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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended September 30, 2025

¨	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. 000-52583

Ridgewood Energy U Fund, LLC

(Exact name of registrant as specified in its charter)

Delaware

(State or other jurisdiction of

incorporation or organization)

20-5464059

(I.R.S. Employer

Identification No.)

103 Foulk Road, Wilmington, DE 19803

(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 ¨

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 ¨

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	¨	Accelerated filer	¨
Non-accelerated filer	x	Smaller reporting company	x
		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 Exchange Act. ¨

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

As of November 4, 2025, there were 486.4825 shares of LLC Membership Interest outstanding.

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			PAGE
PART I - FINANCIAL INFORMATION
Item 1.	Financial Statements		1
		Unaudited Condensed Balance Sheets as of September 30, 2025 and December 31, 2024	1
		Unaudited Condensed Statements of Operations for the three and nine months ended September 30, 2025 and 2024	2
		Unaudited Condensed Statements of Changes in Members’ Capital for the nine months ended September 30, 2025 and 2024	3
		Unaudited Condensed Statements of Cash Flows for the nine months ended September 30, 2025 and 2024	4
		Notes to Unaudited Condensed Financial Statements	5
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		11
Item 3.	Quantitative and Qualitative Disclosures About Market Risk		16
Item 4.	Controls and Procedures		17

PART II - OTHER INFORMATION
Item 1.	Legal Proceedings		18
Item 1A.	Risk Factors		18
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		18
Item 3.	Defaults Upon Senior Securities		18
Item 4.	Mine Safety Disclosures		18
Item 5.	Other Information		18
Item 6.	Exhibits		19

	SIGNATURES		20

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PART I – FINANCIAL INFORMATION

ITEM 1.

FINANCIAL STATEMENTS

RIDGEWOOD ENERGY U FUND, LLC

UNAUDITED CONDENSED BALANCE SHEETS

(in thousands, except share data)


	September 30, 2025			December 31, 2024
Assets
Current assets:
Cash and cash equivalents	$	1,145		$	1,890
Salvage fund		263			43
Production receivable		269			245
Other current assets		610			17
Total current assets		2,287			2,195
Salvage fund		1,652			1,787
Investment in Delta House		119			119
Oil and gas properties:
Advances to operators for capital expenditures		3			-
Proved properties		11,496			11,136
Less: accumulated depletion and amortization		(8,950	)		(8,497	)
Total oil and gas properties, net		2,549			2,639
Total assets	$	6,607		$	6,740

Liabilities and Members' Capital
Current liabilities:
Due to operators	$	86		$	40
Accrued expenses		56			60
Asset retirement obligations		263			43
Total current liabilities		405			143
Asset retirement obligations		1,337			1,588
Total liabilities		1,742			1,731
Commitments and contingencies (Note 3)
Members' capital:
Manager:
Distributions		(4,467	)		(4,342	)
Retained earnings		3,736			3,572
Manager's total		(731	)		(770	)
Shareholders:
Capital contributions (1,000 shares authorized; 486.4825 issued and outstanding)		72,381			72,381
Syndication costs		(8,541	)		(8,541	)
Distributions		(27,605	)		(26,896	)
Accumulated deficit		(30,639	)		(31,165	)
Shareholders' total		5,596			5,779
Total members' capital		4,865			5,009
Total liabilities and members' capital	$	6,607		$	6,740

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

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RIDGEWOOD ENERGY U FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF OPERATIONS

(in thousands, except per share data)


	Three months ended September 30,					Nine months ended September 30,
	2025			2024		2025		2024
Revenue
Oil and gas revenue	$	591		$	804	$	1,933	$	2,581
Expenses
Depletion and amortization		164			148		465		472
Operating expenses		370			166		678		542
Management fees to affiliate (Note 2)		-			-		-		56
General and administrative expenses		61			58		196		160
Total expenses		595			372		1,339		1,230
(Loss) income from operations		(4	)		432		594		1,351
Other income
Dividend income		4			5		14		13
Interest income		28			33		82		90
Total other income		32			38		96		103
Net income	$	28		$	470	$	690	$	1,454

