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 September 30, 2017

or

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

Commission File No. 000-51927

Ridgewood Energy Q Fund, LLC

(Exact name of registrant as specified in its charter)

Delaware (State or other jurisdiction of incorporation or organization) 84-1689138 (I.R.S. Employer Identification No.)

14 Philips Parkway, Montvale, NJ  07645

(Address of principal executive offices) (Zip code)

(800) 942-5550

(Registrant’s telephone number, including area code)

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

  Yes ☒    No ☐

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).   Yes ☒    No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer”, “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Securities Exchange Act of 1934.

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

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Securities Exchange Act of 1934. ☐

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

As of November 9, 2017 there were 830.5577 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 September 30, 2017 and December 31, 2016	1
		Unaudited Condensed Statements of Operations for the three and nine months ended September 30, 2017 and 2016	2
		Unaudited Condensed Statements of Cash Flows for the nine months ended September 30, 2017 and 2016	3
		Notes to Unaudited Condensed Financial Statements	4
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		9
Item 3.	Quantitative and Qualitative Disclosures About Market Risk		15
Item 4.	Controls and Procedures		15
PART II - OTHER INFORMATION
Item 1.	Legal Proceedings		15
Item 1A.	Risk Factors		15
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		15
Item 3.	Defaults Upon Senior Securities		16
Item 4.	Mine Safety Disclosures		16
Item 5.	Other Information		16
Item 6.	Exhibits		16
	SIGNATURES		17

PART I – FINANCIAL INFORMATION

ITEM 1.  FINANCIAL STATEMENTS

RIDGEWOOD ENERGY Q FUND, LLC

UNAUDITED CONDENSED BALANCE SHEETS

(in thousands, except share data)

	September 30, 2017			December 31, 2016
Assets
Current assets:
Cash and cash equivalents	$	1,326		$	1,780
Salvage fund		339			557
Production receivable		228			353
Other current assets		89			131
Total current assets		1,982			2,821
Salvage fund		633			481
Oil and gas properties:
Proved properties		21,813			19,669
Less:  accumulated depletion and amortization		(6,918	)		(3,897	)
Total oil and gas properties, net		14,895			15,772
Total assets	$	17,510		$	19,074
Liabilities and Members' Capital
Current liabilities:
Due to operators	$	621		$	525
Accrued expenses		68			267
Current portion of long-term borrowings		1,620			1,033
Asset retirement obligations		339			557
Total current liabilities		2,648			2,382
Long-term borrowings		3,488			4,302
Asset retirement obligations		575			549
Other liabilities		45			45
Total liabilities		6,756			7,278
Commitments and contingencies (Note 4)
Members' capital:
Manager:
Distributions		(7,081	)		(7,081	)
Retained earnings		4,941			4,631
Manager's total		(2,140	)		(2,450	)
Shareholders:
Capital contributions (1,335 shares authorized;
830.5577 issued and outstanding)		123,037			123,037
Syndication costs		(14,070	)		(14,070	)
Distributions		(40,120	)		(40,120	)
Accumulated deficit		(55,953	)		(54,601	)
Shareholders' total		12,894			14,246
Total members' capital		10,754			11,796
Total liabilities and members' capital	$	17,510		$	19,074

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

1

RIDGEWOOD ENERGY Q FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF OPERATIONS

 (in thousands, except per share data)

	Three months ended September 30,						Nine months ended September 30,
	2017			2016			2017			2016
Revenue
Oil and gas revenue	$	872		$	232		$	2,999		$	350
Expenses
Depletion and amortization		445			171			2,895			247
Operating expenses		183			129			556			194
General and administrative expenses		61			60			192			174
Total expenses		689			360			3,643			615
Income (loss) from operations		183			(128	)		(644	)		(265	)
Interest expense, net		(133	)		(86	)		(398	)		(85	)
Net income (loss)	$	50		$	(214	)	$	(1,042	)	$	(350	)
Manager Interest
Net income (loss)	$	90		$	4		$	310		$	(4	)
Shareholder Interest
Net loss	$	(40	)	$	(218	)	$	(1,352	)	$	(346	)
Net loss per share	$	(49	)	$	(263	)	$	(1,628	)	$	(416	)

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

2

RIDGEWOOD ENERGY Q FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF CASH FLOWS

