	Amortized		Unrealized		Fair
	Cost		Gains		Value
	(in thousands)
Government National Mortgage Association security (GNMA July 2041)
June 30, 2016	$	74	$	4	$	78
December 31, 2015	$	75	$	3	$	78

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.

Debt Discounts and Deferred Financing Costs

Debt discounts and deferred financing costs include lender fees and other costs of acquiring debt (see Note 3. “Credit Agreement – Beta Project Financing”) such as the conveyance of override royalty interests related to the Beta Project.  These costs are deferred and amortized over the term of the debt period or until the redemption of the debt. During the first quarter of 2016, the Fund adopted the accounting guidance issued in April 2015 related to the presentation of debt issuance costs on the balance sheet as a direct reduction from the carrying amount of the debt liability, rather than as an asset. As a result, the unamortized debt discounts and deferred financing costs of $0.2 million as of June 30, 2016 and December 31, 2015 are presented as a reduction of “Long-term borrowings” on the balance sheets. Amortization expense was $31 thousand during each of the three months ended June 30, 2016 and 2015. Amortization expense was $0.1 million during each of the six months ended June 30, 2016 and 2015.  During the period of asset construction, amortization expense, as a component of interest, is capitalized and included on the balance sheet within “Oil and gas properties”.

Oil and Gas Properties

The Fund invests in oil and gas properties, which are operated by unaffiliated entities that are responsible for drilling, administering and producing activities pursuant to the terms of the applicable operating agreements with working interest owners. The Fund’s portion of exploration, drilling, operating and capital equipment expenditures is billed by operators.

Exploration, development and acquisition costs are accounted for using the successful efforts method. Costs of acquiring unproved and proved oil and natural gas leasehold acreage, including lease bonuses, brokers’ fees and other related costs are capitalized. Costs of drilling and equipping productive wells and related production facilities are capitalized.  The costs of exploratory wells are capitalized pending determination of whether proved reserves have been found. If proved commercial reserves are not found, exploratory well costs are expensed as dry-hole costs.  At times, the Fund receives adjustments to certain wells from their respective operators upon review and audit of the wells’ costs.  Interest costs related to the Credit Agreement (see Note 3. “Credit Agreement – Beta Project Financing”) are capitalized during the period of asset construction.  Annual lease rentals and exploration expenses are expensed as incurred.  All costs related to production activity and workover efforts are expensed as incurred.

Once a well has been determined to be fully depleted or upon the sale, retirement or abandonment of a property, the cost and related accumulated depletion and amortization, if any, is eliminated from the property accounts, and the resultant gain or loss is recognized.

As of June 30, 2016 and December 31, 2015, amounts recorded in due to operators totaling $0.3 million and $0.1 million, respectively, related to capital expenditures for oil and gas properties.

Advances to Operators for Working Interests and Expenditures

The Fund may be required to advance its share of the estimated succeeding month’s expenditures to the operator for its oil and gas properties. As the costs are incurred, the advances are reclassified to proved properties.

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 of a property to be 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.  As indicated above, the Fund maintains a salvage fund to provide for the funding of asset retirement obligations.

Syndication Costs

Syndication costs are direct costs incurred by the Fund in connection with the offering of the Fund’s shares, including professional fees, selling expenses and administrative costs payable to the Manager, an affiliate of the Manager and unaffiliated broker-dealers, which are reflected on the Fund’s balance sheet as a reduction of shareholders’ capital.

Revenue Recognition and Imbalances

Oil and gas revenues are recognized when oil and gas is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and collectability of the revenue is reasonably assured.  The Fund uses the sales method of accounting for gas production imbalances.  The volumes of gas sold may differ from the volumes to which the Fund is entitled based on its interests in the properties.  These differences create imbalances that are recognized as a liability only when the properties’ estimated remaining reserves net to the Fund will not be sufficient to enable the underproduced owner to recoup its entitled share through production.  The Fund’s recorded liability, if any, would be reflected in other liabilities.  No receivables are recorded for those wells where the Fund has taken less than its share of production.

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 of oil and natural gas prices, it is reasonably possible that the Fund’s estimate of discounted future net cash flows from proved oil and natural gas reserves could change in the near term.

Significant declines in oil and natural gas prices since fourth quarter 2014 have impacted the fair value of the Fund’s oil and gas properties. If oil and natural gas prices continue to decline, even if only for a short period of time, it is possible that impairments of oil and gas properties will occur.

