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, 2015

or

o	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 x    No o

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 x     No o

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	o	Accelerated filer	o
Non-accelerated filer (Do not check if a smaller reporting company)	o	Smaller reporting company	x

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

 Yes o     No x

As of July 28, 2015 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, 2015 and December 31, 2014	1
		Unaudited Condensed Statements of Operations and Comprehensive (Loss) Income for the three and six months ended June 30, 2015 and 2014	2
		Unaudited Condensed Statements of Cash Flows for the six months ended June 30, 2015 and 2014	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		15
Item 4.	Controls and Procedures		15
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		16
	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, 2015			December 31, 2014
Assets
Current assets:
Cash and cash equivalents	$	4,655		$	5,045
Salvage fund		1,354			-
Production receivable		39			98
Other current assets		-			21
Total current assets		6,048			5,164
Salvage fund		428			1,780
Other assets		305			366
Oil and gas properties:
Proved properties		12,910			14,697
Less:  accumulated depletion and amortization		(2,912	)		(6,318	)
Total oil and gas properties, net		9,998			8,379
Total assets	$	16,779		$	15,689
Liabilities and Members' Capital
Current liabilities:
Due to operators	$	881		$	914
Accrued expenses		51			33
Asset retirement obligations		1,354			-
Total current liabilities		2,286			947
Long-term borrowings		2,900			1,800
Asset retirement obligations		362			965
Other liabilities		151			48
Total liabilities		5,699			3,760
Commitments and contingencies (Note 5)
Members' capital:
Manager:
Distributions		(5,058	)		(5,045	)
Retained earnings		5,139			5,152
Manager's total		81			107
Shareholders:
Capital contributions (250 shares authorized;
207.7026 issued and outstanding)		41,143			41,143
Syndication costs		(4,804	)		(4,804	)
Distributions		(35,427	)		(35,351	)
Retained earnings		10,084			10,830
Shareholders' total		10,996			11,818
Accumulated other comprehensive income		3			4
Total members' capital		11,080			11,929
Total liabilities and members' capital	$	16,779		$	15,689

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) INCOME

(in thousands, except per share data)

	Three months ended June 30,					Six months ended June 30,
	2015			2014		2015			2014
Revenue
Oil and gas revenue	$	201		$	1,092	$	339		$	1,800
Expenses
Depletion and amortization		606			356		633			643
Management fees to affiliate (Note 3)		95			160		190			317
Operating expenses		131			181		211			454
General and administrative expenses		35			35		70			73
Total expenses		867			732		1,104			1,487
Gain on sale of oil and gas properties		-			69		-			10,408
(Loss) income from operations		(666	)		429		(765	)		10,721
Interest income		3			4		6			8
Net (loss) income		(663	)		433		(759	)		10,729
Other comprehensive (loss) income
Unrealized (loss) gain on marketable securities		(1	)		-		(1	)		4
Total comprehensive (loss) income	$	(664	)	$	433	$	(760	)	$	10,733
Manager Interest
Net (loss) income	$	(3	)	$	105	$	(13	)	$	241
Shareholder Interest
Net (loss) income	$	(660	)	$	328	$	(746	)	$	10,488
Net (loss) income per share	$	(3,174	)	$	1,582	$	(3,591	)	$	50,496

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,
	2015			2014
Cash flows from operating activities
Net (loss) income	$	(759	)	$	10,729
Adjustments to reconcile net (loss) income to net cash
(used in) provided by operating activities:
Depletion and amortization		633			643
Gain on sale of oil and gas properties		-			(10,408	)
Accretion expense		83			-
Changes in assets and liabilities:
Decrease in production receivable		59			601
Decrease in other current assets		21			48
Decrease in due to operators		(98	)		(340	)
Increase (decrease) in accrued expenses		18			(8	)
Net cash (used in) provided by operating activities		(43	)		1,265
Cash flows from investing activities
Proceeds from sale of oil and gas properties		-			10,990
Capital expenditures for oil and gas properties		(1,355	)		(1,883	)
Investments in salvage fund		(3	)		(4	)
Net cash (used in) provided by investing activities		(1,358	)		9,103
Cash flows from financing activities
Long-term borrowings		1,100			-
Distributions		(89	)		(9,497	)
Net cash provided by (used in) financing activities		1,011			(9,497	)
Net (decrease) increase in cash and cash equivalents		(390	)		871
Cash and cash equivalents, beginning of period		5,045			4,690
Cash and cash equivalents, end of period	$	4,655		$	5,561
Supplemental schedule of non-cash investing activities
Advances used for capital expenditures in oil and gas properties reclassified to proved properties	$	-		$	68

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 in which the investments are made. 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 3, 4 and 5.

Basis of Presentation

These unaudited interim condensed financial statements have been prepared by the Fund’s management in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and in the opinion of management, contain all adjustments (consisting of only normal recurring adjustments) necessary to present fairly the Fund’s financial position, results of operations and cash flows for the periods presented.  Certain information and note disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted in these unaudited interim condensed financial statements.  The results of operations, financial position, and cash flows for the periods presented herein are not necessarily indicative of future financial results.  These unaudited interim condensed financial statements should be read in conjunction with the Fund’s December 31, 2014 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, 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, property balances, determination of proved reserves, impairments 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 valuations are derived from inputs that are significant and unobservable; hence, these valuations have the lowest priority. Cash and cash equivalents approximate fair value based on Level 1 inputs. 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 and cash equivalents. At times, deposits may be in excess of federally insured limits, which are $250 thousand per insured financial institution.  At June 30, 2015, the Fund’s bank balances were maintained in uninsured bank accounts at Wells Fargo Bank, N.A.