(in thousands)

	Nine months ended September 30,
	2017			2016
Cash flows from operating activities
Net loss	$	(1,042	)	$	(350	)
Adjustments to reconcile net loss to net cash
provided by (used in) operating activities:
Depletion and amortization		2,895			247
Accretion expense		23			-
Amortization of debt discounts and deferred financing costs		60			20
Changes in assets and liabilities:
Decrease (increase) in production receivable		125			(148	)
Decrease (increase) in other current assets		42			(81	)
Increase in due to operators		38			16
(Decrease) increase in accrued expenses		(156	)		93
Settlements of asset retirement obligations		(96	)		-
Net cash provided by (used in) operating activities		1,889			(203	)
Cash flows from investing activities
Capital expenditures for oil and gas properties		(2,122	)		(1,739	)
Decrease (increase) in salvage fund		66			(901	)
Net cash used in investing activities		(2,056	)		(2,640	)
Cash flows from financing activities
Long-term borrowings		-			650
Repayments of long-term borrowings		(287	)		-
Net cash (used in) provided by financing activities		(287	)		650
Net decrease in cash and cash equivalents		(454	)		(2,193	)
Cash and cash equivalents, beginning of period		1,780			2,728
Cash and cash equivalents, end of period	$	1,326		$	535
Supplemental disclosure of cash flow information
Cash paid for interest, net of amounts capitalized	$	495		$	-
Supplemental disclosure of non-cash investing activities
Due to operators for accrued capital expenditures for oil and gas properties	$	526		$	285

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

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RIDGEWOOD ENERGY Q FUND, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

1. Organization and Summary of Significant Accounting Policies

Organization

The Ridgewood Energy Q Fund, LLC (the “Fund”), a Delaware limited liability company, was formed on August 16, 2005 and operates pursuant to a limited liability company agreement (the “LLC Agreement”) dated as of September 6, 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 Fund operations.  Such services include, without limitation, the administration of shareholder accounts, shareholder relations, the preparation, review and dissemination of tax and other financial information and the management of the Fund’s investments in projects.  In addition, the Manager provides office space, equipment and facilities and other services necessary for Fund operations.  The Manager also engages and manages contractual relations with unaffiliated custodians, depositories, accountants, attorneys, corporate fiduciaries, insurers, banks and others as required. See Notes 2, 3 and 4.

Basis of Presentation

These unaudited interim condensed financial statements have been prepared by the Fund’s management in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and in the opinion of management, contain all adjustments (consisting of only normal recurring adjustments) necessary to present fairly the Fund’s financial position, results of operations and cash flows for the periods presented.  Certain information and note disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted in these unaudited interim condensed financial statements.  The results of operations, financial position, and cash flows for the periods presented herein are not necessarily indicative of future financial results.  These unaudited interim condensed financial statements should be read in conjunction with the Fund’s December 31, 2016 financial statements and notes thereto included in the Fund’s Annual Report on Form 10-K (“2016 Annual Report”) filed with the Securities and Exchange Commission (“SEC”).  The year-end condensed balance sheet data was derived from audited financial statements for the year ended December 31, 2016, 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 2016 Annual Report. There have been no significant changes to the Fund’s significant accounting policies during the three and nine months ended September 30, 2017.

Asset Retirement Obligations

For oil and gas properties, there are obligations to perform removal and remediation activities when the properties are retired. Upon the determination that a property is either proved or dry, a retirement obligation is incurred. The Fund recognizes the fair value of a liability for an asset retirement obligation in the period incurred.  Plug and abandonment costs associated with unsuccessful projects are expensed as dry-hole costs.  At least bi-annually, 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 following table presents changes in asset retirement obligations during the nine months ended September 30, 2017 and 2016.

4

	2017			2016
	(in thousands)
Balance, beginning of period	$	1,106		$	1,584
Liabilities incurred		2			-
Liabilities settled		(96	)		-
Accretion expense		23			-
Revision of estimates		(121	)		-
Balance, end of period	$	914		$	1,584

During the nine months ended September 30, 2017, the Fund recorded credits to depletion expense totaling $0.1 million related to an adjustment to the asset retirement obligation for a fully depleted property. The Fund maintains a salvage fund to provide for the funding of asset retirement obligations.