Depletion and Amortization

Depletion and amortization of the cost of proved oil and gas properties are calculated using the units-of-production method.  Proved developed reserves are used as the base for depleting capitalized costs associated with successful exploratory well costs, development costs and related facilities. The sum of proved developed and proved undeveloped reserves is used as the base for depleting or amortizing leasehold acquisition costs.  During the three and six months ended June 30, 2015, the Fund recorded $0.6 million of depletion expense related to adjustments to asset retirement obligations for fully depleted properties.

Income Taxes

No provision is made for income taxes in the financial statements.  The Fund is a limited liability company, and as such, the Fund’s income or loss is passed through and included in the tax returns of the Fund’s shareholders.  The Fund files U.S. Federal and State tax returns and the 2013 through 2015 tax returns remain open for examination by tax authorities.

Income and Expense Allocation

Profits and losses are allocated to shareholders and the Manager in accordance with the LLC Agreement.

Distributions

Distributions to shareholders are allocated in proportion to the number of shares held.  The Manager determines whether available cash from operations, as defined in the LLC Agreement, will be distributed. Such distributions are allocated 85% to the shareholders and 15% to the Manager, as required by the LLC Agreement.

Available cash from dispositions, as defined in the LLC Agreement, will be paid 99% to shareholders and 1% to the Manager until the shareholders have received total distributions equal to their capital contributions. After shareholders have received distributions equal to their capital contributions, 85% of available cash from dispositions will be distributed to shareholders and 15% to the Manager.

Recent Accounting Pronouncements

In April 2015, the Financial Accounting Standards Board (“FASB”) issued accounting guidance related to the presentation of debt issuance costs on the balance sheet as a direct reduction from the carrying amount of the debt liability, consistent with debt discounts, rather than as an asset.  Amortization of debt issuance costs will continue to be reported as interest expense.  In August 2015, the FASB issued accounting guidance related to the presentation and subsequent measurement of debt issuance costs associated with line-of-credit arrangements which clarifies that companies may continue to present unamortized debt issuance costs associated with line of credit arrangements as an asset.  These pronouncements are effective for fiscal years, and interim periods within those years, beginning after December 15, 2015, with early adoption permitted.  The Fund adopted the accounting guidance in first quarter 2016, resulting in a one-time reclassification of $0.2 million of unamortized debt discounts and deferred financing costs from "Other assets" to "Long-term borrowings" on the balance sheet as of December 31, 2015. Long-term borrowings are presented net of $0.2 million of unamortized debt discounts and deferred financing costs as of June 30, 2016. The adoption of these pronouncements did not impact the Fund’s results of operations or cash flows.

In 2014, the FASB issued accounting guidance on revenue recognition, which provides for a single five-step model to be applied to all revenue contracts with customers. In 2015, the FASB issued a deferral of the effective date of the guidance to 2018, with early adoption permitted in 2017. In May 2016, the FASB issued final amendments which provided narrow scope improvements and practical expedients related to the implementation of the guidance. The Fund is currently evaluating the impact of this guidance on its financial statements

XML

Related Parties

6 Months Ended

Jun. 30, 2016

Related Party Transactions [Abstract]

Related Parties

2. Related Parties

Pursuant to the terms of the LLC Agreement, the Manager renders management, administrative and advisory services to the Fund.  For such services, the Manager is entitled to 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.  Management fees during each of the three and six months ended June 30, 2016 and 2015 were $0.1 million and $0.2 million, respectively.

The Manager is entitled to receive a 15% interest in cash distributions from operations made by the Fund.  The Fund did not pay distributions during the three and six months ended June 30, 2016 and during the three months ended June 30, 2015. Distributions paid to the Manager during the six months ended June 30, 2015 were $13 thousand.

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

None of the amounts paid to the Manager have been derived as a result of arm’s length negotiations.

The Fund has working interest ownership in certain projects to acquire and develop oil and natural gas projects with other entities that are likewise managed by the Manager.

