RGCO 10-Q Quarterly Report June 30, 2025

RGC RESOURCES INC

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rgco20250630_10q.htm

Table of Contents

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form

10-Q

(Mark One)

☒

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For Quarterly Period Ended June 30, 2025

☐

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For Transition Period From

Commission File Number 000-26591

RGC Resources, Inc.
(Exact name of Registrant as Specified in its Charter)

Virginia	54-1909697
(State or Other Jurisdiction of Incorporation or Organization)	(I.R.S. Employer Identification No.)

519 Kimball Ave., N.E. , Roanoke , VA	24016
(Address of Principal Executive Offices)	(Zip Code)

( 540 ) 777-4427

(Registrant’s Telephone Number, Including Area Code)

None

(Former Name, Former Address and Former Fiscal Year, if Changed Since Last Report)

Securities registered pursuant to Section 12(b) of the Act:

Title of Each Class			Trading Symbol			Name of Each Exchange on Which Registered
Common Stock, $5 Par Value			RGCO			NASDAQ Global Market

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15 (d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

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

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See 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 ☒

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.

Class	Outstanding at July 31, 2025
Common Stock, $5 Par Value	10,325,514

Table of Contents

INDEX

		Page No.

PART I. FINANCIAL INFORMATION

Item 1.	Financial Statements
	Condensed Consolidated Balance Sheets	1
	CONDENSED CONSOLIDATED STATEMENTS OF INCOME	3
	CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME	4
	CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY	5
	CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS	6
	Notes to Condensed Consolidated Financial Statements	7
Item 2.	Management ’ s Discussion and Analysis of Financial Condition and Results of Operations	26
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	37
Item 4.	Controls and Procedures	38
PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	39
Item 1A.	Risk Factors	39
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	39
Item 3.	Defaults Upon Senior Securities	39
Item 4.	Mine Safety Disclosures	39
Item 5.	Other Information	39
Item 6.	Exhibits	40
Signatures		41

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GLOSSARY OF TERMS

AFUDC		Allowance for Funds Used During Construction

AOCI/AOCL		Accumulated Other Comprehensive Income (Loss)

ARO		Asset Retirement Obligation

ARP		Alternative Revenue Program, regulatory or rate recovery mechanisms approved by the SCC that allow for the adjustment of revenues for certain broad, external factors, or for additional billings if the entity achieves certain performance targets

ASC		Accounting Standards Codification

ASU		Accounting Standards Update as issued by the FASB

ATM		At-the-market program whereby a Company can incrementally offer common stock through a broker at prevailing market prices and on an as-needed basis

Company		RGC Resources, Inc. or Roanoke Gas Company

CPCN		Certificate of Public Convenience and Necessity

DRIP		Dividend Reinvestment and Stock Purchase Plan of RGC Resources, Inc.

DTH		Decatherm (a measure of energy used primarily to measure natural gas)

EPS		Earnings Per Share

ERISA		Employee Retirement Income Security Act of 1974

FASB		Financial Accounting Standards Board

FDIC		Federal Deposit Insurance Corporation

FERC		Federal Energy Regulatory Commission

GAAP		Generally Accepted Accounting Principles in the United States

Table of Contents

HDD

Heating degree day, a measurement designed to quantify the demand for energy. It is the number of degrees that a day’s average temperature falls below 65 degrees Fahrenheit

ICC		Inventory carrying cost revenue, an SCC approved rate structure that mitigates the impact of financing costs on natural gas inventory

IRS		Internal Revenue Service

KEYSOP		RGC Resources, Inc. Key Employee Stock Option Plan

LDI		Liability Driven Investment approach, a strategy which reduces the volatility in the pension plan's funded status and expense by matching the duration of the fixed income investments with the duration of the corresponding pension liabilities

LLC		Mountain Valley Pipeline, L.L.C., a joint venture established to design, construct and operate the Mountain Valley Pipeline and MVP Southgate

LNG		Liquefied natural gas, the cryogenic liquid form of natural gas. Roanoke Gas operates and maintains a plant capable of producing and storing up to 200,000 DTH of liquefied natural gas

MGP		Manufactured gas plant

Midstream		RGC Midstream, L.L.C., a wholly-owned subsidiary of Resources created to invest in pipeline projects including the MVP and Southgate

MVP		Mountain Valley Pipeline, a FERC-regulated natural gas pipeline connecting the EQT Corporation's gathering and transmission system in northern West Virginia to the Transco interstate pipeline in south central Virginia with interconnects to Roanoke Gas’ natural gas distribution system

NQDC Plan		RGC Resources, Inc. Non-qualified Deferred Compensation Plan

Normal Weather		The average number of heating degree days over the most recent 30-year period

PBGC		Pension Benefit Guaranty Corporation

Pension Plan		Defined benefit plan that provides pension benefits to employees hired prior to January 1, 2017 who meet certain years of service criteria

PGA		Purchased Gas Adjustment, a regulatory mechanism, which adjusts natural gas customer rates to reflect changes in the forecasted cost of gas and actual gas costs

Postretirement Plan		Defined benefit plan that provides postretirement medical and life insurance benefits to eligible employees hired prior to January 1, 2000 who meet years of service and other criteria

R&D Tax Credit		Research and development federal tax credit defined under Internal Revenue Code section 41 and the related regulations

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Resources		RGC Resources, Inc., parent company of Roanoke Gas and Midstream

RGCO		Trading symbol for RGC Resources, Inc. on the NASDAQ Global Stock Market

RNG		Renewable Natural Gas

RNG Rider		Renewable Natural Gas Rider, the rate component as approved by the SCC that is billed monthly to the Company’s customers to recover the costs associated with the investment in RNG facilities and related operating costs

Roanoke Gas		Roanoke Gas Company, a wholly-owned subsidiary of Resources

ROU Asset		Right of Use Asset

RSPD		RGC Resources, Inc. Restricted Stock Plan for Outside Directors

RSPO		RGC Resources, Inc. Restricted Stock Plan for Officers

SAVE		Steps to Advance Virginia's Energy, a regulatory mechanism per Chapter 26 of Title 56 of the Code of Virginia that allows natural gas utilities to recover the investment, including related depreciation and expenses and provide return on rate base, in eligible infrastructure replacement projects without the filing of a formal base rate application

SAVE Plan		Steps to Advance Virginia's Energy Plan, the Company's approved operational replacement plan and related spending under the SAVE regulatory mechanism

SAVE Rider		Steps to Advance Virginia's Energy Plan Rider, the rate component of the SAVE Plan as approved by the SCC that is billed monthly to the Company’s customers to recover the costs associated with eligible infrastructure projects including the related depreciation and expenses and return on rate base of the investment

SCC		Virginia State Corporation Commission, the regulatory body with oversight responsibilities of the utility operations of Roanoke Gas

SEC		U.S. Securities and Exchange Commission

SOFR		Secured Overnight Financing Rate

Southgate		Mountain Valley Pipeline, LLC’s Southgate project, which is contemplated to extend from the MVP in south central Virginia to North Carolina, of which Midstream owns less than 1%

S&P 500 Index		Standard & Poor’s 500 Stock Index

WNA		Weather Normalization Adjustment, an ARP mechanism which adjusts revenues for the effects of weather temperature variations as compared to the 30-year average

Some of the terms above may not be included in this filing

Table of Contents

RGC RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(UNAUDITED)

	June 30,			September 30,
	2025			2024
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	2,126,889		$	894,185
Accounts receivable (less allowance for credit losses of $ 500,410 and $ 153,347 , respectively)		6,170,064			4,483,739
Inventories		1,923,963			1,799,631
Gas in storage		6,084,281			8,491,490
Prepaid income taxes		1,176,005			2,362,069
Regulatory assets		1,609,701			5,103,910
Interest rate swaps		958,779			871,026
Other		1,546,030			1,066,251
Total current assets		21,595,712			25,072,301
UTILITY PROPERTY:
In service		359,169,601			345,864,008
Accumulated depreciation and amortization		( 98,284,856	)		( 92,462,376	)
In service, net		260,884,745			253,401,632
Construction work in progress		9,653,720			8,639,822
Utility property, net		270,538,465			262,041,454
OTHER NON-CURRENT ASSETS:
Regulatory assets		4,327,281			4,445,044
Investment in unconsolidated affiliates		20,876,930			21,057,222
Benefit plan assets		5,359,518			5,416,536
Deferred income taxes		841,163			771,746
Interest rate swaps		576,289			1,191,526
Other		642,635			703,394
Total other non-current assets		32,623,816			33,585,468
TOTAL ASSETS	$	324,757,993		$	320,699,223

Table of Contents

RGC RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(UNAUDITED)

	June 30,			September 30,
	2025			2024
LIABILITIES AND STOCKHOLDERS’ EQUITY
CURRENT LIABILITIES:
Current maturities of long-term debt	$	2,534,514		$	800,000
Line-of-credit		—			11,166,181
Dividends payable		2,142,544			2,050,286
Accounts payable		6,659,129			5,429,703
Customer credit balances		1,013,910			1,915,859
Income taxes payable		76,453			—
Customer deposits		1,492,550			1,488,113
Accrued expenses		3,813,325			4,988,281
Regulatory liabilities		2,941,359			834,278
Other		21,989			25,729
Total current liabilities		20,695,773			28,698,430
LONG-TERM DEBT:
Line-of-credit		4,991,528			—
Notes payable		134,965,486			136,955,000
Unamortized debt issuance costs		( 213,624	)		( 282,092	)
Long-term debt, net		139,743,390			136,672,908
DEFERRED CREDITS AND OTHER NON-CURRENT LIABILITIES:
Asset retirement obligations		11,504,134			11,142,095
Regulatory cost of retirement obligations		15,486,948			14,409,847
Benefit plan liabilities		131,568			113,600
Deferred income taxes		1,723,191			1,890,562
Regulatory liabilities		18,882,744			19,326,567
Other		328,927			308,439
Total deferred credits and other non-current liabilities		48,057,512			47,191,110
STOCKHOLDERS’ EQUITY:
Common stock, $ 5 par; authorized 20,000,000 shares; issued and outstanding 10,323,956 and 10,249,899 shares, respectively		51,619,780			51,249,495
Preferred stock, no par, authorized 5,000,000 shares; no shares issued and outstanding		—			—
Capital in excess of par value		49,091,868			47,988,270
Retained earnings		14,637,929			7,572,439
Accumulated other comprehensive income		911,741			1,326,571
Total stockholders’ equity		116,261,318			108,136,775
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$	324,757,993		$	320,699,223

See notes to condensed consolidated financial statements.

Table of Contents

RGC RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(UNAUDITED)

	Three Months Ended June 30,					Nine Months Ended June 30,
	2025		2024			2025		2024
OPERATING REVENUES:
Gas utility	$	17,239,550	$	14,431,379		$	80,938,690	$	71,455,564
Non utility		25,065		26,823			77,508		81,366
Total operating revenues		17,264,615		14,458,202			81,016,198		71,536,930
OPERATING EXPENSES:
Cost of gas - utility		7,816,181		5,344,684			36,581,043		30,741,090
Cost of sales - non utility		4,791		4,567			14,558		16,421
Operations and maintenance		4,587,672		4,221,661			14,599,534		13,879,513
Taxes other than income taxes		750,067		631,990			2,287,068		1,967,446
Depreciation and amortization		2,909,344		2,697,707			8,609,472		8,093,121
Total operating expenses		16,068,055		12,900,609			62,091,675		54,697,591
OPERATING INCOME		1,196,560		1,557,593			18,924,523		16,839,339
Equity in earnings of unconsolidated affiliate		772,082		282,604			2,427,470		2,979,823
Other income (expense), net		244,000		( 69,349	)		1,180,969		140,924
Interest expense		1,512,754		1,567,093			4,922,959		4,769,979
INCOME BEFORE INCOME TAXES		699,888		203,755			17,610,003		15,190,107
INCOME TAX EXPENSE		161,476		47,063			4,125,694		3,570,033
NET INCOME	$	538,412	$	156,692		$	13,484,309	$	11,620,074
BASIC EARNINGS PER COMMON SHARE	$	0.05	$	0.02		$	1.31	$	1.15
DILUTED EARNINGS PER COMMON SHARE	$	0.05	$	0.02		$	1.31	$	1.15

See notes to condensed consolidated financial statements.

Table of Contents

RGC RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(UNAUDITED)

	Three Months Ended June 30,						Nine Months Ended June 30,
	2025			2024			2025			2024
NET INCOME	$	538,412		$	156,692		$	13,484,309		$	11,620,074
Other comprehensive income (loss), net of tax:
Interest rate swaps		( 255,698	)		( 199,217	)		( 391,709	)		( 1,025,405	)
Defined benefit plans		( 7,708	)		11,893			( 23,121	)		35,679
OTHER COMPREHENSIVE LOSS, NET OF TAX		( 263,406	)		( 187,324	)		( 414,830	)		( 989,726	)
COMPREHENSIVE INCOME (LOSS)	$	275,006		$	( 30,632	)	$	13,069,479		$	10,630,348

See notes to condensed consolidated financial statements.

