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, 2019

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. 000-51924

Ridgewood Energy O Fund, LLC

(Exact name of registrant as specified in its charter)

Delaware (State or other jurisdiction of incorporation or organization) 76-0774429 (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)

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

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

Yes x No o

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

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

Large accelerated filer	o	Accelerated filer	o
Non-accelerated filer	x	Smaller reporting company	x
		Emerging growth company	o

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

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

As of August 6, 2019, there were 870.6486 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, 2019 and December 31, 2018	1
		Unaudited Condensed Statements of Operations for the three and six months ended June 30, 2019 and 2018	2
		Unaudited Condensed Statements of Changes in Members’ Capital for the six months ended June 30, 2019 and 2018	3
		Unaudited Condensed Statements of Cash Flows for the six months ended June 30, 2019 and 2018	4
		Notes to Unaudited Condensed Financial Statements	5
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		10
Item 3.	Quantitative and Qualitative Disclosures About Market Risk		16
Item 4.	Controls and Procedures		16
PART II - OTHER INFORMATION
Item 1.	Legal Proceedings		17
Item 1A.	Risk Factors		17
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		17
Item 3.	Defaults Upon Senior Securities		17
Item 4.	Mine Safety Disclosures		17
Item 5.	Other Information		17
Item 6.	Exhibits		17
	SIGNATURES		18

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

RIDGEWOOD ENERGY O FUND, LLC

UNAUDITED CONDENSED BALANCE SHEETS

(in thousands, except share data)

	June 30, 2019			December 31, 2018
Assets
Current assets:
Cash and cash equivalents	$	3,231		$	4,611
Salvage fund		137			19
Production receivable		1,347			1,081
Due from affiliate (Note 2)		28			90
Other current assets		-			271
Total current assets		4,743			6,072
Salvage fund		3,142			3,122
Investment in Delta House		119			119
Oil and gas properties:
Advances to operators for working interests and expenditures		26			-
Proved properties		51,218			51,117
Less:  accumulated depletion and amortization		(29,824	)		(27,668	)
Total oil and gas properties, net		21,420			23,449
Total assets	$	29,424		$	32,762
Liabilities and Members' Capital
Current liabilities:
Due to operators	$	646		$	1,580
Accrued expenses		54			50
Current portion of long-term borrowings		1,451			1,746
Asset retirement obligations		137			19
Total current liabilities		2,288			3,395
Long-term borrowings		3,029			3,475
Asset retirement obligations		2,190			2,303
Total liabilities		7,507			9,173
Commitments and contingencies (Note 4)
Members' capital:
Manager:
Distributions		(6,231	)		(5,778	)
Retained earnings		8,103			7,567
Manager's total		1,872			1,789
Shareholders:
Capital contributions (935 shares authorized;
870.6486 issued and outstanding)		128,990			128,990
Syndication costs		(14,742	)		(14,742	)
Distributions		(37,479	)		(34,914	)
Accumulated deficit		(56,724	)		(57,534	)
Shareholders' total		20,045			21,800
Total members' capital		21,917			23,589
Total liabilities and members' capital	$	29,424		$	32,762

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

 1

RIDGEWOOD ENERGY O FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF OPERATIONS

(in thousands, except per share data)

	Three months ended June 30,						Six months ended June 30,
	2019			2018			2019			2018
Revenue
Oil and gas revenue	$	3,202		$	4,192		$	5,965		$	9,009
Other revenue		111			-			220			-
Total revenue		3,313			4,192			6,185			9,009
Expenses
Depletion and amortization		1,114			2,653			2,156			5,241
Operating expenses		852			727			1,783			1,372
Management fees to affiliate (Note 2)		283			283			565			566
General and administrative expenses		94			48			146			98
Total expenses		2,343			3,711			4,650			7,277
Income from operations		970			481			1,535			1,732
Other income (loss)
Dividend income		9			3			18			6
Interest expense, net		(98	)		(526	)		(207	)		(1,046	)
Total other loss		(89	)		(523	)		(189	)		(1,040	)
Net income (loss)	$	881		$	(42	)	$	1,346		$	692
Manager Interest
Net income	$	303		$	441		$	536		$	990
Shareholder Interest
Net income (loss)	$	578		$	(483	)	$	810		$	(298	)
Net income (loss) per share	$	663		$	(555	)	$	929		$	(343	)

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

 2

RIDGEWOOD ENERGY O FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF CHANGES

IN MEMBERS’ CAPITAL

(in thousands, except share data)

	Six months ended June 30, 2019
	# of Shares		Manager			Shareholders			Total
Balances, December 31, 2018		870.6486	$	1,789		$	21,800		$	23,589
Distributions		-		(274	)		(1,552	)		(1,826	)
Net income		-		233			232			465
Balances, March 31, 2019		870.6486		1,748			20,480			22,228
Distributions		-		(179	)		(1,013	)		(1,192	)
Net income		-		303			578			881
Balances, June 30, 2019		870.6486	$	1,872		$	20,045		$	21,917
		Six months ended June 30, 2018
	# of Shares		Manager			Shareholders			Total
Balances, December 31, 2017		870.6486	$	112		$	15,001		$	15,113
Net income		-		549			185			734
Balances, March 31, 2018		870.6486		661			15,186			15,847
Net income (loss)		-		441			(483	)		(42	)
Balances, June 30, 2018		870.6486	$	1,102		$	14,703		$	15,805

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

 3

RIDGEWOOD ENERGY O FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF CASH FLOWS

(in thousands)

	Six months ended June 30,
	2019			2018
Cash flows from operating activities
Net income	$	1,346		$	692
Adjustments to reconcile net income to net cash
provided by operating activities:
Depletion and amortization		2,156			5,241
Accretion expense		27			31
Amortization of debt discounts		3			-
Changes in assets and liabilities:
(Increase) decrease in production receivable		(266	)		279
Decrease in due from affiliate		62			-
Decrease in other current assets		271			119
Decrease in due to operators		(87	)		(112	)
Increase (decrease) in accrued expenses		4			(1,736	)
Settlement of asset retirement obligations		(22	)		(55	)
Net cash provided by operating activities		3,494			4,459
Cash flows from investing activities
Payments to operators for working interests and expenditures		(26	)		-
Capital expenditures for oil and gas properties		(948	)		(2,784	)
Increase in salvage fund		(138	)		(203	)
Net cash used in investing activities		(1,112	)		(2,987	)
Cash flows from financing activities
Repayments of long-term borrowings		(744	)		-
Distributions		(3,018	)		-
Net cash used in financing activities		(3,762	)		-
Net (decrease) increase in cash and cash equivalents		(1,380	)		1,472
Cash and cash equivalents, beginning of period		4,611			3,457
Cash and cash equivalents, end of period	$	3,231		$	4,929
Supplemental disclosure of cash flow information
Cash paid for interest	$	218		$	2,773
Supplemental disclosure of non-cash investing activities
Due to operators for accrued capital expenditures for oil and gas properties	$	97		$	1,721

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

 4

RIDGEWOOD ENERGY O FUND, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

1. Organization and Summary of Significant Accounting Policies

Organization

The Ridgewood Energy O Fund, LLC (the “Fund”), a Delaware limited liability company, was formed on December 21, 2004 and operates pursuant to a limited liability company agreement (the “LLC Agreement”) dated as of February 16, 2005 by and among Ridgewood Energy Corporation (the “Manager”) and the shareholders of the Fund, which addresses matters such as the authority and voting rights of the Manager and shareholders, capitalization, transferability of membership interests, participation in costs and revenues, distribution of assets and dissolution and winding up. The Fund was organized to primarily acquire interests in oil and gas properties located in the United States offshore waters of Texas, Louisiana and Alabama in the Gulf of Mexico.

The Manager has direct and exclusive control over the management of the Fund’s operations. The Manager performs, or arranges for the performance of, the management, advisory and administrative services required for the Fund’s operations. Such services include, without limitation, the administration of shareholder accounts, shareholder relations, the preparation, review and dissemination of tax and other financial information and the management of the Fund’s investments in projects. In addition, the Manager provides office space, equipment and facilities and other services necessary for the Fund’s operations. The Manager also engages and manages contractual relations with unaffiliated custodians, depositories, accountants, attorneys, corporate fiduciaries, insurers, banks and others as required. See Notes 2, 3 and 4.

Basis of Presentation

These unaudited interim condensed financial statements have been prepared by the Fund’s management in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and in the opinion of management, contain all adjustments (consisting of only normal recurring adjustments) necessary to present fairly the Fund’s financial position, results of operations, changes in members’ capital and cash flows for the periods presented. Certain information and note disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted in these unaudited interim condensed financial statements. The financial position, results of operations, changes in members’ capital and cash flows for the periods presented herein are not necessarily indicative of future financial results. These unaudited interim condensed financial statements should be read in conjunction with the Fund’s December 31, 2018 financial statements and notes thereto included in the Fund’s Annual Report on Form 10-K (“2018 Annual Report”) filed with the Securities and Exchange Commission (“SEC”). The year-end condensed balance sheet data was derived from audited financial statements for the year ended December 31, 2018, but does not include all annual disclosures required by GAAP.

Use of Estimates

The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenue and expense during the reporting period. On an ongoing basis, the Manager reviews its estimates, including those related to the fair value of financial instruments, depletion and amortization, determination of proved reserves, impairment of long-lived assets and asset retirement obligations. Actual results may differ from those estimates.

Summary of Significant Accounting Policies

The Fund has provided discussion of significant accounting policies in Note 1 of “Notes to Financial Statements” – “Organization and Summary of Significant Accounting Policies” contained in Item 8. “Financial Statements and Supplementary Data” within its 2018 Annual Report. There have been no significant changes to the Fund’s significant accounting policies during the three and six months ended June 30, 2019.