Manager Interest
Net income	$	25		$	87	$	164	$	275

Shareholder Interest
Net income	$	3		$	383	$	526	$	1,179
Net income per share	$	6		$	787	$	1,081	$	2,425

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

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RIDGEWOOD ENERGY U FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF CHANGES

IN MEMBERS’ CAPITAL

(in thousands, except share data)


	Nine months ended September 30, 2025
	# of Shares		Manager			Shareholders			Total
Balances, December 31, 2024	-	486.4825	$	(770	)	$	5,779		$	5,009
Distributions		-		(30	)		(167	)		(197	)
Net income	-	-		74			287			361
Balances, March 31, 2025	-	486.4825	$	(726	)	$	5,899		$	5,173
Distributions		-		(58	)		(328	)		(386	)
Net income	-	-		65			236			301
Balances, June 30, 2025	-	486.4825	$	(719	)	$	5,807		$	5,088
Distributions		-		(37	)		(214	)		(251	)
Net income	-	-		25			3			28
Balances, September 30, 2025	-	486.4825	$	(731	)	$	5,596		$	4,865

	Nine months ended September 30, 2024
	# of Shares		Manager			Shareholders			Total
Balances, December 31, 2023	-	486.4825	$	(888	)	$	5,730		$	4,842
Distributions		-		(30	)		(173	)		(203	)
Net income	-	-		78			327			405
Balances, March 31, 2024	-	486.4825	$	(840	)	$	5,884		$	5,044
Distributions		-		(76	)		(430	)		(506	)
Net income	-	-		110			469			579
Balances, June 30, 2024	-	486.4825	$	(806	)	$	5,923		$	5,117
Distributions		-		(76	)		(429	)		(505	)
Net income	-	-		87			383			470
Balances September 30, 2024	-	486.4825	$	(795	)	$	5,877		$	5,082

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

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RIDGEWOOD ENERGY U FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF CASH FLOWS

(in thousands)


	Nine months ended September 30,
	2025			2024

Cash flows from operating activities
Net income	$	690		$	1,454
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion and amortization		465			472
Accretion expense		50			25
Changes in assets and liabilities:
(Increase) decrease in production receivable		(24	)		20
Increase in other current assets		(7	)		(13	)
Increase (decrease) in due to operators		15			(35	)
(Decrease) increase in accrued expenses		(4	)		15
Settlement of asset retirement obligations		(176	)		(2	)
Net cash provided by operating activities		1,009			1,936

Cash flows from investing activities
Advance payments to operators for capital expenditures for oil and gas properties		(3	)		-
(Capital expenditures) credits for oil and gas properties		(1,339	)		39
Proceeds from insurance recovery		507			-
Proceeds from salvage fund		179			2
Increase in salvage fund		(264	)		(153	)
Net cash used in investing activities		(920	)		(112	)

Cash flows from financing activities
Distributions		(834	)		(1,214	)
Net cash used in financing activities		(834	)		(1,214	)

Net (decrease) increase in cash and cash equivalents		(745	)		610
Cash and cash equivalents, beginning of period		1,890			1,104
Cash and cash equivalents, end of period	$	1,145		$	1,714

Supplemental disclosure of non-cash investing activities
Advances used for capital expenditures in oil and gas properties reclassified to proved properties	$	-		$	103
Due to operators for accrued capital expenditures for oil and gas properties	$	31		$	-

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

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RIDGEWOOD ENERGY U FUND, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

Organization and Summary of Significant Accounting Policies

Organization

The Ridgewood Energy U Fund, LLC (the “Fund”), a Delaware limited liability company, was formed on August 28, 2006 and operates pursuant to a limited liability company agreement (the “LLC Agreement”) dated as of October 1, 2006 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 America.

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 and 3.

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, 2024 financial statements and notes thereto included in the Fund’s Annual Report on Form 10-K (“2024 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, 2024, 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, management 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 2024 Annual Report. There have been no significant changes to the Fund’s significant accounting policies during the three and nine months ended September 30, 2025.