4

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.  At June 30, 2015 and December 31, 2014, 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 securities (GNMA July 2041)
June 30, 2015	$	76	$	3	$	79
December 31, 2014	$	84	$	3	$	87
Federal National Mortgage Association security (FNMA January 2042)
June 30, 2015	$	11	$	-	$	11
December 31, 2014	$	109	$	1	$	110

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 4. “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 and are included on the balance sheet within “Other assets”. At June 30, 2015 and December 31, 2014, $0.3 million and $0.4 million, respectively, of debt discounts and deferred financing costs were unamortized. Amortization expense was $31 thousand for each of the three months ended June 30, 2015 and 2014.  Amortization expense was $61 thousand for each of the six months ended June 30, 2015 and 2014.  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.  Exploratory costs are capitalized pending determination of whether proved reserves have been found. If proved commercial reserves are not found, exploratory 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 4. “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. Insurance expense related to operating wells has been reclassified from “General and administrative expense” in prior year to “Operating expense” to correct prior period presentation.

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.

At June 30, 2015 and December 31, 2014, amounts recorded in due to operators totaling $0.8 million 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. The Fund accounts for such payments as advances to operators for working interests and expenditures.  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.   When a project reaches drilling depth and is determined to be either proved or dry, an asset retirement obligation is incurred.  Plug and abandonment costs associated with unsuccessful projects are expensed as dry-hole costs.  The following table presents changes in asset retirement obligations for the six months ended June 30, 2015 and the year ended December 31, 2014.

	2015		2014
	(in thousands)
Balance, beginning of period	$	965	$	946
Accretion expense		83		19
Revisions in estimated cash flows		668		-
Balance, end of period	$	1,716	$	965

Asset retirement obligations are expected to be funded with proceeds from the salvage fund or through amounts withheld from operating income and held in escrow by such projects’ operators.

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 if collectability of the revenue is probable.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 value of its oil and gas properties whenever management determines that events and circumstances indicate that the recorded carrying value of properties may not be recoverable. Impairments of proved properties are determined by comparing future net undiscounted cash flows to the net book value at the time of the review. If the net book value exceeds the future net undiscounted cash flows, the carrying value of the property is written down to fair value, which is determined using net discounted future cash flows from the property. The Fund provides for impairments on unproved properties when it determines that the property will not be developed or a permanent impairment in value has occurred. 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. If oil and natural gas prices decline significantly, even if only for a short period of time, it is possible that write-downs of oil and gas properties could occur.

6

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.

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.   During the six months ended June 30, 2014, the Fund made distributions of available cash from dispositions related to the sale of the Raven Project totaling $7.2 million.  There were no such distributions during the three months ended June 30, 2014 and during the three and six months ended June 30, 2015.

Recent Accounting Pronouncements

In April 2015, the Financial Accounting Standards Board (“FASB”) issued accounting guidance relating to the presentation of debt issuance costs. The intent is to simplify the presentation of debt issuance costs by requiring entities to record debt issuance costs on the balance sheet as a direct deduction from the carrying amount of the related debt liability, similar to debt discounts or premiums.  This pronouncement is effective for fiscal years, and interim periods within those years, beginning after December 15, 2015.  The adoption of this new guidance will not have a significant impact on the Fund’s financial statements.

2.  Oil and Gas Properties

On January 17, 2014, the Fund, along with its affiliates, entered into a purchase and sale agreement to sell its interest in the Raven Project, located in the state waters of Louisiana, to Castex Energy Partners, L.P. for cash consideration totaling $21.7 million.  The closing of the sale transaction occurred on January 30, 2014.  The Fund had a 25.0% working interest in the Raven Project and received $11.0 million in cash proceeds from the sale. The net carrying value for the Raven Project on the date of the sale was $0.6 million, thereby resulting in a gain to the Fund of $10.4 million, which was recognized during the six months ended June 30, 2014.  There was no such amount recorded during the three and six months ended June 30, 2015.

3.  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 paid 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 for the three and six months ended June 30, 2015 were $0.1 million and $0.2 million, respectively.  Management fees for the three and six months ended June 30, 2014 were $0.2 million and $0.3 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 for the three months ended June 30, 2015.  Distributions from operations paid to the Manager for the six months ended June 30, 2015 were $13 thousand.  Distributions from operations paid to the Manager for the three and six months ended June 30, 2014 were $0.1 million and $0.4 million, respectively.  In addition, the Manager is entitled to receive a 1% interest in cash distributions from dispositions.  Distributions from the sale of the Raven project paid to the Manager during the six months ended June 30, 2014 were $0.1 million.  There were no such distributions during the three months ended June 30, 2014 and during the three and six months ended June 30, 2015.

7

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.

4.  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.

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 is currently expected in 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, 2015 and December 31, 2014, the Fund had borrowings of $2.9 million and $1.8 million, respectively, under the Credit Agreement.  As of June 30, 2015 and December 31, 2014, interest costs of $0.2 million and $48 thousand, respectively, were capitalized and included on the balance sheet within “Oil and gas properties”.  Such amounts are accrued on the balance sheet within “Other liabilities”.

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 at June 30, 2015 and December 31, 2014.

5.  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.  Currently, the Fund has one non-producing property, the Beta Project, for which additional development costs must be incurred in order to commence production. The Fund currently anticipates such development will include a four-well development with related platform and pipeline infrastructure.