XML

Credit Agreement - Beta Project Financing

6 Months Ended

Jun. 30, 2016

Debt Disclosure [Abstract]

Credit Agreement - Beta Project Financing

3. Credit Agreement – Beta Project Financing

In November 2012, the Fund entered into a credit agreement (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, collectively “Lenders”) that provides for an aggregate loan commitment to the Fund of approximately $8.3 million (“Loan”), to provide capital toward the funding of the Fund’s share of development costs on the Beta Project. Except in cases of fraud and breach of certain representations, the Loan is non-recourse to the Fund’s other assets and secured solely by the Fund’s interests in the Beta Project. Certain other funds managed by Ridgewood (“Ridgewood Funds”, and when used with the Fund the “Ridgewood Participating Funds”) have also executed the Credit Agreement. Pursuant to the Credit Agreement, each Ridgewood Participating Fund has a separate loan commitment from the Lenders and amounts borrowed are not joint and several obligations. Each of the Ridgewood Participating Funds’ borrowings is secured solely by its separate interest in the Beta Project. Therefore, the Fund is liable for the repayment of its Loan and is not liable to the Lenders to repay any loan made to any other Ridgewood Funds. The Manager serves as the manager for each of the Ridgewood Participating Funds.

The Fund anticipates it will borrow approximately $8.3 million over the development period of the Beta Project. The Loan bears interest at 8% compounded annually and accrues only on Loan proceeds as they are drawn. Principal and interest will not be payable until such time that initial production has commenced for the Beta Project, which commenced production in third quarter 2016.  At that time, if certain revenue production levels are met, principal and interest will be repaid at a monthly rate of 1.25% of the Fund’s total principal outstanding at the date the Beta Project commences production for the first seven months of production, and a monthly rate of 4.5% of the Fund’s total principal outstanding at the date the Beta Project commences production thereafter until the Loan is repaid in full, in no event later than December 31, 2020.  The Loan may be prepaid by the Fund without premium or penalty.

As of June 30, 2016 and December 31, 2015, the Fund had borrowings of $2.9 million under the Credit Agreement. During the first quarter of 2016, the Fund adopted the accounting guidance issued in April 2015 related to the presentation of debt issuance costs on the balance sheet as a direct reduction from the carrying amount of the debt liability, rather than as an asset. As a result, the unamortized debt discounts and deferred financing costs of $0.2 million as of June 30, 2016 and December 31, 2015 are presented as a reduction of “Long-term borrowings” on the balance sheets.  As of June 30, 2016 and December 31, 2015, interest costs of $0.4 million and $0.3 million, respectively, were capitalized and included on the balance sheet within “Oil and gas properties”.  Such amounts are accrued on the balance sheet within “Accrued expenses” as of June 30, 2016 and “Accrued expenses” and “Other liabilities” as of December 31, 2015.

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 Credit Agreement contains customary covenants, for which the Fund believes it was in compliance as of June 30, 2016 and December 31, 2015.

XML

Commitments and Contingencies

6 Months Ended

Jun. 30, 2016

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

4. Commitments and Contingencies

Capital Commitments

The Fund has entered into multiple agreements for the acquisition, drilling and development of its oil and gas properties. The estimated capital expenditures associated with these agreements vary depending on the stage of development on a property-by-property basis.  As of June 30, 2016, the Fund had one property, the Beta Project, for which additional development costs must be incurred in order to commence production. The Fund currently expects to spend an additional $4.5 million (which includes asset retirement obligations) related to the development of the Beta Project, which the Fund anticipates will include the development of four wells with related platform and pipeline infrastructure. During third quarter 2016, one well in the Beta Project commenced production.

As of June 30, 2016, the Fund’s estimated capital commitments related to its oil and gas properties were $6.3 million (which include asset retirement obligations for the Fund’s projects of $2.7 million and projected interest costs of $21 thousand for the Beta Project), of which $3.3 million is expected to be spent during the next twelve months. These expected capital commitments exceed available working capital and salvage fund by $5.2 million as of June 30, 2016.  The Fund has entered into the Credit Agreement to provide capital for funding of the Beta Project.  See Note 3. “Credit Agreement – Beta Project Financing” for additional information.

Based upon its current cash position, its current reserve estimates and its current development plan of the Beta Project, the Fund expects cash flow from operations and borrowings to be sufficient to cover its commitments, as well as 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 capital commitments, the Manager will take action, which may include adjusting its management fee temporarily to accommodate the Fund’s short-term capital commitments.

Environmental Considerations

The exploration for and development of oil and natural gas involves the extraction, production and transportation of materials which, under certain conditions, can be hazardous or cause environmental pollution problems.  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 and do not currently anticipate that compliance with federal, state and local environmental regulations will have a material adverse effect upon capital expenditures, results of operations or the competitive position of the Fund in the oil and gas industry.  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 June 30, 2016 and December 31, 2015, there were no known environmental contingencies that required adjustment to, or disclosure in, the Fund’s financial statements.

