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~~March 3031, ~~2025~~2026

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

Commission File No. 000-53895

Ridgewood Energy A-1 Fund, LLC

(Exact name of registrant as specified in its charter)

Delaware

(State or other jurisdiction of

incorporation or organization)

01-0921132

(I.R.S. Employer

Identification No.)

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

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 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~~May 45, ~~2025~~2026, there were 207.7026 shares of LLC Membership ~~Interest~~ 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 Balance Sheets as of March 31, 2026 and December 31, 2025	1
		Unaudited Condensed Statements of Operations for the three and nine months ended September 30, 2025 and 2024	2
		Unaudited Condensed Statements of Operations for the three months ended March 31, 2026 and 2025	2
		Unaudited Condensed Statements of Changes in Members’ Capital for the nine months ended September 30, 2025 and 2024	3
		Unaudited Condensed Statements of Changes in Members’ Capital for the three months ended March 31, 2026 and 2025	3
		Unaudited Condensed Statements of Cash Flows for the nine months ended September 30, 2025 and 2024	4
		Unaudited Condensed Statements of Cash Flows for the three months ended March 31, 2026 and 2025	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		16
PART II - OTHER INFORMATION
Item 1.	Legal Proceedings		17
Item 1A.	Risk Factors		17
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		17
Item 3.	Defaults Upon Senior Securities		17
Item 4.	Mine Safety Disclosures		17
Item 5.	Other Information		17
Item 6.	Exhibits		18
	SIGNATURES		19

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PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

RIDGEWOOD ENERGY A-1 FUND, LLC

UNAUDITED CONDENSED BALANCE SHEETS

(in thousands, except share data)

	September 30, 2025			December 31, 2024
	March 31, 2026			December 31, 2025
Assets
Current assets:
Cash and cash equivalents	$	~~510~~385		$	~~446~~503
Production receivable		88			136
Salvage fund		1			-
Due from affiliate (Note 2)		12			15
Production receivable		159			75
Other current assets		49			32
Due from affiliate (Note 3)		12			10
Total current assets		659			629
Other current assets		17			32
Salvage fund		2,087			1,940
Total current assets		574			620
Salvage fund		2,184			2,142
Oil and gas properties:
Proved properties		18,~~337~~706			18,~~309~~290
Less: accumulated depletion and amortization		(17,~~138~~313	)		(1617,~~648~~224	)
Total oil and gas properties, net		1,~~199~~393			1,~~661~~066
Total assets	$	34,~~945~~151		$	43,~~230~~828
Liabilities and Members' Capital
Current liabilities:
Due to operators	$	28445		$	1799
Accrued expenses		5851			6068
Total current liabilities		86			77
Asset retirement obligations		1			-
Asset retirement obligations		1,807			1,744
Total current liabilities		497			167
Total liabilities		1,893			1,821
Asset retirement obligations		1,808			1,792
Commitments and contingencies (Note 3)
Total liabilities		2,305			1,959
Commitments and contingencies (Note 4)
Members' capital:
Manager:
Distributions		(6,~~961~~977	)		(6,~~896~~972	)
Retained earnings		8,~~255~~271			8,~~175~~256
Manager's total		1,294			1,~~279~~284
Shareholders:
Capital contributions (250 shares authorized; 207.7026 issued and outstanding)		41,143			41,143
Syndication costs		(4,804	)		(4,804	)
Distributions		(46,~~205~~296	)		(4546,~~834~~265	)
Retained earnings		10,~~624~~509			10,~~625~~511
Shareholders' total		~~758~~552			~~1,130~~585
Total members' capital		21,~~052~~846			21,~~409~~869
Total liabilities and members' capital	$	34,~~945~~151		$	43,~~230~~828

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

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RIDGEWOOD ENERGY A-1 FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF OPERATIONS

(in thousands, except per share data)

	Three months ended September 30,					Nine months ended September 30,
	Three months ended March 31,
	2025			2024		2025			2024
	2026			2025
Revenue
Oil and gas revenue	$	~~277~~225		$	~~467~~381	$	~~996~~		$	~~1,555~~
Other revenue		4329			5355		~~151~~			~~115~~
Total revenue		~~320~~254			~~520~~436		~~1,147~~			~~1,670~~
Expenses
Depletion and amortization		~~145~~89			~~205~~172		~~490~~			~~649~~
Operating expenses		9449			8797		~~289~~			~~256~~
Management fees to affiliate (Note 2)		72			72		217			217
Management fees to affiliate (Note 3)		72			72
General and administrative expenses		4453			3949		~~140~~			~~121~~
Total expenses		~~355~~263			~~403~~390		~~1,136~~			~~1,243~~
(Loss) income from operations		(359	)		~~117~~46		11			~~427~~
Interest income		2422			2722		68			80
Net (loss) income	$	(11	)	$	144	$	79		$	507
Net income	$	13		$	68
Manager Interest
Net income	$	1815		$	4834	$	80		$	~~161~~
Shareholder Interest
Net (loss) income	$	(292	)	$	9634	$	(1	)	$	~~346~~
Net (loss) income per share	$	(~~141~~7	)	$	~~459~~163	$	(5	)	$	~~1,662~~