Impairment of Long-Lived Assets

The Fund reviews the carrying value of its oil and gas properties annually and when management determines that events and circumstances indicate that the recorded carrying value of properties may not be recoverable.  Impairments are determined by comparing estimated future net undiscounted cash flows to the carrying value at the time of the review.  If the carrying value exceeds the estimated future net undiscounted cash flows, the carrying value of the asset is written down to fair value, which is determined using estimated future net discounted cash flows from the asset.  The fair value determinations require considerable judgment and are sensitive to change.  Different pricing assumptions, reserve estimates or discount rates could result in a different calculated impairment.  Given the volatility of oil and natural gas prices, it is reasonably possible that the Fund’s estimate of future net discounted cash flows from proved oil and natural gas reserves could change in the near term.

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

Recent Accounting Pronouncements

In May 2014, the Financial Accounting Standards Board (“FASB”) issued accounting guidance on revenue recognition, which provides for a single five-step model to be applied to all revenue contracts with customers. In July 2015, the FASB issued a deferral of the effective date of the guidance to 2018, with early adoption permitted in 2017. In March 2016, the FASB issued accounting guidance, which clarifies the implementation guidance on principal versus agent considerations in the new revenue recognition standard. In April 2016, the FASB issued guidance on identifying performance obligations and licensing and in May 2016, the FASB issued final amendments which provided narrow scope improvements and practical expedients related to the implementation of the guidance.  The accounting guidance may be applied either retrospectively or through the use of a modified-retrospective method. The Fund has substantially completed the evaluation of the accounting guidance and currently expects the adoption of the accounting guidance will not have a material impact on the Fund’s financial statements. Under the new accounting guidance, the revenue associated with the Fund’s existing contracts will be recognized in the period that control of the related commodity is transferred to the customer, which is generally consistent with its current revenue recognition model. The Fund will adopt the new accounting guidance using the modified retrospective method at the date of adoption, which is January 1, 2018.  Although the Fund has not identified changes to its revenue recognition that would result in a material cumulative effect adjustment to retained earnings on January 1, 2018, the Fund expects the adoption of the accounting guidance will result in enhanced disclosures related to revenue recognition policies, the Fund’s performance obligations and significant judgments used in applying the new revenue recognition accounting guidance.

2. Related Parties

Pursuant to the terms of the LLC Agreement, the Manager is entitled to an annual management fee, payable monthly, of 2.5% of total capital contributions, net of cumulative dry-hole and related well costs incurred by the Fund. During 2009, the Manager waived its management fee for the remaining life of the Fund. Upon the waiver of the management fee, the Fund began recording costs, totaling $20 thousand per quarter, representing reimbursements to the Manager, related to services provided by the Manager for accounting and investor relations.  Such costs are included within general and administrative expenses. Management reimbursement costs during each of the three and nine months ended September 30, 2017 and 2016 were $20 thousand and $60 thousand, respectively.

5

The Manager is also entitled to receive a 15% interest in cash distributions from operations made by the Fund.  The Fund did not pay distributions during the three and nine months ended September 30, 2017 and 2016.

In 2016, the Fund entered into a master agreement with Beta Sales and Transport, LLC, a wholly owned subsidiary of the Manager, to facilitate the transportation and sale of oil and natural gas produced from the Beta Project. The Fund has provided discussion of this agreement in Note 2 of “Notes to Financial Statements” – “Related Parties” contained in Item 8. “Financial Statements and Supplementary Data” within its 2016 Annual Report.

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

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

3. Credit Agreement – Beta Project Financing

As of September 30, 2017 and December 31, 2016, the Fund had borrowings of $5.1 million and $5.4 million, respectively, under the credit agreement. The loan bears interest at 8% compounded annually.  Principal and interest are repaid at the lesser of the Monthly Fixed Amount or the Debt Service Cap amount, as defined in the credit agreement, until the loan is repaid in full, in no event later than December 31, 2020.  The loan may be prepaid by the Fund without premium or penalty. As of December 31, 2016, in accordance with the terms of the credit agreement, there are no additional borrowings available to the Fund. On September 15, 2017, the Fund and other participating funds managed by the Manager, entered into the second amendment to the credit agreement (“Second Amendment”). The Second Amendment principally amended the definition of net revenues, which is the basis for the calculation of the Debt Service Cap amount.

