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, Diversified Energy 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 ~~March 31,~~June 30, 2023, cash flows for the ~~six~~nine months ended ~~March 31,~~June 30, 2023 and 2022, and the results of its operations, comprehensive income, and changes in stockholders' equity for the three and ~~six~~nine months ended ~~March 31,~~June 30, 2023 and 2022. The results of operations for the three and ~~six~~nine months ended ~~March 31,~~June 30, 2023 are not indicative of the results to be expected for the fiscal year ending September 30, 2023 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 condensed 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 condensed 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, 2022. The September 30, 2022 consolidated balance sheet was included in the Company’s audited financial statements included in Form 10-K.

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, 2022.

In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848) - Facilitation of the Effects of Reference Rate Reform on Financial Reporting. In combination with ASU 2021-01 and ASU 2022-06, the ASU provides temporary optional guidance to ease the potential burden in accounting for and recognizing the effects of reference rate change on financial reporting. The new guidance applies specifically to contracts and hedging relationships that reference LIBOR, or any other referenced rate that is expected to be discontinued due to reference rate reform. The new guidance is effective for the Company through December 31, 2024. The Intercontinental Exchange Benchmark Administration, the administrator for LIBOR and other inter-bank offered rates, announced that the LIBOR rates for one-day, one-month, six-month and one-year ~~will~~would cease publication in June 2023 and that no new financial contracts may use LIBOR after December 31, 2021. ~~Currently,~~Subsequent to June 30, 2023, the one-day, one-month, six-month, and one-year LIBOR settings will continue to be published under an unrepresentative synthetic methodology until the end of September 2024 in order to bridge the transition to other reference rates. The Company has transitioned all but one LIBOR based variable rate note to a new reference rate as of June 30, 2023. Each of the ~~Company's LIBOR based financial contracts are based on~~revised notes has a corresponding swap that was also transitioned to align with the ~~one~~~~-month LIBOR rate.~~ ~~None~~ ~~of the holders of these financial contracts have indicated when a~~related notes. The last variable rate note is expected to transition from LIBOR ~~will occur. Accordingly,~~during the ~~Company does~~ ~~not~~fourth ~~anticipate adopting this guidance until later in~~quarter of fiscal 2023. ~~The new guidance could result in a significant impact on the Company's financial position, results of operations,~~See Note 7 and ~~cash flows when the reference rate is changed~~Note 9 for ~~related contracts.~~more information.

Other accounting standards that have been issued by the FASB 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.

In March 2022, the Company issued 1,350,000 shares of common stock in an equity offering resulting in net proceeds of nearly ~~$27,000,000.~~$27 million. The Company issued the common stock to strengthen its balance sheet by increasing its cash position and lowering its outstanding debt. The net proceeds were invested in Roanoke Gas to supplement the funding of its infrastructure improvement and replacement program and in Midstream to reduce its outstanding debt. An additional 95,443 shares of common stock were issued during fiscal 2022 related to the DRIP, Restricted Stock, stock option exercises and ATM activity.

During fiscal 2023, ~~102,812~~177,900 shares of common stock have been issued through ~~March 31,~~June 30, 2023 related to the DRIP, Restricted Stock, stock option exercises and ATM activity.

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.

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

	Nine Months Ended June 30, 2023						Nine Months Ended June 30, 2022
	Gas utility		Non utility		Total operating revenues		Gas utility		Non utility		Total operating revenues
Natural Gas (Billed and Unbilled):
Residential	$	48,148,235	$	—	$	48,148,235	$	40,382,660	$	—	$	40,382,660
Commercial		28,502,754		—		28,502,754		23,213,599		—		23,213,599
Industrial and Transportation		4,508,997		—		4,508,997		4,222,342		—		4,222,342
Other		855,079		86,637		941,716		490,403		95,139		585,542
Total contracts with customers		82,015,065		86,637		82,101,702		68,309,004		95,139		68,404,143
Alternative Revenue Programs		2,870,535		—		2,870,535		1,648,519		—		1,648,519
Total operating revenues	$	84,885,600	$	86,637	$	84,972,237	$	69,957,523	$	95,139	$	70,052,662

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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. Tariff rates represent the transaction price. Performance obligations created under these tariff-based sales include the cost of natural gas sold to customers (commodity) and the cost of transporting natural gas through the Company’s distribution system to customers (delivery). 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 industrial customers at the end of each month, thereby eliminating any unbilled consideration for these rate classes.

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 balances of customer receivables are provided below:

	Current Assets				Current Liabilities					Current Assets						Current Liabilities
	Trade accounts receivable(1)		Unbilled revenue(1)		Customer credit balances			Customer deposits		Trade accounts receivable(1)			Unbilled revenue(1)			Customer credit balances			Customer deposits
Balance at September 30, 2022	$	3,697,431	$	1,585,062	$	1,400,770		$	1,457,610	$	3,697,431		$	1,585,062		$	1,400,770		$	1,457,610
Balance at March 31, 2023		7,166,424		2,862,955		743,376			1,580,082
Balance at June 30, 2023											3,440,361			1,206,943			1,140,998			1,495,493
Increase (decrease)	$	3,468,993	$	1,277,893	$	(657,394	)	$	122,472	$	(257,070	)	$	(378,119	)	$	(259,772	)	$	37,883

⁽¹⁾ Included in accounts receivable in the condensed consolidated balance sheet. Amounts shown net of reserve for credit losses.

The Company had no significant contract assets or liabilities during the period. Furthermore, the Company did not incur any significant costs to obtain contracts.

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4.	Income Taxes

The effective tax rate for the three month period ended June 30, 2023 is greater than the corresponding period in fiscal 2022 primarily due to the exercise of stock options.

The effective tax rates for the three and ~~six~~nine month periods ended ~~March 31,~~June 30, 2023 reflected in the table below are less than the ~~corresponding periods in fiscal~~ ~~2022~~ ~~and the~~ combined federal and state statutory rate of 25.74% ~~due to additional tax deductions from the amortization of excess deferred taxes~~ and ~~amortization of R&D tax credits deferred as a regulatory liability.~~

~~Excluding the effect of the Midstream impairment,~~ the effective tax rate for the ~~three~~ ~~and~~ ~~six~~nine month ~~periods~~period ended ~~March 31, 2022~~June 30, 2022. ~~would have been 24.0% and 23.7%, respectively, reflecting~~The decrease in the ~~impact~~effective tax rate corresponds to the recognition of ~~additional~~a deferred tax ~~deductions from~~asset associated with the ~~amortization~~impairment of ~~R&D tax credits deferred as a regulatory liability and~~ the ~~exercise of stock options.~~Company's investment in the LLC in fiscal 2022. The recognition of the impairment resulted in a net loss position for ~~both periods in fiscal~~the ~~2022,~~nine month period ended June 30, 2022 thereby generating a higher effective tax rate as compared to the effective tax rate for the corresponding periods in fiscal 2023. Excluding the effect of the Midstream impairment, the effective tax rate for the nine month period ended June 30, 2022 would have been 23.6%. The lower effective tax rates are attributable to additional tax deductions related to the amortization of excess deferred income taxes and R&D credits both deferred as regulatory liabilities.