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

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RIDGEWOOD ENERGY A-1 FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF CHANGES

IN MEMBERS’ CAPITAL

(in thousands, except share data)

	Nine months ended September 30, 2025
	Three months ended March 31,2026
	# of Shares		Manager			Shareholders			Total
Balances, December 31, 2024	-	207.7026	$	1,279		$	1,130		$	2,409
Balances, December 31, 2025	-	207.7026	$	1,284		$	585		$	1,869
Distributions		-		(275	)		(~~153~~31	)		(~~180~~36	)
Net income	-	-		34			34			68
Net income (loss)	-	-		15			(2	)		13
Balances, March 31, 2025	-	207.7026	$	1,286		$	1,011		$	2,297
Balances, March 31, 2026	-	207.7026	$	1,294		$	552		$	1,846
Distributions		-		(16	)		(93	)		(109	)
Net income (loss)	-	-		28			(6	)		22
Balances, June 30, 2025	-	207.7026	$	1,298		$	912		$	2,210
Distributions		-		(22	)		(125	)	$	(147	)
Net income (loss)	-	-		18			(29	)		(11	)
Balances, September 30, 2025	-	207.7026	$	1,294		$	758		$	2,052

	Nine months ended September 30, 2024
		Three months ended March 31,2025
	~~# of Shares~~	# of Shares	~~Manager~~	Manager		~~Shareholders~~	Shareholders		~~Total~~	Total
Balances, December 31, 2023	-	207.7026	$	1,298		$	2,086		$	3,384
Balances, December 31, 2024	-	207.7026	$	1,279		$	1,130		$	2,409
Distributions		-		(6427	)		(~~368~~153	)		(~~432~~180	)
Net income	-	-		4834			9134			~~139~~68
Balances, March 31, 2024	-	207.7026	$	1,282		$	1,809		$	3,091
Balances, March 31, 2025	-	207.7026	$	1,286		$	1,011		$	2,297
Distributions		-		(41	)		(231	)		(272	)
Net income	-	-		65			159			224
Balances, June 30, 2024	-	207.7026	$	1,306		$	1,737		$	3,043
Distributions		-		(67	)		(377	)		(444	)
Net income	-	-		48			96			144
Balances, September 30, 2024	-	207.7026	$	1,287		$	1,456		$	2,743

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

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RIDGEWOOD ENERGY A-1 FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF CASH FLOWS

(in thousands)

	Nine months ended September 30,
	Three months ended March 31,
	2025			2024
	2026			2025
Cash flows from operating activities
Net income	$	7913		$	~~507~~68
Adjustments to reconcile net income to net cash provided by operating activities:
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Depletion and amortization		~~490~~89			~~649~~172
Accretion expense		6321			4121
Changes in assets and liabilities:
Decrease in production receivable		48			94
(Increase) decrease in production receivable		(84	)		14
Decrease (increase) in due from affiliate		3			(7	)
Increase in due from affiliate		(2	)		(8	)
Increase in other current assets		(17	)		(21	)
Decrease in other current assets		15			15
Increase (decrease) in due to operators		11			(18	)
Decrease in due to operators		(56	)		-
(Decrease) increase in accrued expenses		(2	)		15
Decrease in accrued expenses		(17	)		(2	)
Net cash provided by operating activities		675			1,260
Settlement of asset retirement obligation		(4	)		-
Net cash (used in) provided by operating activities		(25	)		280
Cash flows from investing activities
(Capital expenditures) credits for oil and gas properties		(28	)		1
Capital expenditures for oil and gas properties		(14	)		-
Proceeds from salvage fund		-4			~~325~~-
Increase in salvage fund		(~~147~~47	)		(7449	)
Net cash (used in) provided by investing activities		(175	)		252
Net cash used in investing activities		(57	)		(49	)
Cash flows from financing activities
Distributions		(~~436~~36	)		(~~1,148~~180	)
Net cash used in financing activities		(~~436~~36	)		(~~1,148~~180	)
Net increase in cash and cash equivalents		64			364
Net (decrease) increase in cash and cash equivalents		(118	)		51
Cash and cash equivalents, beginning of period		~~446~~503			~~131~~446
Cash and cash equivalents, end of period	$	~~510~~385		$	~~495~~497
Supplemental disclosure of non-cash investing activities
Due to operators for accrued capital expenditures for oil and gas properties	$	402		$	-