Table of Contents

RGC RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY

(UNAUDITED)

	Nine Months Ended June 30, 2025
	Common Stock		Capital in Excess of Par Value		Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Total Stockholders' Equity
Balance - September 30, 2024	$	51,249,495	$	47,988,270	$	7,572,439		$	1,326,571		$	108,136,775
Net income		—		—		5,269,689			—			5,269,689
Other comprehensive income		—		—		—			222,428			222,428
Cash dividends declared ($ 0.2075 per share)		—		—		( 2,136,620	)		—			( 2,136,620	)
Net issuance of common stock ( 14,792 shares)		73,960		194,857		—			—			268,817
Balance - December 31, 2024	$	51,323,455	$	48,183,127	$	10,705,508		$	1,548,999		$	111,761,089
Net income		—		—		7,676,208			—			7,676,208
Other comprehensive loss		—		—		—			( 373,852	)		( 373,852	)
Cash dividends declared ($ 0.2075 per share)		—		—		( 2,139,655	)		—			( 2,139,655	)
Net issuance of common stock ( 45,194 shares)		225,970		683,463		—			—			909,433
Balance - March 31, 2025	$	51,549,425	$	48,866,590	$	16,242,061		$	1,175,147		$	117,833,223
Net income		—		—		538,412			—			538,412
Other comprehensive loss		—		—		—			( 263,406	)		( 263,406	)
Cash dividends declared ($ 0.2075 per share)		—		—		( 2,142,544	)		—			( 2,142,544	)
Net issuance of common stock ( 14,071 shares)		70,355		225,278		—			—			295,633
Balance - June 30, 2025	$	51,619,780	$	49,091,868	$	14,637,929		$	911,741		$	116,261,318

	Nine Months Ended June 30, 2024
	Common Stock		Capital in Excess of Par Value		Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Total Stockholders' Equity
Balance - September 30, 2023	$	50,076,270	$	44,430,786	$	3,972,280		$	2,253,289		$	100,732,625
Net income		—		—		5,019,992			—			5,019,992
Other comprehensive loss		—		—		—			( 1,013,827	)		( 1,013,827	)
Cash dividends declared ($ 0.20 per share)		—		—		( 2,032,679	)		—			( 2,032,679	)
Net issuance of common stock ( 44,367 shares)		221,835		616,657		—			—			838,492
Balance - December 31, 2023	$	50,298,105	$	45,047,443	$	6,959,593		$	1,239,462		$	103,544,603
Net income		—		—		6,443,390			—			6,443,390
Other comprehensive income		—		—		—			211,425			211,425
Cash dividends declared ($ 0.20 per share)		—		—		( 2,036,221	)		—			( 2,036,221	)
Net issuance of common stock ( 119,858 shares)		599,290		1,781,375		—			—			2,380,665
Balance - March 31, 2024	$	50,897,395	$	46,828,818	$	11,366,762		$	1,450,887		$	110,543,862
Net income		—		—		156,692			—			156,692
Other comprehensive loss		—		—		—			( 187,324	)		( 187,324	)
Cash dividends declared ($ 0.20 per share)		—		—		( 2,038,956	)		—			( 2,038,956	)
Net issuance of common stock ( 13,681 shares)		68,405		225,113		—			—			293,518
Balance - June 30, 2024	$	50,965,800	$	47,053,931	$	9,484,498		$	1,263,563		$	108,767,792

See notes to condensed consolidated financial statements.

Table of Contents

RGC RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED)

	Nine Months Ended June 30,
	2025			2024
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	13,484,309		$	11,620,074
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		8,609,472			8,285,761
Cost of retirement of utility property		( 381,620	)		( 485,165	)
Stock-based compensation		560,323			595,311
Equity in earnings of unconsolidated affiliate		( 2,427,470	)		( 2,979,823	)
Distributions from unconsolidated affiliate		2,658,656			—
Changes in assets and liabilities which provided cash, exclusive of changes and noncash transactions shown separately		5,769,346			20,028
Net cash provided by operating activities		28,273,016			17,056,186
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to utility property		( 15,739,170	)		( 16,568,542	)
Investment in unconsolidated affiliates		( 50,894	)		( 8,743	)
Proceeds from disposal of utility property		33,395			33,023
Net cash used in investing activities		( 15,756,669	)		( 16,544,262	)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from issuance of unsecured notes		1,825,000			10,115,000
Repayments of notes payable		( 2,080,000	)		( 10,175,000	)
Borrowings under line-of-credit		36,287,974			34,622,405
Repayments under line-of-credit		( 42,462,627	)		( 31,360,152	)
Debt issuance expenses		( 1,312	)		( 99,390	)
Proceeds from issuance of stock		1,473,883			3,461,175
Cash dividends paid		( 6,326,561	)		( 6,047,300	)
Net cash (used in) provided by financing activities		( 11,283,643	)		516,738
NET INCREASE IN CASH AND CASH EQUIVALENTS		1,232,704			1,028,662
BEGINNING CASH AND CASH EQUIVALENTS		894,185			1,512,431
ENDING CASH AND CASH EQUIVALENTS	$	2,126,889		$	2,541,093

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest	$	5,146,549		$	4,604,431
Income taxes		3,400,000			2,640,000

See notes to condensed consolidated financial statements.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

1.	Basis of Presentation

Resources is an energy services company primarily engaged in the sale and distribution of natural gas. The condensed consolidated financial statements include the accounts of Resources and its wholly owned subsidiaries: Roanoke Gas and Midstream.

In the opinion of management, the accompanying unaudited condensed consolidated financial statements contain all adjustments (consisting of only normal recurring accruals) necessary to fairly present Resources' financial position as of June 30, 2025 , cash flows for the nine months ended June 30, 2025 and 2024 , and the results of its operations, comprehensive income, and changes in stockholders' equity for the three and nine months ended June 30, 2025 and 2024 . The results of operations for the three and nine months ended June 30, 2025 are not indicative of the results to be expected for the fiscal year ending September 30, 2025 as quarterly earnings are affected by the highly seasonal nature of the business and weather conditions generally result in greater earnings during the winter months.

The unaudited condensed consolidated financial statements and related notes are presented under the rules and regulations of the SEC. Pursuant to those rules, certain information and note disclosures normally included in the annual financial statements prepared in accordance with GAAP have been condensed or omitted. Although the Company believes that the disclosures are adequate, the unaudited condensed consolidated financial statements and the related notes should be read in conjunction with the financial statements and notes contained in the Company’s Form 10 -K for the year ended September 30, 2024 . The September 30, 2024 consolidated balance sheet was included in the Company’s audited financial statements included in Form 10 -K.

In August 2025, the Company obtained a commitment letter to refinance $ 53.6 million of Midstream debt that was maturing in fiscal 2026. See Note 7 for a discussion of this transaction. These actions have resolved the uncertainty that gave rise to the conditions that were disclosed last quarter under ASU 2014 - 15.

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

The Company’s significant accounting policies are described in Note 1 to the consolidated financial statements contained in the Company's Form 10 -K for the year ended September 30, 2024 .

Certain amounts previously disclosed have been reclassified to conform to current year presentations.

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Recently Issued or Adopted Accounting Standards

In November 2023, the FASB issued ASU 2023 - 07, Segment Reporting (Topic 280 ) - Improvements to Reportable Segment Disclosures . The new guidance is designed to provide users of financial statements with improved reportable segment disclosures, primarily through enhanced disclosures about significant segment expenses, other segment items and measures of segment profit or loss used by the chief operating decision maker (CODM). Additionally, the new guidance requires a public entity to provide in interim periods all disclosures about a reportable segment’s profit or loss and assets that are currently required annually, which the Company currently discloses on an interim basis. The new guidance is effective for the Company for fiscal year beginning October 1, 2024 and interim periods within fiscal year beginning October 1, 2025. The Company continues to refine its assessment of the impact of the new guidance on its financial statement disclosures, and expects the adoption of this standard will result in expanded disclosures within the segment reporting footnote, specifically regarding the information provided to the CODM and how the CODM uses the information in assessing the performance of each segment.

In December 2023, the FASB issued ASU 2023 - 09, Income Taxes (Topic 740 ): Improvements to Income Tax Disclosures . The new guidance requires that on an annual basis public business entities disclose specific categories in the rate reconciliation table and provide additional information for reconciling items that meet a quantitative threshold (items equal to or greater than 5 percent of the amount computed by multiplying pretax income or loss by the applicable statutory rate). The required disclosures will provide more granularity regarding the payment of income taxes to federal, state and foreign entities. The Company does not expect certain requirements of this ASU to have a significant impact to its current disclosures as all of its operations are domestic and reside in two states. Changes to the rate reconciliation table will result in additional disclosure. The new guidance is effective for the Company for annual periods beginning October 1, 2025.

In November 2024, the FASB issued ASU 2024 - 03, Income Statement - Reporting Comprehensive Income (Topic 220 ): Expense Disaggregation Disclosur es. The new guidance requires public business entities to disclose certain additional detail about expenses including, among other items, purchases of inventory, employee compensation, depreciation and intangible asset amortization included within each income statement expense line items within continuing operations. The guidance also requires disclosure of the total amount of selling expenses and the Company’s definition of selling expenses. Such disclosures must be made on an annual and interim basis and integrated with existing disclosure requirements in a tabular format in the footnotes to the financial statements. Further, in January 2025, the FASB issued ASU 2025 - 01, Income Statement - Reporting Comprehensive Income (Topic 220 ): Expense Disaggregation Disclosur es : Clarifying the Effective Date , which clarified the effective date of ASU 2024 - 03. The new guidance is effective for the Company for fiscal year beginning October 1, 2027 and interim periods within fiscal year beginning October 1, 2028. The Company is currently assessing the impacts of the new guidance on its financial statement disclosures.

Other accounting standards that have been issued by the FASB, SEC or other standard-setting bodies are not currently applicable to the Company or are not expected to have a material impact on the Company’s financial position, results of operations or cash flows.

2.	Revenue

The Company assesses new contracts and identifies related performance obligations for promises to transfer distinct goods or services to the customer. Revenue is recognized when performance obligations have been satisfied. In the case of Roanoke Gas, the Company contracts with its customers for the sale and/or delivery of natural gas.

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The following tables summarize revenue by customer, product and income statement classification:

	Three Months Ended June 30, 2025						Three Months Ended June 30, 2024
	Gas utility		Non utility		Total operating revenues		Gas utility		Non utility		Total operating revenues
Natural Gas (Billed and Unbilled):
Residential	$	8,677,898	$	—	$	8,677,898	$	7,333,332	$	—	$	7,333,332
Commercial		6,284,281		—		6,284,281		4,706,086		—		4,706,086
Transportation and interruptible		1,472,948		—		1,472,948		1,317,890		—		1,317,890
Other		148,576		25,065		173,641		168,514		26,823		195,337
Total contracts with customers		16,583,703		25,065		16,608,768		13,525,822		26,823		13,552,645
Alternative revenue programs		655,847		—		655,847		905,557		—		905,557
Total operating revenues	$	17,239,550	$	25,065	$	17,264,615	$	14,431,379	$	26,823	$	14,458,202

	Nine Months Ended June 30, 2025						Nine Months Ended June 30, 2024
	Gas utility		Non utility		Total operating revenues		Gas utility		Non utility		Total operating revenues
Natural Gas (Billed and Unbilled):
Residential	$	47,091,604	$	—	$	47,091,604	$	40,001,039	$	—	$	40,001,039
Commercial		27,740,237		—		27,740,237		22,946,163		—		22,946,163
Transportation and interruptible		4,454,693		—		4,454,693		4,047,151		—		4,047,151
Other		547,686		77,508		625,194		653,571		81,366		734,937
Total contracts with customers		79,834,220		77,508		79,911,728		67,647,924		81,366		67,729,290
Alternative revenue programs		1,104,470		—		1,104,470		3,807,640		—		3,807,640
Total operating revenues	$	80,938,690	$	77,508	$	81,016,198	$	71,455,564	$	81,366	$	71,536,930

Gas utility revenues

Substantially all of Roanoke Gas' revenues are derived from rates authorized by the SCC through its tariffs. Based on its evaluation, the Company has concluded that these tariff-based revenues fall within the scope of ASC 606, Revenue from Contracts with Customers . Tariff rates represent the transaction price. Performance obligations include the procurement and transportation of natural gas through the Company's distribution system to customers. The delivery of natural gas to customers results in the satisfaction of the Company’s respective performance obligations over time.

All customers are billed monthly based on consumption as measured by metered usage with payments due 20 days from the rendering of the bill. Revenue is recognized as bills are issued for natural gas that has been delivered or transported. In addition, the Company utilizes the practical expedient that allows an entity to recognize the invoiced amount as revenue, if that amount corresponds to the value received by the customer. Since customers are billed tariff rates, there is no variable consideration in the transaction price.

Unbilled revenue is included in residential and commercial revenues in the preceding table. Natural gas consumption is estimated for the period subsequent to the last billed date and up through the last day of the month. Estimated volumes and approved tariff rates are utilized to calculate unbilled revenue. The following month, the unbilled estimate is reversed, the actual usage is billed and a new unbilled estimate is calculated. The Company obtains metered usage for transportation and interruptible customers at the end of each month, thereby eliminating any unbilled consideration for these rate classes.

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Other revenues

Other revenues primarily consist of miscellaneous fees and charges, utility-related revenues not directly billed to utility customers and billings for non-utility activities. Customers are invoiced monthly based on services provided for these activities. The Company utilizes the practical expedient allowing revenue to be recognized based on invoiced amounts. The transaction price is based on a contractually predetermined rate schedule; therefore, the transaction price represents total value to the customer and no variable price consideration exists.