	Three Months Ended March 31,						Six Months Ended March 31,						Three Months Ended June 30,						Nine Months Ended June 30,
	2023			2022			2023			2022			2023			2022			2023			2022
Effective tax rate		23.8	%		26.1	%		23.6	%		26.6	%		23.8	%		22.0	%		23.7	%		26.7	%
Effective tax rate - LLC impairment		—			25.7	%		—			25.7	%		—			—			—			25.7	%
Effective tax rate excluding LLC impairment		23.8	%		24.0	%		23.6	%		23.7	%		23.8	%		22.0	%		23.7	%		23.6	%

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 federal tax returns. The Company does not have any indication at this time of the outcome. The Company believes its income tax assets and liabilities are fairly stated as of ~~March 31,~~June 30, 2023 and 2022; however, these assets and liabilities could be adjusted as a result of this examination. With the amendment of the federal returns for fiscal 2017, 2018 and 2019, these years will remain open for IRS examination for two more years. Aside from these exceptions, the federal returns and the state returns for Virginia for the tax years ended prior to September 30, 2017 are no longer subject to examination. The state returns for West Virginia prior to September 30, 2019 are no longer subject to examination.

5.	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.

On December 2, 2022, Roanoke Gas filed an application with the SCC seeking an $8.55 million annual increase in non-gas base rates, of which $4.05 million was being recovered through the Company’s SAVE Rider. Since the Company is seeking recovery of the costs associated with its SAVE plan through its proposed base rates, the Company ~~proposed discontinuing~~discontinued its SAVE Plan and SAVE Rider for the remainder of the current fiscal year, effective January 1, 2023.

On December 21, 2022, the SCC issued its Order for Notice and Hearing which authorized the Company to put the proposed rates into effect on January 1, 2023, on an interim basis. The SCC also established a procedural schedule and set the matter for hearing. The Company expects final resolution of the rate case to occur in late calendar 2023 or early 2024.

The Company has recorded a provision for refund, including interest, associated with customer billings under the new non-gas ~~rates. As the SCC audit is still~~rates based in ~~progress, the Company based its estimate for refund in~~ part ~~based~~ on the history of final awards in previous rate filings, as well as other factors. The amount of the accrued refund is an estimate, and the final order could result in a rate award that is either more or less than the amount currently reflected in the financial statements. ~~Management~~The SCC audit is still in progress and management will refine its estimates as more information becomes available.

The Company filed an application with the SCC for a new, five-year SAVE Plan and Rider on March 31, 2023 ~~for recovery of costs associated with SAVE eligible investments, beginning~~ ~~October 1, 2023.~~ ~~The application seeks~~seeking recovery of costs associated with an estimated $8.5 million in SAVE eligible investment in fiscal 2024 and an estimated cumulative investment of $49.5 million over the five-year SAVE Plan ending September 30, 2028.On July 7, 2023, the SCC Staff filed its report on the Company’s SAVE Plan and Rider in which it recommended approval of the $49.5 million five-year plan with a revenue requirement of approximately $366,000 beginning on October 1, 2023. The Company expects resolution of this matter in the fourth quarter of fiscal 2023.

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On May 16, 2022, Roanoke Gas announced a cooperative agreement under which Roanoke Gas and the Western Virginia Water Authority ~~will~~would produce commercial quality RNG from biogas produced at the regional water pollution control plant. In August 2022, Roanoke Gas filed an application with the SCC seeking approval of a rate adjustment clause ~~under which the Company will~~to recover the costs associated with constructing, owning, operating and maintaining the renewable natural gas facility. The application was filed under Chapter 30 of Title 56 of the Code of Virginia. Chapter 30 allows the Company to accrue AFUDC on the RNG project. In connection with the RNG project, Roanoke Gas began accruing AFUDC in fiscal 2022 associated with construction of the facility. ~~As of~~ ~~March~~ ~~31,~~~~2023,~~ ~~the~~The Company has recognized approximately $273,000 of AFUDC ~~revenue~~ since inception of the RNG project. The Company received a final order from the SCC on January 23, 2023 approving the Company’s application. The RNG ~~project~~facility became operational in March 2023. The Company began billing customers the RNG rate adjustment on March 1, 2023, at which time the Company ceased recording AFUDC.

On May 30, 2023, the Company filed an application with the SCC to update the RNG Rider with an effective date of October 1, 2023. The Company expects resolution of this matter in the fourth quarter of fiscal 2023.

On June 2, 2022, Roanoke Gas filed an application with the SCC to acquire certain natural gas delivery assets from a local housing authority. Under this application, the Company requested the approval to acquire such facilities at five separate apartment complexes, located in the Company’s service territory, that were under housing authority management. Under the proposed plan, the housing authority would renew existing natural gas distribution facilities to include mains, services, and meter installations and then transfer ownership of these facilities to Roanoke Gas. In turn, Roanoke Gas would assume responsibility for the operation and maintenance of these assets and recognize a gain related to the asset acquisition equal to the cost associated with the renewal.

On July 19, 2022, the SCC approved the application and on August 4, 2022, the housing authority transferred the assets from two apartment complexes to Roanoke Gas. Roanoke Gas recorded these assets and recognized a pre-tax gain of approximately $219,000 during the Company’s fourth quarter of fiscal 2022. The housing authority expects to complete the upgrade and subsequent asset transfer atof one ~~more~~ apartment complex in fiscal 2023. The authority is awaiting future funding to complete the two remaining apartment complexes. The timing of funding and the completion of the asset renewals for these complexes is unknown at this time.

6.	Other Investments

~~As of the date of the filing of this Quarterly Report on Form~~ 10~~-Q,~~ Midstream is an approximately 1% equity investment owner of the LLC constructing the MVP, a 303 mile natural gas inter-state pipeline that is designed to extend from northern West Virginia to southern Virginia. Since inception, the MVP has encountered various legal and regulatory issues that have delayed the completion of the project. While under construction, AFUDC has provided the majority of the income recognized by Midstream. However, due to limited growth construction activities, AFUDC accruals ~~have been~~were suspended by the LLC ~~since~~from November ~~2021.~~2021 ~~AFUDC accruals will resume~~ until June 2023 when growth activities resumed as a result of the passage of the FRA. In July 2023, growth activities stopped when the Fourth Circuit issued two stays halting construction ~~activities restart.~~

~~Roanoke Gas will continue~~for the project, which resulted in the MVP's emergency application to ~~suspend accruing AFUDC on its two gate stations that will interconnect with~~ the ~~MVP until such time as~~SCOTUS. Forward construction ~~activities resume on~~resumed following the ~~respective gate stations.~~SCOTUS vacating the Fourth Circuit's stays.