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

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RIDGEWOOD ENERGY A-1 FUND, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

Organization and Summary of Significant Accounting Policies

Organization

The Ridgewood Energy A-1 Fund, LLC (the “Fund”), a Delaware limited liability company, was formed on February 3, 2009 and operates pursuant to a limited liability company agreement (the “LLC Agreement”) dated as of March 2, 2009 by and among Ridgewood Energy Corporation (the “Manager”) and the shareholders of the Fund, which addresses matters such as the authority and voting rights of the Manager and shareholders, capitalization, transferability of membership interests, participation in costs and revenues, distribution of assets and dissolution and winding up. The Fund was organized to primarily acquire interests in oil and gas properties located in the United States offshore waters of Texas, Louisiana and Alabama in the Gulf of 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 23 and 34.

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~~2025 financial statements and notes thereto included in the Fund’s Annual Report on Form 10-K (“~~2024~~2025 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~~2025, 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~~2025 Annual Report. There have been no significant changes to the Fund’s significant accounting policies during the three ~~and nine~~ months ended ~~September~~March 3031, ~~2025~~2026.

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, due from affiliate, other current assets, ~~salvage fund,~~ due to operators and accrued expenses. The carrying amounts of these financial assets and liabilities approximate fair value due to their short-term nature. 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.

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Asset Retirement Obligations

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

Revenue Recognition

Oil and gas revenues 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.

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

The Fund also has an estimation process for revenue and related accruals, and any identified difference between its revenue estimates and actual revenue historically have not been significant. During ~~each of~~ the three ~~and nine~~ months ended ~~September~~March 3031, ~~2025~~2026 and ~~2024~~2025, 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.

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There were no impairments of oil and gas properties during ~~each of~~ the three ~~and nine~~ months ended ~~September~~March 3031, ~~2025~~2026 and ~~2024~~2025. 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 (“FASB”) Update No. 2024-3 “Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures (Subtopic 220-40)” 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~~ periods beginning in 2028 with early adoption permitted. The accounting guidance should be applied on a prospective basis, but retrospective ~~application~~ application is also permitted. The Fund evaluated ~~the~~this ~~effect~~standard ofand ~~this~~does ~~accounting~~not ~~guidance~~expect on the ~~Fund’s~~adoption ~~disclosures~~to ~~and~~have ~~determined it~~a ~~has~~material no impact on its consolidated financial statements, 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.

2In December 2025, the FASB Update No. ~~Related~~2025-11 ~~Parties~~“Interim Reporting (Topic 270): Narrow-Scope Improvements” issued accounting guidance to improve the consistency of interim financial reporting by providing a comprehensive list of required interim disclosures and introducing a disclosure principle requiring entities to disclose events since the end of the last annual reporting period that have a material impact on the entity. The accounting guidance is effective for the Fund in the first quarter 2028 with early adoption permitted and can be applied either prospectively or retrospectively. The Fund is currently evaluating the impact of adopting such guidance on its interim disclosures.

~~Pursuant to the terms of the LLC Agreement, the Manager is entitled to receive an annual management fee, payable monthly, of~~ 2.5% ofOil ~~total capital contributions, net of cumulative dry-hole well costs incurred by the Fund~~ and ~~fully~~Gas depleted project investments, however, the Manager is permitted to waive all or a portion of the 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. Management fees during each of the three and nine months ended September 30, 2025 and 2024 were $0.1 million and $0.2 million, respectively.Properties