Fair Value Measurements

The Fund follows the accounting guidance for fair value measurement for measuring fair value of assets and liabilities in its financial statements. The Fund’s financial instruments consist of cash and cash equivalents, salvage fund, production receivable, due from affiliate, other current assets, investment in Delta House, due to operators, accrued expenses and long-term debt. Except for investment in Delta House and long-term debt, the carrying amounts of these instruments approximate fair value due to their short-term nature.

The Fund’s investment in Delta House is valued using the measurement alternative for investment in other entities (see Investment in Delta House below for additional information). The Fund’s long-term debt is valued using an income approach and classified as Level 3 in the fair value hierarchy. The fair value of long-term debt is estimated by discounting future cash payments of principal and interest to a present value amount using a market yield for debt instruments with similar terms, maturities and credit ratings. The Fund also applies the provisions of the fair value measurement accounting guidance to its non-financial assets and liabilities, such as oil and gas properties and asset retirement obligations, on a non-recurring basis.

 5

Investment in Delta House

The Fund has investments in Delta House Oil and Gas Lateral, LLC and Delta House FPS, LLC (collectively “Delta House”), legal entities that own interests in a deepwater floating production system operated by LLOG Exploration Offshore, L.L.C. The investment in Delta House is valued using the measurement alternative to record the investment at cost, less impairment and plus or minus subsequent adjustments for observable price changes with change in basis reported in current earnings. At each reporting period, the Fund reviews its investment in Delta House to evaluate whether the investment is impaired. Losses on investments, including impairments, are classified as non-operating losses in the Fund’s statements of operations. During each of the three and six months ended June 30, 2019 and 2018, there were no impairments of the Fund’s investment in Delta House.

Asset Retirement Obligations

For oil and gas properties, there are obligations to perform removal and remediation activities when the properties are retired. Upon the determination that a property is either proved or dry, a retirement obligation is incurred. The Fund recognizes the fair value of a liability for an asset retirement obligation in the period incurred based on expected future cash outflows required to satisfy the obligation discounted at the Fund’s credit-adjusted risk-free rate. Plug and abandonment costs associated with unsuccessful projects are expensed as dry-hole costs. Annually, or more frequently if an event occurs that would dictate a change in assumptions or estimates underlying the obligations, the Fund reassesses its asset retirement obligations to determine whether any revisions to the obligations are necessary. The Fund maintains a salvage fund to provide for the funding of future asset retirement obligations.

Revenue Recognition

Oil and gas revenues are recognized at the point when control of oil and natural gas is transferred to the customers. Natural gas liquid sales are included within gas sales. The Fund’s oil and natural gas generally are sold to its customers at prevailing market prices based on an index in which the prices are published, adjusted for pricing differentials, quality of oil and pipeline allowances. Under the Fund’s oil and natural gas contracts, each unit of oil and natural gas represents a separate performance obligation; therefore, future volumes are wholly unsatisfied and the transaction price related to the remaining performance obligations is the variable index-based price attributable to each unit of oil and natural gas that is transferred to the customer. The Fund invoices customers once its performance obligations have been satisfied, at which point the payment is unconditional. Accordingly, the Fund’s oil and natural gas contracts do not give rise to contract assets or liabilities. The receivables related to the Fund’s oil and gas revenue are included within “Production receivable” on the Fund’s balance sheets.

Other revenue is generated from the Fund’s production handling, gathering and operating services agreement with an affiliated entity and other third parties. The Fund simply earns a fee for its services and recognizes these fees as revenue at the time its performance obligations are satisfied as the control of oil and natural gas is never transferred to the Fund, thus there are no unsatisfied performance obligations. The Fund’s project operator performs joint interest billing once the performance obligations have been satisfied, at which point the payment is unconditional. Accordingly, the Fund’s production handling, gathering and operating services agreement with an affiliated entity and other third parties does not give rise to contract assets or liabilities. The receivables related to the Fund’s proportionate share of revenue from an affiliate are included within “Due from affiliate” on the Fund’s balance sheets. The receivables related to the Fund’s proportionate share of revenue from third parties are presented as a reduction from “Due to operator” on the Fund’s balance sheets. The receivables are settled by issuance of a non-cash credit from the Beta Project operator to the Fund when the operator performs the joint interest billing of the lease operating expenses due from the Fund.

The Fund also has an estimation process for revenue and related accruals, and any identified difference between its revenue estimates and actual revenue has not been significant. During each of the three and six months ended June 30, 2019 and 2018, revenue recognized from performance obligations satisfied in previous periods was not significant.

Impairment of Long-Lived Assets

The Fund reviews the carrying value of its oil and gas properties for impairment whenever events and circumstances indicate that the recorded carrying value of the assets may not be recoverable. Impairments are determined by comparing estimated future net undiscounted cash flows to the carrying value of the assets at the time of the review. If the carrying value exceeds the estimated future net undiscounted cash flows, the carrying value of the asset is written down to fair value, which is determined using valuation techniques that include both market and income approaches and use Level 3 inputs. The fair value determinations require considerable judgment and are sensitive to change. Different pricing assumptions, reserve estimates or discount rates could result in a different calculated impairment.

There were no impairments of oil and gas properties during each of the three and six months ended June 30, 2019 and 2018. Fluctuations in oil and natural gas commodity prices may impact the fair value of the Fund’s oil and gas properties. If oil and natural gas commodity prices decline, even if only for a short period of time, it is possible that impairments of oil and gas properties will occur. 

 6

Recent Accounting Pronouncements

In August 2018, the Financial Accounting Standards Board (“FASB”) issued accounting guidance on fair value measurement, which adds, among other things, disclosure requirements for the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. This accounting guidance is effective for the Fund in the first quarter 2020 with early adoption permitted. The Fund does not expect this accounting guidance will have a material impact on its financial statements upon adoption.

In February 2016, the FASB issued accounting guidance on leases as amended on January 2018 and July 2018, which requires an entity to recognize all lease assets and liabilities with a term greater than one year on the balance sheet, disclose key quantitative and qualitative information about leasing arrangements, and permits an entity not to evaluate existing or expired land easements that were not previously assessed under the existing lease guidance. The accounting guidance does not apply to leases of mineral rights to explore for or use of oil and natural gas. The accounting guidance was effective for the Fund beginning January 1, 2019. Although the Fund, as a non-operator, does not enter into lease agreements to support its operations, the Fund completed its evaluation of existing contracts that may have a lease impact and embedded lease features to determine the contracts to which the new guidance applies. Based on this evaluation, the Fund determined its existing contracts did not meet the definition of leases under the new accounting guidance and therefore, did not qualify for lease accounting.

2. Related Parties

Pursuant to the terms of the LLC Agreement, the Manager is entitled to receive an annual management fee, payable monthly, of 2.5% of total capital contributions, net of cumulative dry-hole and related well costs incurred by the Fund, however, the Manager is permitted to waive the management fee at its own discretion. Therefore, the management fee may be temporarily waived to accommodate the Fund’s short-term commitments. Management fees during each of the three and six months ended June 30, 2019 and 2018 were $0.3 million and $0.6 million, respectively.

The Manager is also entitled to receive 15% of the cash distributions from operations made by the Fund. Distributions paid to the Manager during the three and six months ended June 30, 2019 were $0.2 million and $0.5 million, respectively. The Fund did not pay distributions during the three and six months ended June 30, 2018.

The Fund utilizes Beta Sales and Transport, LLC and DH Sales and Transport, LLC, wholly-owned subsidiaries of the Manager, to facilitate the transportation and sale of oil and natural gas produced from the Beta, Diller and Marmalard projects.

During 2016, the Fund and other third-party working interest owners in the Beta Project entered into a production handling, gathering and operating services agreement (“PHA”) with Ridgewood Claiborne, LLC, a wholly-owned entity of Ridgewood Energy Oil & Gas Fund II, L.P. (“Institutional Fund II”), and other third-party working interest owners in the Claiborne Project. Institutional Fund II is an entity that is managed by the Fund’s Manager. During the three and six months ended June 30, 2019, the Fund earned $28 thousand and $0.1 million, respectively, representing its proportionate share of the production handling fees earned from Institutional Fund II, which is included within “Other revenue” on the Fund’s statements of operations. There were no such amounts recorded during the three and six months ended June 30, 2018. As of June 30, 2019 and December 31, 2018, the Fund’s receivables of $28 thousand and $0.1 million, respectively, related to the Fund’s proportionate share of revenue from Institutional Fund II are included within “Due from affiliate” on the Fund’s balance sheets. The receivables are settled by issuance of a non-cash credit from the Beta Project operator to the Fund on behalf of the Claiborne Project working interest owners when the operator performs the joint interest billing of the lease operating expenses due from the Fund. The revenue received from the PHA will be utilized by the Fund to repay a portion of the long-term debt outstanding under its credit agreement until the loan is repaid in full, in no event later than December 31, 2022.

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

The Fund has working interest ownership in certain oil and natural gas projects, which are also owned by other entities that are likewise managed by the Manager.

3. Credit Agreement – Beta Project Financing

As of June 30, 2019 and December 31, 2018, the Fund had outstanding borrowings of $4.5 million and $5.2 million, respectively, under its credit agreement dated November 27, 2012, as amended on September 30, 2016, September 15, 2017, June 1, 2018 and August 10, 2018 (the “Credit Agreement”). As of June 30, 2019, the estimated fair value of the debt was $4.4 million.