Alternative revenue program revenues

ARPs, which fall outside the scope of ASC 606, are SCC-approved mechanisms that allow for the adjustment of revenues for certain broad, external factors, or for additional billings if the entity achieves certain performance targets. The Company's ARPs include its WNA, which adjusts revenues for the effects of weather temperature variations as compared to the 30 -year average; the SAVE Plan over/under collection mechanism, which adjusts revenues for the differences between SAVE Plan revenues billed to customers and the revenue earned, as calculated based on the timing and extent of infrastructure replacement completed during the period; and the RNG over/under collection mechanism, which adjusts revenues similar to the SAVE Plan, but is calculated based on the timing and costs associated with owning, operating and maintaining the RNG facility. These amounts are ultimately collected from, or returned to, customers through future rate changes as approved by the SCC.

Customer accounts receivable and liabilities

Accounts receivable, as reflected in the condensed consolidated balance sheets, includes both billed and unbilled customer revenues, as well as amounts that are not related to customers. The asset and liability balances associated with customers are provided below:

	Current Assets				Current Liabilities
	Trade accounts receivable ⁽¹⁾		Unbilled revenue ⁽¹⁾		Customer credit balances			Customer deposits
Balance at September 30, 2024	$	3,080,140	$	1,294,798	$	1,915,859		$	1,488,113
Balance at June 30, 2025		4,723,496		1,341,438		1,013,910			1,492,550
Increase (decrease)	$	1,643,356	$	46,640	$	( 901,949	)	$	4,437

^{(

1

)} Included in accounts receivable in the condensed consolidated balance sheet. Amounts shown net of reserve for credit losses.

The Company did not incur any significant costs to obtain contracts during the period. Certain customers elect to pay even amounts monthly, giving rise to assets and liabilities presented in the table above. All amounts clear annually.

3.	Segment Information

Operating segments are defined as components of an enterprise for which separate financial information is available and evaluated regularly by the Company's executive management in deciding how to allocate resources and assess performance. The Company uses operating income and equity in earnings to assess segment performance.

Intersegment transactions are recorded at cost.

The reportable segments disclosed herein are defined as follows:

Gas Utility - The natural gas segment of the Company generates revenue from its tariff rates and other regulatory mechanisms through which it provides the sale and distribution of natural gas to its residential, commercial and industrial customers.

Investment in Affiliates - The investment in affiliates segment reflects the income generated through the activities of the Company's investment in the LLC.

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Information related to the Company's segments are provided below:

	*Gas Utility*		*Investment in Affiliates*			*Consolidated Total*
Three Months Ended June 30, 2025
Operating revenues	$	17,239,550	$	—		$	17,239,550
Corporate and other		—		—			25,065
Total revenues		17,239,550		—			17,264,615
Depreciation and amortization		2,909,344		—			2,909,344
Operating income (loss)		1,219,977		( 43,691	)		1,176,286
Corporate and other		—		—			20,274
Total operating income (loss)		1,219,977		( 43,691	)		1,196,560
Equity in earnings		—		772,082			772,082
Interest expense		822,022		690,732			1,512,754
Income before income taxes		640,938		38,676			679,614
Corporate and other		—		—			20,274
Total income before income taxes	$	640,938	$	38,676		$	699,888

	*Gas Utility*		*Investment in Affiliates*			*Consolidated Total*
Three Months Ended June 30, 2024
Operating revenues	$	14,431,379	$	—		$	14,431,379
Corporate and other		—		—			26,823
Total revenues		14,431,379		—			14,458,202
Depreciation and amortization		2,697,707		—			2,697,707
Operating income (loss)		1,574,375		( 37,692	)		1,536,683
Corporate and other		—		—			20,910
Total operating income (loss)		1,574,375		( 37,692	)		1,557,593
Equity in earnings		—		282,604			282,604
Interest expense		868,000		699,093			1,567,093
Income before income taxes		637,332		( 454,462	)		182,870
Corporate and other		—		—			20,885
Total income before income taxes	$	637,332	$	( 454,462	)	$	203,755

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	*Gas Utility*		*Investment in Affiliates*			*Consolidated Total*
Nine Months Ended June 30, 2025
Operating revenues	$	80,938,690	$	—		$	80,938,690
Corporate and other		—		—			77,508
Total revenues		80,938,690		—			81,016,198
Depreciation and amortization		8,609,472		—			8,609,472
Operating income (loss)		18,978,672		( 117,099	)		18,861,573
Corporate and other		—		—			62,950
Total operating income (loss)		18,978,672		( 117,099	)		18,924,523
Equity in earnings		—		2,427,470			2,427,470
Interest expense		2,796,978		2,125,981			4,922,959
Income before income taxes		17,360,579		186,474			17,547,053
Corporate and other		—		—			62,950
Total income before income taxes	$	17,360,579	$	186,474		$	17,610,003

	*Gas Utility*		*Investment in Affiliates*			*Consolidated Total*
Nine Months Ended June 30, 2024
Operating revenues	$	71,455,564	$	—		$	71,455,564
Corporate and other		—		—			81,366
Total revenues		71,455,564		—			71,536,930
Depreciation and amortization		8,093,121		—			8,093,121
Operating income (loss)		16,884,683		( 106,380	)		16,778,303
Corporate and other		—		—			61,036
Total operating income (loss)		16,884,683		( 106,380	)		16,839,339
Equity in earnings		—		2,979,823			2,979,823
Interest expense		2,748,741		2,021,238			4,769,979
Income before income taxes		14,277,365		851,777			15,129,142
Corporate and other		—		—			60,965
Total income before income taxes	$	14,277,365	$	851,777		$	15,190,107

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	*Gas Utility*		*Investment in Affiliates*		*Consolidated Total*
As of June 30, 2025:
Assets	$	285,220,121	$	21,557,941	$	306,778,062
Corporate and other		—		—		17,979,931
Total assets		285,220,121		21,557,941		324,757,993
Gross additions to utility property		15,739,170		—		15,739,170
Gross investment in affiliates	$	—	$	50,894	$	50,894

	*Gas Utility*		*Investment in Affiliates*		*Consolidated Total*
As of September 30, 2024:
Assets	$	280,508,989	$	21,324,361	$	301,833,350
Corporate and other		—		—		18,865,873
Total assets		280,508,989		21,324,361		320,699,223
Gross additions to utility property		22,094,406		—		22,094,406
Gross investment in affiliates	$	—	$	18,258	$	18,258

4.	Rates and Regulatory Matters

The SCC exercises regulatory authority over the natural gas operations of Roanoke Gas. Such regulation encompasses terms, conditions and rates to be charged to customers for natural gas service, safety standards, service extension and depreciation.

In response to continued inflationary pressures, Roanoke Gas filed a general rate application with the SCC on February 2, 2024 seeking to increase its annual non-gas base rates by $ 4.33 million and its permitted return on equity from 9.44 % to 10.35 % reflecting its higher cost of capital, including higher interest expense. The SCC permitted the Company to implement its new rates on an interim basis for customer billings on or after July 1, 2024, subject to refund. On October 16, 2024, the Company reached a settlement with the SCC staff on all outstanding issues in the case. Under the terms of the settlement, the Company agreed to an annual incremental revenue requirement increase of $ 4.08 million based on a return on equity of 9.90 %. On April 10, 2025, the SCC issued a final order approving the settlement agreement in its entirety. Refunds for the difference in amounts that were billed based on interim and settlement rates, which had previously been accrued, were made to customers in May 2025.

On May 30, 2025, Roanoke Gas filed for approval of an updated RNG Rider to become effective October 1, 2025. The revenue requirement associated with the proposed RNG Rider is $ 1.66 million, offset by the sale of environmental credits, the recovery of under recovery of costs during the prior fiscal year and the over crediting of customers for RIN sales. The Company expects a decision from the SCC in September 2025.

On June 30, 2025, Roanoke Gas filed for approval of an updated annual SAVE Rider rate to become effective October 1, 2025. The proposed SAVE Rider is based on an estimated $ 10.33 million of SAVE eligible investment during fiscal 2026 and a revenue requirement of $ 2.64 million, inclusive of the adjustment for under-recovered costs incurred during the prior year. The updated SAVE Rider also reflects the cost of capital approved by the Commission in its April 10, 2025 Rate Case Final Order. The Company expects a decision from the SCC in September 2025.

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5.	Other Investments

Midstream owns a less than 1 % equity investment in the LLC that owns and operates the MVP. The Company accounts for its interest in the LLC under the equity method of accounting given the LLC maintains specific ownership accounts for each investor, and also considering the Company's rights under the LLC management agreement. The Company has been using the equity method since the inception of its investment in fiscal 2016. Following receipt of authorization from the FERC, the MVP entered commercial operation on June 14, 2024 and became available for interruptible or short-term firm transportation service. On July 1, 2024, the MVP commenced long-term firm capacity obligations. Midstream is also a less than 1 % investor, accounted for under the cost method, in Southgate, which is in the design and permitting phase. Completion of the Southgate project is targeted for 2028.

AFUDC attributable to MVP construction was recognized during the prior year and is included in the equity in earnings of unconsolidated affiliate in the tables below. AFUDC ceased in June 2024 when MVP went into commercial operation.

The Company participates in the earnings of the LLC proportionate to its level of investment, favorably adjusted for a basis difference between the Company's capital account and its carrying value that arose when the Company recorded an other-than-temporary impairment of its investment in 2022. This basis difference amortization is a favorable non-cash adjustment to income over the book life of the MVP, which is 40 years. The Company's share of earnings from the LLC and the basis difference amortization are presented under equity in earnings of unconsolidated affiliate on the condensed consolidated statements of income. The Company received three quarterly cash distributions totaling approximately $ 2.7 million from the LLC during the first nine months of fiscal 2025 and expects future quarterly distributions to be of a similar magnitude to those received to date.

Midstream assesses the value of its investment in the LLC on at least a quarterly basis, and no impairment indicators were identified in fiscal 2025 or 2024.

Investment balances of MVP and Southgate, as of June 30, 2025 and September 30, 2024 , are reflected in the table below:

Balance Sheet location:	June 30, 2025		September 30, 2024
Other Assets:
MVP	$	20,717,161	$	20,948,347
Southgate		159,769		108,875
Investment in unconsolidated affiliates	$	20,876,930	$	21,057,222

The change in the investment in unconsolidated affiliates is provided below:

	Nine Months Ended June 30,
	2025			2024
Cash investment	$	50,894		$	8,743
Equity in earnings of unconsolidated affiliate		2,427,470			2,979,823
Distribution from unconsolidated affiliate		( 2,658,656	)		—
Change in investment in unconsolidated affiliates	$	( 180,292	)	$	2,988,566

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Summary unaudited financial statements of MVP are presented below. Southgate financial statements, which are accounted for under the cost method, are not included.

	Income Statements
	Three Months Ended June 30,						Nine Months Ended June 30,
	2025			2024			2025			2024
Revenue	$	139,410,586		$	3,723,469		$	424,079,412		$	3,723,469
Operating expenses		( 75,210,039	)		( 10,822,325	)		( 221,547,701	)		( 10,822,325	)
AFUDC		45,553			38,815,497			111,088			343,916,298
Other income, net		1,612,418			1,899,904			4,989,603			7,799,966
Net income	$	65,858,518		$	33,616,545		$	207,632,402		$	344,617,408

	Balance Sheets
	June 30, 2025		September 30, 2024
Assets:
Current assets	$	229,791,783	$	263,966,727
Construction work in progress		—		1,568,267
Property, plant and equipment, net		9,448,500,810		9,522,815,742
Other assets		8,963,640		13,732,299
Total assets	$	9,687,256,233	$	9,802,083,035

Liabilities and Equity:
Current liabilities	$	69,667,426	$	168,645,751
Noncurrent liabilities		1,120,286		68,965
Capital		9,616,468,521		9,633,368,319
Total liabilities and equity	$	9,687,256,233	$	9,802,083,035

6.	Line of Credit

The Company had been operating with an unsecured Revolving Note in the principal amount of $ 25 million that it renewed annually each March. On March 31, 2025, Roanoke Gas amended its Revolving Note to increase the principal amount to $ 30 million and extend the maturity date to March 31, 2027. The Revolving Note's variable interest rate is based upon Term SOFR plus 1.25 % and provides for multiple tier borrowing limits to accommodate seasonal borrowing demands. Other key terms and requirements of the Revolving Note were retained. The Company's total available borrowing limits during the term of the Revolving Note range from $ 20 million to $ 30 million. As of June 30, 2025 , the Company had an outstanding balance of $ 4,991,528 under the Revolving Note.

7.	Long-Term Debt

On March 6, 2024, Midstream entered into the Sixth Amendment to Credit Agreement and related Promissory Notes on the non-revolving credit facility. The Sixth Amendment revised the interest rate from Term SOFR plus 2.00 % to Term SOFR plus 2.00 % subject to adjustment to Term SOFR plus 1.75 % and Term SOFR plus 1.55 % upon meeting certain milestones. The Sixth Amendment also consolidated the Promissory Notes to one Promissory Note with one lender, increased the available non-revolving credit facility to $ 25 million, and extended the maturity date to December 31, 2025. All other terms and requirements remained unchanged.

On May 2, 2024, Midstream established a new $ 9 million revolving credit facility. The interest rate on the borrowings under the facility is Daily Simple SOFR plus 2.215%; the arrangement included a 0.40 % upfront fee and 0.125 % unused line fee. The facility matures on May 2, 2026.