As of June 30, 2015, the Fund’s estimated capital commitments related to its oil and gas properties were $10.1 million (which include asset retirement obligations for the Fund’s projects of $2.7 million and projected interest costs of $0.4 million for the Beta Project), of which $5.6 million is expected to be spent during the next twelve months. These expected capital commitments exceed available working capital and salvage fund by $4.6 million at June 30, 2015.  The Fund has entered into a credit agreement to provide capital for the Beta Project.  See Note 4. “Credit Agreement – Beta Project Financing” for additional information.

Based upon its current cash position and its current reserve estimates, 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.

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.  At June 30, 2015 and December 31, 2014, there were no known environmental contingencies that required the Fund to record a liability.
   

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 “Notes to Unaudited Condensed Financial Statements” in Part I of this Quarterly Report for a presentation of the Fund’s significant accounting policies. No changes have been made to the Fund’s critical accounting policies and estimates disclosed in its 2014 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.  However, the Fund is not required to make distributions to shareholders except as provided in the Fund’s limited liability company agreement (the “LLC Agreement”).

Ridgewood Energy Corporation (the “Manager” or “Ridgewood Energy”) is the Manager, and as such, has direct and exclusive control over the management of the Fund’s operations.  The Manager performs certain duties on the Fund’s behalf including the evaluation of projects, including ongoing management, administrative and advisory services.  For these services, the Manager receives an annual management fee equal to 2.5% of capital contributions, net of cumulative dry-hole and related well costs incurred by the Fund, payable monthly.  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

Revenues are subject to market pricing for oil and natural gas, which has been 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. Low commodity prices could have an adverse effect on the Fund’s future profitability.  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.  The budget for each project is inclusive of estimated asset retirement obligations.

				Total Spent		Total
		Working		through		Fund
	Project	Interest		June 30, 2015		Budget		Status
				(in thousands)
Non-producing Properties
	Beta Project		2.0%	$	9,876	$	18,183	Well deemed to be a discovery in 2012.  Completion efforts are ongoing and production is expected to commence in 2016.
Producing Properties
	Liberty Project		2.0%	$	3,008	$	3,469	Production commenced in 2010.  Recompletion is planned for 2016.
Fully Depleted
	Alpha Project		3.75%	$	6,607	$	7,470	Production commenced in 2012.  Well reached the end of its productive life in fourth quarter 2014.
	Carrera Project		2.0%	$	3,247	$	3,712	Production commenced in 2011. Well reached the end of its productive life in fourth quarter 2014.
Sold Properties
	Raven Project wells #1 & #2		25.0%	$	11,452	$	11,452	In January 2014, the Fund sold its interest in the Raven Project.  See "Raven Sale" below for additional information.

11

Raven Sale

On January 17, 2014, the Fund, along with its affiliates, entered into a purchase and sale agreement to sell its interest in the Raven Project, located in the state waters of Louisiana, to Castex Energy Partners, L.P. for cash consideration totaling $21.7 million.  The closing of the sale transaction occurred on January 30, 2014.  The Fund had a 25.0% working interest in the Raven Project and received $11.0 million in cash proceeds from the sale. The net carrying value for the Raven Project on the date of the sale was $0.6 million, thereby resulting in a gain to the Fund of $10.4 million, which was recognized during the six months ended June 30, 2014.  There was no such amount recorded during the three and six months ended June 30, 2015.

Results of Operations

The following table summarizes the Fund’s results of operations for the three and six months ended June 30, 2015 and 2014, and should be read in conjunction with the Fund’s financial statements and notes thereto included within Item 1.  “Financial Statements” in Part I in this Quarterly Report.

	Three months ended June 30,					Six months ended June 30,
	2015			2014		2015			2014
	(in thousands)
Revenue
Oil and gas revenue	$	201		$	1,092	$	339		$	1,800
Expenses
Depletion and amortization		606			356		633			643
Management fees to affiliate		95			160		190			317
Operating expenses		131			181		211			454
General and administrative expenses		35			35		70			73
Total expenses		867			732		1,104			1,487
Gain on sale of oil and gas properties		-			69		-			10,408
(Loss) income from operations		(666	)		429		(765	)		10,721
Interest income		3			4		6			8
Net (loss) income		(663	)		433		(759	)		10,729
Other comprehensive (loss) income
Unrealized (loss) gain on marketable securities		(1	)		-		(1	)		4
Total comprehensive (loss) income	$	(664	)	$	433	$	(760	)	$	10,733

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, 2015 and 2014.  Natural gas liquid (“NGL”) sales are included within gas sales.

	Three months ended June 30,				Six months ended June 30,
	2015		2014		2015		2014
Number of wells producing		1		3		1		3
Total number of production days		85		236		171		404
Oil sales (in thousands of barrels)		3		8		6		13
Average oil price per barrel	$	58	$	102	$	52	$	101
Gas sales (in thousands of mcfs)		8		43		15		89
Average gas price per mcf	$	2.40	$	5.31	$	2.30	$	5.40

The decreases noted in the overview table were attributable to the Alpha and Carrera projects, which reached the end of their productive lives in fourth quarter 2014, and the Liberty Project, which experienced natural declines in well production.  See additional discussion in “Business Update” section above.