 7

The Credit Agreement bears interest at 8.75% compounded monthly. Principal and interest payments are based on the fixed percentage of the Fund’s Net Revenue, as defined in the Credit Agreement. Beginning on April 1, 2019 and each April 1^st thereafter, the Fund’s fixed percentage is the greater of (i) 30% or (ii) the Fixed Reassessment Percentage, as defined in the Credit Agreement. The Fixed Reassessment Percentage is determined annually beginning April 1, 2019 and each April 1^st thereafter, and is based on the Fund’s ratio of its outstanding debt as of the reassessment date relative to 80% of third-party reserve engineer’s proved plus probable future undiscounted cash flows attributable to the Beta Project through the maturity of the loan. As of April 1, 2019, the Fund’s fixed percentage was determined to be 30%. The loan may be prepaid by the Fund without premium or penalty. Pursuant to the Credit Agreement, the Fund also agreed to convey a fixed percentage of 12.56% overriding royalty interest in its working interest in the Beta Project to the lenders, which will become payable to the lenders on January 1, 2023.

As of June 30, 2019 and December 31, 2018, the unamortized debt discounts related to the Credit Agreement of $20 thousand and $22 thousand, respectively, were presented as a reduction of “Long-term borrowings” on the Fund’s balance sheets. Amortization expense during the three and six months ended June 30, 2019 of $1 thousand and $3 thousand, respectively, was included on the Fund’s statements of operations within “Interest expense, net”. There were no such amounts recorded during the three and six months ended June 30, 2018. As of June 30, 2019 and December 31, 2018, there were no accrued interest costs outstanding. Interest costs incurred during the three and six months ended June 30, 2019 of $0.1 million and $0.2 million, respectively, were included on the Fund’s statements of operations within “Interest expense, net”. Interest costs incurred during the three and six months ended June 30, 2018 of $0.5 million and $1.1 million, respectively, were included on the Fund’s statements of operations within “Interest expense, net”.

The Credit Agreement contains customary covenants, with which the Fund was in compliance as of June 30, 2019 and December 31, 2018.

4. Commitments and Contingencies

Capital Commitments

As of June 30, 2019, the Fund’s estimated capital commitments related to its oil and gas properties were $8.0 million (which include asset retirement obligations for the Fund’s projects of $3.8 million), of which $1.9 million is expected to be spent during the next twelve months. Future results of operations and cash flows are dependent on the continued successful development and the related production of oil and gas revenues from the Fund’s producing projects.

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

Environmental and Governmental Regulations

Many aspects of the oil and gas industry are subject to federal, state and local environmental laws and regulations. The Manager and operators of the Fund’s properties are continually taking action they believe appropriate to satisfy applicable federal, state and local environmental regulations. However, due to the significant public and governmental interest in environmental matters related to those activities, the Manager cannot predict the effects of possible future legislation, rule changes, or governmental or private claims. As of June 30, 2019 and December 31, 2018, there were no known environmental contingencies that required adjustment to, or disclosure in, the Fund’s financial statements.

Oil and gas industry legislation and administrative regulations are periodically changed for a variety of political, economic, and other reasons. Any such future laws and regulations could result in increased compliance costs or additional operating restrictions, which could have a material adverse effect on the Fund’s operating results and cash flows. It is not possible at this time to predict whether such legislation or regulation, if proposed, will be adopted as initially written, if at all, or how legislation or new regulation that may be adopted would impact the Fund’s business.

 8

BOEM Notice to Lessees on Supplemental Bonding

On July 14, 2016, the Bureau of Ocean Energy Management (“BOEM”) issued a Notice to Lessees (“NTL”) that discontinued and materially replaced existing policies and procedures regarding financial security (i.e. supplemental bonding) for decommissioning obligations of lessees of federal oil and gas leases and owners of pipeline rights-of-way, rights-of use and easements on the Outer Continental Shelf (“Lessees”).  Generally, the NTL (i) ended the practice of excusing Lessees from providing such additional security where co-lessees had sufficient financial strength to meet such decommissioning obligations, (ii) established new criteria for determining financial strength and additional security requirements of such Lessees, (iii) provided acceptable forms of such additional security and (iv) replaced the waiver system with one of self-insurance. The rule became effective as of September 12, 2016; however on January 6, 2017, the BOEM announced that it was suspending the implementation timeline for six months in certain circumstances. On June 22, 2017, the BOEM announced that the implementation timeline extension will remain in effect pending the completion of its review of the NTL. As of June 30, 2019, the BOEM has not completed its review nor has the NTL been enforced.  The impact of the NTL, if enforced without change or amendment, may require the Fund to fully secure all of its potential abandonment liabilities to the BOEM’s satisfaction using one or more of the enumerated methods for doing so.  Potentially this could increase costs to the Fund if the Fund is required to obtain additional supplemental bonding, fund escrow accounts or obtain letters of credit.

Insurance Coverage

The Fund is subject to all risks inherent in the oil and natural gas business. Insurance coverage as is customary for entities engaged in similar operations is maintained, but losses may occur from uninsurable risks or amounts in excess of existing insurance coverage. The occurrence of an event that is not insured or not fully insured could have a material adverse impact upon earnings and financial position. Moreover, insurance is obtained as a package covering all of the entities managed by the Manager. Depending on the extent, nature and payment of claims made by the Fund or other entities managed by the Manager, yearly insurance coverage may be exhausted and become insufficient to cover a claim by the Fund in a given year.

5. Subsequent Event

The Fund as well as other funds managed by the Manager that invested in the Beta Project elected not to participate in the drilling of the 8th well proposed by Walter Oil and Gas Corporation.  As a result, the Fund is due reimbursement for a portion of the cost relating to the slot on the Beta Project platform that was utilized by the other third-party working interest partners for the 8th well.  On July 17, 2019, the Fund as well as the other funds managed by the Manager and the other third-party working interest owners in the Beta Project agreed to a reimbursement to the Fund of $0.8 million, which will be recorded as a reduction to oil and gas properties in the third quarter 2019.  The amount received will be utilized by the Fund to repay a portion of the long-term debt outstanding under the Credit Agreement. 

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

Critical Accounting Policies and Estimates

There were no changes to the Fund’s critical accounting policies and estimates from those disclosed in its Annual Report on Form 10-K for the year ended December 31, 2018.

Overview of the Fund’s Business

The Fund was organized primarily to acquire interests in oil and natural gas properties located in the United States offshore waters of Texas, Louisiana and Alabama in the Gulf of Mexico. The Fund’s primary investment objective is to generate cash flow for distribution to its shareholders by generating returns across a portfolio of oil and natural gas projects. Distributions to shareholders are made in accordance with the Fund’s limited liability company agreement (the “LLC Agreement”).

Ridgewood Energy Corporation (the “Manager”) is the Manager, and as such, has direct and exclusive control over the management of the Fund’s operations. The Manager performs, or arranges for the performance of, the management, advisory and administrative services required for the Fund’s operations. As compensation for its services, the Manager is entitled to an annual management fee, payable monthly, equal to 2.5% of the total capital contributions made by the Fund’s shareholders, net of cumulative dry-hole and related well costs incurred by the Fund. The Fund does not currently, nor is there any plan to, operate any project in which the Fund participates. The Manager enters into operating agreements with third-party operators for the management of all exploration, development and producing operations, as appropriate. The Manager also participates in distributions.

Subsequent Event

The Fund as well as other funds managed by the Manager that invested in the Beta Project elected not to participate in the drilling of the 8th well proposed by Walter Oil and Gas Corporation.  As a result, the Fund is due reimbursement for a portion of the cost relating to the slot on the Beta Project platform that was utilized by the other third-party working interest partners for the 8th well.  On July 17, 2019, the Fund as well as the other funds managed by the Manager and the other third-party working interest owners in the Beta Project agreed to a reimbursement to the Fund of $0.8 million, which will be recorded as a reduction to oil and gas properties in the third quarter 2019.  The amount received will be utilized by the Fund to repay a portion of the long-term debt outstanding under the credit agreement.

Commodity Price Changes

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

 10

Oil and natural gas commodity prices have been subject to significant fluctuations during the past several years. The Fund anticipates price cyclicality in its planning and believes it is well positioned to withstand price volatility. The Fund will continue to closely manage and coordinate its capital spending estimates within its expected cash flows to provide for future development costs of its producing projects, as budgeted. See “Results of Operations” under this Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Quarterly Report for more information on the average oil and natural gas prices received by the Fund during the three and six months ended June 30, 2019 and 2018 and the effect of such average prices on the Fund’s results of operations. If oil and natural gas commodity prices decline, even if only for a short period of time, the Fund’s results of operations and liquidity will be adversely impacted.

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

· weather conditions;

· economic conditions, including demand for petroleum-based products;

· actions by OPEC, the Organization of Petroleum Exporting Countries;

· political instability in the Middle East and other major oil and gas producing regions;

· governmental regulations, both domestic and foreign;

· domestic and foreign tax policy;

· the pace adopted by foreign governments for the exploration, development, and production of their national reserves;

· the supply and price of foreign oil and gas;

· the cost of exploring for, producing and delivering oil and gas;

· the discovery rate of new oil and gas reserves;

· the rate of decline of existing and new oil and gas reserves;

· available pipeline and other oil and gas transportation capacity;

· the ability of oil and gas companies to raise capital;

· the overall supply and demand for oil and gas; and

· the price and availability of alternate fuel sources.

Business Update 

Information regarding the Fund’s current projects, all of which are located in the United States offshore waters in the Gulf of Mexico, is provided in the following table. See “Liquidity Needs” under this Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Quarterly Report for information regarding the funding of the Fund’s capital commitments.