Unamortized debt discounts and deferred financing costs of $20 thousand as of September 30, 2017 and $0.1 million as of December 31, 2016 are presented as a reduction of “Long-term borrowings” on the balance sheets.  Amortization expense during the three and nine months ended September 30, 2017 of $20 thousand and $0.1 million, respectively, and amortization expense during the three months ended September 30, 2016 of $20 thousand were expensed and included on the statements of operations within “Interest expense, net”. Amortization expense during the nine months ended September 30, 2016 of $40 thousand was capitalized and included on the balance sheet within “Oil and gas properties”.

As of September 30, 2017, there were no accrued interest costs outstanding. As of December 31, 2016, accrued interest costs of $0.2 million were included on the balance sheets within “Accrued expenses”. Interest costs incurred during the three and nine months ended September 30, 2017 of $0.1 million and $0.3 million, respectively, and interest costs incurred during the three months ended September 30, 2016 of $0.1 million were expensed and included on the statements of operations within “Interest expense, net”. Interest costs incurred during the nine months ended September 30, 2016 of $0.1 million were capitalized and included on the balance sheet within “Oil and gas properties”. During the nine months ended September 30, 2017, the Fund made payments on the loan of $43 thousand, which related to capitalized interest costs.

As additional consideration to the lenders, the Fund has agreed to convey an overriding royalty interest (“ORRI”) in its working interest in the Beta Project to the lenders. Such ORRI will not accrue or become payable to the lenders until after the loan is repaid in full. The credit agreement contains customary covenants, with which the Fund was in compliance as of September 30, 2017 and December 31, 2016.

6

4. Commitments and Contingencies

Capital Commitments

As of September 30, 2017, the Fund’s estimated capital commitments related to its oil and gas properties were $3.4 million (which include asset retirement obligations for the Fund’s projects of $1.8 million), of which $1.6 million is expected to be spent during the next twelve months primarily related to the additional development costs for the Beta Project. As a result of continued development of the Beta Project, the Fund has experienced negative cash flows for the nine months ended September 30, 2017.  Additionally, current liabilities exceed current assets as of September 30, 2017.  Future results of operations and cash flows are dependent on the continued successful development and the related production of oil and gas revenues from the Beta Project.

Based upon its current cash position and its current reserve estimates, the Fund expects cash flow from operations to be sufficient to cover its commitments, borrowing repayments and ongoing operations. Reserve estimates are projections based on engineering data that cannot be measured with precision, require substantial judgment, and are subject to frequent revision.  However, if cash flow from operations is not sufficient to meet the Fund’s commitments, the Manager will provide short-term 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 September 30, 2017 and December 31, 2016, there were no known environmental contingencies that required adjustment to, or disclosure in, the Fund’s financial statements.

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

BOEM Notice to Lessees on Supplemental Bonding

On July 14, 2016, the Bureau of Ocean Energy Management (“BOEM”) issued a Notice to Lessees (“NTL”) that discontinued and materially replaced existing policies and procedures regarding financial security (i.e. supplemental bonding) for decommissioning obligations of lessees of federal oil and gas leases and owners of pipeline rights-of-way, rights-of use and easements on the Outer Continental Shelf (“Lessees”).  Generally, the new NTL (i) ended the practice of excusing Lessees from providing such additional security where co-lessees had sufficient financial strength to meet such decommissioning obligations, (ii) established new criteria for determining financial strength and additional security requirements of such Lessees,  (iii) provided acceptable forms of such additional security and (iv) replaced the waiver system with one of self-insurance.  The new rule became effective as of September 12, 2016; however on January 6, 2017, the BOEM announced that it was suspending the implementation timeline for six months in certain circumstances. On June 22, 2017, the BOEM announced that the implementation timeline extension will remain in effect pending the completion of its review of the new NTL. The Fund, as well as other industry participants, are working with the BOEM, its operators and working interest partners to determine and agree upon the correct level of decommissioning obligations to which they may be liable and the manner in which such obligations will be secured.  The impact of the NTL, if enforced without change or amendment, may require the Fund to fully secure all of its potential abandonment liabilities to the BOEM’s satisfaction using one or more of the enumerated methods for doing so.  Potentially this could increase costs to the Fund if the Fund is required to obtain additional supplemental bonding, fund escrow accounts or obtain letters of credit.