Oil and Gas Revenue.   Oil and gas revenue for the three months ended June 30, 2015 was $0.2 million, a decrease of $0.9 million from the three months ended June 30, 2014.  The decrease was attributable to decreased sales volume totaling $0.6 million coupled with decreased oil and gas prices totaling $0.2 million. Oil and gas revenue for the six months ended June 30, 2015 was $0.3 million, a decrease of $1.5 million from the six months ended June 30, 2014.  The decrease was attributable to decreased sales volume totaling $1.1 million coupled with decreased oil and gas prices totaling $0.3 million. See “Overview” above for additional information.

12

Depletion and Amortization.  Depletion and amortization for the three months ended June 30, 2015 was $0.6 million, an increase of $0.3 million from the three months ended June 30, 2014.  The increase was attributable to adjustments to asset retirement obligations of $0.6 million, related to the Carrera and Alpha projects, partially offset by decreases in production volumes totaling $0.3 million and average depletion rates totaling $0.1 million.  Depletion and amortization for the six months ended June 30, 2015 was $0.6 million, a decrease of $10 thousand from the six months ended June 30, 2014.  The decrease was attributable to decreases in production volumes totaling $0.5 million and average depletion rates totaling $0.1 million, partially offset by adjustments to asset retirement obligations of $0.6 million.   The decrease in the average depletion rates was primarily attributable to the Alpha Project, which had higher cost reserves and reached the end of its productive life in fourth quarter 2014.   See “Overview” above for additional information.

Management Fees to Affiliate.Management fees for the three months ended June 30, 2015 and 2014 were $0.1 million and $0.2 million, respectively.  Management fees for the six months ended June 30, 2015 and 2014 were $0.2 million and $0.3 million, respectively.   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,
	2015		2014			2015			2014
	(in thousands)
Lease operating expense	$	33	$	170		$	122		$	262
Accretion expense		83		-			83			-
Insurance expense		15		17			23			42
Workover expense and other		-		(6	)		(17	)		150
	$	131	$	181		$	211		$	454

Lease operating expense relates to the Fund’s producing properties during each period as outlined above in “Overview”.  The average production cost was $10.77 per barrel of oil equivalent (“BOE”) and $17.11 per BOE during the three and six months ended June 30, 2015, respectively, compared to $11.33 per BOE and $9.55 per BOE during the three and six months ended June 30, 2014, respectively.  The increase in the average production cost for the six months ended June 30, 2015 is attributable to the impact of ongoing costs for wells that are no longer producing, including the Alpha Project.  Accretion expense related to the asset retirement obligations established for the Fund’s proved properties.  Insurance expense represents premiums related to producing well and control of well insurance, which varies depending upon the number of wells producing or drilling.  Insurance expense related to operating wells has been reclassified from “General and administrative expense” in prior year to “Operating expense” to conform to current year presentation. Workover expense represents costs to restore or stimulate production of existing reserves.

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.

Gain on Sale of Oil and Gas Properties.  The Fund did not record a gain on sale of oil and gas properties during the three and six months ended June 30, 2015.  During the three and six months ended June 30, 2014, the Fund recorded a gain on sale of oil and gas properties of $0.1 million and $10.4 million, respectively, related to the Raven Project.  See “Business Update” for additional information regarding the sale.

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

Unrealized (Loss) Gain on Marketable Securities.  At June 30, 2015, the Fund had available-for-sale investments within its salvage fund in federal agency mortgage-backed securities totaling $0.1 million, which mature between 2041 and 2042.  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.  The Fund recognized an unrealized loss of $1 thousand during the three and six months ended June 30, 2015.  The Fund recognized an unrealized gain of $4 thousand during the six months ended June 30, 2014.  There was no such amount recorded during the three months ended June 30, 2014.

13

Capital Resources and Liquidity

Operating Cash Flows

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

Cash flows provided by operating activities for the six months ended June 30, 2014 were $1.3 million, primarily related to revenue received of $2.4 million, partially offset by operating expenses paid of $0.6 million, management fees of $0.3 million, workover expense paid of $0.2 million, and general and administrative expenses paid of $0.1 million.

Investing Cash Flows

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

Cash flows provided by investing activities for the six months ended June 30, 2014 were $9.1 million, primarily related to proceeds from the sale of the Raven Project of $11.0 million, partially offset by capital expenditures for oil and gas properties of $1.9 million.

Financing Cash Flows

Cash flows provided by financing activities for 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.

Cash flows used in financing activities for the six months ended June 30, 2014 were $9.5 million, related to manager and shareholder distributions, of which $7.2 million was related to the distribution of the proceeds from the sale of the Raven Project.

Estimated Capital Expenditures

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, 2015, the Fund had one non-producing 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 $8.3 million related to the development of this project, which the Fund anticipates will include a four-well development with related platform and pipeline infrastructure.  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, 2015, the Fund’s estimated capital commitments related to its oil and gas properties were $10.1 million (which include asset retirement obligations for the Fund’s projects of $2.7 million and projected interest costs of $0.4 million for the Beta Project), of which $5.6 million is expected to be spent during the next twelve months. These expected capital commitments exceed available working capital and salvage fund by $4.6 million at June 30, 2015. The Fund has entered into a credit agreement to provide capital for the Beta Project.  See “Credit Agreement” below for additional information.

Based upon its current cash position and its current reserve estimates, 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.

14

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

The Fund has 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, 2015 and December 31, 2014, the Fund had borrowed $2.9 million and $1.8 million, respectively, under the Credit Agreement.  Principal and interest amounts are contracted to be repaid upon the onset of production of the Beta Project, which is expected in 2016, over a period not to extend beyond December 31, 2020.  See Note 4 of “Notes to Unaudited Condensed Financial Statements” – “Credit Agreement – Beta Project Financing” in Part I of this Quarterly Report for more information regarding the Credit Agreement.