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On May 29, 2024, Midstream paid in full the $ 9 million note payable that was set to mature June 1, 2024 with proceeds from the new credit facility.

On March 6, 2024, Midstream amended and restated its $ 8 million Term Note. The amendment suspended quarterly principal payments beginning April 1, 2024 through January 1, 2025. Principal payments began again on April 1, 2025. All other terms and requirements of the Term Note were retained. The interest rate swap related to the $ 8 million Term Note was not amended on March 6, 2024.

Long-term debt consists of the following:

	June 30, 2025					September 30, 2024
	Principal			Unamortized Debt Issuance Costs		Principal			Unamortized Debt Issuance Costs
Roanoke Gas:
Unsecured senior note payable at 4.26 %, due September 18, 2034	$	30,500,000		$	89,300	$	30,500,000		$	96,541
Unsecured term note payable at 3.58 %, due October 2, 2027		8,000,000			10,836		8,000,000			14,448
Unsecured term note payable at 4.41 %, due March 28, 2031		10,000,000			18,013		10,000,000			20,362
Unsecured term note payable at 3.60 %, due December 6, 2029		10,000,000			15,852		10,000,000			18,494
Unsecured term note payable at 30-day SOFR plus 1.20 %, due August 20, 2026 (swap rate at 2.00 %)		15,000,000			—		15,000,000			—
Unsecured term note payable at Term SOFR plus 1.00 %, due October 1, 2028 (swap rate at 2.49 %)		10,000,000			23,031		10,000,000			27,044
Midstream:
Unsecured term note payable at Term SOFR plus 1.55 %, due December 31, 2025		25,000,000			12,919		24,855,000			32,299
Unsecured term note payable at Daily Simple SOFR plus 1.26448 %, due June 12, 2026 (swap rate at 3.24 %)		14,000,000			2,408		14,000,000			4,213
Unsecured term note payable at Daily Simple SOFR plus 1.26448 %, due January 1, 2028 with quarterly principal installments of $ 400,000 that began April 1, 2023, were suspended April 1, 2024, and resumed April 1, 2025 (swap rate at 2.443 % on designated principal)		6,000,000			16,378		6,400,000			21,406
Revolving credit facility at Daily Simple SOFR plus 2.215 %, due May 2, 2026		9,000,000			24,887		9,000,000			47,285
Total long-term debt		137,500,000			213,624		137,755,000			282,092
Less: current maturities of long-term debt		( 2,534,514	)		—		( 800,000	)		—
Total long-term debt, net current maturities	$	134,965,486		$	213,624	$	136,955,000		$	282,092

Debt issuance costs are amortized over the life of the related debt. As of June 30, 2025 and September 30, 2024 , the Company also had an unamortized loss on the early retirement of debt of $ 1,056,231 and $ 1,141,872 , respectively, which has been deferred as a regulatory asset and is being amortized over a 20 -year period.

All debt agreements set forth certain representations, warranties and covenants to which the Company is subject, including financial covenants that limit consolidated long-term indebtedness to not more than 65 % of total capitalization. All of the debt agreements provide for Priority Indebtedness (defined in the debt agreements) to not exceed 15 % of consolidated total assets. The $ 15 million and $ 10 million notes, as well as the line-of-credit, have an interest coverage ratio requirement of not less than 1.5 to 1, which excludes the effect of the non-cash impairments on the LLC investments up to the total investment as of December 31, 2021, as revised by the Seventh Amendment to the Credit Agreement. The $ 9 million revolving line of credit facility also has an interest coverage ratio requirement of not less than 1.5 to 1. The Company was in compliance with all debt covenants as of June 30, 2025 and September 30, 2024 .

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Subsequent to the end of the quarter, the Company entered into a firm letter of commitment with two banks that will refinance Midstream-related debt totaling $ 53.6 million. The note will have a seven -year term and an interest rate of SOFR plus 1.55 %. In addition to interest, Midstream will repay principal based on a schedule aligned with the shipper contracts at MVP which will expire in June 2044. The note is guaranteed by RGC Resources, Inc., and there is a 30 basis point origination fee. Covenants are similar to those that exist on Midstream's outstanding debt. As a result of this firm commitment letter, the Company has reflected only $ 2.5 million of long-term debt as current on the balance sheet as of June 30, 2025 as it now has the intent and ability to refinance the existing maturities. The Company expects to finalize the arrangement in the fourth quarter.

8.	Derivatives and Hedging

The Company’s hedging and derivative policy allows management to enter into derivatives for the purpose of managing the commodity and financial market risks of its business operations, including the price of natural gas and the cost of borrowed funds. This policy specifically prohibits the use of derivatives for speculative purposes.

The Company has four interest rate swaps associated with certain of its variable rate debt as of June 30, 2025 . Roanoke Gas has two variable-rate term notes in the amounts of $ 15 million and $ 10 million, with corresponding swap agreements to effectively convert the variable interest rates into fixed rates of 2.00 % and 2.49 %, respectively. Midstream has two swap agreements corresponding to the variable-rate term notes with original principal amounts of $ 14 million and $ 8 million. The swap agreement pertaining to the $ 14 million note effectively converts the variable interest rate into a fixed rate of 3.24 %. The swap agreement pertaining to the $ 8 million note remains in place and was concurrently re-designated to hedge an applicable portion of the note, taking into account the temporary suspension of amortization described in Note 7, and converts that portion of the note to a fixed rate of 2.443 %. The swaps qualify as cash flow hedges with changes in fair value reported in other comprehensive income. No portion of the swaps were deemed ineffective during the periods presented.

The fair value of the current and non-current portions of the interest rate swaps are reflected in the condensed consolidated balance sheets under the caption interest rate swaps. The table in Note 11 reflects the effect on income and other comprehensive income of the Company's cash flow hedges.

9.	Fair Value Measurements

ASC 820, Fair Value Measurements and Disclosures , established a fair value hierarchy that prioritizes each input to the valuation method used to measure fair value of financial and nonfinancial assets and liabilities that are measured and reported on a fair value basis into one of the following three levels:

Level 1 – Unadjusted quoted prices in active markets for identical assets or liabilities that the Company has the ability to access at the measurement date.

Level 2 – Inputs other than quoted prices in Level 1 that are either for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability, or inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 3 – Unobservable inputs for the asset or liability where there is little, if any, market activity for the asset or liability at the measurement date, which require the Company to develop its own assumptions.

The fair value hierarchy gives the highest priority to unadjusted quoted prices in active markets (Level 1 ) and the lowest priority to unobservable inputs (Level 3 ). All fair value disclosures are categorized within one of the three categories in the hierarchy based on the lowest level that is significant to the valuation.

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The following table summarizes the Company’s financial assets and liabilities that are measured at fair value on a recurring basis as required by existing guidance and the fair value measurements by level within the fair value hierarchy:

	Fair Value Measurements - June 30, 2025
			Quoted		Significant
			Prices		Other		Significant
			in Active		Observable		Unobservable
	Fair		Markets		Inputs		Inputs
	Value		(Level 1)		(Level 2)		(Level 3)
Assets:
Interest rate swaps	$	1,535,068	$	—	$	1,535,068	$	—
Total	$	1,535,068	$	—	$	1,535,068	$	—

Liabilities:
Natural gas purchases	$	775,477	$	—	$	775,477	$	—
Total	$	775,477	$	—	$	775,477	$	—

	Fair Value Measurements - September 30, 2024
			Quoted		Significant
			Prices		Other		Significant
			in Active		Observable		Unobservable
	Fair		Markets		Inputs		Inputs
	Value		(Level 1)		(Level 2)		(Level 3)
Assets:
Interest rate swaps	$	2,062,551	$	—	$	2,062,551	$	—
Total	$	2,062,551	$	—	$	2,062,551	$	—

Liabilities:
Natural gas purchases	$	761,020	$	—	$	761,020	$	—
Total	$	761,020	$	—	$	761,020	$	—

The fair value of the interest rate swaps are determined by using the counterparty's proprietary models that can include observable quoted market interest rates and interest rate futures as well as certain assumptions regarding past, present and future market conditions.

Under the asset management contract, a timing difference can exist between the payment for natural gas purchases and the actual receipt of such purchases. Payments are made based on a predetermined monthly volume with the price based on weighted average first of the month index prices corresponding to the month of the scheduled payment. At June 30, 2025 and September 30, 2024 , the Company had recorded in accounts payable the estimated fair value of the liability valued at the corresponding first of month index prices for which the liability is expected to be settled.

The Company’s nonfinancial assets and liabilities measured at fair value on a nonrecurring basis consist of its AROs. The AROs are measured at fair value at initial recognition based on expected future cash flows required to settle the obligation.

The carrying value of cash and cash equivalents, accounts receivable, borrowings under line-of-credit, accounts payable, customer credit balances and customer deposits is a reasonable estimate of fair value due to the short-term nature of these financial instruments. In addition, the carrying amount of the variable rate line-of-credit is a reasonable approximation of its fair value.

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The following table summarizes the fair value of the Company’s financial assets and liabilities that are not adjusted to fair value in the financial statements:

	Fair Value Measurements - June 30, 2025
			Quoted		Significant
			Prices		Other		Significant
			in Active		Observable		Unobservable
	Carrying		Markets		Inputs		Inputs
	Value		(Level 1)		(Level 2)		(Level 3)
Liabilities:
Current maturities of long-term debt	$	2,534,514	$	—	$	—	$	2,534,514
Notes payable		134,965,486		—		—		131,790,067
Total	$	137,500,000	$	—	$	—	$	134,324,581

	Fair Value Measurements - September 30, 2024
			Quoted		Significant
			Prices		Other		Significant
			in Active		Observable		Unobservable
	Carrying		Markets		Inputs		Inputs
	Value		(Level 1)		(Level 2)		(Level 3)
Liabilities:
Current maturities of long-term debt	$	800,000	$	—	$	—	$	800,000
Notes payable		136,955,000		—		—		135,471,275
Total	$	137,755,000	$	—	$	—	$	136,271,275

The fair value of long-term debt is estimated by discounting the future cash flows of the fixed rate debt based on the underlying treasury rate or other treasury instruments with a corresponding maturity period and estimated credit spread extrapolated based on market conditions since the issuance of the debt.

ASC 825, Financial Instruments , requires disclosures regarding concentrations of credit risk from financial instruments. Cash equivalents are investments in high-grade, short-term securities (original maturity less than three months), placed with financially sound institutions. Accounts receivable are from a diverse group of customers including individuals and small and large companies in various industries. No individual customer amounted to more than 5% of total accounts receivable at June 30, 2025 and September 30, 2024 . The Company maintains certain credit standards with its customers and requires a customer deposit, if warranted.

10.

Earnings Per Share

Basic EPS for the three and nine months ended June 30, 2025 and 2024 was calculated by dividing net income by the weighted-average common shares outstanding during the period. Diluted EPS was calculated by dividing net income by the weighted-average common shares outstanding during the period plus potential dilutive common shares. Potential dilutive common shares are calculated in accordance with the treasury stock method, which assumes that proceeds from the exercise of all options are used to repurchase common stock at market value. The number of shares remaining after the proceeds are exhausted represents the potentially dilutive effect of the securities. The computation of diluted EPS for the three months ended June 30, 2025 and 2024 excludes potentially dilutive shares of 1,695 and 2,164 respectively, and 2,000 and 2,793 , respectively, for the nine months ended June 30, 2025 and 2024 , because to include them would be antidilutive for the periods. However, these shares could potentially dilute EPS in the future.

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A reconciliation of basic and diluted earnings per share is presented below:

	Three Months Ended June 30,				Nine Months Ended June 30,
	2025		2024		2025		2024
Net income	$	538,412	$	156,692	$	13,484,309	$	11,620,074
Weighted-average common shares		10,319,232		10,188,592		10,294,227		10,129,111
Effect of dilutive securities:
Options to purchase common stock		4,933		4,205		4,461		3,236
Diluted average common shares		10,324,165		10,192,797		10,298,688		10,132,347
Earnings per share of common stock:
Basic	$	0.05	$	0.02	$	1.31	$	1.15
Diluted	$	0.05	$	0.02	$	1.31	$	1.15

11.