The Fund, as well as other Funds managed by the Manager, isthat ~~also~~have ~~entitled~~an toownership ~~receive~~interest ~~15%~~in ofthe Beta Project elected not to participate in the ~~cash~~drilling ~~distributions~~of ~~from~~the ~~operations~~5th ~~made~~well proposed by the ~~Fund~~operator Walter Oil and Gas Corporation. ~~Distributions~~As ~~paid~~a result, the Fund was due reimbursement under the terms of the Beta Unit Operating Agreement for a portion of the cost relating to the ~~Manager~~slot ~~during~~on the ~~three~~Beta ~~and~~Project ~~nine~~platform ~~months~~that ~~ended~~was ~~September~~utilized 30by the other participating third-party working interest owners for the 5th well. On January 21, ~~2025~~2026, ~~were~~the ~~$22~~Fund ~~thousand~~received ~~and~~reimbursement for slot related costs of $0.1 million, ~~respectively.~~which ~~Distributions~~was ~~paid~~recorded as a reduction to ~~the~~oil ~~Manager~~and ~~during~~gas properties on the ~~three~~Fund’s ~~and~~balance ~~nine~~sheet ~~months~~as ~~ended~~of ~~September 30~~March 31, ~~2024~~2026 ~~were~~and presented ~~$0.1~~within ~~million~~“Capital expenditures for oil and ~~$0.2~~gas ~~million~~properties” in the investing section of the Fund’s statement of cash flows for the period ended March 31, ~~respectively~~2026.

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, however, the Manager is permitted to waive all or a portion of the 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. Management fees during each of the three months ended March 31, 2026 and 2025 were $0.1 million.

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 months ended March 31, 2026 and 2025 were $5 thousand and $27 thousand, respectively.

The Fund utilizes 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 is a party to a production handling, gathering and operating services agreement (“PHA”) with affiliated entities and other third-party working interest owners in the Claiborne Project. Under the terms of the PHA, the Claiborne Project producers have agreed to pay the Beta Project owners a fixed production handling fee for each barrel of oil and mcf of natural gas processed through the Beta Project production facility. During the three ~~and nine~~ months ended ~~September~~March 3031, 2026 and 2025, the Fund earned $1912 thousand and $~~0.1~~23 ~~million~~thousand, respectively, representing its proportionate share of the production handling fees earned from affiliates, which are included within “Other revenue” on the Fund’s statements of operations. During the three and nine months ended September 30, 2024, the Fund earned $22 thousand and $49 thousand, respectively, representing its proportionate share of the production handling fees earned from affiliates, which are included within “Other revenue” on the Fund’s statements of operations. As of ~~September~~March 3031, ~~2025~~2026 and December 31, ~~2024~~2025, the Fund’s receivables of $12 thousand and $1510 thousand, respectively, related to the Fund’s proportionate share of revenue from affiliates are included within “Due from affiliate” on the Fund’s balance sheets. The receivables are settled by issuance of a non-cash credit from the Beta Project operator to the Fund on behalf of the Claiborne Project working interest owners when the operator performs the joint interest billing of the lease operating expenses due from the Fund. However, if applying the joint interest billing credit results in a net credit balance due to the Fund, the Beta Project operator remits such balance in cash to the Fund.

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

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

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3.At ~~Commitments~~times, short-term payables and ~~Contingencies~~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~~March 3031, ~~2025~~2026, the Fund’s estimated capital commitments related to its oil and gas properties were $3.40 million (which include asset retirement obligations for the Fund’s projects of $2.3 million), of which $10.16 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 Beta Project.

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~~various ~~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~~geopolitical, ~~and the Trump Administration is taking an increasingly hawkish stance towards key crude exporters,~~ ~~such~~political ~~as Russia, Iran~~ and ~~Venezuela.~~regulatory ~~The~~developments ~~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~~March 3031, ~~2025~~2026 and December 31, ~~2024~~2025, there were no known ~~environmental~~ 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.

BSEE and BOEM Supplemental Financial Assurance Requirements

On ~~October~~April 1618, ~~2020~~2023, the Bureau of ~~Ocean Energy Management (“BOEM”) and the Bureau of~~ Safety and Environmental Enforcement (“BSEE”) published a ~~proposed~~final ~~new~~ rule ~~entitled~~ “at 88 FR 23569 on Risk Management, Financial Assurance and Loss Prevention” toeffective May ~~update~~18, ~~BOEM’s~~2023 ~~financial~~to ~~assurance~~clarify ~~criteria~~ and ~~other~~ ~~BSEE-administered~~formalize its regulations. ~~Upon~~related ~~review~~to decommissioning responsibilities of ~~the~~Outer ~~2020~~Continental ~~joint~~Shelf ~~proposed~~(“OCS”) oil, ~~rule~~gas, and ~~analysis~~sulfur oflessees ~~public~~and ~~comments~~grant holders to ensure compliance with lease, ~~the~~grant, ~~Secretary~~and regulatory obligations. The rule clarifies decommissioning responsibilities of ~~the~~right-of-use and easement grant holders and formalizes BSEE's policies regarding performance by predecessors Uordered to decommission OCS facilities.S. ~~Department~~The offinal ~~the~~rule ~~Interior~~withdraws ~~(“Interior”)~~a ~~elected~~proposal from 2020 to ~~separate~~amend ~~the~~BSEE's ~~BOEM~~regulations ~~and~~to require BSEE ~~portions~~to proceed in reverse chronological order against predecessor lessees, owners of ~~the~~operating ~~supplemental~~rights, ~~bonding~~and ~~requirements.~~grant holders when requiring such entities ~~BSEE~~to ~~finalized~~perform ~~some~~their ~~provisions~~accrued ~~from~~decommissioning obligations if the ~~2020~~current ~~proposal~~lessees, asowners, ~~discussed~~or ~~below~~holders have failed to perform. ~~BOEM~~In ~~rescinded~~addition, ~~its~~BSEE also ~~portion~~decided ofnot to finalize the ~~2020~~appeal bonding requirements proposed ~~rule~~in ~~and~~2020 ~~issued its~~in ~~new~~this ~~rule~~final ~~below~~rule.