 11

			Total Spent		Total
	Working		through		Fund
Project	Interest		June 30, 2019		Budget		Status
			(in thousands)
Beta Project		2.93%	$	28,909	$	31,697	The Beta Project is expected to include the development of seven wells.  Wells #1 and #2 commenced production in 2016.  Wells #3  and #4 commenced production in 2017. Wells #5 and #6 commenced production in first quarter 2018 and third quarter 2018, respectively. Well #7 commenced production in first quarter 2019. The Fund expects to spend $1.5 million for additional development costs and $1.3 million for asset retirement obligations.
Diller Project		0.88%	$	3,110	$	4,465	The Diller Project is expected to include the development of three wells.  Well #1 commenced production in 2015.  Well #2, which completed drilling in third quarter 2018, is expected to commence production in first quarter 2020. Well #3 is expected to commence production in third quarter 2020. The Fund expects to spend $1.1 million for additional development costs and $0.3 million for asset retirement obligations.
Liberty Project		5.0%	$	5,578	$	6,239	The Liberty Project, a single-well project, commenced production in 2010.  The Fund expects to spend $0.7 million for asset retirement obligations.
Marmalard Project		0.88%	$	5,618	$	7,886	The Marmalard Project is expected to include the development of six wells.  Four wells commenced production in 2015.  Additional wells are expected to commence production in 2020 and 2021.  Two wells, which were shut-in during early-December 2017 due to replacement of well jumpers, resumed production in third quarter 2018.  One well, which had been shut-in since late-February 2019 due to remediation work for downhole mechanical issues, resumed production in third quarter 2019. The Fund expects to spend $1.8 million for additional development costs and $0.5 million for asset retirement obligations.
South Pelto 9		16.67%	$	5,026	$	5,233	South Pelto 9, a single-well project, commenced production in 2007 and is producing at nominal rates. The Fund expects to spend $0.2 million for asset retirement obligations.

 12

Results of Operations

The following table summarizes the Fund’s results of operations during the three and six months ended June 30, 2019 and 2018, and should be read in conjunction with the Fund’s financial statements and notes thereto included within Item 1. “Financial Statements” in Part I of this Quarterly Report.

	Three months ended June 30,						Six months ended June 30,
	2019			2018			2019			2018
	(in thousands)
Revenue
Oil and gas revenue	$	3,202		$	4,192		$	5,965		$	9,009
Other revenue		111			-			220			-
Total revenue		3,313			4,192			6,185			9,009
Expenses
Depletion and amortization		1,114			2,653			2,156			5,241
Operating expenses		852			727			1,783			1,372
Management fees to affiliate		283			283			565			566
General and administrative expenses		94			48			146			98
Total expenses		2,343			3,711			4,650			7,277
Income from operations		970			481			1,535			1,732
Other income (loss)
Dividend income		9			3			18			6
Interest expense, net		(98	)		(526	)		(207	)		(1,046	)
Total other loss		(89	)		(523	)		(189	)		(1,040	)
Net income (loss)	$	881		$	(42	)	$	1,346		$	692

Overview. The following table provides information related to the Fund’s oil and natural gas production and oil and gas revenue during the three and six months ended June 30, 2019 and 2018. Natural gas liquid sales are included within gas sales.

	Three months ended June 30,				Six months ended June 30,
	2019		2018		2019		2018
Number of wells producing		13		11		14		12
Total number of production days		1,162		728		2,203		1,572
Oil sales (in thousands of barrels)		47		62		90		133
Average oil price per barrel	$	64	$	65	$	61	$	63
Gas sales (in thousands of mcfs)		95		104		181		240
Average gas price per mcf	$	2.66	$	3.57	$	2.87	$	3.47

The increases in the number of wells producing and production days were primarily related to the commencement of production of two wells in the Beta Project, one well during third quarter 2018 and one well during first quarter 2019. The decreases in oil and gas sales volumes were primarily related to the partial sale of working interest in the Beta Project during third quarter 2018 coupled with periodic shut-ins during 2019 due to certain drilling and completion operations performed at the project’s production facility. See additional discussion in “Business Update” section above.

Oil and Gas Revenue. Oil and gas revenue during the three months ended June 30, 2019 was $3.2 million, a decrease of $1.0 million from the three months ended June 30, 2018. The decrease was attributable to decreased sales volume totaling $1.0 million coupled with decreased oil and gas prices totaling $0.1 million.

Oil and gas revenue during the six months ended June 30, 2019 was $6.0 million, a decrease of $3.0 million from the six months ended June 30, 2018. The decrease was attributable to decreased sales volume totaling $2.9 million coupled with decreased oil and gas prices totaling $0.2 million.

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

Other Revenue. Other revenue is generated from the Fund’s production handling, gathering and operating services agreement with an affiliated entity and other third parties. There were no such amounts recorded during the three and six months ended June 30, 2018.

 13

Depletion and Amortization. Depletion and amortization during the three months ended June 30, 2019 was $1.1 million, a decrease of $1.5 million from the three months ended June 30, 2018. The decrease was attributable to a decrease in the average depletion rate totaling $1.0 million coupled with a decrease in production volumes totaling $0.6 million. 

Depletion and amortization during the six months ended June 30, 2019 was $2.2 million, a decrease of $3.1 million from the six months ended June 30, 2018. The decrease was attributable to a decrease in production volumes totaling $1.6 million coupled with a decrease in the average depletion rate totaling $1.5 million. 

The decreases in the average depletion rates were primarily attributable to lower cost of reserves from the Fund’s producing projects. Depletion and amortization was also impacted by the partial sale of working interest in the Beta Project during third quarter 2018. 

See “Overview” above for certain factors that impact the depletion and amortization volume and rate variances. Depletion and amortization rates may also be impacted by changes in reserve estimates provided annually by the Fund’s independent petroleum engineers.

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

	Three months ended June 30,				Six months ended June 30,
	2019		2018		2019		2018
	(in thousands)
Lease operating expense	$	398	$	485	$	795	$	937
Workover expense		265		47		585		47
Transportation and processing expense		121		90		254		186
Insurance expense		56		86		124		156
Accretion expense and other		12		19		25		46
	$	852	$	727	$	1,783	$	1,372

Lease operating expense and transportation and processing expense relate to the Fund’s producing projects. Workover expense represents costs to restore or stimulate production of existing reserves. During the three and six months ended June 30, 2019, workover expense primarily related to remediation work for mechanical issues in the Marmalard Project. Insurance expense represents premiums related to the Fund’s projects, which vary depending upon the number of wells producing or drilling. Accretion expense relates to the asset retirement obligations established for the Fund’s oil and gas properties.

Production costs, which include lease operating expense, transportation and processing expense and insurance expense, were $0.6 million ($9.19 per barrel of oil equivalent or “BOE”) and $1.2 million ($9.76 per BOE) during the three and six months ended June 30, 2019, respectively, compared to $0.7 million ($8.37 per BOE) and $1.3 million ($7.37 per BOE) during the three and six months ended June 30, 2018, respectively. Production costs remained relatively consistent during the three and six months ended June 30, 2019 compared to the three and six months ended June 30, 2018. The increase in production costs per BOE during the six months ended June 30, 2019 compared to the six months ended June 30, 2018 was primarily due to the impact of ongoing costs for the Beta Project, which experienced decreased production volumes due to periodic shut-ins during first half of 2019. In addition, production costs and costs per BOE were also impacted by certain fixed costs associated with the Diller and Marmalard projects, which were shut-in periodically during first half of 2019 due to mechanical issues. See “Overview” above for factors that impact oil and natural gas production.

Management Fees to Affiliate. An annual management fee, totaling 2.5% of total capital contributions, net of cumulative dry-hole and related well costs incurred by the Fund, is paid monthly to the Manager. Such fee may be temporarily waived by the Manager to accommodate the Fund’s short-term commitments.

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

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

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

 14

Capital Resources and Liquidity

Operating Cash Flows

Cash flows provided by operating activities during the six months ended June 30, 2019 were $3.5 million, primarily related to revenue received of $5.9 million, partially offset by operating expenses of $1.5 million, management fees of $0.6 million, interest payments of $0.2 million and general and administrative expenses of $0.1 million. 

Cash flows provided by operating activities during the six months ended June 30, 2018 were $4.5 million, primarily related to revenue received of $9.3 million, partially offset by interest payments of $2.8 million, operating expenses of $1.3 million, management fees of $0.6 million and the settlement of an asset retirement obligation of $0.1 million. 

Investing Cash Flows 

Cash flows used in investing activities during the six months ended June 30, 2019 were $1.1 million, related to capital expenditures for oil and gas properties of $1.0 million, inclusive of advances, and investments in salvage fund of $0.1 million. 

Cash flows used in investing activities during the six months ended June 30, 2018 were $3.0 million, related to capital expenditures for oil and gas properties of $2.8 million and investments in salvage fund of $0.2 million. 

Financing Cash Flows

Cash flows used in financing activities during the six months ended June 30, 2019 were $3.8 million, related to manager and shareholder distributions of $3.0 million and the repayments of long-term borrowings of $0.7 million.

There were no cash flows from financing activities during the six months ended June 30, 2018.

Estimated Capital Expenditures  

Capital expenditures for oil and gas properties have been funded with the capital raised by the Fund in its private placement offering and through debt financing. The Fund’s capital has been fully allocated to its projects. As a result, the Fund will not invest in any new projects and will limit its investment activities, if any, to those projects in which it currently has a working interest. See “Business Update” under this Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Quarterly Report for information regarding the Fund’s current projects. See “Liquidity Needs” below for additional information. 

Liquidity Needs

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

As of June 30, 2019, the Fund’s estimated capital commitments related to its oil and gas properties were $8.0 million (which include asset retirement obligations for the Fund’s projects of $3.8 million), of which $1.9 million is expected to be spent during the next twelve months. Future results of operations and cash flows are dependent on the continued successful development and the related production of oil and gas revenues from the Fund’s producing projects.

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

The Manager is entitled to receive an annual management fee from the Fund regardless of the Fund’s profitability in that year. However, pursuant to the terms of the LLC Agreement, the Manager is also permitted to waive the management fee at its own discretion.