7

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

8

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

Critical Accounting Policies and Estimates

There were no changes to the Fund’s critical accounting policies and estimates from those disclosed in its Annual Report on Form 10-K for the year ended December 31, 2016.

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.  During 2009, the Manager waived its management fee for the remaining life of the Fund. Upon the waiver of the management fee, the Fund began recording costs related to services provided by the Manager for accounting and investor relations.  The Fund does not currently, nor is there any plan to, operate any project in which the Fund participates.  The Manager enters into operating agreements with third-party operators for the management of all exploration, development and producing operations, as appropriate.  The Manager also participates in distributions.

Commodity Price Changes

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

9

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. Despite operating in a sustained lower commodity price environment, the Fund continued to advance the development of the Beta Project, which commenced production during the second half of 2016. The Fund has suspended distributions and continues to conserve cash to provide for the continued development of the Beta Project. See “Results of Operations” under this Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Quarterly Report for more information on the average oil and natural gas prices received by the Fund during the three and nine months ended September 30, 2017 and 2016 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 offshore waters of the Gulf of Mexico, is provided in the following table.  See “Liquidity Needs” under this Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Quarterly Report for information regarding the funding of the Fund’s capital commitments.

10

		Total Spent		Total
	Working	through		Fund
Project	Interest	September 30, 2017		Budget		Status
		(in thousands)
Producing Properties
Beta Project	2.25%	$	18,464	$	21,141	The Beta Project is expected to include the development of five wells.  Wells #1 and #2 commenced production during third quarter 2016 and fourth quarter 2016, respectively.  Wells #3  and #4 commenced production during second  quarter 2017 and  third quarter 2017, respectively. Well #5 began drilling in third quarter 2017 and is expected to commence production in first quarter 2018. The Fund expects to spend $1.7 million for additional development costs and $1.0 million for asset retirement obligations.
Liberty Project	2.0%	$	3,004	$	3,445	The Liberty Project, a single-well project, commenced production in 2010.  After various shut-ins in late-2015 and early-2016, due to third-party facilities' repair and maintenance activities, the well resumed production in early-May 2016.  The well was shut-in again in late-June 2017 due to gas dehydration unit work, resuming production in late-September 2017. The operator is currently flowing the well's current zone together with the behind-pipe zone at no cost to the Fund.  The Fund expects to spend $0.4 million for asset retirement obligations.

 Results of Operations

The following table summarizes the Fund’s results of operations during the three and nine months ended September 30, 2017 and 2016, 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 September 30,						Nine months ended September 30,
	2017			2016			2017			2016
	(in thousands)
Revenue
Oil and gas revenue	$	872		$	232		$	2,999		$	350
Expenses
Depletion and amortization		445			171			2,895			247
Operating expenses		183			129			556			194
General and administrative expenses		61			60			192			174
Total expenses		689			360			3,643			615
Income (loss) from operations		183			(128	)		(644	)		(265	)
Interest expense, net		(133	)		(86	)		(398	)		(85	)
Net income (loss)	$	50		$	(214	)	$	(1,042	)	$	(350	)

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Overview.  The following table provides information related to the Fund’s oil and gas production and oil and gas revenue during the three and nine months ended September 30, 2017 and 2016.  Natural gas liquid (“NGL”) sales are included within gas sales.

	Three months ended September 30,				Nine months ended September 30,
	2017		2016		2017		2016
Number of wells producing		5		2		5		2
Total number of production days		280		117		859		190
Oil sales (in thousands of barrels)		20		5		63		7
Average oil price per barrel	$	43	$	40	$	43	$	39
Gas sales (in thousands of mcfs)		23		9		80		14
Average gas price per mcf	$	3.62	$	2.38	$	3.37	$	1.99

The increases in the above table were primarily related to the commencement of production of four wells in the Beta Project, two wells during the second half of 2016 and two wells during 2017, partially offset by the Liberty Project, which was shut-in during the majority of third quarter 2017.  See additional discussion in “Business Update” section above.

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

Oil and gas revenue during the three months ended September 30, 2017 was $0.9 million, an increase of $0.6 million from the three months ended September 30, 2016. The increase was attributable to increased sales volume totaling $0.6 million coupled with increased oil and gas prices totaling $0.1 million.