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.

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On April 24, 2024, the Bureau of Ocean Energy Management (“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. The ~~That~~ litigation iswas ~~ongoing,~~stayed ~~and~~in ~~a decision~~anticipation onof the ~~motion~~issuance toof ~~stay~~a ~~the~~new rule, iswhich ~~pending. The~~could ~~Fund~~make ~~has~~the litigation ~~evaluated~~moot. On ~~the~~December ~~impact~~10, of2025, the ~~new~~court ~~rule~~ordered ona ~~its~~continuation ~~operations~~of ~~and~~the ~~increased its~~stay ~~estimated~~with ~~asset~~a ~~retirement~~requirement ~~obligations~~for asthe ofdefendants ~~December~~to ~~31,~~file a ~~2024.~~status ~~The~~report ~~Fund~~upon ~~will~~the ~~also~~earlier ~~continue~~of ~~to maintain~~ the ~~salvage~~issuance ~~fund,~~of a ~~separate interest-bearing~~new ~~account,~~rule toor ~~fund~~120 ~~its~~days ~~proportionate~~from ~~share of~~ the ~~estimated~~date ~~future costs~~ of ~~decommissioning~~the ~~liabilities for its projects~~order. ~~The~~ ~~Fund~~There ~~will~~have ~~continue~~been tono ~~reassess~~substantive rulings ~~its~~on ~~estimated~~the ~~decommissioning~~merits, ~~liabilities~~ and ~~reserve~~the ~~for~~case ~~additional~~remains ~~funding~~stayed aspending ~~necessary~~BOEM’s ongoing rulemaking.

On ~~May~~March 29, ~~2025~~2026, ~~Interior~~BOEM ~~announced~~published ~~its~~a ~~intent to~~proposed ~~revise the final~~ rule titled on “Risk Management and Financial Assurance for OCS Lease and Grant Obligations” (the “2026 Proposed Rule”), which would revise and ~~proceed~~potentially toreplace ~~issue~~the a2024 ~~new~~final rule consistent with the Trump administration’s 2020 framework. The ~~proposed~~proposal is ~~rule~~intended into ~~2020~~reduce supplemental financial assurance requirements and includes, among other ~~things~~changes, ~~(i)~~reinstating ~~proposed~~consideration ~~only~~of ~~two~~the ~~evaluation~~financial ~~factors~~strength ~~(1)~~of ajointly ~~company’s~~and ~~credit~~severally ~~rating~~liable ~~(or~~predecessor alessees, ~~proxy~~revising credit rating ifthresholds, amodifying ~~company~~decommissioning ~~does~~liability estimation ~~not have a credit rating)~~methodologies, and ~~(2)~~ expanding the ~~value~~flexibility of ~~oil~~acceptable ~~and~~financial ~~gas~~assurance ~~reserves;~~instruments. ~~(ii)~~BOEM ~~maintained~~has ~~joint~~indicated ~~and~~that ~~several~~the ~~responsibility of all current and predecessor lessees; (iii) created~~proposed ~~reverse~~changes ~~chronological~~could ~~order~~significantly ~~through~~reduce ~~the chain~~industry-~~of-title~~wide tosupplemental ~~perform~~financial ~~decommissioning~~assurance ~~starting~~requirements. ~~with~~The ~~the~~2026 ~~most~~Proposed ~~recent~~Rule ~~predecessor~~remains ~~before turning~~subject to ~~more~~public ~~remote~~comment ~~predecessors in time;~~ and ~~(iv)~~may ~~provided~~be ~~more~~revised ~~flexibility~~prior into ~~the use of third-party guarantees and decommissioning accounts~~finalization. ~~Interior~~ ~~anticipates~~Accordingly, ~~finalizing~~ the ~~new rule in 2025. The~~ Fund is ~~not~~currently ~~able~~evaluating ~~to evaluate~~ the potential impact of athe proposal ~~proposed~~but ~~new~~cannot ~~rule~~reasonably onestimate its ~~operations or~~effect ~~financial~~on ~~condition until~~ the ~~final~~Fund’s ~~rule~~financial iscondition ~~issued~~ or ~~some~~results ~~other~~of ~~definitive~~operations ~~action~~at isthis ~~taken by the Interior or BOEM~~time.