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 assets and liabilities consist of cash and cash equivalents, salvage fund, production receivable, other current assets, investment in Delta House, due to operators and accrued expenses. Except for investment in Delta House, the carrying amounts of these financial assets and liabilities approximate fair value due to their short-term nature.

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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 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.

Other Current Assets

Other current assets as of September 30, 2025 and December 31, 2024 consist of the following:

Schedule of other current assets
	September 30, 2025		December 31, 2024
	(in thousands)
Insurance receivable	$	587	$	-
Prepaid insurance		23		17
	$	610	$	17

The insurance receivable relates to the insurance claim on Marmalard well #5’s sidetrack operation that began in March 2025 and was completed in August 2025. The sidetrack operation was needed to resume the well’s production due to a downhole mechanical failure that occurred after the well was completed in 2024. During the nine months ended September 30, 2025, the Fund received proceeds from the insurance claim totaling $0.5 million, which was presented as “Proceeds from insurance recovery” within the investing section of the Fund’s statement of cash flows. The Fund expects to receive the remaining insurance proceeds during fourth quarter 2025.

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 Murphy Exploration & Production Company - USA. 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. During each of the three and nine months ended September 30, 2025 and 2024, 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. The following table presents changes in asset retirement obligations for the following periods:

Schedule of changes in asset retirement obligations
	Nine months ended September 30,
	2025			2024
	(in thousands)
Balance, beginning of period	$	1,631		$	1,149
Liabilities settled		(176	)		(2	)
Accretion expense		50			25
Revision of estimates		95			19
Balance, end of period	$	1,600		$	1,191

Revenue Recognition

Oil and gas revenues from contracts with customers are recognized at the point when control of oil and natural gas is transferred to the customers in accordance with Accounting Standard Codification Topic 606, Revenue from Contracts with Customers. Revenues from the sale of natural gas liquid are included within gas revenues. 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.

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The Fund also has an estimation process for revenue and related accruals, and any identified difference between its revenue estimates and actual revenue historically have not been significant. During each of the three and nine months ended September 30, 2025 and 2024, revenue recognized from performance obligations satisfied in previous periods was not significant.

Allowance for Credit Losses

The Fund is exposed to credit losses through the sale of oil and natural gas to customers. However, the Fund only sells to a small number of major oil and gas companies that have investment-grade credit ratings. Based on historical collection experience, current and future economic and market conditions and a review of the current status of customers' production receivables, the Fund has not recorded an expected loss allowance as there are no past due receivable balances or projected credit losses.

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 its oil and gas properties may not be recoverable. Recoverability is evaluated by comparing estimated future net undiscounted cash flows to the carrying value of the oil and gas properties at the time of the review. If the carrying value exceeds the estimated future net undiscounted cash flows, the carrying value of the oil and gas properties is impaired, and written down to fair value. Fair value 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, estimates of oil and gas reserves and future development costs or discount rates could result in a significant impact on the amount of impairment.

There were no impairments of oil and gas properties during each of the three and nine months ended September 30, 2025 and 2024. Fluctuations in oil and natural gas commodity prices may impact the fair value of the Fund’s oil and gas properties. In addition, significant declines in oil and natural gas commodity prices could reduce the quantities of reserves that are commercially recoverable, which could result in impairment.

Recent Accounting Pronouncements

In November 2024, the Financial Accounting Standards Board issued accounting guidance on the required disaggregated disclosures of certain costs and expenses on the statement of operations on an annual and interim basis. The accounting guidance is effective for the Fund for the year ending December 31, 2027 and for interim periods beginning in 2028 with early adoption permitted. The accounting guidance should be applied on a prospective basis, but retrospective application is also permitted. The Fund evaluated the effect of this accounting guidance on the Fund’s disclosures and determined it has no impact as the Fund’s only relevant expense line item is “Depletion and amortization”, which is already presented separately on the Fund’s statements of operations.