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

 15

Credit Agreement

As of June 30, 2019 and December 31, 2018, the Fund had outstanding borrowings of $4.5 million and $5.2 million, respectively, under its credit agreement dated November 27, 2012, as amended on September 30, 2016, September 15, 2017, June 1, 2018 and August 10, 2018 (the “Credit Agreement”).

The Credit Agreement bears interest at 8.75% compounded monthly. Principal and interest payments are based on the fixed percentage of the Fund’s Net Revenue, as defined in the Credit Agreement. Beginning on April 1, 2019 and each April 1^st thereafter, the Fund’s fixed percentage is the greater of (i) 30% or (ii) the Fixed Reassessment Percentage, as defined in the Credit Agreement. The Fixed Reassessment Percentage is determined annually beginning April 1, 2019 and every April 1^st thereafter, and is based on the Fund’s ratio of its outstanding debt as of the reassessment date relative to 80% of third-party reserve engineer’s proved plus probable future undiscounted cash flows attributable to the Beta Project through the maturity of the loan. As of April 1, 2019, the Fund’s fixed percentage was determined to be 30%. The loan may be prepaid by the Fund without premium or penalty. The Credit Agreement also provides for a fixed percentage of 12.56% overriding royalty interest to the lenders, which will become payable to the lenders in January 2023.

The Credit Agreement contains customary negative covenants including covenants that limit the Fund’s ability to, among other things, grant liens, change the nature of its business, or merge into or consolidate with other persons. The events which constitute events of default are also customary for credit facilities of this nature and include payment defaults, breaches of representations, warranties and covenants, insolvency and change of control. Upon the occurrence of a default, in some cases following a notice and cure period, the lenders under the Credit Agreement may accelerate the maturity of the loan and require full and immediate repayment of all borrowings under the Credit Agreement. The Fund believes it is in compliance with all covenants under the Credit Agreement as of June 30, 2019 and December 31, 2018.

Off-Balance Sheet Arrangements

The Fund had no off-balance sheet arrangements as of June 30, 2019 and December 31, 2018 and does not anticipate the use of such arrangements in the future.

Contractual Obligations

The Fund enters into participation and joint operating agreements with operators. On behalf of the Fund, an operator enters into various contractual commitments pertaining to exploration, development and production activities. The Fund does not negotiate such contracts. No contractual obligations exist as of June 30, 2019 and December 31, 2018, other than those discussed in “Estimated Capital Expenditures” and “Liquidity Needs – Credit Agreement” above.

Recent Accounting Pronouncements

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

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, 2019.

There has been no change in the Fund’s internal control over financial reporting that occurred during the three months ended June 30, 2019 that has materially affected, or is reasonably likely to materially affect, the Fund’s internal control over financial reporting.

 16

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

 17

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 O FUND, LLC
Dated:	August 6, 2019	By:	/s/	ROBERT E. SWANSON
			Name:	Robert E. Swanson
			Title:	Chief Executive Officer
				(Principal Executive Officer)
Dated:	August 6, 2019	By:	/s/	KATHLEEN P. MCSHERRY
			Name:	Kathleen P. McSherry
			Title:	Executive Vice President and Chief Financial Officer
				(Principal Financial and Accounting Officer)

18

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 O Fund, LLC;

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

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

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

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

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

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

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

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

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

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

Dated:	August 6, 2019
/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 O Fund, LLC;

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

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

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

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

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

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

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

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

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

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

Dated:	August 6, 2019
/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 O Fund, LLC (the “Fund”) for the period ended June 30, 2019, as filed with the Securities and Exchange Commission on the date hereof, (the “Report”), each of the undersigned officers of the Fund hereby certifies, pursuant to 18 U.S.C. (section) 1350, as adopted pursuant to (section) 906 of the Sarbanes-Oxley Act of 2002, that to the best of their knowledge:

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

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

Dated:	August 6, 2019
		/s/	ROBERT E. SWANSON
		Name:	Robert E. Swanson
		Title:	Chief Executive Officer
			(Principal Executive Officer)
Dated:	August 6, 2019
		/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.

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Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2019	Aug. 06, 2019
Document And Entity Information Abstract
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2019
Entity Registrant Name	Ridgewood Energy O Fund LLC
Entity Central Index Key	0001315061
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q2
Entity Filer Category	Non-accelerated Filer
Entity Small Business	true
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		870.6486
Entity File Number	000-51924
Entity Interactive Data Current	Yes
Document Quarterly Report	true
Document Transition Report	false
Entity Current Reporting Status	Yes
Entity Incorporation, State or Country Code	DE

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UNAUDITED CONDENSED BALANCE SHEETS - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 3,231	$ 4,611
Salvage fund	137	19
Production receivable	1,347	1,081
Due from affiliate (Note 2)	28	90
Other current assets		271
Total current assets	4,743	6,072
Salvage fund	3,142	3,122
Investment in Delta House	119	119
Oil and gas properties:
Advances to operators for working interests and expenditures	26
Proved properties	51,218	51,117
Less: accumulated depletion and amortization	(29,824)	(27,668)
Total oil and gas properties, net	21,420	23,449
Total assets	29,424	32,762
Current liabilities:
Due to operators	646	1,580
Accrued expenses	54	50
Current portion of long-term borrowings	1,451	1,746
Asset retirement obligations	137	19
Total current liabilities	2,288	3,395
Long-term borrowings	3,029	3,475
Asset retirement obligations	2,190	2,303
Total liabilities	7,507	9,173
Commitments and contingencies (Note 4)
Members' capital:
Distributions	(6,231)	(5,778)
Retained earnings	8,103	7,567
Manager's total	1,872	1,789
Capital contributions (935 shares authorized; 870.6486 issued and outstanding)	128,990	128,990
Syndication costs	(14,742)	(14,742)
Distributions	(37,479)	(34,914)
Accumulated deficit	(56,724)	(57,534)
Shareholders' total	20,045	21,800
Total members' capital	21,917	23,589
Total liabilities and members' capital	$ 29,424	$ 32,762

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UNAUDITED CONDENSED BALANCE SHEETS (Parenthetical) - shares	Jun. 30, 2019	Dec. 31, 2018
Statement of Financial Position [Abstract]
Shares authorized	935	935
Shares issued	870.6486	870.6486
Shares outstanding	870.6486	870.6486

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UNAUDITED CONDENSED STATEMENTS OF OPERATIONS - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Revenue
Oil and gas revenue	$ 3,202	$ 4,192	$ 5,965	$ 9,009
Other revenue	111		220
Total revenue	3,313	4,192	6,185	9,009
Expenses
Depletion and amortization	1,114	2,653	2,156	5,241
Operating expenses	852	727	1,783	1,372
Management fees to affiliate	283	283	565	566
General and administrative expenses	94	48	146	98
Total expenses	2,343	3,711	4,650	7,277
Income from operations	970	481	1,535	1,732
Other income (loss)
Dividend income	9	3	18	6
Interest expense, net	(98)	(526)	(207)	(1,046)
Total other loss	(89)	(523)	(189)	(1,040)
Net income (loss)	881	(42)	1,346	692
Manager Interest
Net income	303	441	536	990
Shareholder Interest
Net income (loss)	$ 578	$ (483)	$ 810	$ (298)
Net income (loss) per share	$ 663	$ (555)	$ 929	$ (343)

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UNAUDITED CONDENSED STATEMENTS OF CHANGES IN PARTNERS CAPITAL - USD ($) $ in Thousands	# of Shares [Member]	Manager [Member]	Shareholders [Member]	Total
Balances at Dec. 31, 2017		$ 112	$ 15,001	$ 15,113
Balances, shares at Dec. 31, 2017	870.6486			870.6486
Net income (loss)		549	185	$ 734
Balances at Mar. 31, 2018		661	15,186	15,847
Balances, shares at Mar. 31, 2018	870.6486
Balances at Dec. 31, 2017		112	15,001	$ 15,113
Balances, shares at Dec. 31, 2017	870.6486			870.6486
Net income (loss)				$ 692
Balances at Jun. 30, 2018		1,102	14,703	15,805
Balances, shares at Jun. 30, 2018	870.6486
Balances at Mar. 31, 2018		661	15,186	15,847
Balances, shares at Mar. 31, 2018	870.6486
Net income (loss)		441	(483)	(42)
Balances at Jun. 30, 2018		1,102	14,703	15,805
Balances, shares at Jun. 30, 2018	870.6486
Balances at Dec. 31, 2018		1,789	21,800	$ 23,589
Balances, shares at Dec. 31, 2018	870.6486			870.6486
Distributions		(274)	(1,552)	$ (1,826)
Net income (loss)		233	232	465
Balances at Mar. 31, 2019		1,748	20,480	22,228
Balances, shares at Mar. 31, 2019	870.6486
Balances at Dec. 31, 2018		1,789	21,800	$ 23,589
Balances, shares at Dec. 31, 2018	870.6486			870.6486
Distributions		(500)
Net income (loss)				$ 1,346
Balances at Jun. 30, 2019		1,872	20,045	$ 21,917
Balances, shares at Jun. 30, 2019	870.6486			870.6486
Balances at Mar. 31, 2019		1,748	20,480	$ 22,228
Balances, shares at Mar. 31, 2019	870.6486
Distributions		(179)	(1,013)	(1,192)
Net income (loss)		303	578	881
Balances at Jun. 30, 2019		$ 1,872	$ 20,045	$ 21,917
Balances, shares at Jun. 30, 2019	870.6486			870.6486