Midstream is a less than 1% investor in Southgate, which is being accounted for under the cost method.

On May 4, 2023, Midstream agreed with the LLC’s managing partner and primary interest owner tothat the primary interest owner would make Midstream’s future capital contributions to the LLC up to the point of project in-service or cancellation, as a result of which Midstream's ownership interest percentage in the LLC as it relates to the MVP project has been and will be proportionately adjusted.

In the second quarter of fiscal 2022, Midstream incurred an other-than-temporary decline in the fair value of its equity investment in the LLC, primarily due to unfavorable decisions by the Fourth Circuit that vacated and remanded key authorizations, which required a pre-tax impairment charge of approximately $39.8 million. During the fourth quarter of fiscal 2022, Midstream incurred an additional other-than-temporary decline in value in its equity investment in the LLC due to increased uncertainty in the permitting process for the MVP project as a result of legal developments and regulatory uncertainties at that time, as well as macroeconomic pressures primarily due to increased interest rates impacting the discount rate. As a result of the impairment, the carrying value of Midstream’s equity investment in the LLC was further reduced by $15.3 million pre-tax.

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Midstream estimated the fair value of its investment in the LLC, with the assistance of a valuation specialist, using an income-based approach that primarily considered probability-weighted scenarios of discounted future cash flows based on the estimated project costs at completion and projected revenues. These scenarios reflected assumptions and judgments regarding the ultimate outcome of further matters relating to, or resulting from the Fourth Circuit rulings, as well as various other ongoing legal and regulatory matters affecting MVP and Southgate. Such assumptions and judgments also included certain additional potential delays and related cost increases that could result from unfavorable decisions on these proceedings and matters. Midstream’s analysis considered probability weighted growth expectations from additional compression expansion opportunities, how ongoing or new legal and regulatory matters may further delay the completion and increase the total costs of the project and the potential of MVP and Southgate cancellation.

Midstream reassesses the value of its investment in the LLC on at least a quarterly basis. With the assistance of a valuation specialist, Midstream conducted the quarterly evaluation of its investment in the LLC as of ~~March~~June 30, 2023 ~~31,~~~~2023~~and determined that its investment was fairly stated and no further impairment was required. The fair value of the investment in the LLC was determined under a Level 3 measurement considering the significant assumptions and judgments required in estimating the fair value of the Company's investment in the LLC.

There is risk that Midstream’s equity investment in the LLC may be impaired further in the future. There are continuing, and potential future, legal and regulatory matters related to MVP and Southgate, any of which could affect the ability to complete and/or operate the project, as well as potential macroeconomic factors, changes in interest rates, cost increases, other unanticipated events and legal and regulatory matters that must be resolved. While macroeconomic factors in and of themselves may not be a direct indicator of impairment, should an impairment indicator be identified in the future, macroeconomic factors such as changes in interest rates could ultimately impact the size and scope of any potential impairment. Assumptions and estimates utilized in assessing the fair value of Midstream’s investment in the LLC may change depending on the nature or timing of resolutions to the legal and regulatory matters or based on other relevant developments. Adverse changes in circumstances relevant to the likelihood of project or expansion completion could prompt Midstream, in future assessments, to apply lower probability of project or expansion completion. Such changes in assumptions or estimates, including discount rates, could have a material adverse effect on the fair value of Midstream’s investment in the LLC and potentially result in additional impairment, which could have a material adverse effect on the results of operations and financial position of Midstream and the Company as a whole.

On July 27,2023,two recent stays issued by the Fourth Circuit were vacated by the SCOTUS after an emergency application was filed by the LLC, which allowed the project to resume construction in the fourth quarter of fiscal 2023.

Funding for Midstream's investments in the LLC for both MVP and Southgate has been provided through two variable rate unsecured promissory notes, under a non-revolving credit agreement ~~maturing in~~ ~~December 2023,~~ and three additional notes as detailed in Note 9, as well as by equity contributions from Resources.

The Company will participate in the earnings generated from the transportation of natural gas through both pipelines proportionate to its level of investment once the pipelines are placed in service.

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Investment balances of MVP and Southgate, as of ~~March 31,~~June 30, 2023, are reflected in the table below:

Balance Sheet location:	March 31, 2023		September 30, 2022		June 30, 2023		September 30, 2022
Other Assets:
MVP	$	15,008,995	$	13,689,370	$	15,535,067	$	13,689,370
Southgate		88,080		83,705		90,270		83,705
Investment in unconsolidated affiliates	$	15,097,075	$	13,773,075	$	15,625,337	$	13,773,075

Current Liabilities:
MVP	$	624,580	$	804,404	$	—	$	804,404
Southgate		490		102		508		102
Capital contributions payable	$	625,070	$	804,506	$	508	$	804,506

	Three Months Ended					Six Months Ended				Three Months Ended				Nine Months Ended
Income Statement location:	March 31, 2023		March 31, 2022			March 31, 2023		March 31, 2022		June 30, 2023		June 30, 2022		June 30, 2023		June 30, 2022
Equity in earnings (loss) of unconsolidated affiliate	$	2,867	$	(445	)	$	4,099	$	71,682
Equity in earnings of unconsolidated affiliate										$	519,482	$	235	$	523,581	$	71,917

March 31, 2023

September 30, 2022

Undistributed earnings, net of income taxes, of MVP in retained earnings, excluding impairment
$ 8,138,526 $ 8,135,482

		June 30, 2023				September 30, 2022
Undistributed earnings, net of income taxes, of MVP in retained earnings, excluding impairment		$	8,524,294			$	8,135,482

The undistributed earnings does not include the impairment of the investment in the LLC.

~~RGC RESOURCES, INC. AND SUBSIDIARIES~~

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

	Six Months Ended						Nine Months Ended
	March 31, 2023			March 31, 2022			June 30, 2023			June 30, 2022
Cash investment	$	1,499,337		$	3,572,011		$	2,132,679		$	4,345,712
Change in accrued capital calls		(179,436	)		(1,367,548	)		(803,998	)		(1,299,387	)
Pre-tax impairment		—			(39,822,213	)		—			(39,822,213	)
Equity in earnings of unconsolidated affiliate		4,099			71,682			523,581			71,917
Change in investment in unconsolidated affiliates	$	1,324,000		$	(37,546,068	)	$	1,852,262		$	(36,703,971	)

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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									Income Statements
	Three Months Ended				Six Months Ended					Three Months Ended				Nine Months Ended
	March 31, 2023		March 31, 2022		March 31, 2023		March 31, 2022			June 30, 2023		June 30, 2022		June 30, 2023		June 30, 2022
AFUDC	$	—	$	—	$	—	$	6,883,069		$	49,744,717	$	—	$	49,744,717	$	6,883,069
Other income (expense), net		259,240		9,245		419,712		(35,818	)
Other income, net											304,093		82,394		723,805		46,576
Net income	$	259,240	$	9,245	$	419,712	$	6,847,251		$	50,048,810	$	82,394	$	50,468,522	$	6,929,645