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 well costs incurred by the Fund and fully depleted project investments. In 2012, the Manager elected to reduce its management fee to 1% annually, however, the Manager is still permitted to waive all or a portion of the reduced management fee at its own discretion. Therefore, all or a portion of the management fee may be temporarily waived to accommodate the Fund’s short-term commitments. There were no management fees during the three and nine months ended September 30, 2025. Effective April 1, 2024, 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 on the statements of operations within general and administrative expenses. Management reimbursement costs during the three and nine months ended September 30, 2025 were $20 thousand and $60 thousand, respectively. Management reimbursement costs during the three and nine months ended September 30, 2024 were $20 thousand and $40 thousand, respectively, as there were no management fees during the three months ended September 30, 2024. Management fees during the nine months ended September 30, 2024 were $0.1 million.

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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 nine months ended September 30, 2025 were $37 thousand and $0.1 million, respectively. Distributions paid to the Manager during the three and nine months ended September 30, 2024 were $0.1 million and $0.2 million, respectively.

The Fund utilizes DH 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 Diller and Marmalard projects.

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.

Commitments and Contingencies

Capital Commitments

As of September 30, 2025, the Fund’s estimated capital commitments related to its oil and gas properties were $3.2 million (which include asset retirement obligations for the Fund’s projects of $2.3 million), of which $0.4 million is expected to be spent during the next twelve months. Future results of operations and cash flows are dependent on the revenues from production and sale of oil and natural gas from the Fund’s producing projects.

Based upon its current cash position, salvage fund and its current reserves estimates, the Fund expects cash flow from operations to be sufficient to cover its commitments and ongoing operations. Reserves estimates are projections based on engineering data that cannot be measured with precision, require substantial judgment, and are subject to frequent revision.

Impact from Market Conditions

Although briefly spiking in June 2025 related to the war between Israel and Iran, oil prices have softened so far throughout 2025. The movement in oil prices reflected the rolling back of production cuts by OPEC Plus and continued uncertainty about the near-term impact of the Trump Administration’s trade policies. The markets have been extremely volatile with the prospect that tariffs will remain a cornerstone of President Trump’s economic and foreign policy for the remainder of his term. While oil prices are generally correlated to global economic activity, geopolitics is also a huge factor for the crude market, and the Trump Administration is taking an increasingly hawkish stance towards key crude exporters, such as Russia, Iran and Venezuela. The impact of these issues on global financial and commodity market oil and natural gas prices and their corresponding effect on the Fund remains uncertain.

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, 2025 and December 31, 2024, 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.

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BSEE and BOEM Supplemental Financial Assurance Requirements

On October 16, 2020, the Bureau of Ocean Energy Management (“BOEM”) and the Bureau of Safety and Environmental Enforcement (“BSEE”) published a proposed new rule entitled “Risk Management, Financial Assurance and Loss Prevention” to update BOEM’s financial assurance criteria and other BSEE-administered regulations. Upon review of the 2020 joint proposed rule and analysis of public comments, the Secretary of the U.S. Department of the Interior (“Interior”) elected to separate the BOEM and BSEE portions of the supplemental bonding requirements. BSEE finalized some provisions from the 2020 proposal as discussed below. BOEM rescinded its portion of the 2020 proposed rule and issued its new rule below.

On April 18, 2023, BSEE published a final rule at 88 FR 23569 on Risk Management, Financial Assurance and Loss Prevention effective May 18, 2023 to clarify and formalize its regulations related to decommissioning responsibilities of Outer Continental Shelf (“OCS”) oil, gas, and sulfur lessees and grant holders to ensure compliance with lease, grant, and regulatory obligations. The rule implements provisions of the proposed rule intended to clarify decommissioning responsibilities of right-of-use and easement grant holders and to formalize BSEE's policies regarding performance by predecessors ordered to decommission OCS facilities. The final rule withdraws the proposal set forth in the 2020 proposed rule to amend BSEE's regulations to require BSEE to proceed in reverse chronological order against predecessor lessees, owners of operating rights, and grant holders when requiring such entities to perform their accrued decommissioning obligations if the current lessees, owners, or holders have failed to perform. In addition, BSEE also decided not to finalize the proposed appeal bonding requirements in this final rule.