Off-Balance Sheet Arrangements

The Fund had no off-balance sheet arrangements at June 30, 2015 and December 31, 2014 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 at June 30, 2015 and December 31, 2014, other than those discussed in “Estimated Capital Expenditures” and “Liquidity Needs” – Credit Agreement above.

Recent Accounting Pronouncements

In April 2015, the Financial Accounting Standards Board (“FASB”) issued accounting guidance relating to the presentation of debt issuance costs. The intent is to simplify the presentation of debt issuance costs by requiring entities to record debt issuance costs on the balance sheet as a direct deduction from the carrying amount of the related debt liability, similar to debt discounts or premiums.  This pronouncement is effective for fiscal years, and interim periods within those years, beginning after December 15, 2015.  The adoption of this new guidance will not have a significant impact on the Fund’s financial statements.

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, 2015.

There has been no change in the Fund’s internal control over financial reporting that occurred during the three months ended June 30, 2015 that has materially affected, or is reasonably likely to materially affect, the Fund’s internal control over financial reporting.

15

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.

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

16

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

				RIDGEWOOD ENERGY A-1 FUND, LLC
Dated:	July 28, 2015	By:	/s/	ROBERT E. SWANSON
			Name:	Robert E. Swanson
			Title:	Chief Executive Officer
				(Principal Executive Officer)
Dated:	July 28, 2015	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:	July 28, 2015
/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:	July 28, 2015
/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, 2015, 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:	July 28, 2015
		/s/	ROBERT E. SWANSON
		Name:	Robert E. Swanson
		Title:	Chief Executive Officer
			(Principal Executive Officer)
Dated:	July 28, 2015
		/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

Credit Agreement - Beta Project Financing

6 Months Ended

Jun. 30, 2015

Credit Agreement - Beta Project Financing [Abstract]

Credit Agreement - Beta Project Financing

4.  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.

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 is currently expected in 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, 2015 and December 31, 2014, the Fund had borrowings of $2.9 million and $1.8 million, respectively, under the Credit Agreement.  As of June 30, 2015 and December 31, 2014, interest costs of $0.2 million and $48 thousand, respectively, were capitalized and included on the balance sheet within “Oil and gas properties”.  Such amounts are accrued on the balance sheet within “Other liabilities”.

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 at June 30, 2015 and December 31, 2014.

XML

Related Parties

6 Months Ended

Jun. 30, 2015

Related Parties [Abstract]

Related Parties

3.  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 paid 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 for the three and six months ended June 30, 2015 were $0.1 million and $0.2 million, respectively.  Management fees for the three and six months ended June 30, 2014 were $0.2 million and $0.3 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 for the three months ended June 30, 2015.  Distributions from operations paid to the Manager for the six months ended June 30, 2015 were $13 thousand.  Distributions from operations paid to the Manager for the three and six months ended June 30, 2014 were $0.1 million and $0.4 million, respectively.  In addition, the Manager is entitled to receive a 1% interest in cash distributions from dispositions.  Distributions from the sale of the Raven project paid to the Manager during the six months ended June 30, 2014 were $0.1 million.  There were no such distributions during the three months ended June 30, 2014 and during the three and six months ended June 30, 2015.

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

UNAUDITED CONDENSED BALANCE SHEETS - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 4,655	$ 5,045
Salvage fund	1,354
Production receivable	$ 39	$ 98
Other current assets		21
Total current assets	$ 6,048	5,164
Salvage fund	428	1,780
Other assets	305	366
Oil and gas properties:
Proved properties	12,910	14,697
Less: accumulated depletion and amortization	(2,912)	(6,318)
Total oil and gas properties, net	9,998	8,379
Total assets	16,779	15,689
Current liabilities:
Due to operators	881	914
Accrued expenses	51	$ 33
Asset retirement obligations	1,354
Total current liabilities	2,286	$ 947
Long-term borrowings	2,900	1,800
Asset retirement obligations	362	965
Other liabilities	151	48
Total liabilities	$ 5,699	$ 3,760
Commitments and contingencies (Note 5)
Members' capital:
Distributions	$ (5,058)	$ (5,045)
Retained earnings	5,139	5,152
Manager's total	81	107
Capital contributions (250 shares authorized; 207.7026 issued and outstanding)	41,143	41,143
Syndication costs	(4,804)	(4,804)
Distributions	(35,427)	(35,351)
Retained earnings	10,084	10,830
Shareholders' total	10,996	11,818
Accumulated other comprehensive income	3	4
Total members' capital	11,080	11,929
Total liabilities and members' capital	$ 16,779	$ 15,689

XML

Organization and Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 2015

Organization and Summary of Significant Accounting Policies [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 in which the investments are made. 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 3, 4 and 5.

Basis of Presentation

These unaudited interim condensed financial statements have been prepared by the Fund's management in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and in the opinion of management, contain all adjustments (consisting of only normal recurring adjustments) necessary to present fairly the Fund's financial position, results of operations and cash flows for the periods presented.  Certain information and note disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted in these unaudited interim condensed financial statements.  The results of operations, financial position, and cash flows for the periods presented herein are not necessarily indicative of future financial results.  These unaudited interim condensed financial statements should be read in conjunction with the Fund's December 31, 2014 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, 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, property balances, determination of proved reserves, impairments 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 valuations are derived from inputs that are significant and unobservable; hence, these valuations have the lowest priority. Cash and cash equivalents approximate fair value based on Level 1 inputs. 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 and cash equivalents. At times, deposits may be in excess of federally insured limits, which are $250 thousand per insured financial institution.  At June 30, 2015, 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.  At June 30, 2015 and December 31, 2014, 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.