	Balance Sheets				Balance Sheets
	March 31, 2023		September 30, 2022		June 30, 2023		September 30, 2022
Assets:
Current assets	$	64,263,722	$	76,474,981	$	360,817,998	$	76,474,981
Construction work in progress		6,792,163,524		6,667,146,408		6,914,678,901		6,667,146,408
Other assets		9,392,970		8,021,877		9,684,447		8,021,877
Total assets	$	6,865,820,216	$	6,751,643,266	$	7,285,181,346	$	6,751,643,266

Liabilities and Equity:
Current liabilities	$	115,481,349	$	115,061,723	$	128,011,871	$	115,061,723
Capital		6,750,338,867		6,636,581,543		7,157,169,475		6,636,581,543
Total liabilities and equity	$	6,865,820,216	$	6,751,643,266	$	7,285,181,346	$	6,751,643,266

7.	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 five interest rate swaps associated with its variable rate debt as of ~~March~~June 30, 2023. ~~31,~~~~2023.~~Roanoke Gas has two variable-rate term notes in the amounts of $15 million and $10 million, with corresponding swap agreements to convert the variable interest rates into fixed rates of 2.00% and 2.49%, respectively. Under the provisions of the $10 million note, Roanoke Gas received $5 million on April 1, 2022 and the remaining $5 million on September 30, 2022. Midstream has three swap agreements corresponding to the $14 million, $10 million, and $8 million variable rate term notes. The swap agreements convert these three notes into fixed rate instruments with effective interest rates of 3.24%, 3.14%, and 2.443%, respectively. 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.

On April 3, 2023, Roanoke Gas amended and restated its $10 million interest rate swap initially entered into on September 24, 2021. The amendment revised the interest rate swap's floating rate from LIBOR plus 100 basis points to Term SOFR plus 100 basis points, effective April 1, 2023, to align with the variable interest rate on the $10 million Term Note dated September 24, 2021, and subsequently amended and restated on March 24, 2023. All other terms and requirements of the original interest rate swap, including the fixed rate of 2.49%, were retained. See Note 9 for additional information.

On June 28, 2023, Midstream amended and restated its $14 million and $8 million interest rate swaps initially entered into on June 12, 2019 and November 1, 2021, respectively. The amendments revised the interest rate swaps' floating rates from LIBOR plus 115 basis points to Daily Simple SOFR plus 126.448 basis points, effective July 1, 2023, to align with the variable interest rates on the $14 million and $8 million Term Notes entered on June 12, 2019 and November 1, 2021, respectively, and subsequently amended and restated on June 28, 2023. All other terms and requirements of the original interest rate swaps, including the fixed rates of 3.24% and 2.443%, respectively, were retained. See Note 9 for additional information.

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The Company had no outstanding derivative instruments for the purchase of natural gas.

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 10 reflects the effect on income and other comprehensive income of the Company's cash flow hedges.

8.	Short-Term Debt

On March 31, 2022, Roanoke Gas entered into an unsecured line-of-credit agreement replacing the line-of-credit agreement dated March 25, 2021. The agreement provided for a variable interest rate based upon Daily Simple SOFR plus 110 basis points and multiple tier borrowing limits to accommodate seasonal borrowing demands. The Company's total available borrowing limits during the term of the line-of-credit agreement ranged from $21 million to $33 million. In connection with the line-of-credit, the Company also entered into the Seventh Amendment to Credit Agreement as of March 31, 2022, which amended the original Credit Agreement dated March 31, 2016 and all subsequent amendments. The Amendment aligned the termination date, maximum principal amount available under the line-of-credit, amended certain financial conditions required of Resources, and retained all other terms and requirements of prior credit agreements. The line-of-credit agreement expired on March 31, 2023.

On March 24, 2023, Roanoke Gas entered into an unsecured Revolving Note in the principal amount of $25 million. The Revolving Note replaces the unsecured line-of-credit agreement dated March 31, 2022 and will mature on March 31, 2024. The Revolving Note's variable interest is based upon Term SOFR plus 110 basis points and provides for multiple tier borrowing limits to accommodate seasonal borrowing demands. The Company's total borrowing limits during the term of the Revolving Note range from $4 million to $25 million. As of ~~March 31,~~June 30, 2023, the Company had no outstanding balance under the Revolving Note.

9.	Long-Term Debt

On June 28, 2023, Midstream amended and restated its $14 million and $8 million Term Notes initially entered into on June 12, 2019 and November 1, 2021, respectively. The amendments revised each of the original Term Note's interest rate from LIBOR plus 115 basis points to Daily Simple SOFR plus 126.448 basis points, effective July 1, 2023. All other terms and requirements of the Term Notes were retained. In conjunction with the amendment of the Term Notes, Midstream also amended the corresponding interest rate swaps associated with the Term Notes. The amendments provided for the floating rates on the interest rate swaps to continue to match the rate of the associated notes as well as retain the overall fixed interest rates of 3.24% and 2.443%, respectively.

On March 24, 2023, Roanoke Gas amended and restated the $10 million Term Note originally entered into on September 24, 2021. The amendment revised the original Term Note's interest rate from LIBOR plus 100 basis points to Term SOFR plus 100 basis points. All other terms and requirements of the original Term Note were retained. The effective date of the Amended Term Note was April 1, 2023. In addition, on April 3, 2023, the interest rate swap was amended to align with the Amended Term Note and retained the fixed interest rate of 2.49%. In connection with the Revolving Note and Amended Term Note, Roanoke Gas also amended and restated the Loan Agreement dated September 24, 2021. The amendment provides for borrowing limits on the Revolving Note and amends certain financial conditions required of Roanoke Gas and Resources. All other terms and requirements of the original Loan Agreement were retained. See Note 7 for additional information regarding the interest rate swap and Note 8 for additional information regarding the Revolving Note.

~~November~~ 151,~~2021,~~ ~~Midstream entered into an unsecured promissory note in the principal amount~~

Table of ~~$8 million with an interest rate based on~~ 30~~-day LIBOR plus 115 basis points maturing~~ ~~January 1, 2028.~~ Related to this note, Midstream also entered into an interest rate swap agreement that effectively converted the variable rate note into a fixed rate instrument with an effective annual interest rate of 2.443%. The loan converted into an installment loan with principal pay-down beginning on ~~April 1, 2023.~~ In addition, this note reduced the borrowing capacity defined by the Third Amendment to Credit Agreement and related Promissory Notes. The total borrowing capacity declined from $41 million to $33 million effective with the new promissory note.Contents

RGC RESOURCES, INC. AND SUBSIDIARIES

On March 31, 2022, Midstream applied $10 million from a cash infusion received from Resources to pay down a corresponding amount on the non-revolving credit facility which in turn reduced the total borrowing capacity from $33 million to $23 million. On June 30, 2022, Midstream entered into the Fourth Amendment to Credit Agreement and related Promissory Notes. The Fourth Amendment modified the original Credit Agreement and prior amendments by replacing the 30-day LIBOR plus 1.35% interest on the Promissory Notes with Term SOFR plus 1.50%~~, as well as~~. On July 28, 2023, Midstream entered into the Fifth Amendment to Credit Agreement and related Promissory Notes. The Fifth Amendment revised the interest rate from Term SOFR plus 1.50% to Term SOFR plus 2.00% and extended the maturity date of the Promissory Notes to December 31, ~~2023.~~2024. All other terms ~~of the Fourth Amendment to Credit Agreement~~and requirements remain unchanged.