During the past several years, the United States Congress, as well as certain regulatory agencies with jurisdiction over the Fund’s business, have considered or proposed legislation or regulation relating to the upstream oil and gas industry both onshore and offshore.  If any such proposals were to be enacted or adopted they could potentially materially impact the Fund’s operations.  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. 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.

Insurance Coverage

The Fund is subject to all risks inherent in the exploration for and development of oil and natural gas. 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 funds managed by the Manager.  Claims made by other funds managed by the Manager can reduce or eliminate insurance for the Fund.

XML

Organization and Summary of Significant Accounting Policies (Policy)

6 Months Ended

Jun. 30, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

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, 2015 financial statements and notes thereto included in the Fund’s Annual Report on Form 10-K 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, 2015, but does not include all disclosures required by GAAP.

Use of Estimates

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, net property balances, determination of proved reserves, impairment of long-lived assets and asset retirement obligations.  Actual results may differ from those estimates.

Fair Value Measurements

Fair Value Measurements

The fair value measurement guidance provides a hierarchy that prioritizes and defines the types of inputs used to measure fair value. The fair value hierarchy gives the highest priority to Level 1 inputs, which consists of unadjusted quoted prices for identical instruments in active markets. Level 2 inputs consist of quoted prices for similar instruments.  Level 3 inputs are unobservable inputs and include situations where there is little, if any, market activity for the instrument; hence, these inputs have the lowest priority.  Mortgage-backed securities are recorded based on Level 2 inputs, as such instruments trade in over-the-counter markets.

Cash and Cash Equivalents

Cash and Cash Equivalents

All highly liquid investments with maturities, when purchased, of three months or less, are considered cash equivalents. These balances, as well as cash on hand, are included in “Cash and cash equivalents” on the balance sheet. As of June 30, 2016, the Fund had no cash equivalents. At times, deposits may be in excess of federally insured limits, which are $250 thousand per insured financial institution.  As of June 30, 2016, the Fund’s bank balances were maintained in uninsured bank accounts at Wells Fargo Bank, N.A.

Salvage Fund

Salvage Fund

The Fund deposits in a separate interest-bearing account, or salvage fund, money to provide for the dismantling and removal of 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 June 30, 2016 and December 31, 2015, 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.

			Gross
	Amortized		Unrealized		Fair
	Cost		Gains		Value
	(in thousands)
Government National Mortgage Association security (GNMA July 2041)
June 30, 2016	$	74	$	4	$	78
December 31, 2015	$	75	$	3	$	78

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.

Debt Discounts and Deferred Financing Costs

Debt Discounts and Deferred Financing Costs

Debt discounts and deferred financing costs include lender fees and other costs of acquiring debt (see Note 3. “Credit Agreement – Beta Project Financing”) such as the conveyance of override royalty interests related to the Beta Project.  These costs are deferred and amortized over the term of the debt period or until the redemption of the debt. During the first quarter of 2016, the Fund adopted the accounting guidance issued in April 2015 related to the presentation of debt issuance costs on the balance sheet as a direct reduction from the carrying amount of the debt liability, rather than as an asset. As a result, the unamortized debt discounts and deferred financing costs of $0.2 million as of June 30, 2016 and December 31, 2015 are presented as a reduction of “Long-term borrowings” on the balance sheets. Amortization expense was $31 thousand during each of the three months ended June 30, 2016 and 2015. Amortization expense was $0.1 million during each of the six months ended June 30, 2016 and 2015.  During the period of asset construction, amortization expense, as a component of interest, is capitalized and included on the balance sheet within “Oil and gas properties”.

Oil and Gas Properties

Oil and Gas Properties

The Fund invests in oil and gas properties, which are operated by unaffiliated entities that are responsible for drilling, administering and producing activities pursuant to the terms of the applicable operating agreements with working interest owners. The Fund’s portion of exploration, drilling, operating and capital equipment expenditures is billed by operators.

Exploration, development and acquisition costs are accounted for using the successful efforts method. Costs of acquiring unproved and proved oil and natural gas leasehold acreage, including lease bonuses, brokers’ fees and other related costs are capitalized. Costs of drilling and equipping productive wells and related production facilities are capitalized.  The costs of exploratory wells are capitalized pending determination of whether proved reserves have been found. If proved commercial reserves are not found, exploratory well costs are expensed as dry-hole costs.  At times, the Fund receives adjustments to certain wells from their respective operators upon review and audit of the wells’ costs.  Interest costs related to the Credit Agreement (see Note 3. “Credit Agreement – Beta Project Financing”) are capitalized during the period of asset construction.  Annual lease rentals and exploration expenses are expensed as incurred.  All costs related to production activity and workover efforts are expensed as incurred.