On April 24, 2024, BOEM published a final rule at 89 FR 31544 on Risk Management and Financial Assurance for OCS Lease and Grant Obligations, effective June 29, 2024. This rule substantially revises the supplemental financial assurance requirements for decommissioning offshore wells and infrastructure once they are no longer in use. The rule establishes a simplified test using only two criteria by which BOEM would determine whether supplemental financial assurance should be required of OCS oil and gas lessees: (1) credit rating, and (2) the ratio of the value of proved oil and gas reserves of the lease to the estimated decommissioning liability associated with the reserves. If a current lessee meets one of these criteria, it will not be required to provide supplemental financial assurance. In addition, as it relates to supplemental financial assurance requirements for OCS oil and gas right-of-use and easement grant holders, BOEM will only consider the first criteria – i.e., credit rating. Under the rule, BOEM would no longer consider or rely upon the financial strength of prior grant holders and lessees in determining whether, or how much, supplemental financial assurance should be provided by the current grant holders and lessees. The rule would allow existing lessees and grant holders to request phased-in payments over three years to meet the new financial assurance amounts. On June 28, 2024, BOEM issued a timeline on its website for implementing the rule. BOEM indicates that it will begin sending out notices to companies to submit financial and property information, to which such companies have six months to respond. BOEM can take up to 18 months from receipt of such information to complete its review and an additional six months thereafter to complete financial assurance demands. Moreover, on June 17, 2024, the States of Louisiana, Texas and Mississippi, along with several industry advocate groups, filed a lawsuit in federal court in Louisiana challenging many parts of the rule and BOEM’s statutory power to issue it. That litigation is ongoing, and a decision on the motion to stay the rule is pending. The Fund has evaluated the impact of the new rule on its operations and increased its estimated asset retirement obligations as of December 31, 2024. The Fund will also continue to maintain the salvage fund, a separate interest-bearing account, to fund its proportionate share of the estimated future costs of decommissioning liabilities for its projects. The Fund will continue to reassess its estimated decommissioning liabilities and reserve for additional funding as necessary.

On May 2, 2025, Interior announced its intent to revise the final rule on Risk Management and Financial Assurance for OCS Lease and Grant Obligations and proceed to issue a new rule consistent with the Trump administration’s 2020 framework. The proposed rule in 2020, among other things, (i) proposed only two evaluation factors (1) a company’s credit rating (or a proxy credit rating if a company does not have a credit rating), and (2) the value of oil and gas reserves; (ii) maintained joint and several responsibility of all current and predecessor lessees; (iii) created reverse chronological order through the chain-of-title to perform decommissioning starting with the most recent predecessor before turning to more remote predecessors in time; and (iv) provided more flexibility in the use of third-party guarantees and decommissioning accounts. Interior anticipates finalizing the new rule in 2025. The Fund is not able to evaluate the impact of a proposed new rule on its operations or financial condition until the final rule is issued or some other definitive action is taken by the Interior or BOEM.

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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Segment Information

The Fund’s operations are managed through a single operating segment. As such, the Fund has only a single reportable segment that derives its revenue from the sale of oil and gas. The Fund’s chief operating decision-maker is the Executive Vice President, Chief Financial Officer and Assistant Secretary of the Fund, who reviews the Fund’s operating results to make decisions about allocating resources and assessing performance for the Fund. The profit or loss metric used to evaluate segment performance is net income; consistent with net income reported on the statement of operations.

The measure of segment assets is reported on the balance sheet as total assets. The following table is a summary of segment information for the three and nine months ended September 30, 2025 and 2024.

Schedule of segment information
	Three months ended September 30,				Nine months ended September 30,
	2025		2024		2025		2024
	(in thousands)
Revenue
Oil and gas revenue	$	591	$	804	$	1,933	$	2,581
Less
Depletion and amortization		164		148		465		472
Lease operating expense		111		118		317		297
Transportation and processing expense		20		25		59		76
Insurance expense		13		8		29		27
Workover expense		209		6		223		117
Management fees to affiliate		-		-		-		56
Other segment items		46		29		150		82
Net income	$	28	$	470	$	690	$	1,454

Other segment items include accretion expense related to the asset retirement obligations established for the Fund’s oil and gas properties, general and administrative expenses representing costs specifically identifiable or allocable to the Fund, such as accounting and professional fees and insurance expenses, net of dividend income related to the Fund’s investment in Delta House and interest income earned on cash and cash equivalents and salvage fund.