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~~RGC RESOURCES, INC. AND SUBSIDIARIES~~

Long-term debt consists of the following:

	March 31, 2023					September 30, 2022					June 30, 2023					September 30, 2022
	Principal			Unamortized Debt Issuance Costs		Principal			Unamortized Debt Issuance Costs		Principal			Unamortized Debt Issuance Costs		Principal			Unamortized Debt Issuance Costs
Roanoke Gas:
Unsecured senior notes payable, at 4.26%, due September 18, 2034	$	30,500,000		$	111,022	$	30,500,000		$	115,849	$	30,500,000		$	108,608	$	30,500,000		$	115,849
Unsecured term notes payable, at 3.58%, due October 2, 2027		8,000,000			21,672		8,000,000			24,080		8,000,000			20,468		8,000,000			24,080
Unsecured term notes payable, at 4.41%, due March 28, 2031		10,000,000			25,061		10,000,000			26,627		10,000,000			24,277		10,000,000			26,627
Unsecured term notes payable, at 3.60%, due December 6, 2029		10,000,000			23,778		10,000,000			25,539		10,000,000			22,898		10,000,000			25,539
Unsecured term note payable, at 30-day SOFR plus 1.20%, due August 20, 2026		15,000,000			—		15,000,000			—
Unsecured term note payable, at Term SOFR plus 1.00%, due October 1, 2028		10,000,000			40,160		10,000,000			28,674
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			35,350		10,000,000			28,674
Midstream:
Unsecured term notes payable, at TERM SOFR plus 1.50%, due December 31, 2023		23,000,000			9,344		21,896,200			18,553
Unsecured term note payable, at 30-day LIBOR plus 1.15%, due June 12, 2026		14,000,000			7,825		14,000,000			9,029
Unsecured term note payable, at 30-day LIBOR plus 1.20%, due June 1, 2024		9,625,000			2,750		9,875,000			3,929
Unsecured term note payable, at 30-day LIBOR plus 1.15%, due January 1, 2028		8,000,000			21,343		8,000,000			23,631
Unsecured term notes payable, at TERM SOFR plus 2.00%, due December 31, 2024												23,000,000			6,229		21,896,200			18,553
Unsecured term note payable, at Daily Simple SOFR plus 1.26448%, due June 12, 2026 (swap rate at 3.24%)												14,000,000			7,223		14,000,000			9,029
Unsecured term note payable, at 30-day LIBOR plus 1.20%, due June 1, 2024 (swap rate at 3.14%)												9,500,000			2,161		9,875,000			3,929
Unsecured term note payable, at Daily Simple SOFR plus 1.26448%, due January 1, 2028 (swap rate at 2.443%)												7,600,000			20,200		8,000,000			23,631
Total long-term debt		138,125,000			262,955		137,271,200			275,911		137,600,000			247,414		137,271,200			275,911
Less: current maturities of long-term debt		(25,100,000	)		—		(1,300,000	)		—		(11,100,000	)		—		(1,300,000	)		—
Total long-term debt, net current maturities	$	113,025,000		$	262,955	$	135,971,200		$	275,911	$	126,500,000		$	247,414	$	135,971,200		$	275,911

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 and priority indebtedness to not exceed 15% of consolidated total assets. The $15 million and $10 million notes have an interest coverage ratio requirement of 1.5, which excludes the effect of athe non-cash ~~impairment~~impairments on the LLC investments. The Company was in compliance with all debt covenants as of ~~March 31,~~June 30, 2023 and September 30, 2022.

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10.

Other Comprehensive Income (Loss)

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

				Tax										Tax
	Before-Tax			(Expense)			Net-of-Tax				Before-Tax				(Expense)				Net-of-Tax
	Amount			or Benefit			Amount				Amount				or Benefit				Amount
Three Months Ended March 31, 2023
Three Months Ended June 30, 2023
Interest rate swaps:
Unrealized losses	$	(260,544	)	$	67,065		$	(193,479	)
Unrealized gains										$	1,111,338			$	(286,058	)		$	825,280
Transfer of realized gains to interest expense		(419,712	)		108,034			(311,678	)			(490,371	)			126,221				(364,150	)
Net interest rate swaps		(680,256	)		175,099			(505,157	)			620,967				(159,837	)			461,130
Defined benefit plans:
Amortization of actuarial losses		19,703			(5,072	)		14,631				19,703				(5,072	)			14,631
Other comprehensive loss	$	(660,553	)	$	170,027		$	(490,526	)
Three Months Ended March 31, 2022
Other comprehensive income										$	640,670			$	(164,909	)		$	475,761
Three Months Ended June 30, 2022
Interest rate swaps:
Unrealized gains	$	1,903,875		$	(490,057	)	$	1,413,818			$	1,409,027			$	(362,683	)		$	1,046,344
Transfer of realized losses to interest expense		163,860			(42,179	)		121,681				112,297				(28,905	)			83,392
Net interest rate swaps		2,067,735			(532,236	)		1,535,499				1,521,324				(391,588	)			1,129,736
Defined benefit plans:
Amortization of actuarial gains		(15,070	)		3,879			(11,191	)			(15,070	)			3,879				(11,191	)
Other comprehensive income	$	2,052,665		$	(528,357	)	$	1,524,308			$	1,506,254			$	(387,709	)		$	1,118,545

				Tax									Tax
	Before-Tax			(Expense)			Net-of-Tax			Before-Tax			(Expense)			Net-of-Tax
	Amount			or Benefit			Amount			Amount			or Benefit			Amount
Six Months Ended March 31, 2023
Nine Months Ended June 30, 2023
Interest rate swaps:
Unrealized losses	$	(216,597	)	$	55,754		$	(160,843	)
Unrealized gains										$	894,741		$	(230,304	)	$	664,437
Transfer of realized gains to interest expense		(710,491	)		182,879			(527,612	)		(1,200,862	)		309,100			(891,762	)
Net interest rate swaps		(927,088	)		238,633			(688,455	)		(306,121	)		78,796			(227,325	)
Defined benefit plans:
Amortization of actuarial losses		39,406			(10,144	)		29,262			59,109			(15,216	)		43,893
Other comprehensive loss	$	(887,682	)	$	228,489		$	(659,193	)	$	(247,012	)	$	63,580		$	(183,432	)
Six Months Ended March 31, 2022
Nine Months Ended June 30, 2022
Interest rate swaps:
Unrealized gains	$	2,219,858		$	(571,390	)	$	1,648,468		$	3,628,885		$	(934,073	)	$	2,694,812
Transfer of realized losses to interest expense		335,723			(86,418	)		249,305			448,020			(115,323	)		332,697
Net interest rate swaps		2,555,581			(657,808	)		1,897,773			4,076,905			(1,049,396	)		3,027,509
Defined benefit plans:
Amortization of actuarial gains		(30,140	)		7,758			(22,382	)		(45,210	)		11,637			(33,573	)
Other comprehensive income	$	2,525,441		$	(650,050	)	$	1,875,391		$	4,031,695		$	(1,037,759	)	$	2,993,936

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 16 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.