Once a well has been determined to be fully depleted or upon the sale, retirement or abandonment of a property, the cost and related accumulated depletion and amortization, if any, is eliminated from the property accounts, and the resultant gain or loss is recognized.

As of June 30, 2016 and December 31, 2015, amounts recorded in due to operators totaling $0.3 million and $0.1 million, respectively, related to capital expenditures for oil and gas properties.

Advances to Operators for Working Interests and Expenditures

Advances to Operators for Working Interests and Expenditures

The Fund may be required to advance its share of the estimated succeeding month’s expenditures to the operator for its oil and gas properties. As the costs are incurred, the advances are reclassified to proved properties.

Asset Retirement Obligations

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 of a property to be 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.  As indicated above, the Fund maintains a salvage fund to provide for the funding of asset retirement obligations.

Syndication Costs

Syndication Costs

Syndication costs are direct costs incurred by the Fund in connection with the offering of the Fund’s shares, including professional fees, selling expenses and administrative costs payable to the Manager, an affiliate of the Manager and unaffiliated broker-dealers, which are reflected on the Fund’s balance sheet as a reduction of shareholders’ capital.

Revenue Recognition and Imbalances

Revenue Recognition and Imbalances

Oil and gas revenues are recognized when oil and gas is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and collectability of the revenue is reasonably assured.  The Fund uses the sales method of accounting for gas production imbalances.  The volumes of gas sold may differ from the volumes to which the Fund is entitled based on its interests in the properties.  These differences create imbalances that are recognized as a liability only when the properties’ estimated remaining reserves net to the Fund will not be sufficient to enable the underproduced owner to recoup its entitled share through production.  The Fund’s recorded liability, if any, would be reflected in other liabilities.  No receivables are recorded for those wells where the Fund has taken less than its share of production.

Impairment of Long-Lived Assets

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 of oil and natural gas prices, it is reasonably possible that the Fund’s estimate of discounted future net cash flows from proved oil and natural gas reserves could change in the near term.

Significant declines in oil and natural gas prices since fourth quarter 2014 have impacted the fair value of the Fund’s oil and gas properties. If oil and natural gas prices continue to decline, even if only for a short period of time, it is possible that impairments of oil and gas properties will occur.

Depletion and Amortization

Depletion and Amortization

Depletion and amortization of the cost of proved oil and gas properties are calculated using the units-of-production method.  Proved developed reserves are used as the base for depleting capitalized costs associated with successful exploratory well costs, development costs and related facilities. The sum of proved developed and proved undeveloped reserves is used as the base for depleting or amortizing leasehold acquisition costs.  During the three and six months ended June 30, 2015, the Fund recorded $0.6 million of depletion expense related to adjustments to asset retirement obligations for fully depleted properties.

Income Taxes

Income Taxes

No provision is made for income taxes in the financial statements.  The Fund is a limited liability company, and as such, the Fund’s income or loss is passed through and included in the tax returns of the Fund’s shareholders.  The Fund files U.S. Federal and State tax returns and the 2013 through 2015 tax returns remain open for examination by tax authorities.

Income and Expense Allocation

Income and Expense Allocation

Profits and losses are allocated to shareholders and the Manager in accordance with the LLC Agreement.

Distributions

Distributions

Distributions to shareholders are allocated in proportion to the number of shares held.  The Manager determines whether available cash from operations, as defined in the LLC Agreement, will be distributed. Such distributions are allocated 85% to the shareholders and 15% to the Manager, as required by the LLC Agreement.

Available cash from dispositions, as defined in the LLC Agreement, will be paid 99% to shareholders and 1% to the Manager until the shareholders have received total distributions equal to their capital contributions. After shareholders have received distributions equal to their capital contributions, 85% of available cash from dispositions will be distributed to shareholders and 15% to the Manager.