The measure of expenditures for segment assets is reported on the statements of cash flows as “(Capital expenditures) credits for oil and gas properties.” Significant noncash items represent “Depletion and amortization” and “Accretion expense” as reported on the statements of cash flows.

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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 U 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. Such forward-looking statements 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 the impact on the Fund’s business and operations of any future widespread health emergencies or public health crises such as pandemics and epidemics, 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, the military conflicts between Russia and Ukraine and Israel and Iran (and proxies) and the global response to such conflicts, acts of terrorism 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, 2024.

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 America. 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 receive an annual management fee, payable monthly, equal to 1% of the total capital contributions made by the Fund’s shareholders, net of cumulative dry-hole well costs incurred by the Fund and fully depleted project investments. Effective April 1, 2024, 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.

Market Conditions

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Commodity Price Changes

Changes in oil and natural gas commodity prices may significantly affect liquidity and expected operating results. Significant 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 and higher depletion rates.

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 nine months ended September 30, 2025 and 2024 and the effect of such average prices on the Fund’s results of operations.

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:

worldwide economic, political and social conditions impacting the global supply and demand for oil and natural gas, which may be driven by various risks, including war (such as the invasion of Ukraine by Russia and the evolving Israel-Iran (and proxies) conflict), terrorism, political unrest, or health epidemics;

weather conditions;

economic conditions, including the impact of continued inflation and associated changes in monetary and trade policies and demand for petroleum-based products;

actions by OPEC Plus, the Organization of the Petroleum Exporting Countries and other state-controlled oil companies;

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

governmental regulations (inclusive of impacts of climate change), 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.

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Business Update

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

		Total Spent
	Working	through		Total Fund
Project	Interest	September 30, 2025		Budget		Status
		(in thousands)

Diller Project	0.88%	$	3,776	$	4,289	The Diller Project includes the development of two wells. Well #1 and Well #2 commenced production in 2015 and 2019, respectively. Well #1 is currently producing. Well #2 was permanently shut-in during 2023 and did not resume production. The Fund expects to spend $0.5 million for asset retirement obligations.
Marmalard Project	0.84%	$	7,087	$	8,981	The Marmalard Project is expected to include the development of five wells. Four wells commenced production in 2015. Well #2 was shut-in since first quarter 2024 due to a mechanical issue. During third quarter 2025 a workover operation could not restore production from this well and it is currently undergoing plug and abandonment operations. Well #5, which commenced production in early January 2024 and was shut-in due to a downhole mechanical failure, returned to production in late August 2025 after a sidetrack operation was completed. The Fund expects to spend $0.9 million for additional development costs and $1.0 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, 2025 and 2024, 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,
	2025			2024		2025		2024
	(in thousands)
Revenue
Oil and gas revenue	$	591		$	804	$	1,933	$	2,581
Expenses
Depletion and amortization		164			148		465		472
Operating expenses		370			166		678		542
Management fees to affiliate		-			-		-		56
General and administrative expenses		61			58		196		160
Total expenses		595			372		1,339		1,230
(Loss) income from operations		(4	)		432		594		1,351
Other income
Dividend income		4			5		14		13
Interest income		28			33		82		90
Total other income		32			38		96		103
Net income	$	28			470	$	690		1,454

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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 nine months, ended September 30, 2025 and 2024. Natural gas liquid sales are included within gas sales.

	Three months ended September 30,				Nine months ended September 30,
	2025		2024		2025		2024
Number of wells producing		5		4		5		6
Total number of production days		338		368		1,057		1,123
Oil sales (in thousands of barrels)		9		10		27		31
Average oil price per barrel	$	64	$	75	$	67	$	78
Gas sales (in thousands of mcfs)		17		21		51		69
Average gas price per mcf	$	3.27	$	2.86	$	3.60	$	2.84

The decreases noted in the table above primarily related to the Marmalard Project. One well in the Marmalard Project was shut-in due to mechanical issues; production from this well could not be restored during a workover operation and the well is currently undergoing plug and abandonment operations. A second Marmalard well, which was shut in since early 2024, underwent a sidetrack operation, and production commenced in late August 2025. See additional discussion in the “Business Update” section above.