	Amortized		Gross Unrealized		Fair
	Cost		Gains		Value
	(in thousands)
Government National Mortgage Association securities (GNMA July 2041)
June 30, 2015	$	76	$	3	$	79
December 31, 2014	$	84	$	3	$	87
Federal National Mortgage Association security (FNMA January 2042)
June 30, 2015	$	11	$	-	$	11
December 31, 2014	$	109	$	1	$	110

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 4. “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 and are included on the balance sheet within “Other assets”. At June 30, 2015 and December 31, 2014, $0.3 million and $0.4 million, respectively, of debt discounts and deferred financing costs were unamortized. Amortization expense was $31 thousand for each of the three months ended June 30, 2015 and 2014.  Amortization expense was $61 thousand for each of the six months ended June 30, 2015 and 2014.  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.  Exploratory costs are capitalized pending determination of whether proved reserves have been found. If proved commercial reserves are not found, exploratory 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 4. “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. Insurance expense related to operating wells has been reclassified from “General and administrative expense” in prior year to “Operating expense” to correct prior period presentation.

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.

At June 30, 2015 and December 31, 2014, amounts recorded in due to operators totaling $0.8 million 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. The Fund accounts for such payments as advances to operators for working interests and expenditures.  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.   When a project reaches drilling depth and is determined to be either proved or dry, an asset retirement obligation is incurred.  Plug and abandonment costs associated with unsuccessful projects are expensed as dry-hole costs.  The following table presents changes in asset retirement obligations for the six months ended June 30, 2015 and the year ended December 31, 2014.

	2015		2014
	(in thousands)
Balance, beginning of period	$	965	$	946
Accretion expense		83		19
Revisions in estimated cash flows		668		-
Balance, end of period	$	1,716	$	965

Asset retirement obligations are expected to be funded with proceeds from the salvage fund or through amounts withheld from operating income and held in escrow by such projects' operators.

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 if collectability of the revenue is probable.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 value of its oil and gas properties whenever management determines that events and circumstances indicate that the recorded carrying value of properties may not be recoverable. Impairments of proved properties are determined by comparing future net undiscounted cash flows to the net book value at the time of the review. If the net book value exceeds the future net undiscounted cash flows, the carrying value of the property is written down to fair value, which is determined using net discounted future cash flows from the property. The Fund provides for impairments on unproved properties when it determines that the property will not be developed or a permanent impairment in value has occurred. 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. If oil and natural gas prices decline significantly, even if only for a short period of time, it is possible that write-downs of oil and gas properties could 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.

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.   During the six months ended June 30, 2014, the Fund made distributions of available cash from dispositions related to the sale of the Raven Project totaling $7.2 million.  There were no such distributions during the three months ended June 30, 2014 and during the three and six months ended June 30, 2015.

Recent Accounting Pronouncements

In April 2015, the Financial Accounting Standards Board (“FASB”) issued accounting guidance relating to the presentation of debt issuance costs. The intent is to simplify the presentation of debt issuance costs by requiring entities to record debt issuance costs on the balance sheet as a direct deduction from the carrying amount of the related debt liability, similar to debt discounts or premiums.  This pronouncement is effective for fiscal years, and interim periods within those years, beginning after December 15, 2015.  The adoption of this new guidance will not have a significant impact on the Fund's financial statements.

XML

Oil and Gas Properties

6 Months Ended

Jun. 30, 2015

Oil and Gas Properties [Abstract]

Oil and Gas Properties

2.  Oil and Gas Properties

On January 17, 2014, the Fund, along with its affiliates, entered into a purchase and sale agreement to sell its interest in the Raven Project, located in the state waters of Louisiana, to Castex Energy Partners, L.P. for cash consideration totaling $21.7 million.  The closing of the sale transaction occurred on January 30, 2014.  The Fund had a 25.0% working interest in the Raven Project and received $11.0 million in cash proceeds from the sale. The net carrying value for the Raven Project on the date of the sale was $0.6 million, thereby resulting in a gain to the Fund of $10.4 million, which was recognized during the six months ended June 30, 2014.  There was no such amount recorded during the three and six months ended June 30, 2015.

XML

UNAUDITED CONDENSED BALANCE SHEETS (Parenthetical) - shares	Jun. 30, 2015	Dec. 31, 2014
UNAUDITED CONDENSED BALANCE SHEETS [Abstract]
Shares authorized	250	250
Shares issued	207.7026	207.7026
Shares outstanding	207.7026	207.7026

XML

Related Parties (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Related Party Transaction [Line Items]
Annual management fee percentage rate	2.50%		2.50%
Annual management fees paid to Fund Manager	$ 95	$ 160	$ 190	$ 317
Percentage of total distributions allocated to Fund Manager	15.00%		15.00%
Fund Manager [Member]
Related Party Transaction [Line Items]
Distributions		$ (100)	$ (13)	(400)
Fund Manager [Member] | Raven Project [Member]
Related Party Transaction [Line Items]
Percentage of total distributions allocated to Fund Manager	1.00%		1.00%
Distributions				$ (100)

XML

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2015	Jul. 28, 2015
Document And Entity Information Abstract
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2015
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	2015
Document Fiscal Period Focus	Q2
Entity Filer Category	Smaller Reporting Company
Entity Common Stock, Shares Outstanding		207.7026