Oil and gas revenue during the nine months ended September 30, 2017 was $3.0 million, an increase of $2.6 million from the nine months ended September 30, 2016. The increase was attributable to increased sales volume totaling $2.3 million coupled with increased oil and gas prices totaling $0.4 million.

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

Depletion and Amortization.  Depletion and amortization during the three months ended September 30, 2017 was $0.4 million, an increase of $0.3 million from the three months ended September 30, 2016.  The increase was attributable to an increase in production volumes totaling $0.5 million, partially offset by a decrease in the average depletion rate totaling $0.2 million.  The decrease in the average depletion rate was primarily attributable the Liberty Project, which was shut-in during the majority of third quarter 2017.

Depletion and amortization during the nine months ended September 30, 2017 was $3.0 million, an increase of $2.6 million from the nine months ended September 30, 2016.  The increase was attributable to an increase in production volumes totaling $1.4 million coupled with an increase in the average depletion rate totaling $1.4 million, partially offset by an adjustment to the asset retirement obligation related to a fully depleted property totaling $0.1 million. The increase in the average depletion rate was primarily attributable to the onset of production of the Beta Project.

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

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

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	Three months ended September 30,				Nine months ended September 30,
	2017		2016		2017		2016
	(in thousands)
Lease operating expense	$	109	$	61	$	351	$	99
Insurance expense		48		58		118		74
Transportation and processing expense		14		-		32		-
Accretion expense		7		-		23		-
Workover expense and other		5		10		32		21
	$	183	$	129	$	556	$	194

Lease operating expense and transportation and processing expense, relates to the Fund’s producing properties. Insurance expense represents premiums related to the Fund’s properties, which vary depending upon the number of wells producing or drilling. Accretion expense relates to the asset retirement obligations established for the Fund’s proved properties. Workover expense represents costs to restore or stimulate production of existing reserves.

The average production cost, which includes lease operating expense, transportation and processing expense and insurance expense, was $7.27 per barrel of oil equivalent (“BOE”) and $6.58 per BOE during the three and nine months ended September 30, 2017, respectively, compared to $17.48 per BOE and $17.57 per BOE during the three and nine months ended September 30, 2016, respectively. The decreases were primarily attributable to the Beta Project, which commenced production in third quarter 2016, and has lower cost per BOE as compared to the Liberty Project due to the processing of production through its standalone facility. The production costs per BOE may decline over time as throughput increases from the project or other projects expected to tie-in to the facility.

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

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

Capital Resources and Liquidity

Operating Cash Flows

Cash flows provided by operating activities during the nine months ended September 30, 2017 were $1.9 million, related to revenue received of $3.1 million, partially offset by operating expenses of $0.9 million, general and administrative expenses of $0.2 million and settlements of asset retirement obligations of $0.1 million.

Cash flows used in operating activities during the nine months ended September 30, 2016 were $0.2 million, related to operating expenses of $0.2 million and general and administrative expenses of $0.2 million, partially offset by revenue received of $0.2 million.

Investing Cash Flows

Cash flows used in investing activities during the nine months ended September 30, 2017 were $2.1 million, primarily related to capital expenditures for oil and gas properties.

Cash flows used in investing activities during the nine months ended September 30, 2016 were $2.6 million, related to capital expenditures for oil and gas properties of $1.7 million and investments in salvage fund of $0.9 million.

Financing Cash Flows

Cash flows used in financing activities during the nine months ended September 30, 2017 were $0.3 million, related to repayments of long-term borrowings.

Cash flows provided by financing activities during the nine months ended September 30, 2016 were $0.7 million, related to proceeds from long-term borrowings.

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Estimated Capital Expenditures

Capital Commitments

The Fund has entered into multiple agreements for the acquisition, drilling and development of its oil and gas properties. The estimated capital expenditures associated with these agreements vary depending on the stage of development on a property-by-property basis.  See “Business Update” under this Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Quarterly Report for information regarding the Fund’s current projects. See “Liquidity Needs” below for additional information.

Capital expenditures for oil and gas properties have been funded with the capital raised by the Fund in its private placement offering, and in certain circumstances, through debt financing.  The Fund’s remaining capital has been fully allocated to complete its projects. As a result, the Fund will not invest in any new projects and will limit its investment activities, if any, to those projects in which it currently has a working interest.