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Reconciliation of Accumulated Other Comprehensive Income (Loss)

							Accumulated									Accumulated
							Other									Other
	Interest Rate			Defined Benefit			Comprehensive			Interest Rate			Defined Benefit			Comprehensive
	Swaps			Plans			Income (Loss)			Swaps			Plans			Income (Loss)
Balance at September 30, 2022	$	3,563,341		$	(1,598,977	)	$	1,964,364		$	3,563,341		$	(1,598,977	)	$	1,964,364
Other comprehensive income (loss)		(688,455	)		29,262			(659,193	)		(227,325	)		43,893			(183,432	)
Balance at March 31, 2023	$	2,874,886		$	(1,569,715	)	$	1,305,171
Balance at June 30, 2023										$	3,336,016		$	(1,555,084	)	$	1,780,932

11.

Commitments and Contingencies

Roanoke Gas currently holds the only franchises and CPCNs to distribute natural gas in its service area. The current franchise agreements expire December 31, 2035. The Company's CPCNs are exclusive and generally are intended for perpetual duration.

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. The Company utilizes an asset manager 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. 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 two primary pipelines that deliver all of 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. The MVP will provide Roanoke Gas with access to an additional delivery source to its distribution system, increasing system reliability and the Company's ability to meet future demands for natural gas.

12.

Earnings Per Share

Basic earnings per common share for the three and ~~six~~nine months ended ~~March 31,~~June 30, 2023 and 2022 were calculated by dividing net income by the weighted average common shares outstanding during the period. Diluted earnings per common share were calculated by dividing net income by the weighted average common shares outstanding during the period plus potential dilutive common shares.

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

	Three Months Ended March 31,					Six Months Ended March 31,					Three Months Ended June 30,				Nine Months Ended June 30,
	2023		2022			2023		2022			2023		2022		2023		2022
Net income (loss)	$	6,341,886	$	(24,494,429	)	$	9,598,291	$	(20,909,900	)	$	686,816	$	592,527	$	10,285,107	$	(20,317,373	)
Weighted average common shares		9,911,202		8,486,518			9,870,259		8,434,689			9,939,843		9,798,700		9,893,454		8,889,359
Effect of dilutive securities:
Options to purchase common stock		7,506		—			7,242		—			3,028		5,589		5,767		—
Diluted average common shares		9,918,708		8,486,518			9,877,501		8,434,689			9,942,871		9,804,289		9,899,221		8,889,359
Earnings (loss) per share of common stock:
Basic	$	0.64	$	(2.89	)	$	0.97	$	(2.48	)	$	0.07	$	0.06	$	1.04	$	(2.29	)
Diluted	$	0.64	$	(2.89	)	$	0.97	$	(2.48	)	$	0.07	$	0.06	$	1.04	$	(2.29	)

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13.

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						Six Months Ended						Three Months Ended						Nine Months Ended
	March 31,						March 31,						June 30,						June 30,
	2023			2022			2023			2022			2023			2022			2023			2022
Components of net periodic pension cost (benefit):
Service cost	$	91,635		$	162,072		$	183,270		$	324,144		$	91,635		$	162,072		$	274,905		$	486,216
Interest cost		343,025			253,279			686,050			506,558			343,025			253,279			1,029,075			759,837
Expected return on plan assets		(308,149	)		(457,888	)		(616,298	)		(915,776	)		(308,149	)		(457,888	)		(924,447	)		(1,373,664	)
Recognized loss		79,181			36,600			158,362			73,200			79,181			36,600			237,543			109,800
Net periodic pension cost (benefit)	$	205,692		$	(5,937	)	$	411,384		$	(11,874	)	$	205,692		$	(5,937	)	$	617,076		$	(17,811	)

	Three Months Ended						Six Months Ended						Three Months Ended						Nine Months Ended
	March 31,						March 31,						June 30,						June 30,
	2023			2022			2023			2022			2023			2022			2023			2022
Components of postretirement benefit cost (benefit):
Service cost	$	11,475		$	24,450		$	22,950		$	48,900		$	11,475		$	24,450		$	34,425		$	73,350
Interest cost		155,156			110,930			310,312			221,860			155,156			110,930			465,468			332,790
Expected return on plan assets		(116,012	)		(166,541	)		(232,024	)		(333,082	)		(116,012	)		(166,541	)		(348,036	)		(499,623	)
Net postretirement benefit cost (benefit)	$	50,619		$	(31,161	)	$	101,238		$	(62,322	)	$	50,619		$	(31,161	)	$	151,857		$	(93,483	)

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 inunder operations and maintenance expense in the condensed consolidated statements of income.

For the three and ~~six~~nine month periods ended ~~March~~June 30, 2023, ~~31,~~~~2023,~~no funding contributions were made to the pension plan or postretirement plan. The Company is not planning any funding contributions to either plan for the remainder of fiscal 2023.

14.

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.

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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.

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).

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 - March 31, 2023								Fair Value Measurements - June 30, 2023
			Quoted		Significant						Quoted		Significant
			Prices		Other		Significant				Prices		Other		Significant
			in Active		Observable		Unobservable				in Active		Observable		Unobservable
	Fair		Markets		Inputs		Inputs		Fair		Markets		Inputs		Inputs
	Value		(Level 1)		(Level 2)		(Level 3)		Value		(Level 1)		(Level 2)		(Level 3)
Assets:
Interest rate swaps	$	3,871,379	$	—	$	3,871,379	$	—	$	4,492,346	$	—	$	4,492,346	$	—
Total	$	3,871,379	$	—	$	3,871,379	$	—	$	4,492,346	$	—	$	4,492,346	$	—

Liabilities:
Natural gas purchases	$	623,009	$	—	$	623,009	$	—	$	1,452,442	$	—	$	1,452,442	$	—
Total	$	623,009	$	—	$	623,009	$	—	$	1,452,442	$	—	$	1,452,442	$	—

	Fair Value Measurements - September 30, 2022
			Quoted		Significant
			Prices		Other		Significant
			in Active		Observable		Unobservable
	Fair		Markets		Inputs		Inputs
	Value		(Level 1)		(Level 2)		(Level 3)
Assets:
Interest rate swaps	$	4,798,467	$	—	$	4,798,467	$	—
Total	$	4,798,467	$	—	$	4,798,467	$	—

Liabilities:
Natural gas purchases	$	1,295,225	$	—	$	1,295,225	$	—
Total	$	1,295,225	$	—	$	1,295,225	$	—

The fair value of the interest rate swaps are determined by using the counterparty's proprietary models and certain assumptions regarding past, present and future market conditions.