Other Comprehensive Income (Loss)

A summary of other comprehensive income and loss is provided below:

				Tax
	Before-Tax			(Expense)			Net-of-Tax
	Amount			or Benefit			Amount
Three Months Ended June 30, 2025
Interest rate swaps:
Unrealized losses	$	( 20,816	)	$	5,358		$	( 15,458	)
Transfer of realized gains to interest expense		( 323,513	)		83,273			( 240,240	)
Net interest rate swaps		( 344,329	)		88,631			( 255,698	)
Defined benefit plans:
Amortization of net actuarial gains		( 10,379	)		2,671			( 7,708	)
Other comprehensive loss	$	( 354,708	)	$	91,302		$	( 263,406	)
Three Months Ended June 30, 2024
Interest rate swaps:
Unrealized gains	$	207,785		$	( 53,484	)	$	154,301
Transfer of realized gains to interest expense		( 476,053	)		122,535			( 353,518	)
Net interest rate swaps		( 268,268	)		69,051			( 199,217	)
Defined benefit plans:
Amortization of net actuarial losses		16,015			( 4,122	)		11,893
Other comprehensive loss	$	( 252,253	)	$	64,929		$	( 187,324	)

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				Tax
	Before-Tax			(Expense)			Net-of-Tax
	Amount			or Benefit			Amount
Nine Months Ended June 30, 2025
Interest rate swaps:
Unrealized gains	$	507,492		$	( 130,628	)	$	376,864
Transfer of realized gains to interest expense		( 1,034,976	)		266,403			( 768,573	)
Net interest rate swaps		( 527,484	)		135,775			( 391,709	)
Defined benefit plans:
Amortization of net actuarial gains		( 31,134	)		8,013			( 23,121	)
Other comprehensive loss	$	( 558,618	)	$	143,788		$	( 414,830	)
Nine Months Ended June 30, 2024
Interest rate swaps:
Unrealized gains	$	174,113		$	( 44,816	)	$	129,297
Transfer of realized gains to interest expense		( 1,554,942	)		400,240			( 1,154,702	)
Net interest rate swaps		( 1,380,829	)		355,424			( 1,025,405	)
Defined benefit plans:
Amortization of net actuarial losses		48,045			( 12,366	)		35,679
Other comprehensive loss	$	( 1,332,784	)	$	343,058		$	( 989,726	)

The amortization of actuarial gains and losses, reflected in the preceding table, relate to the unregulated operations of the Company. Actuarial gains and losses attributable to the regulated operations are included as a regulatory asset. See Note 13 for a schedule of regulatory assets. The amortization of actual gains and losses is recognized as a component of net periodic pension and postretirement benefit costs under other income, net in the condensed consolidated statements of income.

Reconciliation of Accumulated Other Comprehensive Income

							Accumulated
							Other
	Interest Rate			Defined Benefit			Comprehensive
	Swaps			Plans			Income (Loss)
Balance at September 30, 2024	$	1,531,649		$	( 205,078	)	$	1,326,571
Other comprehensive loss		( 391,709	)		( 23,121	)		( 414,830	)
Balance at June 30, 2025	$	1,139,940		$	( 228,199	)	$	911,741

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12.

Income Taxes

The effective tax rates for the three -month and nine -month periods ended June 30, 2025 and 2024 reflected in the table below are less than the combined federal and state statutory rate of 25.74 %. The reduction to the effective tax rates is due to additional tax deductions from the amortization of excess deferred taxes and amortization of RNG tax credits deferred as a regulatory liability.

	Three Months Ended June 30,						Nine Months Ended June 30,
	2025			2024			2025			2024
Effective tax rate		23.1	%		23.1	%		23.4	%		23.5	%

ASC 740 provides for the determination of whether tax benefits claimed or expected to be claimed on a tax return should be recognized in the financial statements. The Company has a reserve recorded for unrecognized tax benefits of $ 273,936 as of June 30, 2025 and September 30, 2024 related to tax positions taken in the Company's prior tax returns. The Company has evaluated its tax positions for the three and nine months ended June 30, 2025 and determined no additional reserve for unrecognized tax benefits was necessary. A reconciliation of the Company's unrecognized tax benefits is as follows:

Balance at September 30, 2024	$	273,936
Increase resulting from prior period tax positions		—
Balance at June 30, 2025	$	273,936

The Company’s policy is to classify interest associated with uncertain tax positions as interest expense in the financial statements. Tax penalties, if any, are netted against other income.

The Company files a consolidated federal income tax return and state income tax returns in Virginia and West Virginia, and thus subject to examinations by federal and state tax authorities. The IRS is currently examining the Company's 2018 and 2019 amended federal tax returns. The focus of the examination relates to research and development credits, and the final results of the examination have not been presented to the Company as of the date of this Form 10 -Q. The Company believes its income tax assets and liabilities are fairly stated as of June 30, 2025 and September 30, 2024 ; however, these assets and liabilities could be adjusted as a result of this examination. The Company's amended federal returns for fiscal 2018 and 2019 remain open related to the examination. Aside from these exceptions, the federal returns and the state returns for Virginia and West Virginia for the tax years ended prior to September 30, 2022 are no longer subject to examination.

13.

Regulatory Assets and Liabilities

The Company’s regulated operations follow the accounting and reporting requirements of ASC 980, Regulated Operations . A regulated company may defer costs that have been or are expected to be recovered from customers in a period different from the period in which the costs would ordinarily be charged to expense by an unregulated enterprise. When this situation occurs, costs are deferred as assets in the condensed consolidated balance sheet (regulatory assets) and amortized into expense over periods when such amounts are reflected in customer rates. Additionally, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for current collection in customer rates of costs that are expected to be incurred in the future (regulatory liabilities). In the event the provisions of ASC 980 no longer apply to any or all regulatory assets or liabilities, the Company would write off such amounts and include the effects in the condensed consolidated statements of income and comprehensive income in the period which ASC 980 no longer applied.

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Regulatory assets included in the Company’s accompanying balance sheets are as follows:

	June 30, 2025		September 30, 2024
Assets:
Current Assets:
Regulatory assets:
Accrued WNA revenues	$	414,812	$	919,375
Under-recovery of gas costs		—		2,690,247
Under-recovery of RNG revenues		1,068,795		1,331,064
Under-recovery of SAVE Plan revenues		102,635		107,678
Accrued pension		10,697		42,785
Other deferred expenses		12,762		12,761
Total current		1,609,701		5,103,910
Other Non-Current Assets:
Regulatory assets:
Premium on early retirement of debt		1,056,231		1,141,872
Accrued pension		2,998,881		2,998,881
Other deferred expenses		272,169		304,291
Total non-current		4,327,281		4,445,044

Total regulatory assets	$	5,936,982	$	9,548,954

Regulatory liabilities included in the Company’s accompanying balance sheets are as follows:

	June 30, 2025		September 30, 2024
Liabilities and Stockholders' Equity:
Current Liabilities:
Regulatory liabilities:
Over-recovery of gas costs	$	1,413,992	$	—
Rate refund		—		37,500
Deferred income taxes		591,764		591,764
Supplier refunds		891,994		30,556
Other deferred liabilities		43,609		174,458
Total current		2,941,359		834,278
Deferred Credits and Other Non-Current Liabilities:
Regulatory cost of retirement obligations		15,486,948		14,409,847
Regulatory liabilities:
Deferred income taxes		15,024,273		15,468,096
Deferred postretirement medical		3,858,471		3,858,471
Total non-current		34,369,692		33,736,414

Total regulatory liabilities	$	37,311,051	$	34,570,692

As of June 30, 2025 and September 30, 2024 , the Company had regulatory assets in the amount of $ 5,936,982 and $ 9,548,954 , respectively, on which the Company did not earn a return during the recovery period.

14.

Commitments and Contingencies

Roanoke Gas currently holds the only franchises and/or CPCNs to distribute natural gas in its service area. These franchises generally extend for multi-year periods and are renewable by the municipalities, including exclusive franchises in the cities of Roanoke and Salem and the Town of Vinton, Virginia. All three franchises are set to expire December 31, 2035.

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Due to the nature of the natural gas distribution business, the Company has entered into agreements with both suppliers and pipelines for natural gas commodity purchases, storage capacity and pipeline delivery capacity. Through March 31, 2025, the Company utilized two asset managers to assist in optimizing the use of its transportation, storage rights and gas supply in order to provide a secure and reliable source of natural gas to its customers. Those services were consolidated to one asset manager as of April 1, 2025. The Company also has storage and pipeline capacity contracts to store and deliver natural gas to the Company’s distribution system. Roanoke Gas is currently served directly by three primary pipelines that deliver the natural gas supplied to the Company’s distribution system. Depending on weather conditions and the level of customer demand, failure of one of these transmission pipelines could have a major adverse impact on the Company's ability to deliver natural gas to its customers and its results of operations.

15.

Employee Benefit Plans

The Company has both a pension plan and a postretirement plan. The pension plan covers the Company’s employees hired before January 1, 2017 and provides a retirement benefit based on years of service and employee compensation. The postretirement plan, covering employees hired before January 1, 2000, provides certain health care and supplemental life insurance benefits to retired employees who meet specific age and service requirements. Net pension plan and postretirement plan expense is detailed as follows:

	Three Months Ended June 30,						Nine Months Ended June 30,
	2025			2024			2025			2024
Components of net periodic pension cost:
Service cost	$	96,858		$	81,066		$	290,574		$	243,198
Interest cost		352,602			367,206			1,057,806			1,101,618
Expected return on plan assets		( 375,976	)		( 294,958	)		( 1,127,928	)		( 884,874	)
Recognized loss		14,857			79,132			44,571			237,396
Net periodic pension cost	$	88,341		$	232,446		$	265,023		$	697,338

	Three Months Ended June 30,						Nine Months Ended June 30,
	2025			2024			2025			2024
Components of postretirement benefit cost:
Service cost	$	1,095		$	7,599		$	3,285		$	22,797
Interest cost		126,856			153,369			380,568			460,107
Expected return on plan assets		( 182,430	)		( 133,311	)		( 547,290	)		( 399,933	)
Recognized gain		( 58,153	)		( 10,149	)		( 174,459	)		( 30,447	)
Net postretirement benefit cost	$	( 112,632	)	$	17,508		$	( 337,896	)	$	52,524

The components of net periodic benefit cost, excluding the service cost component, are included in other income, net in the condensed consolidated statements of income. Service cost is included in operations and maintenance expense in the condensed consolidated statements of income.

No funding contributions were made to the pension plan or postretirement plan for the periods presented in the tables above. The Company is not currently planning to make any funding contributions to either plan for the remainder of fiscal 2025.

16.

Leases

The Company has four leases for certain assets including office space and land classified as operating leases with original terms ranging from 3 to 20 years. The Company entered into a new lease during the period, which is a continuation of a prior lease. The Company determines if an arrangement is a lease at inception of the agreement based on the terms and conditions in the contract. The operating lease ROU assets and operating lease liabilities are recognized at the present value of the future minimum lease payments over the lease term at commencement date. As most of the leases do not provide an implicit rate, the Company uses an estimate of its secured incremental borrowing rate based on the information available at commencement date in determining the present value of future payments. The incremental borrowing rate is determined by management aided by inquiries of a third party.

Lease expense for minimum lease payments is recognized on a straight-line basis over the term of the agreement. The Company made an accounting policy election that payments under agreements with an initial term of 12 months or less will not be included on the condensed consolidated balance sheet but will be recognized when paid in the consolidated statements of operations.

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The operating lease ROU assets are reflected in other non-current assets in the condensed consolidated balance sheets. The current operating lease liabilities and non-current lease liabilities are included in other current liabilities and deferred credits and other non-current liabilities, respectively, in the condensed consolidated balance sheets. The expense components of the Company’s operating leases are included under operations and maintenance expense in the condensed consolidated statements of income and were less than $ 50,000 for each period presented.

Other information related to leases were as follows:

		Three Months Ended June 30,
	2025			2024
Supplemental Cash Flow Information:
Cash paid on operating leases	$	16,500		$	9,900
Right of use obtained in exchange for operating lease obligations		36,734			N/A
Weighted-average remaining term (in years)		15.8			17.4
Weighted-average discount rate		5.64	%		5.65	%

		Nine Months Ended June 30,
	2025			2024
Supplemental Cash Flow Information:
Cash paid on operating leases	$	33,000		$	22,166
Right of use obtained in exchange for operating lease obligations		36,734			N/A
Weighted-average remaining term (in years)		15.8			17.4
Weighted-average discount rate		5.64	%		5.65	%

On June 30, 2025 , the future minimum rental payments under non-cancelable operating leases by fiscal year were as follows:

2025	$	21,230
2026		39,938
2027		43,238
2028		39,600
2029		26,400
Thereafter		343,200
Total minimum lease payments		513,606
Less imputed interest		( 162,690	)
Total	$	350,916

17.

Subsequent Events

The Company has evaluated subsequent events through the date the financial statements were issued. There were no items not otherwise disclosed which would have materially impacted the Company’s condensed consolidated financial statements.

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ITEM 2 – MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Forward-Looking Statements

This report contains forward-looking statements that relate to future transactions, events or expectations. In addition, Resources may announce or publish forward-looking statements relating to such matters as anticipated financial performance, business prospects, investments, inflation, ratemaking, debt refinancing, technological developments, new products, research and development activities, operational impacts and similar matters. These statements are based on management’s current expectations and information available at the time of such statements and are believed to be reasonable and are made in good faith. The Private Securities Litigation Reform Act of 1995 provides a safe harbor for forward-looking statements. In order to comply with the terms of the safe harbor, the Company notes that a variety of factors could cause the Company’s actual results and experience to differ materially from the anticipated results or other expectations expressed in the Company’s forward-looking statements. The risks and uncertainties that may affect the operations, performance, development and results of the Company’s business include, but are not limited to, those set forth in the following discussion and within Item 1A “Risk Factors” in the Company’s 2024 Annual Report on Form 10-K. These factors are difficult to predict and many are beyond the Company’s control. Accordingly, while the Company believes its forward-looking statements to be reasonable, there can be no assurance that they will approximate actual experience or that the expectations derived from them will be realized. When used in the Company’s documents or news releases, the words “anticipate,” “believe,” “intend,” “plan,” “estimate,” “predict,” “target,” “expect,” “objective,” “projection,” “potential,” “forecast,” “budget,” “assume,” “indicate” or similar words or future or conditional verbs such as “will,” “would,” “should,” “can,” “could,” “may,” or “might” are intended to identify forward-looking statements.