XML

Credit Agreement - Beta Project Financing (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Credit Agreement - Beta Project Financing [Abstract]
Credit agreement, maximum borrowing capacity	$ 8,300
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	$ 2,900	$ 1,800
Capitalized interest	$ 200	$ 48

XML

UNAUDITED CONDENSED STATEMENTS OF OPERATIONS AND COMPREHENSIVE (LOSS) INCOME - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Revenue
Oil and gas revenue	$ 201	$ 1,092	$ 339	$ 1,800
Expenses
Depletion and amortization	606	356	633	643
Management fees to affiliate (Note 3)	95	160	190	317
Operating expenses	131	181	211	454
General and administrative expenses	35	35	70	73
Total expenses	$ 867	732	$ 1,104	1,487
Gain on sale of oil and gas properties		69		10,408
(Loss) income from operations	$ (666)	429	$ (765)	10,721
Interest income	3	4	6	8
Net (loss) income	(663)	$ 433	(759)	10,729
Other comprehensive (loss) income
Unrealized (loss) gain on marketable securities	(1)		(1)	4
Total comprehensive (loss) income	(664)	$ 433	(760)	10,733
Manager Interest
Net (loss) income	(3)	105	(13)	241
Shareholder Interest
Net (loss) income	$ (660)	$ 328	$ (746)	$ 10,488
Net (loss) income per share	$ (3,174)	$ 1,582	$ (3,591)	$ 50,496

XML

Organization and Summary of Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2015

Organization and Summary of Significant Accounting Policies [Abstract]

Summary of Available-For-Sale Securities

	Amortized		Gross Unrealized		Fair
	Cost		Gains		Value
	(in thousands)
Government National Mortgage Association securities (GNMA July 2041)
June 30, 2015	$	76	$	3	$	79
December 31, 2014	$	84	$	3	$	87
Federal National Mortgage Association security (FNMA January 2042)
June 30, 2015	$	11	$	-	$	11
December 31, 2014	$	109	$	1	$	110

Schedule of Changes in Asset Retirement Obligations

	2015		2014
	(in thousands)
Balance, beginning of period	$	965	$	946
Accretion expense		83		19
Revisions in estimated cash flows		668		-
Balance, end of period	$	1,716	$	965

XML

Organization and Summary of Significant Accounting Policies (Policy)

6 Months Ended

Jun. 30, 2015

Organization and Summary of Significant Accounting Policies [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, 2014 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, 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, property balances, determination of proved reserves, impairments 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 valuations are derived from inputs that are significant and unobservable; hence, these valuations have the lowest priority. Cash and cash equivalents approximate fair value based on Level 1 inputs. 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 and cash equivalents. At times, deposits may be in excess of federally insured limits, which are $250 thousand per insured financial institution.  At June 30, 2015, 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.  At June 30, 2015 and December 31, 2014, 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.

	Amortized		Gross Unrealized		Fair
	Cost		Gains		Value
	(in thousands)
Government National Mortgage Association securities (GNMA July 2041)
June 30, 2015	$	76	$	3	$	79
December 31, 2014	$	84	$	3	$	87
Federal National Mortgage Association security (FNMA January 2042)
June 30, 2015	$	11	$	-	$	11
December 31, 2014	$	109	$	1	$	110

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 4. “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 and are included on the balance sheet within “Other assets”. At June 30, 2015 and December 31, 2014, $0.3 million and $0.4 million, respectively, of debt discounts and deferred financing costs were unamortized. Amortization expense was $31 thousand for each of the three months ended June 30, 2015 and 2014.  Amortization expense was $61 thousand for each of the six months ended June 30, 2015 and 2014.  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.  Exploratory costs are capitalized pending determination of whether proved reserves have been found. If proved commercial reserves are not found, exploratory 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 4. “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. Insurance expense related to operating wells has been reclassified from “General and administrative expense” in prior year to “Operating expense” to correct prior period presentation.

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.

At June 30, 2015 and December 31, 2014, amounts recorded in due to operators totaling $0.8 million 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. The Fund accounts for such payments as advances to operators for working interests and expenditures.  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.   When a project reaches drilling depth and is determined to be either proved or dry, an asset retirement obligation is incurred.  Plug and abandonment costs associated with unsuccessful projects are expensed as dry-hole costs.  The following table presents changes in asset retirement obligations for the six months ended June 30, 2015 and the year ended December 31, 2014.

	2015		2014
	(in thousands)
Balance, beginning of period	$	965	$	946
Accretion expense		83		19
Revisions in estimated cash flows		668		-
Balance, end of period	$	1,716	$	965

Asset retirement obligations are expected to be funded with proceeds from the salvage fund or through amounts withheld from operating income and held in escrow by such projects' operators.

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 if collectability of the revenue is probable.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 value of its oil and gas properties whenever management determines that events and circumstances indicate that the recorded carrying value of properties may not be recoverable. Impairments of proved properties are determined by comparing future net undiscounted cash flows to the net book value at the time of the review. If the net book value exceeds the future net undiscounted cash flows, the carrying value of the property is written down to fair value, which is determined using net discounted future cash flows from the property. The Fund provides for impairments on unproved properties when it determines that the property will not be developed or a permanent impairment in value has occurred. 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. If oil and natural gas prices decline significantly, even if only for a short period of time, it is possible that write-downs of oil and gas properties could 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.