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UNAUDITED CONDENSED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Cash flows from operating activities
Net income	$ 1,346	$ 692
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion and amortization	2,156	5,241
Accretion expense	27	31
Amortization of debt discounts	3
Changes in assets and liabilities:
(Increase) decrease in production receivable	(266)	279
Decrease in due from affiliate	62
Decrease in other current assets	271	119
Decrease in due to operators	(87)	(112)
Increase (decrease) in accrued expenses	4	(1,736)
Settlement of asset retirement obligations	(22)	(55)
Net cash provided by operating activities	3,494	4,459
Cash flows from investing activities
Payments to operators for working interests and expenditures	(26)
Capital expenditures for oil and gas properties	(948)	(2,784)
Increase in salvage fund	(138)	(203)
Net cash used in investing activities	(1,112)	(2,987)
Cash flows from financing activities
Repayments of long-term borrowings	(744)
Distributions	(3,018)
Net cash used in financing activities	(3,762)
Net (decrease) increase in cash and cash equivalents	(1,380)	1,472
Cash and cash equivalents, beginning of period	4,611	3,457
Cash and cash equivalents, end of period	3,231	4,929
Supplemental disclosure of cash flow information
Cash paid for interest	218	2,773
Supplemental disclosure of non-cash investing activities
Due to operators for accrued capital expenditures for oil and gas properties	$ 97	$ 1,721

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Organization and Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization and Summary of Significant Accounting Policies

1. Organization and Summary of Significant Accounting Policies

Organization

The Ridgewood Energy O Fund, LLC (the “Fund”), a Delaware limited liability company, was formed on December 21, 2004 and operates pursuant to a limited liability company agreement (the “LLC Agreement”) dated as of February 16, 2005 by and among Ridgewood Energy Corporation (the “Manager”) and the shareholders of the Fund, which addresses matters such as the authority and voting rights of the Manager and shareholders, capitalization, transferability of membership interests, participation in costs and revenues, distribution of assets and dissolution and winding up. The Fund was organized to primarily acquire interests in oil and gas properties located in the United States offshore waters of Texas, Louisiana and Alabama in the Gulf of Mexico.

The Manager has direct and exclusive control over the management of the Fund’s operations. The Manager performs, or arranges for the performance of, the management, advisory and administrative services required for the Fund’s operations. Such services include, without limitation, the administration of shareholder accounts, shareholder relations, the preparation, review and dissemination of tax and other financial information and the management of the Fund’s investments in projects. In addition, the Manager provides office space, equipment and facilities and other services necessary for the Fund’s operations. The Manager also engages and manages contractual relations with unaffiliated custodians, depositories, accountants, attorneys, corporate fiduciaries, insurers, banks and others as required. See Notes 2, 3 and 4.

Basis of Presentation

These unaudited interim condensed financial statements have been prepared by the Fund’s management in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and in the opinion of management, contain all adjustments (consisting of only normal recurring adjustments) necessary to present fairly the Fund’s financial position, results of operations, changes in members’ capital and cash flows for the periods presented. Certain information and note disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted in these unaudited interim condensed financial statements. The financial position, results of operations, changes in members’ capital and cash flows for the periods presented herein are not necessarily indicative of future financial results. These unaudited interim condensed financial statements should be read in conjunction with the Fund’s December 31, 2018 financial statements and notes thereto included in the Fund’s Annual Report on Form 10-K (“2018 Annual Report”) filed with the Securities and Exchange Commission (“SEC”). The year-end condensed balance sheet data was derived from audited financial statements for the year ended December 31, 2018, but does not include all annual disclosures required by GAAP.

Use of Estimates

The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenue and expense during the reporting period. On an ongoing basis, the Manager reviews its estimates, including those related to the fair value of financial instruments, depletion and amortization, determination of proved reserves, impairment of long-lived assets and asset retirement obligations. Actual results may differ from those estimates.

Summary of Significant Accounting Policies

The Fund has provided discussion of significant accounting policies in Note 1 of “Notes to Financial Statements” – “Organization and Summary of Significant Accounting Policies” contained in Item 8. “Financial Statements and Supplementary Data” within its 2018 Annual Report. There have been no significant changes to the Fund’s significant accounting policies during the three and six months ended June 30, 2019.

Fair Value Measurements

The Fund follows the accounting guidance for fair value measurement for measuring fair value of assets and liabilities in its financial statements. The Fund’s financial instruments consist of cash and cash equivalents, salvage fund, production receivable, due from affiliate, other current assets, investment in Delta House, due to operators, accrued expenses and long-term debt. Except for investment in Delta House and long-term debt, the carrying amounts of these instruments approximate fair value due to their short-term nature.

The Fund’s investment in Delta House is valued using the measurement alternative for investment in other entities (see Investment in Delta House below for additional information). The Fund’s long-term debt is valued using an income approach and classified as Level 3 in the fair value hierarchy. The fair value of long-term debt is estimated by discounting future cash payments of principal and interest to a present value amount using a market yield for debt instruments with similar terms, maturities and credit ratings. The Fund also applies the provisions of the fair value measurement accounting guidance to its non-financial assets and liabilities, such as oil and gas properties and asset retirement obligations, on a non-recurring basis.

Investment in Delta House

The Fund has investments in Delta House Oil and Gas Lateral, LLC and Delta House FPS, LLC (collectively “Delta House”), legal entities that own interests in a deepwater floating production system operated by LLOG Exploration Offshore, L.L.C. The investment in Delta House is valued using the measurement alternative to record the investment at cost, less impairment and plus or minus subsequent adjustments for observable price changes with change in basis reported in current earnings. At each reporting period, the Fund reviews its investment in Delta House to evaluate whether the investment is impaired. Losses on investments, including impairments, are classified as non-operating losses in the Fund’s statements of operations. During each of the three and six months ended June 30, 2019 and 2018, there were no impairments of the Fund’s investment in Delta House.

Asset Retirement Obligations

For oil and gas properties, there are obligations to perform removal and remediation activities when the properties are retired. Upon the determination that a property is either proved or dry, a retirement obligation is incurred. The Fund recognizes the fair value of a liability for an asset retirement obligation in the period incurred based on expected future cash outflows required to satisfy the obligation discounted at the Fund’s credit-adjusted risk-free rate. Plug and abandonment costs associated with unsuccessful projects are expensed as dry-hole costs. Annually, or more frequently if an event occurs that would dictate a change in assumptions or estimates underlying the obligations, the Fund reassesses its asset retirement obligations to determine whether any revisions to the obligations are necessary. The Fund maintains a salvage fund to provide for the funding of future asset retirement obligations.

Revenue Recognition

Oil and gas revenues are recognized at the point when control of oil and natural gas is transferred to the customers. Natural gas liquid sales are included within gas sales. The Fund’s oil and natural gas generally are sold to its customers at prevailing market prices based on an index in which the prices are published, adjusted for pricing differentials, quality of oil and pipeline allowances. Under the Fund’s oil and natural gas contracts, each unit of oil and natural gas represents a separate performance obligation; therefore, future volumes are wholly unsatisfied and the transaction price related to the remaining performance obligations is the variable index-based price attributable to each unit of oil and natural gas that is transferred to the customer. The Fund invoices customers once its performance obligations have been satisfied, at which point the payment is unconditional. Accordingly, the Fund’s oil and natural gas contracts do not give rise to contract assets or liabilities. The receivables related to the Fund’s oil and gas revenue are included within “Production receivable” on the Fund’s balance sheets.

Other revenue is generated from the Fund’s production handling, gathering and operating services agreement with an affiliated entity and other third parties. The Fund simply earns a fee for its services and recognizes these fees as revenue at the time its performance obligations are satisfied as the control of oil and natural gas is never transferred to the Fund, thus there are no unsatisfied performance obligations. The Fund’s project operator performs joint interest billing once the performance obligations have been satisfied, at which point the payment is unconditional. Accordingly, the Fund’s production handling, gathering and operating services agreement with an affiliated entity and other third parties does not give rise to contract assets or liabilities. The receivables related to the Fund’s proportionate share of revenue from an affiliate are included within “Due from affiliate” on the Fund’s balance sheets. The receivables related to the Fund’s proportionate share of revenue from third parties are presented as a reduction from “Due to operator” on the Fund’s balance sheets. The receivables are settled by issuance of a non-cash credit from the Beta Project operator to the Fund when the operator performs the joint interest billing of the lease operating expenses due from the Fund.

The Fund also has an estimation process for revenue and related accruals, and any identified difference between its revenue estimates and actual revenue has not been significant. During each of the three and six months ended June 30, 2019 and 2018, revenue recognized from performance obligations satisfied in previous periods was not significant.

Impairment of Long-Lived Assets

The Fund reviews the carrying value of its oil and gas properties for impairment whenever events and circumstances indicate that the recorded carrying value of the assets may not be recoverable. Impairments are determined by comparing estimated future net undiscounted cash flows to the carrying value of the assets at the time of the review. If the carrying value exceeds the estimated future net undiscounted cash flows, the carrying value of the asset is written down to fair value, which is determined using valuation techniques that include both market and income approaches and use Level 3 inputs. The fair value determinations require considerable judgment and are sensitive to change. Different pricing assumptions, reserve estimates or discount rates could result in a different calculated impairment.

There were no impairments of oil and gas properties during each of the three and six months ended June 30, 2019 and 2018. Fluctuations in oil and natural gas commodity prices may impact the fair value of the Fund’s oil and gas properties. If oil and natural gas commodity prices decline, even if only for a short period of time, it is possible that impairments of oil and gas properties will occur. 

Recent Accounting Pronouncements

In August 2018, the Financial Accounting Standards Board (“FASB”) issued accounting guidance on fair value measurement, which adds, among other things, disclosure requirements for the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. This accounting guidance is effective for the Fund in the first quarter 2020 with early adoption permitted. The Fund does not expect this accounting guidance will have a material impact on its financial statements upon adoption.