Forward-looking statements reflect the Company’s current expectations only as of the date they are made. The Company assumes no duty to update these statements should expectations change or actual results differ from current expectations except as required by applicable laws and regulations.

The three-month and nine-month earnings presented herein should not be considered as reflective of the Company’s consolidated financial results for the fiscal year ending September 30, 2025. The total revenues and margins realized during the first nine months reflect higher billings due to the weather-sensitive nature of the natural gas business.

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Overview

Resources is an energy services company primarily engaged in the regulated sale and distribution of natural gas to approximately 62,700 residential, commercial and industrial customers in Roanoke, Virginia and surrounding localities through its Roanoke Gas subsidiary. Midstream, a wholly owned subsidiary of Resources, is a less than 1% investor in both the MVP and Southgate. The utility operations of Roanoke Gas are regulated by the SCC, which oversees the terms, conditions and rates charged to customers for natural gas service, safety standards, extension of service and depreciation. The Company is also subject to regulation from the United States Department of Transportation in regard to the construction, operation, maintenance, safety and integrity of its transmission and distribution pipelines. FERC regulates the prices for the transportation and delivery of natural gas to the Company’s distribution system and underground storage services. In addition, the Company is subject to other regulations which are not necessarily industry specific.

Nearly all of the Company’s revenues are derived from the sale and delivery of natural gas to Roanoke Gas customers based on rates and fees authorized by the SCC. These rates are designed to provide the Company with the opportunity to recover its gas and non-gas expenses and to earn a reasonable rate of return for shareholders based on normal weather. These rates are determined based on various rate applications filed with the SCC. Generally, investments related to extending service to new customers are recovered through the additional revenues generated by the non-gas base rates in place at that time. The investment in replacing and upgrading existing non-SAVE infrastructure, as well as recovering increases in non-gas expenses due to inflationary pressures, regulatory requirements or operational needs, are generally not recoverable until a formal rate application is filed to include the additional investment and higher costs, and new non-gas base rates are approved.

On February 2, 2024, primarily in response to continued inflationary pressures, Roanoke Gas filed for an annual non-gas base rate increase of $4.33 million. The filing also reflected an increase in the Company's authorized return on equity from 9.44% to 10.35%. The new interim non-gas base rates went into effect for customer billings on or after July 1, 2024, subject to refund. On October 16, 2024, the Company reached a settlement with the SCC staff on all outstanding issues in the case. Under the terms of the settlement, the Company agreed to an annual incremental revenue requirement increase of $4.08 million based on a return on equity of 9.90%. On April 10, 2025, the SCC issued a final order approving the settlement in its entirety. The order also directed Roanoke Gas to refund the excess revenues collected during the time the interim rates were in effect with interest. The refunds to customers, which had previously been accrued as a regulatory liability, were made to customers in May 2025.

As the Company’s business is seasonal in nature, volatility in winter weather and the commodity price of natural gas can impact the effectiveness of the Company’s rates in recovering its costs and providing a reasonable return for its shareholders. In order to mitigate the effect of weather variations and other factors not provided for in the Company's base rates, Roanoke Gas has certain approved rate mechanisms in place that help provide stability in earnings, adjust for volatility in the price of natural gas and provide a return on qualified infrastructure investment. These mechanisms include the SAVE Rider, WNA, ICC, RNG Rider and PGA.

The SAVE Plan and Rider provides the Company with a mechanism through which it recovers costs related to qualified SAVE infrastructure investments on a prospective basis, until a rate application is filed incorporating these investments in non-gas base rates. Roanoke Gas filed and received approval from the SCC for an updated annual SAVE Rider rate which became effective October 1, 2024. As a result of the updated SAVE Rider, SAVE Plan revenues increased by approximately $299,000 and $855,000, respectively, for the three-month and nine-month periods ended June 30, 2025 compared to the same periods last year when the recovery of all prior SAVE Plan investment was incorporated into the non-gas base rates that were effective January 1, 2023. The updated SAVE Rider is expected to result in approximately $1,489,000 of annualized SAVE-related revenues during fiscal 2025. Additional information regarding the SAVE Plan and Rider is provided in Note 4 of the condensed consolidated financial statements.

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The WNA mechanism reduces the volatility in earnings due to the variability in temperatures during the heating season. The WNA is based on the most recent 30-year temperature average and provides the Company with a level of earnings protection when weather is warmer than normal and provides its customers with price protection when weather is colder than normal. The WNA allows the Company to recover from its customers the lost margin (excluding gas costs) from warmer-than-normal weather and correspondingly requires the Company to refund the excess margin earned for colder-than-normal weather. The WNA mechanism used by the Company is based on a linear regression model that determines the value of a single heating degree day and thereby estimates the revenue adjustment based on weather variance from normal. Any billings or refunds related to the WNA are completed following each WNA year, which extends for the 12-month period from April to March. For the three and nine months ended June 30, 2025, the Company accrued approximately $493,000 and $966,000 in additional revenues under the WNA model for weather that was 22% and 4% warmer than normal, respectively, compared to approximately $821,000 and $3,689,000 in additional revenues for weather that was 48% and 19% warmer than normal for the corresponding periods last year. The adjusted WNA balance for the 12-month period ended March 31, 2025 was approximately $1,473,000, and was collected from customers during May and June 2025.

The Company has an approved rate structure to mitigate the impact of the financing costs of its natural gas inventory. Under this rate structure, Roanoke Gas recognizes revenue by applying the ICC factor, based on the Company’s weighted-average cost of capital, including interest rates on short-term and long-term debt, and the Company’s authorized return on equity, to the average cost of natural gas inventory during the period. Total ICC revenues decreased by approximately $44,000 and $145,000 for the three-month and nine-month periods ended June 30, 2025 compared to the corresponding periods last year, due to lower natural gas commodity prices during the 2024 summer storage injection season resulting in a lower average cost of natural gas in storage and lower storage balances in the second and third quarters of fiscal 2025. Accordingly, fiscal 2025 and 2026 ICC revenues are expected to continue to remain below last year's levels.

In March 2023, Roanoke Gas began operating the RNG facility, through a cooperative agreement with the Western Virginia Water Authority, to produce commercial quality RNG for delivery into its distribution system. Roanoke Gas is allowed to recover the costs associated with the investment in RNG facilities and the related operating costs through an RNG Rider added to customer bills. Customers receive the benefit of environmental credits generated through the production of RNG. Roanoke Gas recognized approximately $479,000 and $1,296,000 in RNG revenue for the three and nine months ended June 30, 2025 compared to approximately $394,000 and $1,211,000 for the corresponding periods in the prior year.

The cost of natural gas, which is a pass-through cost, is independent of the Company's non-gas rates. Accordingly, the Company's approved billing rates include a component designed to allow for the recovery of the cost of natural gas used by its customers. This rate component, referred to as the PGA, allows the Company to pass along to its customers increases and decreases in natural gas costs through a quarterly filing, or more frequent if necessary, once SCC staff approval is received. As actual costs will differ from the projections used in establishing the PGA rate, the Company will either over-recover or under-recover its actual gas costs during the period. The difference between actual costs incurred and costs recovered through the application of the PGA is recorded as a regulatory asset or liability. At the end of the annual deferral period, the balance is amortized over a succeeding 12-month period through the ensuing non-gas rate component.

Results of Operations

The analysis on the results of operations is based on the consolidated operations of the Company, which is primarily associated with the utility segment. Additional segment analysis is provided when Midstream's investment in affiliates represents a significant component of the comparison.

The Company's operating revenues are affected by the cost of natural gas, as reflected in the condensed consolidated statements of income under cost of gas - utility. The cost of natural gas, which includes commodity price, transportation, storage, injection and withdrawal fees, with any increase or decrease offset by a correlating change in revenue through the PGA, is passed through to customers at cost. Accordingly, management believes that gross utility margin, a non-GAAP financial measure defined as utility revenues less cost of gas, is a useful and relevant measure to analyze financial performance. The term gross utility margin is not intended to represent or replace gross margin, the most comparable GAAP financial measure, as an indicator of operating performance and is not necessarily comparable to similarly titled measures reported by other companies. A reconciliation between gross utility margin and gross margin is presented under the Gross Utility Margin section below. The following results of operations analyses will reference gross utility margin.

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Three Months Ended June 30, 2025:

Net income increased by $381,720 for the three months ended June 30, 2025, compared to the same period last year, primarily due to increased equity earnings from the MVP as the project was service for the entire quarter in fiscal 2025 compared to less than a month during the same period in the prior year.

The tables below reflect operating revenues, volume activity and heating degree days.

	Three Months Ended June 30,					Increase / (Decrease)
		2025		2024		Increase / (Decrease)			Percentage
Operating Revenues
Gas utility		$	17,239,550	$	14,431,379	$	2,808,171			19	%
Non utility			25,065		26,823		(1,758	)		(7	)%
Total operating revenues		$	17,264,615	$	14,458,202	$	2,806,413			19	%
Delivered Volumes
Regulated natural gas (DTH)
Residential and commercial			735,293		786,221		(50,928	)		(6	)%
Transportation and interruptible			1,146,410		996,813		149,597			15	%
Total delivered volumes			1,881,703		1,783,034		98,669			6	%
HDD			250		167		83			50	%

Total operating revenues for the three months ended June 30, 2025 , compared to the same period last year, increased by approximately 19% primarily due to higher gas costs, delivered volumes and SAVE revenues, along with the implementation of a non-gas base rate increase, slightly offset by a decrease in WNA revenue. G as costs were the main contributing factor to the increase in operating revenues over the prior period primarily due to pipeline capacity charges increasing over $2,000,000 as a result of higher rates and MVP capacity. Pipeline capacity charges, which do not impact margin, increased meaningfully during the period, subject to refund, due to FERC rate increase proceedings. While the Company is unable to predict the ultimate outcome, these costs and potential refunds will be passed through to customers. In addition, SAVE Plan revenues increased as Roanoke Gas continues to invest in qualified SAVE infrastructure projects, resulting in approximately $299,000 more revenue compared to the same period in the prior year. T ransportation and interruptible volumes increased 15% primarily driven by business activity of a single, multi-fuel customer during the quarter. The Company expects this customer's usage to remain elevated in the near term, although much of this volume has a lower margin contribution. These increased volumes, coupled with the non-gas base rate increase implemented in July 2024, contributed to an approximate $272,000 increase in non-gas volumetric revenues. WNA revenues declined approximately $328,000 from the corresponding period last year as weather was 22% warmer than the 30-year normal during the current period compared to 48% warmer than normal during the prior period.

	Three Months Ended June 30,					Increase
		2025		2024		Increase		Percentage
Gross Utility Margin
Gas utility revenues		$	17,239,550	$	14,431,379	$	2,808,171		19	%
Cost of gas - utility			7,816,181		5,344,684		2,471,497		46	%
Gross utility margin		$	9,423,369	$	9,086,695	$	336,674		4	%

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Gross utility margin increased over the same period last year primarily as a result of the aforementioned increases in SAVE revenues, as well as increased RNG revenues, slightly offset by the reduction in ICC revenues. As discussed in the Overview section, the WNA model adjusts for the impact of variability of temperatures during the heating season. The WNA model calculates what the corresponding volumes would be if temperatures were equivalent to the 30-year normal during each period and adjusts for the difference in margin from normal. In applying the WNA model to both the current and prior years, the volumetric margin, net of the WNA, decreased slightly by approximately $56,000 due a decrease of 17% in WNA adjusted residential and commercial delivered volumes. The SAVE Plan and RNG Riders contributed an additional $299,000 and $85,000, respectively, to margin, while ICC revenues decreased by approximately $44,000 due to lower cost of gas in storage.

The changes in the components of gas utility margin are summarized below:

		Three Months Ended June 30,				Increase/
	2025		2024		(Decrease)
Customer base charge	$	4,094,700	$	4,066,559	$	28,141
ICC		92,187		136,162		(43,975	)
SAVE Plan		426,551		127,073		299,478
Volumetric		3,781,321		3,509,482		271,839
WNA		492,840		821,145		(328,305	)
RNG		479,380		393,921		85,459
Other revenues		56,390		32,353		24,037
Total	$	9,423,369	$	9,086,695	$	336,674

The tables below provide a reconciliation between gross utility margin and gross margin:

	Gas Utility			Investment in Affiliates			Consolidated Total
Three Months Ended June 30, 2025
Operating revenues
Gas utility	$	17,239,550		$	—		$	17,239,550
Non utility		25,065			—			25,065
Total operating revenues		17,264,615			—			17,264,615
Cost of sales
Cost of gas - utility		(7,816,181	)		—			(7,816,181	)
Cost of sales - non utility		(4,791	)		—			(4,791	)
Depreciation and amortization		(2,909,344	)		—			(2,909,344	)
Operations and maintenance		(4,544,554	)		(43,118	)		(4,587,672	)
Total cost of sales		(15,274,870	)		(43,118	)		(15,317,988	)
Gross margin (GAAP)		1,989,745			(43,118	)		1,946,627
Corporate and other, net		(20,274	)		—			(20,274	)
Depreciation and amortization		2,909,344			—			2,909,344
Operations and maintenance		4,544,554			43,118			4,587,672
Gross utility margin (Non-GAAP)	$	9,423,369		$	—		$	9,423,369

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	Gas Utility			Investment in Affiliates			Consolidated Total
Three Months Ended June 30, 2024
Operating revenues
Gas utility	$	14,431,379		$	—		$	14,431,379
Non utility		26,823			—			26,823
Total operating revenues		14,458,202			—			14,458,202
Cost of sales
Cost of gas - utility		(5,344,684	)		—			(5,344,684	)
Cost of sales - non utility		(4,567	)		—			(4,567	)
Depreciation and amortization		(2,697,707	)		—			(2,697,707	)
Operations and maintenance		(4,183,281	)		(37,084	)		(4,220,365	)
Corporate and other		—			—			(1,296	)
Total operations and maintenance		(4,183,281	)		(37,084	)		(4,221,661	)
Total cost of sales		(12,230,239	)		(37,084	)		(12,268,619	)
Gross margin (GAAP)		2,227,963			(37,084	)		2,189,583
Corporate and other, net		(22,256	)		—			(20,960	)
Depreciation and amortization		2,697,707			—			2,697,707
Operations and maintenance		4,183,281			37,084			4,220,365
Gross utility margin (Non-GAAP)	$	9,086,695		$	—		$	9,086,695

RGC RESOURCES, INC. AND SUBSIDIARIES

Operations and maintenance expenses increased $366,011, or 9%, from the same period last year. Personnel costs increased by approximately $166,000 due to increased staffing and the inflationary impact on salaries and benefits. Contracted services increased by approximately $83,000 also due to inflationary pressures. These increases were slightly offset by a decrease in professional services expenses. C osts associated with the RNG facility increased approximately $104,000.