See Note 6 for discussion on the fair value assumptions of the Company's investment in the LLC.

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 ~~March 31,~~June 30, 2023 and September 30, 2022, 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.

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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 (with the exception of the timing difference under the asset management contract), 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.

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 - March 31, 2023								Fair Value Measurements - June 30, 2023
			Quoted		Significant						Quoted		Significant
			Prices		Other		Significant				Prices		Other		Significant
			in Active		Observable		Unobservable				in Active		Observable		Unobservable
	Carrying		Markets		Inputs		Inputs		Carrying		Markets		Inputs		Inputs
	Value		(Level 1)		(Level 2)		(Level 3)		Value		(Level 1)		(Level 2)		(Level 3)
Liabilities:
Current maturities of long-term debt	$	25,100,000	$	—	$	—	$	25,075,314	$	11,100,000	$	—	$	—	$	11,100,000
Notes payable		113,025,000		—		—		110,157,640		126,500,000		—		—		123,002,182
Total	$	138,125,000	$	—	$	—	$	135,232,954	$	137,600,000	$	—	$	—	$	134,102,182

	Fair Value Measurements - September 30, 2022
			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	$	1,300,000	$	—	$	—	$	1,300,000
Notes payable		135,971,200		—		—		130,266,252
Total	$	137,271,200	$	—	$	—	$	131,566,252

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 ~~March 31,~~June 30, 2023 and one customer amounted to approximately 5.1% of total receivables at September 30, 2022. The Company maintains certain credit standards with its customers and requires a customer deposit if warranted.

15.

Segment Information

Operating segments are defined as components of an enterprise for which separate financial information is available and is evaluated regularly by the Company's chief operating decision maker 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.

2021

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RGC RESOURCES, INC. AND SUBSIDIARIES

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 activities of the Company's investment in the LLC.

Parent and Other - The category parent and other includes the unregulated activities of the Company as well as certain corporate eliminations.

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

	Three Months Ended March 31, 2023									Three Months Ended June 30, 2023
	Gas Utility		Investment in Affiliates			Parent and Other		Consolidated Total		Gas Utility		Investment in Affiliates			Parent and Other		Consolidated Total
Operating revenues	$	38,000,977	$	—		$	28,680	$	38,029,657	$	13,631,856	$	—		$	28,389	$	13,660,245
Depreciation		2,419,541		—			—		2,419,541		2,419,541		—			—		2,419,541
Operating income (loss)		9,627,320		(58,747	)		22,849		9,591,422		1,839,910		(63,766	)		22,321		1,798,465
Equity in earnings		—		2,867			—		2,867		—		519,482			—		519,482
Interest expense		810,346		585,516			—		1,395,862		808,384		615,182			—		1,423,566
Income (loss) before income taxes		8,939,360		(641,933	)		22,824		8,320,251		1,039,212		(160,402	)		22,296		901,106

	Three Months Ended March 31, 2022										Three Months Ended June 30, 2022
	Gas Utility		Investment in Affiliates			Parent and Other		Consolidated Total			Gas Utility		Investment in Affiliates			Parent and Other		Consolidated Total
Operating revenues	$	29,499,219	$	—		$	30,464	$	29,529,683		$	17,226,649	$	—		$	33,250	$	17,259,899
Depreciation		2,268,704		—			—		2,268,704			2,218,322		—			—		2,218,322
Operating income (loss)		7,528,839		(108,987	)		23,536		7,443,388			1,677,714		(62,722	)		25,180		1,640,172
Equity in earnings (loss)		—		(445	)		—		(445	)
Impairment of investments in affiliates		—		(39,822,213	)		—		(39,822,213	)
Equity in earnings												—		235			—		235
Interest expense		751,038		352,806			—		1,103,844			748,020		354,194			—		1,102,214
Income (loss) before income taxes		7,117,202		(40,279,495	)		23,689		(33,138,604	)		1,147,894		(413,857	)		25,297		759,334

~~Table of Contents~~

	Nine Months Ended June 30, 2023
	Gas Utility		Investment in Affiliates			Parent and Other		Consolidated Total
Operating revenues	$	84,885,600	$	—		$	86,637	$	84,972,237
Depreciation		7,258,623		—			—		7,258,623
Operating income (loss)		17,034,575		(169,217	)		69,014		16,934,372
Equity in earnings		—		523,581			—		523,581
Interest expense		2,441,296		1,747,296			—		4,188,592
Income (loss) before income taxes		14,798,527		(1,394,950	)		68,939		13,472,516

~~RGC RESOURCES, INC. AND SUBSIDIARIES~~

	Nine Months Ended June 30, 2022
	Gas Utility		Investment in Affiliates			Parent and Other		Consolidated Total
Operating revenues	$	69,957,523	$	—		$	95,139	$	70,052,662
Depreciation		6,757,720		—			—		6,757,720
Operating income (loss)		14,610,869		(223,269	)		74,383		14,461,983
Equity in earnings		—		71,917			—		71,917
Impairment of investments in affiliates		—		(39,822,213	)		—		(39,822,213	)
Interest expense		2,263,921		1,046,993			—		3,310,914
Income (loss) before income taxes		13,224,278		(41,010,233	)		74,818		(27,711,137	)

Six Months Ended March 31, 2023

Gas Utility

Investment in Affiliates

Parent and Other

Consolidated Total

Operating revenues
$ 71,253,744 $ — $ 58,248 $ 71,311,992
Depreciation
4,839,082 — — 4,839,082
Operating income (loss)
15,194,665 (105,451 ) 46,693 15,135,907
Equity in earnings
— 4,099 — 4,099
Interest expense
1,632,912 1,132,114 — 2,765,026
Income (loss) before income taxes
13,759,315 (1,234,548 ) 46,643 12,571,410

Six Months Ended March 31, 2022

Gas Utility

Investment in Affiliates

Parent and Other

Consolidated Total

Operating revenues
$ 52,730,874 $ — $ 61,889 $ 52,792,763
Depreciation
4,539,398 — — 4,539,398
Operating income (loss)
12,933,155 (160,547 ) 49,203 12,821,811
Equity in earnings
— 71,682 — 71,682
Impairment of investments in affiliates
— (39,822,213 ) — (39,822,213 )
Interest expense
1,515,901 692,799 — 2,208,700
Income (loss) before income taxes
12,076,384 (40,596,376 ) 49,521 (28,470,471 )

March 31, 2023

Gas Utility

Investment in Affiliates

Parent and Other

Consolidated Total

Total assets
$ 262,105,231 $ 16,022,382 $ 18,324,609 $ 296,452,222

September 30, 2022

Gas Utility

Investment in Affiliates

Parent and Other

Consolidated Total

Total assets
$ 258,519,230 $ 13,838,108 $ 17,951,905 $ 290,309,243

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RGC RESOURCES, INC. AND SUBSIDIARIES

	June 30, 2023
	Gas Utility		Investment in Affiliates		Parent and Other		Consolidated Total
Total assets	$	263,822,583	$	16,294,673	$	14,648,828	$	294,766,084

	September 30, 2022
	Gas Utility		Investment in Affiliates		Parent and Other		Consolidated Total
Total assets	$	258,519,230	$	13,838,108	$	17,951,905	$	290,309,243

16.