In February 2016, the FASB issued accounting guidance on leases as amended on January 2018 and July 2018, which requires an entity to recognize all lease assets and liabilities with a term greater than one year on the balance sheet, disclose key quantitative and qualitative information about leasing arrangements, and permits an entity not to evaluate existing or expired land easements that were not previously assessed under the existing lease guidance. The accounting guidance does not apply to leases of mineral rights to explore for or use of oil and natural gas. The accounting guidance was effective for the Fund beginning January 1, 2019. Although the Fund, as a non-operator, does not enter into lease agreements to support its operations, the Fund completed its evaluation of existing contracts that may have a lease impact and embedded lease features to determine the contracts to which the new guidance applies. Based on this evaluation, the Fund determined its existing contracts did not meet the definition of leases under the new accounting guidance and therefore, did not qualify for lease accounting.

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Related Parties

6 Months Ended

Jun. 30, 2019

Related Party Transactions [Abstract]

Related Parties

2. Related Parties

Pursuant to the terms of the LLC Agreement, the Manager is entitled to receive an annual management fee, payable monthly, of 2.5% of total capital contributions, net of cumulative dry-hole and related well costs incurred by the Fund, however, the Manager is permitted to waive the management fee at its own discretion. Therefore, the management fee may be temporarily waived to accommodate the Fund’s short-term commitments. Management fees during each of the three and six months ended June 30, 2019 and 2018 were $0.3 million and $0.6 million, respectively.

The Manager is also entitled to receive 15% of the cash distributions from operations made by the Fund. Distributions paid to the Manager during the three and six months ended June 30, 2019 were $0.2 million and $0.5 million, respectively. The Fund did not pay distributions during the three and six months ended June 30, 2018.

The Fund utilizes Beta Sales and Transport, LLC and DH Sales and Transport, LLC, wholly-owned subsidiaries of the Manager, to facilitate the transportation and sale of oil and natural gas produced from the Beta, Diller and Marmalard projects.

During 2016, the Fund and other third-party working interest owners in the Beta Project entered into a production handling, gathering and operating services agreement (“PHA”) with Ridgewood Claiborne, LLC, a wholly-owned entity of Ridgewood Energy Oil & Gas Fund II, L.P. (“Institutional Fund II”), and other third-party working interest owners in the Claiborne Project. Institutional Fund II is an entity that is managed by the Fund’s Manager. During the three and six months ended June 30, 2019, the Fund earned $28 thousand and $0.1 million, respectively, representing its proportionate share of the production handling fees earned from Institutional Fund II, which is included within “Other revenue” on the Fund’s statements of operations. There were no such amounts recorded during the three and six months ended June 30, 2018. As of June 30, 2019 and December 31, 2018, the Fund’s receivables of $28 thousand and $0.1 million, respectively, related to the Fund’s proportionate share of revenue from Institutional Fund II are included within “Due from affiliate” on the Fund’s balance sheets. The receivables are settled by issuance of a non-cash credit from the Beta Project operator to the Fund on behalf of the Claiborne Project working interest owners when the operator performs the joint interest billing of the lease operating expenses due from the Fund. The revenue received from the PHA will be utilized by the Fund to repay a portion of the long-term debt outstanding under its credit agreement until the loan is repaid in full, in no event later than December 31, 2022.

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

The Fund has working interest ownership in certain oil and natural gas projects, which are also owned by other entities that are likewise managed by the Manager.

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Credit Agreement - Beta Project Financing

6 Months Ended

Jun. 30, 2019

Debt Disclosure [Abstract]

Credit Agreement - Beta Project Financing

3. Credit Agreement – Beta Project Financing

As of June 30, 2019 and December 31, 2018, the Fund had outstanding borrowings of $4.5 million and $5.2 million, respectively, under its credit agreement dated November 27, 2012, as amended on September 30, 2016, September 15, 2017, June 1, 2018 and August 10, 2018 (the “Credit Agreement”). As of June 30, 2019, the estimated fair value of the debt was $4.4 million.

The Credit Agreement bears interest at 8.75% compounded monthly. Principal and interest payments are based on the fixed percentage of the Fund’s Net Revenue, as defined in the Credit Agreement. Beginning on April 1, 2019 and each April 1^st thereafter, the Fund’s fixed percentage is the greater of (i) 30% or (ii) the Fixed Reassessment Percentage, as defined in the Credit Agreement. The Fixed Reassessment Percentage is determined annually beginning April 1, 2019 and each April 1^st thereafter, and is based on the Fund’s ratio of its outstanding debt as of the reassessment date relative to 80% of third-party reserve engineer’s proved plus probable future undiscounted cash flows attributable to the Beta Project through the maturity of the loan. As of April 1, 2019, the Fund’s fixed percentage was determined to be 30%. The loan may be prepaid by the Fund without premium or penalty. Pursuant to the Credit Agreement, the Fund also agreed to convey a fixed percentage of 12.56% overriding royalty interest in its working interest in the Beta Project to the lenders, which will become payable to the lenders on January 1, 2023.

As of June 30, 2019 and December 31, 2018, the unamortized debt discounts related to the Credit Agreement of $20 thousand and $22 thousand, respectively, were presented as a reduction of “Long-term borrowings” on the Fund’s balance sheets. Amortization expense during the three and six months ended June 30, 2019 of $1 thousand and $3 thousand, respectively, was included on the Fund’s statements of operations within “Interest expense, net”. There were no such amounts recorded during the three and six months ended June 30, 2018. As of June 30, 2019 and December 31, 2018, there were no accrued interest costs outstanding. Interest costs incurred during the three and six months ended June 30, 2019 of $0.1 million and $0.2 million, respectively, were included on the Fund’s statements of operations within “Interest expense, net”. Interest costs incurred during the three and six months ended June 30, 2018 of $0.5 million and $1.1 million, respectively, were included on the Fund’s statements of operations within “Interest expense, net”.

The Credit Agreement contains customary covenants, with which the Fund was in compliance as of June 30, 2019 and December 31, 2018.

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Commitments and Contingencies

6 Months Ended

Jun. 30, 2019

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

4. Commitments and Contingencies

Capital Commitments

As of June 30, 2019, the Fund’s estimated capital commitments related to its oil and gas properties were $8.0 million (which include asset retirement obligations for the Fund’s projects of $3.8 million), of which $1.9 million is expected to be spent during the next twelve months. Future results of operations and cash flows are dependent on the continued successful development and the related production of oil and gas revenues from the Fund’s producing projects.

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

Environmental and Governmental Regulations

Many aspects of the oil and gas industry are subject to federal, state and local environmental laws and regulations. The Manager and operators of the Fund’s properties are continually taking action they believe appropriate to satisfy applicable federal, state and local environmental regulations. However, due to the significant public and governmental interest in environmental matters related to those activities, the Manager cannot predict the effects of possible future legislation, rule changes, or governmental or private claims. As of June 30, 2019 and December 31, 2018, there were no known environmental contingencies that required adjustment to, or disclosure in, the Fund’s financial statements.

Oil and gas industry legislation and administrative regulations are periodically changed for a variety of political, economic, and other reasons. Any such future laws and regulations could result in increased compliance costs or additional operating restrictions, which could have a material adverse effect on the Fund’s operating results and cash flows. It is not possible at this time to predict whether such legislation or regulation, if proposed, will be adopted as initially written, if at all, or how legislation or new regulation that may be adopted would impact the Fund’s business.

BOEM Notice to Lessees on Supplemental Bonding

On July 14, 2016, the Bureau of Ocean Energy Management (“BOEM”) issued a Notice to Lessees (“NTL”) that discontinued and materially replaced existing policies and procedures regarding financial security (i.e. supplemental bonding) for decommissioning obligations of lessees of federal oil and gas leases and owners of pipeline rights-of-way, rights-of use and easements on the Outer Continental Shelf (“Lessees”).  Generally, the NTL (i) ended the practice of excusing Lessees from providing such additional security where co-lessees had sufficient financial strength to meet such decommissioning obligations, (ii) established new criteria for determining financial strength and additional security requirements of such Lessees, (iii) provided acceptable forms of such additional security and (iv) replaced the waiver system with one of self-insurance. The rule became effective as of September 12, 2016; however on January 6, 2017, the BOEM announced that it was suspending the implementation timeline for six months in certain circumstances. On June 22, 2017, the BOEM announced that the implementation timeline extension will remain in effect pending the completion of its review of the NTL. As of June 30, 2019, the BOEM has not completed its review nor has the NTL been enforced.  The impact of the NTL, if enforced without change or amendment, may require the Fund to fully secure all of its potential abandonment liabilities to the BOEM’s satisfaction using one or more of the enumerated methods for doing so.  Potentially this could increase costs to the Fund if the Fund is required to obtain additional supplemental bonding, fund escrow accounts or obtain letters of credit.

Insurance Coverage

The Fund is subject to all risks inherent in the oil and natural gas business. Insurance coverage as is customary for entities engaged in similar operations is maintained, but losses may occur from uninsurable risks or amounts in excess of existing insurance coverage. The occurrence of an event that is not insured or not fully insured could have a material adverse impact upon earnings and financial position. Moreover, insurance is obtained as a package covering all of the entities managed by the Manager. Depending on the extent, nature and payment of claims made by the Fund or other entities managed by the Manager, yearly insurance coverage may be exhausted and become insufficient to cover a claim by the Fund in a given year.

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Subsequent Event

6 Months Ended

Jun. 30, 2019

Subsequent Event

Subsequent Event

5. Subsequent Event

The Fund as well as other funds managed by the Manager that invested in the Beta Project elected not to participate in the drilling of the 8th well proposed by Walter Oil and Gas Corporation.  As a result, the Fund is due reimbursement for a portion of the cost relating to the slot on the Beta Project platform that was utilized by the other third-party working interest partners for the 8th well.  On July 17, 2019, the Fund as well as the other funds managed by the Manager and the other third-party working interest owners in the Beta Project agreed to a reimbursement to the Fund of $0.8 million, which will be recorded as a reduction to oil and gas properties in the third quarter 2019.  The amount received will be utilized by the Fund to repay a portion of the long-term debt outstanding under the Credit Agreement. 