Liquidity Needs

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

As of September 30, 2017, the Fund’s estimated capital commitments related to its oil and gas properties were $3.4 million (which include asset retirement obligations for the Fund’s projects of $1.8 million), of which $1.6 million is expected to be spent during the next twelve months primarily related to the additional development costs for the Beta Project. As a result of continued development of the Beta Project, the Fund has experienced negative cash flows for the nine months ended September 30, 2017.  Additionally, current liabilities exceed current assets as of September 30, 2017.  Future results of operations and cash flows are dependent on the continued successful development and the related production of oil and gas revenues from the Beta Project. Based upon its current cash position and its current reserve estimates, the Fund expects cash flow from operations to be sufficient to cover its commitments, borrowing repayments, as well as ongoing operations. Reserve estimates are projections based on engineering data that cannot be measured with precision, require substantial judgment, and are subject to frequent revision. However, if cash flow from operations is not sufficient to meet the Fund’s commitments, the Manager will provide short-term financing to accommodate the Fund’s short-term commitments if needed.

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

Credit Agreement

In November 2012, the Fund entered into a credit agreement (as amended on September 30, 2016 and September 15, 2017, the “Credit Agreement”) to provide capital toward the funding of the Fund’s share of development costs on the Beta Project.  As of September 30, 2017 and December 31, 2016, the Fund had borrowings of $5.1 million and $5.4 million, respectively, under the Credit Agreement. As of December 31, 2016, in accordance with the terms of the Credit Agreement, there are no additional borrowings available to the Fund.

The loan bears interest at 8% compounded annually. Monthly principal and interest payments are the lesser of the Monthly Fixed Amount or the Debt Service Cap amount, as defined in the Credit Agreement, until the loan is repaid in full, in no event later than December 31, 2020. The Fund expects operating income from the Beta Project to be sufficient to cover the principal and interest payments required under the Credit Agreement. The loan may be prepaid by the Fund without premium or penalty.

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

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The Credit Agreement contains customary negative covenants including covenants that limit the Fund’s ability to, among other things, grant liens, change the nature of its business, or merge into or consolidate with other persons. The events which constitute events of default are also customary for credit facilities of this nature and include payment defaults, breaches of representations, warrants and covenants, insolvency and change of control. Upon the occurrence of a default, in some cases following a notice and cure period, the lenders under the Credit Agreement may accelerate the maturity of the loan and require full and immediate repayment of all borrowings under the Credit Agreement. The Fund believes it is in compliance with all covenants under the Credit Agreement as of September 30, 2017 and December 31, 2016.

Off-Balance Sheet Arrangements

The Fund had no off-balance sheet arrangements as of September 30, 2017 and December 31, 2016 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 September 30, 2017 and December 31, 2016, 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 September 30, 2017.

There has been no change in the Fund’s internal control over financial reporting that occurred during the three months ended September 30, 2017 that has materially affected, or is reasonably likely to materially affect, the Fund’s internal control over financial reporting.

PART II – OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

None.

ITEM 1A. RISK FACTORS

Not required.

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

None.

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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
10.3	Second Amendment to Credit Agreement and Reaffirmation of Waiver dated September 15, 2017 by and among Ridgewood Energy O Fund, LLC, Ridgewood Energy Q Fund, LLC, Ridgewood Energy S Fund, LLC, Ridgewood Energy T Fund, LLC, Ridgewood Energy V Fund, LLC, Ridgewood Energy W Fund, LLC, Ridgewood Energy A-1 Fund, LLC, Ridgewood Energy B-1 Fund, LLC, Rahr Energy Investments LLC, as Administrative Agent, and certain Lenders party thereto	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

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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 Q FUND, LLC
Dated:	November 9, 2017	By:	/s/	ROBERT E. SWANSON
			Name:	Robert E. Swanson
			Title:	Chief Executive Officer
				(Principal Executive Officer)
Dated:	November 9, 2017	By:	/s/	KATHLEEN P. MCSHERRY
			Name:	Kathleen P. McSherry
			Title:	Executive Vice President and Chief Financial Officer
				(Principal Financial and Accounting Officer)

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