Taxes other than income taxes increased by $118,077, or 19%, due to higher property taxes associated with growth in utility property and increased valuations.

Depreciation expense increased by $211,637, or 8%, consistent with an increase in utility property balances.

Equity in earnings of unconsolidated affiliate increased by $489,478. With the MVP in service, the Company now recognizes its share of operational earnings from the MVP, favorably adjusted for the amortization of a basis difference that arose when the Company recorded an other-than-temporary impairment of its investment in 2022, which exceeded the amount of AFUDC recognized during the prior period as construction activities were winding down at the end of the project. See Note 5 of the consolidated financial statements for additional information related to the MVP.

Other income, net increased by $313,349 primarily due to an approximate $284,000 decrease in benefit plan costs other than service cost, coupled with an increase of approximately $68,000 in revenue sharing related to the asset management agreement, which is described in more detail in the Asset Management section.

Interest expense decreased by $54,339, or 4%, as the weighted-average interest rate on total debt decreased from 4.42% during the third quarter of fiscal 2024 to 4.12% during the third quarter of fiscal 2025. Roanoke Gas' interest expense decreased by $45,984, or 5%, as total average debt outstanding decreased by approximately $2,671,000 associated with net payments on the Company's line-of-credit. See Notes 6 and 7 of the consolidated financial statements for more information on the Company's debt.

Income tax expense increased by $114,413 corresponding to the increase in pre-tax income. The effective tax rate was 23.1% for the three-month periods ended June 30, 2025 and 2024. The effective tax rate is below the combined statutory state and federal rate due to the amortization of excess deferred taxes and tax credits.

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Nine Months Ended June 30, 2025:

Net income increased by $1,864,235 for the nine months ended June 30, 2025, compared to the same period last year, primarily due to the implementation of higher non-gas base rates and increased natural gas deliveries, partially offset by lower WNA revenues and lower equity earnings from the MVP as the project transitioned from construction to in service, as well as lower benefit plan costs.

The tables below reflect operating revenues, volume activity and heating degree days.

	Nine Months Ended June 30,				Increase/
	2025		2024		(Decrease)			Percentage
Operating Revenues
Gas utility	$	80,938,690	$	71,455,564	$	9,483,126			13	%
Non utility		77,508		81,366		(3,858	)		(5	)%
Total operating revenues	$	81,016,198	$	71,536,930	$	9,479,268			13	%
Delivered Volumes
Regulated natural gas (DTH)
Residential and commercial		6,270,883		5,744,657		526,226			9	%
Transportation and interruptible		3,630,280		2,835,348		794,932			28	%
Total delivered volumes		9,901,163		8,580,005		1,321,158			15	%
HDD		3,641		3,084		557			18	%

Total operating revenues for the nine months ended June 30, 2025 , compared to the same period last year, increased by approximately 13% primarily due to the implementation of a non-gas base rate increase, along with higher delivered volumes, gas costs and SAVE revenues, partially offset by a decrease in WNA revenue. The non-gas base rate increase implemented in 2024 was the main contributing factor to an approximate $5.4 million increase in non-gas volumetric revenues. In addition, total heating degree days increased by 18% from the same period last year, resulting in a 9% increase in the weather-sensitive residential and commercial volumes, while transportation and interruptible volumes increased 28%, primarily driven by business activity of a single, multi-fuel customer during the period. Total gas costs also increased over the prior period primarily due to pipeline capacity charges increasing over $3.7 million as a result of higher rates and MVP capacity. SAVE Plan revenues increased as Roanoke Gas continues to invest in qualified SAVE infrastructure projects, resulting in approximately $855,000 more revenue compared to the same period in the prior year. WNA revenues declined approximately $2.7 million from the corresponding period last year as weather was only 4% warmer than normal during the current period compared to 20% warmer than normal during the prior period.

	Nine Months Ended June 30,
	2025		2024		Increase		Percentage
Gross Utility Margin
Gas utility revenues	$	80,938,690	$	71,455,564	$	9,483,126		13	%
Cost of gas - utility		36,581,043		30,741,090		5,839,953		19	%
Gross utility margin	$	44,357,647	$	40,714,474	$	3,643,173		9	%

Gross utility margin increased over the same period last year primarily as a result of the implementation of new non-gas base rates and increases in SAVE revenues, slightly offset by the reduction in ICC revenues. The volumetric margin, net of the WNA, increased by approximately $2.7 million primarily due to the new non-gas base rates and increases in transportation and interruptible volumes. The SAVE Plan contributed an additional $855,000 to margin, while ICC revenues decreased by approximately $145,000 due to lower cost of gas in storage.

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The changes in the components of gas utility margin are summarized below:

	Nine Months Ended June 30,				Increase/
	2025		2024		(Decrease)
Customer base charge	$	12,278,739	$	12,177,584	$	101,155
ICC		383,852		528,883		(145,031	)
SAVE Plan		1,070,742		215,890		854,852
Volumetric		28,197,870		22,767,198		5,430,672
WNA		966,296		3,688,767		(2,722,471	)
RNG		1,296,313		1,211,464		84,849
Other revenues		163,835		124,688		39,147
Total	$	44,357,647	$	40,714,474	$	3,643,173

The tables below provide a reconciliation between gross utility margin and gross margin:

	Gas Utility			Investment in Affiliates			Consolidated Total
Nine Months Ended June 30, 2025
Operating revenues
Gas utility	$	80,938,690		$	—		$	80,938,690
Non utility		77,508			—			77,508
Total operating revenues		81,016,198			—			81,016,198
Cost of sales
Cost of gas - utility		(36,581,043	)		—			(36,581,043	)
Cost of sales - non utility		(14,558	)		—			(14,558	)
Depreciation and amortization		(8,609,472	)		—			(8,609,472	)
Operations and maintenance		(14,484,248	)		(115,286	)		(14,599,534	)
Total cost of sales		(59,689,321	)		(115,286	)		(59,804,607	)
Gross margin (GAAP)		21,326,877			(115,286	)		21,211,591
Corporate and other, net		(62,950	)		—			(62,950	)
Depreciation and amortization		8,609,472			—			8,609,472
Operations and maintenance		14,484,248			115,286			14,599,534
Gross utility margin (Non-GAAP)	$	44,357,647		$	—		$	44,357,647

	Gas Utility			Investment in Affiliates			Consolidated Total
Nine Months Ended June 30, 2024
Operating revenues
Gas utility	$	71,455,564		$	—		$	71,455,564
Non utility		81,366			—			81,366
Total operating revenues		71,536,930			—			71,536,930
Cost of sales
Cost of gas - utility		(30,741,090	)		—			(30,741,090	)
Cost of sales - non utility		(16,421	)		—			(16,421	)
Depreciation and amortization		(8,093,121	)		—			(8,093,121	)
Operations and maintenance		(13,772,433	)		(103,296	)		(13,875,729	)
Corporate and other		—			—			(3,784	)
Total operations and maintenance		(13,772,433	)		(103,296	)		(13,879,513	)
Total cost of sales		(52,623,065	)		(103,296	)		(52,730,145	)
Gross margin (GAAP)		18,913,865			(103,296	)		18,806,785
Corporate and other, net		(64,945	)		—			(61,161	)
Depreciation and amortization		8,093,121			—			8,093,121
Operations and maintenance		13,772,433			103,296			13,875,729
Gross utility margin (Non-GAAP)	$	40,714,474		$	—		$	40,714,474

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Operations and maintenance expenses increased by $720,021, or 5%, from the same period last year primarily due to inflationary effects on personnel costs and contracted services, and lower capitalized overheads . Personnel costs and contracted services increased by approximately $367,000 due to increased staffing and the inflationary impact on salaries and benefits, as well as third party services. T otal capitalized overheads declined by approximately $179,000 due to a reduction in direct construction expenditures related to Roanoke Gas capital projects compared to the same period last year and lower overheads capitalized as part of LNG due to timing of production. Increased RNG expenses, corporate insurance premiums and bad debt expense associated with the higher accounts receivable balances accounted for much of the remaining cost increase.

Taxes other than income taxes increased by $319,622, or 16%, primarily due to higher property taxes associated with growth in utility property and increased valuations.

Depreciation expense increased by $516,351, or 6%, consistent with an increase in utility property balances.

Equity in earnings of unconsolidated affiliate decreased by $552,353, or 19%. With the MVP in service, the Company now recognizes its share of operational earnings from the MVP, favorably adjusted for the amortization of a basis difference that arose when the Company recorded an other-than-temporary impairment of its investment in 2022. These in-service earnings did not fully replace the amount of AFUDC recognized while construction activities were ongoing during the first eight months of fiscal 2024. See Note 5 of the consolidated financial statements for additional information related to the MVP.

Other income, net increased by $1,040,045 primarily due to an approximate $848,000 decrease in benefit plan costs other than service cost, coupled with an increase of approximately $270,000 in revenue sharing related to the asset management agreements, which are described in more detail in the Asset Management section.

Interest expense increased by $152,980, or 3%, primarily due to higher borrowing levels, along with higher interest rates on the Company's variable-rate debt. Total average debt outstanding during the first nine months of fiscal 2025 increased by 4% from the first nine months of fiscal 2024. Roanoke Gas' total average debt outstanding increased by approximately $2,445,000 associated with net borrowings under the Company's line-of-credit, while Midstream's total average debt outstanding increased by approximately $2,170,000 during the period. There were minimal fluctuations in the weighted-average interest rates between the periods. See Notes 6 and 7 of the consolidated financial statements for more information on the Company's debt.

Income tax expense increased by $555,661, or 16%, corresponding to an increase in pre-tax income. The effective tax rate was 23.4% and 23.5% for the nine-month periods ended June 30, 2025 and 2024, respectively. The effective tax rate is below the combined statutory state and federal rate due to the amortization of excess deferred taxes and tax credits.

Critical Accounting Policies and Estimates

The consolidated financial statements of Resources are prepared in accordance with GAAP. The amounts of assets, liabilities, revenues and expenses reported in the Company’s consolidated financial statements are affected by accounting policies, estimates and assumptions that are necessary to comply with generally accepted accounting principles. Estimates used in the financial statements are derived from prior experience, statistical analysis and management judgments. Actual results may differ significantly from these estimates and assumptions.

There have been no significant changes to the critical accounting policies as reflected in the Company’s Annual Report on Form 10-K for the year ended September 30, 2024.

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RGC RESOURCES, INC. AND SUBSIDIARIES

Asset Management

Roanoke Gas uses a third-party asset manager to oversee its pipeline transportation, storage rights and gas supply inventories and deliveries in order to provide a secure and reliable source of natural gas to its customers. In return for utilizing the excess capacities of the transportation and storage rights, the asset manager pays Roanoke Gas a monthly utilization fee. In accordance with an SCC order issued in 2018, a portion of the utilization fee is retained by the Company with the balance passed through to customers through reduced gas costs. On March 26, 2025, the Company entered into a new asset manager agreement effective April 1, 2025 and is set to expire on March 31, 2028.

Equity Investment in Mountain Valley Pipeline

The Company has a less than 1% interest in the MVP, which is accounted for as an equity investment, and a less than 1% interest in the Southgate pipeline, which is contemplated to interconnect with the MVP and accounted for under the cost method.

From inception through May 2024, earnings from the LLC were primarily attributable to AFUDC income. With the MVP in operation, the Company recognizes its share of earnings from the LLC, favorably adjusted for a basis difference between the Company's proportional share of assets and its carrying value that arose when the Company recorded an other-than-temporary impairment of its investment in 2022. This basis difference amortization is a favorable non-cash adjustment over the operational life of the MVP, or 40 years. For the three and nine months ended June 30, 2025, the Company recorded equity in earnings of consolidated affiliate of approximately $772,000 and $2.4 million, respectively, compared to $283,000 and $3.0 million for the same periods in 2024, with the 2024 amounts being derived from AFUDC. Midstream has received quarterly cash distributions of its share from the LLC totaling approximately $2.7 million during the first nine months of fiscal 2025 which was a return on its invested capital. Future quarterly distributions are expected to be of a similar magnitude. The Company is using this cash to pay interest and other expenditures related to Midstream.