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.   During the six months ended June 30, 2014, the Fund made distributions of available cash from dispositions related to the sale of the Raven Project totaling $7.2 million.  There were no such distributions during the three months ended June 30, 2014 and during the three and six months ended June 30, 2015.

Recent Accounting Pronouncements

Recent Accounting Pronouncements

In April 2015, the Financial Accounting Standards Board (“FASB”) issued accounting guidance relating to the presentation of debt issuance costs. The intent is to simplify the presentation of debt issuance costs by requiring entities to record debt issuance costs on the balance sheet as a direct deduction from the carrying amount of the related debt liability, similar to debt discounts or premiums.  This pronouncement is effective for fiscal years, and interim periods within those years, beginning after December 15, 2015.  The adoption of this new guidance will not have a significant impact on the Fund's financial statements.

XML

Commitments and Contingencies (Details) - Jun. 30, 2015 - USD ($) $ in Millions	Total
Commitments and Contingencies [Abstract]
Commitments for the drilling and development of investment properties	$ 10.1
Commitments for asset retirement obligations included in estimated capital commitments	2.7
Commitments for projected interest costs included in estimated capital commitments	0.4
Commitments for the drilling and development of investment properties expected to be incurred in the next 12 months	5.6
Commitments for the drilling and development of investment properties in excess of working capital	$ 4.6

XML

Organization and Summary of Significant Accounting Policies (Schedule of Changes in Asset Retirement Obligations) (Details) - USD ($) $ in Thousands	6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Organization and Summary of Significant Accounting Policies [Abstract]
Balance, beginning of period	$ 965	$ 946	$ 946
Accretion expense	83		$ 19
Revisions in estimated cash flows	668
Balance, end of period	$ 1,716		$ 965

XML

Organization and Summary of Significant Accounting Policies (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Organization and Summary of Significant Accounting Policies [Abstract]
Maximum cash balance federally insured per financial institution	$ 250		$ 250
Unamortized debt discounts and deferred financing costs	300		300		$ 400
Amortization of financing costs	31	$ 31	61	$ 61
Value of capital expenditures for oil and gas properties owed to operators	800		800		$ 800
Depletion	$ 600		$ 600
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%
Distributions related to Raven Project				$ 7,200

XML

Organization and Summary of Significant Accounting Policies (Schedule of Available-For-Sale Securities) (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
GNMA July 2041 [Member]
Schedule of Available-for-sale Securities [Line Items]
Amortized Cost	$ 76	$ 84
Gross Unrealized Gains	3	3
Fair Value	79	87
FNMA January 2042 [Member]
Schedule of Available-for-sale Securities [Line Items]
Amortized Cost	$ 11	109
Gross Unrealized Gains		1
Fair Value	$ 11	$ 110

XML

Oil and Gas Properties (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Oil and Gas Properties [Abstract]
Cash consideration		$ 21,700		$ 21,700
Working interest percentage				25.00%
Proceeds from sale of oil and gas properties				$ 10,990
Carrying value of oil and gas properties at date of sale		600		600
Gain on sale of oil and gas properties		$ 69		$ 10,408

XML

UNAUDITED CONDENSED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Cash flows from operating activities
Net (loss) income	$ (759)	$ 10,729
Adjustments to reconcile net (loss) income to net cash (used in) provided by operating activities:
Depletion and amortization	$ 633	643
Gain on sale of oil and gas properties		$ (10,408)
Accretion expense	$ 83
Changes in assets and liabilities:
Decrease in production receivable	59	$ 601
Decrease in other current assets	21	48
Decrease in due to operators	(98)	(340)
Increase (decrease) in accrued expenses	18	(8)
Net cash (used in) provided by operating activities	$ (43)	1,265
Cash flows from investing activities
Proceeds from sale of oil and gas properties		10,990
Capital expenditures for oil and gas properties	$ (1,355)	(1,883)
Investments in salvage fund	(3)	(4)
Net cash (used in) provided by investing activities	(1,358)	$ 9,103
Cash flows from financing activities
Long-term borrowings	1,100
Distributions	(89)	$ (9,497)
Net cash provided by (used in) financing activities	1,011	(9,497)
Net (decrease) increase in cash and cash equivalents	(390)	871
Cash and cash equivalents, beginning of period	5,045	4,690
Cash and cash equivalents, end of period	$ 4,655	5,561
Supplemental schedule of non-cash investing activities
Advances used for capital expenditures in oil and gas properties reclassified to proved properties		$ 68

XML

Commitments and Contingencies

6 Months Ended

Jun. 30, 2015

Commitments and Contingencies [Abstract]

Commitments and Contingencies

5.  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.  Currently, the Fund has one non-producing property, the Beta Project, for which additional development costs must be incurred in order to commence production. The Fund currently anticipates such development will include a four-well development with related platform and pipeline infrastructure.

As of June 30, 2015, the Fund's estimated capital commitments related to its oil and gas properties were $10.1 million (which include asset retirement obligations for the Fund's projects of $2.7 million and projected interest costs of $0.4 million for the Beta Project), of which $5.6 million is expected to be spent during the next twelve months. These expected capital commitments exceed available working capital and salvage fund by $4.6 million at June 30, 2015.  The Fund has entered into a credit agreement to provide capital for the Beta Project.  See Note 4. “Credit Agreement – Beta Project Financing” for additional information.

Based upon its current cash position and its current reserve estimates, 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.

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.  At June 30, 2015 and December 31, 2014, there were no known environmental contingencies that required the Fund to record a liability.
   

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.