Oil and Gas Revenue. Oil and gas revenue during the three months ended September 30, 2025 was $0.6 million, a decrease of $0.2 million from the three months ended September 30, 2024. The decrease was primarily attributable to decreased sales volume totaling $0.1 million coupled with decreased oil prices totaling $0.1 million.

Oil and gas revenue during the nine months ended September 30, 2025 was $1.9 million, a decrease of $0.6 million from the nine months ended September 30, 2024. The decrease was primarily attributable to decreased sales volume totaling $0.4 million coupled with decreased oil prices totaling $0.3 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, 2025 was $0.2 million. Depletion and amortization was relatively consistent during the three months ended September 30, 2025 compared to the three months ended September 30, 2024.

Depletion and amortization during the nine months ended September 30, 2025 was $0.5 million, a decrease of $7 thousand from the nine months ended September 30, 2024. The decrease was primarily attributable to a decrease in production volumes totaling $0.1 million, partially offset by an increase in the average depletion rate totaling $0.1 million. The increase in the average depletion rate was primarily attributable to the changes in reserves estimates provided annually by the Fund’s independent petroleum engineers.

See “Overview” above for certain factors that impact the depletion and amortization volume and rate variances.

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

	Three months ended September 30,				Nine months ended September 30,
	2025		2024		2025		2024
	(in thousands)
Lease operating expense	$	111	$	118	$	317	$	297
Workover expense		209		6		223		117
Transportation and processing expense		20		25		59		76
Accretion expense		17		9		50		25
Insurance expense		13		8		29		27
	$	370	$	166	$	678	$	542

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 nine months ended September 30, 2025, workover expense primarily related to mechanical issues in the Marmalard Project. Accretion expense relates to the asset retirement obligations established for the Fund’s oil and gas properties. Insurance expense represents premiums related to the Fund’s projects, which vary depending upon the number of wells producing or drilling.

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Production costs, which include lease operating expense, transportation and processing expense and insurance expense, were $0.1 million ($12.52 per barrel of oil equivalent or “BOE”) and $0.4 million ($11.55 per BOE) during the three and nine months ended September 30, 2025, respectively, compared to $0.2 million ($11.24 per BOE) and $0.4 million ($9.51 per BOE) during the three and nine months ended September 30, 2024, respectively.

Production costs were relatively consistent during the three and nine months ended September 30, 2025 compared to the three and nine months ended September 30, 2024. The increases in production costs per BOE during the three and nine months ended September 30, 2025 compared to the three and nine months ended September 30, 2024 were primarily attributable to the Diller Project, which had higher production costs per BOE during the three and nine months ended September 30, 2025 due to increased chemical costs incurred to remediate and prevent hydrates.

See “Overview” above for factors that impact oil and natural gas production.

Management Fees to Affiliate. An annual management fee, totaling 1% of total capital contributions, net of cumulative dry-hole well costs incurred by the Fund and fully depleted project investments, was paid monthly to the Manager during the first quarter 2024. Effective April 1, 2024, the Fund began recording costs related to services provided by the Manager for accounting and investor relations. Such costs are included within general and administrative expenses.

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. Management reimbursement costs related to services provided by the Manager for accounting and investor relations are included within general and administrative expenses.

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

Interest Income. Interest income is comprised of interest 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, 2025 were $1.0 million, primarily related to revenue received of $1.9 million and interest income received of $0.1 million, partially offset by operating expenses of $0.6 million, general and administrative expenses of $0.2 million and the settlement of asset retirement obligations of $0.2 million.

Cash flows provided by operating activities during the nine months ended September 30, 2024 were $1.9 million, primarily related to revenue received of $2.6 million and interest income received of $0.1 million, partially offset by operating expenses of $0.6 million, general and administrative expenses of $0.2 million and management fees of $0.1 million.