Regulatory

See Note 4 of the condensed consolidated financial statements for discussion on Regulatory matters.

Capital Resources and Liquidity

Due to the capital-intensive nature of the utility business, as well as the impact of weather variability, the Company’s primary capital needs are the funding of its capital projects, the seasonal funding of its natural gas inventories and accounts receivables, debt service and payments of dividends to shareholders. The Company anticipates funding these items through its operating cash flows, credit availability under short-term and long-term debt agreements and proceeds from the sale of its common stock.

Cash and cash equivalents increased by $1,232,704 for the nine-month period ended June 30, 2025 compared to an increase of $1,028,662 for the nine-month period ended June 30, 2024. The following table summarizes the sources and uses of cash:

	Nine Months Ended June 30,
Cash Flow Summary	2025			2024
Net cash provided by operating activities	$	28,273,016		$	17,056,186
Net cash used in investing activities		(15,756,669	)		(16,544,262	)
Net cash (used in) provided by financing activities		(11,283,643	)		516,738
Increase in cash and cash equivalents	$	1,232,704		$	1,028,662

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RGC RESOURCES, INC. AND SUBSIDIARIES

Cash Flows Provided by Operating Activities:

The seasonal nature of the natural gas business causes operating cash flows to fluctuate significantly during the year as well as from year-to-year. Factors, including weather, energy prices, natural gas storage levels and customer collections, contribute to working capital levels and related cash flows. Generally, operating cash flows are positive during the second and third fiscal quarters as a combination of earnings, declining storage gas levels and collections on customer accounts contribute to higher cash inflows. During the first and fourth fiscal quarters, operating cash flows generally decrease due to increases in natural gas storage levels and rising customer receivable balances.

Cash flows from operating activities for the nine months ended June 30, 2025 increased by $11,216,830 compared to the same period last year. The table below summarizes the significant components of operating cash flows:

	Nine Months Ended June 30,						Increase/
Cash Flow From Operating Activities:	2025			2024			(Decrease)
Net income	$	13,484,309		$	11,620,074		$	1,864,235
Non-cash adjustments:
Depreciation		8,609,472			8,285,761			323,711
Equity in earnings		(2,427,470	)		(2,979,823	)		552,353
Distribution from unconsolidated affiliate		2,658,656			—			2,658,656
Changes in working capital and regulatory assets and liabilities:
Accounts receivable		(2,033,388	)		(1,323,520	)		(709,868	)
Gas in storage		2,407,209			3,953,984			(1,546,775	)
Change in over collection of gas costs		4,104,239			1,066,611			3,037,628
Accounts payable		1,312,082			577,245			734,837
Supplier refunds		861,438			(242,685	)		1,104,123
Change in accrued WNA revenues		504,562			(1,503,472	)		2,008,034
Rate refund		(37,500	)		(652,018	)		614,518
Other		(1,170,593	)		(1,745,971	)		575,378
Net cash provided by operating activities	$	28,273,016		$	17,056,186		$	11,216,830

The increase in operating cash flows is primarily due to higher net income and the cash distributions received from the LLC, along with direct impacts from weather and increased pipeline and storage capacity charges. During the first nine months of fiscal 2025, t he Company received approximately $2,659,000 in quarterly cash distributions from the LLC, which was has been accounted for as a return on its invested capital. In addition, colder weather and increased gas costs compared to the same period last year resulted in higher accounts receivable and accounts payable balances. Pipeline and storage capacity charges during the first nine months of fiscal 2025 increased over $3,100,000 from the same period in the prior year. Additionally, total commodity costs increased from $3.53 per DTH in the first nine months of fiscal 2024 to $3.69 per DTH in the first nine months of fiscal 2025. WNA revenues for the first nine months of fiscal 2025 declined by approximately $2.7 million from the same period last year corresponding to an 18% increase in the number of heating degree days between periods. This decline in WNA receivable contributed $2.0 million in additional operating cash. In December 2024, the Company received an approximate $890,000 supplier refund, resulting from a FERC rate case settlement, from one of the interstate pipelines that supplies the Company with natural gas.

Cash Flows Used in Investing Activities:

Investing activities primarily consist of expenditures related to Roanoke Gas' utility property, which includes replacing aging natural gas pipe with new plastic or coated steel pipe, improvements to the LNG plant and gas distribution system facilities and expansion of its natural gas system to meet new customer demand. The Company is continuing its focus on SAVE infrastructure replacement projects, including the replacement of pre-1973 first generation plastic pipe. New customer demand for natural gas continues to be steady and therefore extending the natural gas distribution system within its service territory is also a priority. Roanoke Gas' total capital expenditures for the nine-month period ended June 30, 2025 were approximately $ 15.7 million compared to $16.6 million during the same period last year. Total fiscal 2025 capital expenditures are expected to be approximately $22 million. Midstream continues to be invested in the LLC; however, the Company did not make capital contributions in 2024 or 2025 under a prior agreement with the LLC's managing partner. Accordingly, Midstream's ownership percentage declined during the remaining construction period of the project. Now that the MVP is in service, Midstream will incur periodic, future capital investment related to ongoing MVP operations requirements and system improvements. Midstream has and will continue to make capital investments in Southgate. The targeted timing for completion of the Southgate project is 2028.

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RGC RESOURCES, INC. AND SUBSIDIARIES

Cash Flows Provided by Financing Activities:

F inancing activities generally consist of borrowings and repayments under credit agreements, issuance of common stock and the payment of dividends. Net cash flows used in financing activities were approximately $11.3 million for the nine months ended June 30, 2025, compared to $517,000 in net cash flows provided by financing activities for the same period last year. The $11.8 million decrease in financing cash flows is primarily attributable to net payments of $6.2 million under Roanoke Gas' line-of-credit during the first nine months of fiscal 2025 compared to net borrowings of $3.3 million in the same period last year.

In addition, Resources issued a total of 74,057 shares of common stock resulting in net proceeds of approximately $1.5 million. No shares were issued through the ATM program during the first nine months of fiscal 2025. During the same period last year, Resources issued 177,906 shares for approximately $3.5 million, including 85,501 shares through the ATM program for approximately $1.7 million, net of fees.

Management regularly evaluates the Company’s liquidity through a review of its available financing resources and its cash flows. Resources maintains the ability to raise equity capital through its ATM program, private placement or other public offerings. Management believes Roanoke Gas has access to sufficient financing resources to meet its cash requirements for the next year, including the line of credit and the two private shelf facilities. Roanoke Gas may also adjust capital spending if such a need would arise.

With the MVP in service, Midstream's future cash requirements will relate to regular monthly operating expenses, debt service and capital contributions. The Company has received three quarterly cash distributions from MVP totaling approximately $2.7 million during the first nine months of fiscal 2025, and going forward should receive similar distributions quarterly. Subsequent to the end of the quarter, the Company entered into a firm letter of commitment with two banks for long-term structures related to the debt that supports its investment in Midstream as discussed more fully in Note 7. Under the letter of commitment, Midstream will enter into a new loan with a seven-year term bearing an interest rate of SOFR plus 1.55%. In addition to interest, Midstream will repay principal based on a schedule aligned with the MVP shipper contracts, which expire in June 2044 and will approximate $2.8 million annually. With these firm commitments, the Company has classified all debt related to Midstream as long-term except for $2.5 million of principal amortization expected in the coming 12 months. Covenants on these facilities are similar to the existing arrangements. The Company expects to consummate the arrangement in the fourth quarter of fiscal 2025.

The Company believes this new debt structure in conjunction with cash distributions from MVP and support from RGC Resources, as needed, will enable Midstream to satisfy all of its obligations, including amortization, while the LLC works to increase cash flows. The Company believes this will enhance the value of the Company's investment.

As of June 30, 2025, Resources' long-term capitalization ratio was 45% equity and 55% debt.

ITEM 3 – QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Not applicable.

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ITEM 4 – CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

The Company maintains disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”)) that are designed to be effective in providing reasonable assurance that information required to be disclosed in reports under the Exchange Act are identified, recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC, and that such information is accumulated and communicated to management to allow for timely decisions regarding required disclosure.

Through June 30, 2025, the Company has evaluated, under the supervision and with the participation of management, including the chief executive officer and the chief financial officer, the effectiveness of the design and operation of the Company’s disclosure controls and procedures. Based upon that evaluation, the chief executive officer and chief financial officer concluded that the Company’s disclosure controls and procedures were effective at the reasonable assurance level as of June 30, 2025.

Changes in Internal Control over Financial Reporting

On April 1, 2025, the Company implemented a new enterprise resource planning (“ERP”) system, which replaced the existing ERP system, to improve the efficiency of certain financial and related transactional processes; this system did not replace the system of record for revenue transactions with customers. In connection with this implementation, the Company has enhanced its processes and procedures, which has resulted in changes to internal control over financial reporting, to align with the upgraded system functionality. The Company will continue to monitor and evaluate the operating effectiveness of the related controls during subsequent periods.

Management routinely reviews the Company’s internal control over financial reporting and makes changes, as necessary, to enhance the effectiveness of the internal controls. Except for the implementation of the new ERP system, there were no other changes in internal control over financial reporting that occurred during the three months ended June 30, 2025, that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

Limitations on the Effectiveness of Controls

Because of the inherent limitations in an effective internal control system, any control system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance that it will prevent or detect all misstatements, due to error or fraud, from occurring in the consolidated financial statements. Additionally, management is required to use judgment in evaluating controls and procedures.

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RGC RESOURCES, INC. AND SUBSIDIARIES

Part II – Other Information

ITEM 1 – LEGAL PROCEEDINGS

None.

ITEM 1A – RISK FACTORS

There have been no material changes to the risk factors previously disclosed in Resources' Annual Report on Form 10-K for the year ended September 30, 2024.

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

None.

ITEM 3 – DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4 – MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5 – OTHER INFORMATION

None.

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RGC RESOURCES, INC. AND SUBSIDIARIES

ITEM 6 – EXHIBITS

Number						Description
10.1						Natural Gas Asset Management A greement by and between Roanoke Gas Company and DTE Energy Trading, Inc. effective as of April 1, 2025 (incorporated herein by reference to Exhibit 10.1 on Form 8-K as filed March 31, 2025).
10.2						Guaranty Agreement by RGC Resources, Inc. in favor of DTE Energy Trading, Inc. effective April 1, 2025 (incorporated herein by reference to Exhibit 10.2 on Form 8-K as filed March 31, 2025).
31.1						Rule 13a–14(a)/15d–14(a) Certification of Principal Executive Officer
31.2						Rule 13a–14(a)/15d–14(a) Certification of Principal Financial Officer
32.1*						Section 1350 Certification of Principal Executive Officer
32.2*						Section 1350 Certification of Principal Financial Officer
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)
101.SCH						Inline XBRL Taxonomy Extension Schema Document
101.CAL						Inline XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF						Inline XBRL Taxonomy Extension Definition Linkbase Document
101.LAB						Inline XBRL Taxonomy Extension Label Linkbase Document
101.PRE						Inline XBRL Taxonomy Extension Presentation Linkbase Document
104						Cover Page Interactive Data File (formatted as inline XBRL and contained in Exhibit 101)

These certifications are being furnished solely to accompany this quarterly report pursuant to 18 U.S.C. Section 1350, and are not being filed for purposes of Section 18 of the Securities Exchange Act of 1934 and are not to be incorporated by reference into any filing of the Registrant, whether made before or after the date hereof, regardless of any general incorporation language in such filing.

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RGC RESOURCES, INC. AND SUBSIDIARIES

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.

		RGC Resources, Inc.

Date: August 12, 2025	By:	/s/ Timothy J. Mulvaney
		Timothy J. Mulvaney
		Vice President, Treasurer and Chief Financial Officer
		(Principal Financial Officer)

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Item 2 Management S Discussion and Analysis Of Financial Condition and Results Of Operations Item 3 Quantitative and Qualitative Disclosures About Market Risk Item 4 Controls and Procedures Part II Other Information Item 1 Legal Proceedings Item 1A Risk Factors Item 2 Unregistered Sales Of Equity Securities and Use Of Proceeds Item 3 Defaults Upon Senior Securities Item 4 Mine Safety Disclosures Item 5 Other Information Item 6 Exhibits

Exhibits

10.1 Natural Gas Asset Management Agreement by and between Roanoke Gas Company and DTE Energy Trading, Inc. effective as of April 1, 2025(incorporated herein by reference to Exhibit 10.1 on Form 8-K as filed March 31, 2025). 10.2 Guaranty Agreement by RGC Resources, Inc. in favor of DTE Energy Trading, Inc. effective April 1, 2025(incorporated herein by reference to Exhibit 10.2 on Form 8-K as filed March 31, 2025). 31.1 Rule 13a14(a)/15d14(a) Certification of Principal Executive Officer 31.2 Rule 13a14(a)/15d14(a) Certification of Principal Financial Officer 32.1* Section 1350 Certification of Principal Executive Officer 32.2* Section 1350 Certification of Principal Financial Officer

RGCO 10-Q Quarter ended June 30, 2025

Exhibits