Recent Accounting Pronouncements

Recent Accounting Pronouncements

In April 2015, the Financial Accounting Standards Board (“FASB”) issued accounting guidance related to the presentation of debt issuance costs on the balance sheet as a direct reduction from the carrying amount of the debt liability, consistent with debt discounts, rather than as an asset.  Amortization of debt issuance costs will continue to be reported as interest expense.  In August 2015, the FASB issued accounting guidance related to the presentation and subsequent measurement of debt issuance costs associated with line-of-credit arrangements which clarifies that companies may continue to present unamortized debt issuance costs associated with line of credit arrangements as an asset.  These pronouncements are effective for fiscal years, and interim periods within those years, beginning after December 15, 2015, with early adoption permitted.  The Fund adopted the accounting guidance in first quarter 2016, resulting in a one-time reclassification of $0.2 million of unamortized debt discounts and deferred financing costs from "Other assets" to "Long-term borrowings" on the balance sheet as of December 31, 2015. Long-term borrowings are presented net of $0.2 million of unamortized debt discounts and deferred financing costs as of June 30, 2016. The adoption of these pronouncements did not impact the Fund’s results of operations or cash flows.

In 2014, the FASB issued accounting guidance on revenue recognition, which provides for a single five-step model to be applied to all revenue contracts with customers. In 2015, the FASB issued a deferral of the effective date of the guidance to 2018, with early adoption permitted in 2017. In May 2016, the FASB issued final amendments which provided narrow scope improvements and practical expedients related to the implementation of the guidance. The Fund is currently evaluating the impact of this guidance on its financial statements.

XML

Organization and Summary of Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Summary of Available-For-Sale Securities

			Gross
	Amortized		Unrealized		Fair
	Cost		Gains		Value
	(in thousands)
Government National Mortgage Association security (GNMA July 2041)
June 30, 2016	$	74	$	4	$	78
December 31, 2015	$	75	$	3	$	78

XML

Organization and Summary of Significant Accounting Policies (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Maximum cash balance federally insured per financial institution	$ 250		$ 250
Unamortized debt discounts and deferred financing costs	200		200		$ 200
Amortization of financing costs	31	$ 31	100	$ 100
Value of capital expenditures for oil and gas properties owed to operators	$ 300		$ 300		$ 100
Percentage of cash from operations allocated to shareholders	85.00%		85.00%
Percentage of cash from operations allocated to fund manager	15.00%		15.00%
Percentage of available cash from dispositions allocated to shareholders	99.00%		99.00%
Percentage of available cash from dispositions allocated to fund manager	1.00%		1.00%
Percentage of available cash from dispositions allocated to shareholders after distributions have equaled capital contributions	85.00%		85.00%
Percentage of available cash from dispositions allocated to fund manager after distributions have equaled capital contributions	15.00%		15.00%
Depletion		$ 600		$ 600
Reclassification of unamortized debt discounts and deferred financing costs			$ 200

XML

Organization and Summary of Significant Accounting Policies (Schedule of Available-For-Sale Securities) (Details) - GNMA July 2041 [Member] - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Schedule of Available-for-sale Securities [Line Items]
Amortized Cost	$ 74	$ 75
Gross Unrealized Gains	4	3
Fair Value	$ 78	$ 78

XML

Related Parties (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Related Party Transaction [Line Items]
Annual management fee percentage rate	2.50%		2.50%
Annual management fees paid to Fund Manager	$ 95	$ 95	$ 190	$ 190
Percentage of total distributions allocated to Fund Manager	15.00%		15.00%
Fund Manager [Member]
Related Party Transaction [Line Items]
Distributions				$ 13

XML

Credit Agreement - Beta Project Financing (Details) - USD ($) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Debt Disclosure [Abstract]
Credit agreement, maximum borrowing capacity	$ 8.3
Credit agreement, interest rate	8.00%
Credit agreement, contingency repayment rate, first seven months of production	1.25%
Credit agreement, contingency repayment rate, after first seven months of production	4.50%
Credit agreement, maturity date	Dec. 31, 2020
Long-term borrowings	$ 2.9	$ 2.9
Deferred financing cost	0.2	0.2
Capitalized interest	$ 0.4	$ 0.3

XML

Commitments and Contingencies (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2016 USD ($)
Impaired Long-Lived Assets Held and Used [Line Items]
Commitments for the drilling and development of investment properties	$ 6,300
Commitments for asset retirement obligations included in estimated capital commitments	2,700
Commitments for projected interest costs included in estimated capital commitments	21
Commitments for the drilling and development of investment properties expected to be incurred in the next 12 months	3,300
Commitments for the drilling and development of investment properties in excess of working capital	5,200
Beta Project [Member]
Impaired Long-Lived Assets Held and Used [Line Items]
Commitments for the drilling and development of investment properties	$ 4,500