Investing Cash Flows

Cash flows used in investing activities during the nine months ended September 30, 2025 were $0.9 million, related to capital expenditures for oil and gas properties of $1.3 million, inclusive of advances, and investments in salvage fund of $0.3 million, partially offset by proceeds from insurance recovery of $0.5 million and proceeds from the salvage fund of $0.2 million.

Cash flows used in investing activities during the nine months ended September 30, 2024 were $0.1 million, primarily related to investments in salvage fund of $0.2 million.

Financing Cash Flows

Cash flows used in financing activities during the nine months ended September 30, 2025 were $0.8 million, related to manager and shareholder distributions.

Cash flows used in financing activities during the nine months ended September 30, 2024 were $1.2 million, related to manager and shareholder distributions.

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Capital Expenditures

Capital expenditures for oil and gas properties have been funded with the capital raised by the Fund in its private placement offering. The Fund’s capital has been fully invested and 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. Such investment activities, which include estimated capital spending on planned well recompletions and ongoing development of the Fund’s producing projects, are expected to be funded from cash flows from operations and existing cash-on-hand and not from equity, debt or off-balance sheet financing arrangements.

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 and long-term liquidity needs are to fund its operations and capital expenditures for its oil and gas properties. Such needs are funded utilizing operating income and existing cash on-hand.

In addition, cash flow from operations may be impacted by fluctuations in oil and natural gas commodity prices. Based upon its current cash position, salvage fund and its current reserves estimates, the Fund expects cash flow from operations to be sufficient to cover its commitments and ongoing operations. Reserves estimates are projections based on engineering data that cannot be measured with precision, require substantial judgment, and are subject to frequent revision.

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. However, distributions may be impacted by amounts of future capital required for the ongoing development of the Fund’s producing projects, as budgeted, as well as the funding of estimated asset retirement obligations. Distributions may also be impacted by fluctuations in oil and natural gas commodity prices.

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, 2025 and December 31, 2024, other than those discussed in “Capital Expenditures” 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.

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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 President and Partner 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 President and Partner and Chief Financial Officer concluded that the Fund’s disclosure controls and procedures were effective as of September 30, 2025.

There has been no change in the Fund’s internal control over financial reporting that occurred during the three months ended September 30, 2025 that has materially affected, or is reasonably likely to materially affect, the Fund’s internal control over financial reporting.

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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.

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ITEM 6.

EXHIBITS

EXHIBIT NUMBER	TITLE OF EXHIBIT	METHOD OF FILING

31.1	Certification of Niloy Shah, President and Partner of the Fund, pursuant to Exchange Act Rule 13a-14(a)	Filed herewith

31.2	Certification of Kathleen P. McSherry, Executive Vice President, Chief Financial Officer and Assistant Secretary 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 Niloy Shah, President and Partner of the Fund and Kathleen P. McSherry, Executive Vice President, Chief Financial Officer and Assistant Secretary of the Fund	Filed herewith

101.INS	Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document	Filed herewith

101.SCH	Inline XBRL Taxonomy Extension Schema	Filed herewith

101.CAL	Inline XBRL Taxonomy Extension Calculation Linkbase	Filed herewith

101.DEF	Inline XBRL Taxonomy Extension Definition Linkbase Document	Filed herewith

101.LAB	Inline XBRL Taxonomy Extension Label Linkbase	Filed herewith

101.PRE	Inline XBRL Taxonomy Extension Presentation Linkbase	Filed herewith

104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)	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 U FUND, LLC

Dated:	November 4, 2025	By:	/s/	NILOY SHAH
			Name:	Niloy Shah
			Title:	President and Partner
				(Principal Executive Officer)


Dated:	November 4, 2025	By:	/s/	KATHLEEN P. MCSHERRY
			Name:	Kathleen P. McSherry
			Title:	Executive Vice President, Chief Financial Officer and Assistant Secretary
				(Principal Financial and Accounting Officer)

Ridgewood Energy U Fund LLC 10-Q