The Fund will 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.

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.

45. 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.

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The following table is a summary of segment information for the three ~~and nine~~ months ended ~~September~~March 3031, ~~2025~~2026 and ~~2024~~2025.

Schedule of segment information
	Three months ended September 30,					Nine months ended September 30,
	Three months ended March 31,
	2025			2024		2025		2024
	2026			2025
	(in thousands)
Revenue:
Oil and gas revenue	$	~~277~~225		$	~~467~~381	$	~~996~~	$	~~1,555~~
Other revenue		4329			5355		~~151~~		~~115~~
Total revenue		~~320~~254			~~520~~436		~~1,147~~		~~1,670~~
Less:
Depletion and amortization		~~145~~89			~~205~~172		~~490~~		~~649~~
Lease operating expense		42-			4348		~~132~~		~~123~~
Transportation and processing expense		1510			2118		51		66
Insurance expense		1614			910		33		26
Workover expense		-4			-		10		-
Management fees to affiliate		72			72		~~217~~		~~217~~
Other segment items		4152			2648		~~135~~		82
Net (loss) income	$	(11	)	$	144	$	79	$	507
Net income	$	13		$	68

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 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~~ 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 A-1 Fund, LLC (the “Fund”) has incorporated by reference into this Quarterly Report, other than purely historical information, including estimates, projections, statements relating to the Fund’s business plans, strategies, objectives and expected operating results, and the assumptions upon which those statements are based, are “forward-looking statements” within the meaning of the 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~~2025.

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 2.5% 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. 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 the costs associated with the well recompletions for the Beta Project, 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.11

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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 the costs associated with the well recompletions for the Beta Project, 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 months ended March 31, 2026 and 2025 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 Beta Project, which is 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~~

Total Spent

~~Total~~

Total

Working

~~through~~

through

~~Fund~~

Fund

Project

Interest

~~September 30, 2025~~

March 31, 2026

~~Budget~~

Budget

Status

~~(in thousands)~~

(in thousands)

Beta Project

1.64%

16,~~520~~974

19,~~125~~091

The Beta Project, a seven-well project, commenced production from its first two wells in 2016. Additional five wells commenced production in 2017, 2018 and 2019. ~~Two~~Well ~~wells~~#4 ~~are~~was ~~currently~~ shut-in for pressure build that occurred during third quarter 2025. A rig recompletion operation for Well #4 that began in January 2026 was completed with the well returning to production in March 2026. Rig recompletion on Well #5 is ongoing with Well #2 scheduled to follow. The Fund expects to spend $10.16 million for additional development costs. ~~and~~Well #3 is currently shut-in for pressure build that occurred during third quarter 2025. The operator plans to recomplete Well #3 that the Fund elected to non-consent. The Fund expects to spend $1.5 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~~March 3031, ~~2025~~2026 and ~~2024~~2025, and should be read in conjunction with the Fund’s ~~financial~~ 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,
	Three months ended March 31,
	2025			2024		2025		2024
	2026			2025
	(in thousands)
Revenue
Oil and gas revenue	$	~~277~~225		$	~~467~~381	$	~~996~~	$	~~1,555~~
Other revenue		4329			5355		~~151~~		~~115~~
Total revenue		~~320~~254			~~520~~436		~~1,147~~		~~1,670~~
Expenses
Depletion and amortization		~~145~~89			~~205~~172		~~490~~		~~649~~
Operating expenses		9449			8797		~~289~~		~~256~~
Management fees to affiliate		72			72		~~217~~		~~217~~
General and administrative expenses		4453			3949		~~140~~		~~121~~
Total expenses		~~355~~263			~~403~~390		~~1,136~~		~~1,243~~
(Loss) income from operations		(359	)		~~117~~46		11		~~427~~
Interest income		2422			2722		68		80
Net (loss) income		(11	)	$	144	$	79	$	507
Net income	$	13		$	68

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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~~ 30March 31, 2026 ~~2025~~ and ~~2024~~2025. Natural gas liquid sales are included within gas sales.