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Organization and Summary of Significant Accounting Policies (Policy)

6 Months Ended

Jun. 30, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

Basis of Presentation

These unaudited interim condensed financial statements have been prepared by the Fund’s management in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and in the opinion of management, contain all adjustments (consisting of only normal recurring adjustments) necessary to present fairly the Fund’s financial position, results of operations, changes in members’ capital and cash flows for the periods presented. Certain information and note disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted in these unaudited interim condensed financial statements. The financial position, results of operations, changes in members’ capital and cash flows for the periods presented herein are not necessarily indicative of future financial results. These unaudited interim condensed financial statements should be read in conjunction with the Fund’s December 31, 2018 financial statements and notes thereto included in the Fund’s Annual Report on Form 10-K (“2018 Annual Report”) filed with the Securities and Exchange Commission (“SEC”). The year-end condensed balance sheet data was derived from audited financial statements for the year ended December 31, 2018, but does not include all annual 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, depletion and amortization, determination of proved reserves, impairment of long-lived assets and asset retirement obligations. Actual results may differ from those estimates.

Fair Value Measurements

Fair Value Measurements

The Fund follows the accounting guidance for fair value measurement for measuring fair value of assets and liabilities in its financial statements. The Fund’s financial instruments consist of cash and cash equivalents, salvage fund, production receivable, due from affiliate, other current assets, investment in Delta House, due to operators, accrued expenses and long-term debt. Except for investment in Delta House and long-term debt, the carrying amounts of these instruments approximate fair value due to their short-term nature.

The Fund’s investment in Delta House is valued using the measurement alternative for investment in other entities (see Investment in Delta House below for additional information). The Fund’s long-term debt is valued using an income approach and classified as Level 3 in the fair value hierarchy. The fair value of long-term debt is estimated by discounting future cash payments of principal and interest to a present value amount using a market yield for debt instruments with similar terms, maturities and credit ratings. The Fund also applies the provisions of the fair value measurement accounting guidance to its non-financial assets and liabilities, such as oil and gas properties and asset retirement obligations, on a non-recurring basis.

Investment in Delta House

Investment in Delta House

The Fund has investments in Delta House Oil and Gas Lateral, LLC and Delta House FPS, LLC (collectively “Delta House”), legal entities that own interests in a deepwater floating production system operated by LLOG Exploration Offshore, L.L.C. The investment in Delta House is valued using the measurement alternative to record the investment at cost, less impairment and plus or minus subsequent adjustments for observable price changes with change in basis reported in current earnings. At each reporting period, the Fund reviews its investment in Delta House to evaluate whether the investment is impaired. Losses on investments, including impairments, are classified as non-operating losses in the Fund’s statements of operations. During each of the three and six months ended June 30, 2019 and 2018, there were no impairments of the Fund’s investment in Delta House.

Asset Retirement Obligations

Asset Retirement Obligations

For oil and gas properties, there are obligations to perform removal and remediation activities when the properties are retired. Upon the determination that a property is either proved or dry, a retirement obligation is incurred. The Fund recognizes the fair value of a liability for an asset retirement obligation in the period incurred based on expected future cash outflows required to satisfy the obligation discounted at the Fund’s credit-adjusted risk-free rate. Plug and abandonment costs associated with unsuccessful projects are expensed as dry-hole costs. Annually, or more frequently if an event occurs that would dictate a change in assumptions or estimates underlying the obligations, the Fund reassesses its asset retirement obligations to determine whether any revisions to the obligations are necessary. The Fund maintains a salvage fund to provide for the funding of future asset retirement obligations.

Revenue Recognition

Revenue Recognition

Oil and gas revenues are recognized at the point when control of oil and natural gas is transferred to the customers. Natural gas liquid sales are included within gas sales. The Fund’s oil and natural gas generally are sold to its customers at prevailing market prices based on an index in which the prices are published, adjusted for pricing differentials, quality of oil and pipeline allowances. Under the Fund’s oil and natural gas contracts, each unit of oil and natural gas represents a separate performance obligation; therefore, future volumes are wholly unsatisfied and the transaction price related to the remaining performance obligations is the variable index-based price attributable to each unit of oil and natural gas that is transferred to the customer. The Fund invoices customers once its performance obligations have been satisfied, at which point the payment is unconditional. Accordingly, the Fund’s oil and natural gas contracts do not give rise to contract assets or liabilities. The receivables related to the Fund’s oil and gas revenue are included within “Production receivable” on the Fund’s balance sheets.

Other revenue is generated from the Fund’s production handling, gathering and operating services agreement with an affiliated entity and other third parties. The Fund simply earns a fee for its services and recognizes these fees as revenue at the time its performance obligations are satisfied as the control of oil and natural gas is never transferred to the Fund, thus there are no unsatisfied performance obligations. The Fund’s project operator performs joint interest billing once the performance obligations have been satisfied, at which point the payment is unconditional. Accordingly, the Fund’s production handling, gathering and operating services agreement with an affiliated entity and other third parties does not give rise to contract assets or liabilities. The receivables related to the Fund’s proportionate share of revenue from an affiliate are included within “Due from affiliate” on the Fund’s balance sheets. The receivables related to the Fund’s proportionate share of revenue from third parties are presented as a reduction from “Due to operator” on the Fund’s balance sheets. The receivables are settled by issuance of a non-cash credit from the Beta Project operator to the Fund when the operator performs the joint interest billing of the lease operating expenses due from the Fund.

The Fund also has an estimation process for revenue and related accruals, and any identified difference between its revenue estimates and actual revenue has not been significant. During each of the three and six months ended June 30, 2019 and 2018, revenue recognized from performance obligations satisfied in previous periods was not significant.

Impairment of Long-Lived Assets

Impairment of Long-Lived Assets

The Fund reviews the carrying value of its oil and gas properties for impairment whenever events and circumstances indicate that the recorded carrying value of the assets may not be recoverable. Impairments are determined by comparing estimated future net undiscounted cash flows to the carrying value of the assets at the time of the review. If the carrying value exceeds the estimated future net undiscounted cash flows, the carrying value of the asset is written down to fair value, which is determined using valuation techniques that include both market and income approaches and use Level 3 inputs. The fair value determinations require considerable judgment and are sensitive to change. Different pricing assumptions, reserve estimates or discount rates could result in a different calculated impairment.

There were no impairments of oil and gas properties during each of the three and six months ended June 30, 2019 and 2018. Fluctuations in oil and natural gas commodity prices may impact the fair value of the Fund’s oil and gas properties. If oil and natural gas commodity prices decline, even if only for a short period of time, it is possible that impairments of oil and gas properties will occur.

Recent Accounting Pronouncements

Recent Accounting Pronouncements

In August 2018, the Financial Accounting Standards Board (“FASB”) issued accounting guidance on fair value measurement, which adds, among other things, disclosure requirements for the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. This accounting guidance is effective for the Fund in the first quarter 2020 with early adoption permitted. The Fund does not expect this accounting guidance will have a material impact on its financial statements upon adoption.

In February 2016, the FASB issued accounting guidance on leases as amended on January 2018 and July 2018, which requires an entity to recognize all lease assets and liabilities with a term greater than one year on the balance sheet, disclose key quantitative and qualitative information about leasing arrangements, and permits an entity not to evaluate existing or expired land easements that were not previously assessed under the existing lease guidance. The accounting guidance does not apply to leases of mineral rights to explore for or use of oil and natural gas. The accounting guidance was effective for the Fund beginning January 1, 2019. Although the Fund, as a non-operator, does not enter into lease agreements to support its operations, the Fund completed its evaluation of existing contracts that may have a lease impact and embedded lease features to determine the contracts to which the new guidance applies. Based on this evaluation, the Fund determined its existing contracts did not meet the definition of leases under the new accounting guidance and therefore, did not qualify for lease accounting.

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Related Parties (Details) - USD ($) $ in Thousands	3 Months Ended			6 Months Ended
	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Annual management fee percentage rate	2.50%			2.50%
Annual management fees paid to Fund Manager	$ 283		$ 283	$ 565	$ 566
Percentage of total distributions allocated to Fund Manager	15.00%			15.00%
Distributions	$ (1,192)	$ (1,826)
Other revenue from affiliate	28			$ 100
Due from affiliate	28			28		$ 90
Manager [Member]
Distributions	$ (179)	$ (274)		$ (500)

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Credit Agreement - Beta Project Financing (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Debt Disclosure [Abstract]
Long-term borrowings	$ 4,500		$ 4,500		$ 5,200
Fair value of debt	$ 4,400		$ 4,400
Interest rate	8.75%		8.75%
Periodic payment, fixed percentage	30.00%		30.00%
Overriding royalty interest	12.56%		12.56%
Unamortized debt discounts	$ 20		$ 20		22
Amortization of financing costs	1		3
Accrued interest
Interest expense	$ 100	$ 500	$ 200	$ 1,100

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Commitments and Contingencies (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2019 USD ($)
Commitments and Contingencies Disclosure [Abstract]
Commitments for the drilling and development of investment properties	$ 8,000
Commitments for asset retirement obligations included in estimated capital commitments	3,800
Commitments for the drilling and development of investment properties expected to be incurred in the next 12 months	$ 1,900

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Subsequent Event (Details) $ in Thousands	Jul. 17, 2019 USD ($)
Subsequent Event [Member]
Other receivable	$ 800