	Three months ended September 30,				Nine months ended September 30,
	Three months ended March 31,
	2025		2024		2025		2024
	2026		2025
Number of wells producing		76		7		7		7
Total number of production days		~~550~~307		~~598~~626		~~1,806~~		~~1,795~~
Oil sales (in thousands of barrels)		43		65		14		19
Average oil price per barrel	$	6573	$	7572	$	67	$	77
Gas sales (in thousands of mcfs)		64		98		22		27
Average gas price per mcf	$	35.4414	$	24.9252	$	~~3.78~~	$	~~3.16~~

The ~~decrease~~production inrelated ~~production~~decreases ~~days~~noted ~~during~~in the ~~three~~ ~~months~~table ~~ended~~above ~~September~~were ~~30, 2025 was~~ attributable to the Beta Project, which ~~shut-in~~is ~~two~~currently ~~wells~~undergoing ~~for~~a ~~pressure~~series ~~build~~of ~~while~~recompletion ~~the~~operations. ~~increase~~Recompletion inwork ~~production~~on ~~days~~the ~~during~~first ~~the~~well ~~nine~~was ~~months~~completed ~~ended~~in ~~September~~early 30March 2026, ~~2025~~and ~~was~~the ~~attributable~~well tohas ~~the~~since ~~Beta~~been ~~Project’s~~returned ~~shut-in~~to ~~during~~production. ~~March~~In ~~2024 for~~addition, ~~scheduled~~one ~~maintenance~~well atin athe Beta ~~third-party~~Project ~~gas~~was ~~processing~~not ~~facility.~~producing ~~The~~during ~~decreases~~the inquarter ~~sales~~due ~~volumes~~to ~~noted~~a inmechanical issue; the ~~table~~operator ~~above~~proposed ~~were~~a ~~primarily attributable~~recompletion tooperation ~~natural~~in ~~declines~~which inthe Fund ~~production~~elected ~~from~~to ~~the~~non-consent. The Beta Project’s ~~wells.~~production volumes were also further impacted by natural declines in production. See additional discussion in the “Business Update” section above.

Oil and Gas Revenue. Oil and gas revenue during the three months ended ~~September~~March 3031, ~~2025~~2026 was $0.32 million, a decrease of $0.2 million from the three months ended ~~September 30,~~March ~~2024~~31, 2025. The decrease was primarily attributable to decreased sales volume totaling $0.2 million.

Oil and gas revenue during the nine months ended September 30, 2025 was $1.0 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 $0.1 million.

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

Other Revenue. Other revenue is generated from the Fund’s production handling, gathering and operating services agreement with affiliated entities and other third parties.

Depletion and Amortization. Depletion and amortization during the three months ended ~~September~~March 3031, ~~2025~~2026 was $0.1 million, a decrease of $0.1 million from the three months ended ~~September~~March 3031, ~~2024~~2025. The decrease was primarily attributable to a decrease in production volumes totaling $0.1 million.

Depletion and amortization during the nine months ended September 30, 2025 was $0.5 million, a decrease of $0.2 million from the nine months ended September 30, 2024. The decrease was primarily attributable to a decrease in production volumes totaling $0.2 million.

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,
	Three months ended March 31,
	2025		2024		2025		2024
	2026		2025
	(in thousands)
Lease operating expense	$	42-	$	4348	$	~~132~~	$	~~123~~
Accretion expense		21		1421		63		41
Transportation and processing expense		15		21		51		66
Insurance expense		14		10
Insurance expense		16		9		33		26
Transportation and processing expense		10		18
Workover expense		-4		-		10		-
	$	9449	$	8797	$	~~289~~	$	~~256~~

Lease operating expense and transportation and processing expense relate to the Fund’s producing projects. 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. Workover expense represents costs to restore or stimulate production of existing reserves.

Production costs, which include lease operating expense, transportation and processing expense and insurance expense, were $24 thousand ($6.92 per barrel of oil equivalent or “BOE”) during the three months ended March 31, 2026, compared to $0.1 million ($12.37 per BOE) during the three months ended March 31, 2025.

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Production costs, ~~which~~were ~~include~~relatively ~~lease~~consistent ~~operating~~during ~~expense,~~the ~~transportation~~three ~~and~~months ~~processing~~ended ~~expense~~March ~~and insurance expense~~31, ~~were~~2026 ~~$0.1~~compared ~~million~~to ~~($14.80~~the ~~per~~three ~~barrel~~months ofended ~~oil~~March ~~equivalent~~31, or2025. ~~“BOE”) and~~The ~~$0.2~~decrease ~~million~~in ~~($12.48~~production costs per BOE) during the three ~~and~~months ~~nine~~ended March 31, 2026 compared to the three months ended ~~September~~March 3031, 2025, ~~respectively,~~was ~~compared~~primarily attributable to ~~$0.1~~a ~~million~~credit ~~($9.94~~received ~~per~~for ~~BOE)~~a ~~and~~Beta ~~$0.2~~Project ~~million~~well’s ~~($9.10~~conductor ~~per~~pipe ~~BOE)~~installation ~~during~~that the ~~three~~Fund ~~and~~went ~~nine~~non-consent ~~months~~on ~~ended~~when ~~September~~the ~~30,~~well ~~2024,~~was ~~respectively~~later drilled.

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 Beta Project, which had higher production costs per BOE during the three and nine months ended September 30, 2025 primarily attributable to reduced production volumes due to natural declines in production.

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

Management Fees to Affiliate. An annual management fee, totaling 2.5% of total capital contributions, net of cumulative dry-hole well costs incurred by the Fund and fully depleted project investments, is paid monthly to the Manager. All or a portion of such fee may be temporarily waived by the Manager to accommodate the Fund’s short-term commitments.

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

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~~used byin operating activities during the ~~nine~~three months ended ~~September~~March 3031, ~~2025~~2026 were $~~0.7~~25 ~~million~~thousand, primarily related to ~~revenue~~operating ~~received~~expenses of $10.21 million, ~~and~~management ~~interest~~fees ~~income received~~ of $0.1 million, ~~partially~~and ~~offset~~general byand ~~operating~~administrative expenses of $0.21 million, ~~management~~partially ~~fees~~offset ofby ~~$0.2~~revenue ~~million~~received ~~and general and administrative expenses~~ of $0.2 million.

Cash flows provided by operating activities during the ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025 were $10.3 million, primarily related to revenue received of $~~1.7 million and interest income received of $~~0.14 million, partially offset by ~~operating expenses of $0.2 million,~~ management fees of $0.21 million and ~~general~~operating ~~and administrative~~ expenses of $0.1 million.

Investing Cash Flows

Cash flows used in investing activities during the ~~nine~~three months ended ~~September~~March 3031, ~~2025~~2026 were $0.21 million, primarily related to investments in salvage fund.

Cash flows ~~provided~~used byin investing activities during the ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025 were $~~0.3~~49 ~~million~~thousand, ~~primarily~~ related to ~~proceeds from the salvage fund of $0.3 million, partially offset by~~ investments in salvage fund ~~of $0~~.~~1 million.~~

Financing Cash Flows

Cash flows used in financing activities during the ~~nine~~three months ended ~~September~~March 3031, ~~2025~~2026 were $~~0.4~~36 ~~million~~thousand, related to manager and shareholder distributions.

Cash flows used in financing activities during the ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025 were $10.12 million, related to manager and shareholder distributions.

Capital Expenditures

Capital expenditures for oil and gas properties have been funded with the capital raised by the Fund in its private placement offering and through debt financing. The Fund’s capital has been fully 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 for the Beta Project, 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.

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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.

As of September 30, 2025, 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 $2.3 million), of which $1.1 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 gas from the Beta Project. 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.15

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As of March 31, 2026, the Fund’s estimated capital commitments related to its oil and gas properties were $3.0 million (which include asset retirement obligations for the Fund’s projects of $2.3 million), of which $0.6 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 gas from the Beta Project. 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.

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

Distributions, if any, are funded from available cash from operations, as defined in the LLC Agreement, and the frequency and amount are within the Manager’s discretion. However, distributions may be impacted by amounts of future capital required for the costs associated with the well recompletions for the Beta Project, 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~~March 3031, ~~2025~~2026 and December 31, ~~2024~~2025, 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.

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~~March 3031, ~~2025~~2026.

There has been no change in the Fund’s internal control over financial reporting that occurred during the three months ended ~~September~~March 3031, ~~2025~~2026 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 A-1 FUND, LLC
Dated:	~~November~~May 45, ~~2025~~2026	By:	/s/	NILOY SHAH
			Name:	Niloy Shah
			Title:	President and Partner
				(Principal Executive Officer)

Dated:	~~November~~May 45, ~~2025~~2026	By:	/s/	KATHLEEN P. MCSHERRY
			Name:	Kathleen P. McSherry
			Title:	Executive Vice President, Chief Financial Officer and Assistant Secretary
				(Principal Financial and Accounting Officer)

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