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.

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

	March 31, 2023		September 30, 2022		June 30, 2023		September 30, 2022
Assets:
Current Assets:
Regulatory assets:
Accrued WNA revenues	$	2,805,972	$	193,518	$	1,227,171	$	193,518
Under-recovery of gas costs		—		1,316,580		—		1,316,580
Under-recovery of RNG revenues		95,290		—		414,623		—
Accrued pension and postretirement medical		118,955		237,911		59,477		237,911
Other deferred expenses		129,459		129,459		106,438		129,459
Total current		3,149,676		1,877,468		1,807,709		1,877,468
Utility Property:
In service:
Other		11,945		11,945		11,945		11,945
Construction work in progress:
AFUDC		659,650		461,342		645,961		461,342
Other Non-Current Assets:
Regulatory assets:
Premium on early retirement of debt		1,313,152		1,370,246		1,284,606		1,370,246
Accrued pension and postretirement medical		3,894,561		3,894,561		3,894,561		3,894,561
Other deferred expenses		150,224		181,740		276,150		181,740
Total non-current		5,357,937		5,446,547		5,455,317		5,446,547

Total regulatory assets	$	9,179,208	$	7,797,302	$	7,920,932	$	7,797,302

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RGC RESOURCES, INC. AND SUBSIDIARIES

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

	March 31, 2023		September 30, 2022		June 30, 2023		September 30, 2022
Liabilities and Stockholders' Equity:
Current Liabilities:
Regulatory liabilities:
Over-recovery of gas costs	$	1,246,485	$	—	$	448,602	$	—
Over-recovery of SAVE Plan revenues		157,766		158,847		179,507		158,847
Rate refund		763,282		—		976,108		—
Deferred income taxes		363,320		363,297		460,448		363,297
Supplier refunds		695,474		2,484,992		298,270		2,484,992
Other deferred liabilities		164,377		160,930		178,066		160,930
Total current		3,390,704		3,168,066		2,541,001		3,168,066
Deferred Credits and Other Non-Current Liabilities:
Asset retirement obligations		10,468,057		10,204,079		10,610,503		10,204,079
Regulatory cost of retirement obligations		12,649,167		12,277,796		12,865,747		12,277,796
Regulatory liabilities:
Deferred income taxes		12,946,583		13,193,006		12,791,007		13,193,006
Other		30,118		30,118		30,118		30,118
Total non-current		36,093,925		35,704,999		36,297,375		35,704,999

Total regulatory liabilities	$	39,484,629	$	38,873,065	$	38,838,376	$	38,873,065

As of ~~March 31,~~June 30, 2023 and September 30, 2022, the Company had regulatory assets in the amount of ~~$9,167,263~~$7,908,987 and $7,785,357, respectively, on which the Company did not earn a return during the recovery period.

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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RGC RESOURCES, INC. AND SUBSIDIARIES

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 publish forward-looking statements relating to such matters as anticipated financial performance, business prospects, 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 2022 Annual Report on Form 10-K. All of 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,” “expect,” “objective,” “projection,” “forecast,” “budget,” “assume,” “indicate” or similar words or future or conditional verbs such as “will,” “would,” “should,” “can,” “could” or “may” 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.

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The three-month and ~~six-month~~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, 2023. The total revenues and margins realized during the first ~~six~~nine months reflect higher billings due to the weather sensitive nature of the natural gas business.

Overview

Resources is an energy services company primarily engaged in the regulated sale and distribution of natural gas to approximately ~~63,200~~62,600 residential, commercial and industrial customers in Roanoke, Virginia and surrounding localities through its Roanoke Gas subsidiary. Midstream, a wholly-owned subsidiary of Resources, is an approximate 1% investor in MVP and a less than 1% investor in Southgate.

Despite ~~certain progress made in~~recent legislation to expedite the completion of the MVP project passed by the US Congress and signed into law by the President, the Fourth Circuit again stayed the permits necessary to complete the remaining sections of the pipeline. In response to ~~prior rulings~~the Fourth Circuit's actions, the LLC filed a petition with the SCOTUS to request relief from the stays issued by the Fourth Circuit. On July 27, 2023, the SCOTUS granted the relief requested by the LLC and ~~actions~~vacated the stays issued by the Fourth Circuit, ~~including~~allowing construction to immediately resume on the denial of challenges to the permit for Virginia water crossings, construction activities to complete the MVP project continue to be on hold in part due to the Fourth Circuit's recent action to vacate the West Virginia water crossing permit on certain issues. The LLC is actively pursuing the resolution of the issues raised by the Fourth Circuit.MVP. See Note 6 and the Equity Investment in Mountain Valley Pipeline section for more information.

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. 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 on investment 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 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.

Beginning January 1, 2023, Roanoke Gas implemented new, non-gas base rates designed to provide $8.55 million in additional annual revenues in response to higher operating costs and to recover its investment in non-SAVE related projects since the last non-gas base rate ~~increase.~~increase in fiscal 2019. Revenues from the SAVE Plan and Rider were incorporated into the new non-gas base rates. These additional revenues are subject to refund pending audit and hearing with a final order by the SCC, expected in the latter part of calendar 2023 or early 2024. See the Regulatory section for additional information.

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, Roanoke Gas is subject to other regulations which are not necessarily industry specific.

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 and PGA.

The SAVE Plan and Rider provides the Company with a mechanism through which it recovers costs related to SAVE qualified infrastructure investments on a prospective basis, until a rate application is filed incorporating these investments in non-gas base rates. The SAVE Plan and Rider was reset effective January 1, 2023 when the recovery of all prior SAVE Plan investment was incorporated into the ~~current~~new non-gas rates. Accordingly, SAVE Plan revenues decreased by approximately ~~$422,000~~$1,242,000 for the ~~six-month~~nine month period ended ~~March 31,~~June 30, 2023 compared to the same period last year, reflecting the movement of the SAVE Plan revenues into the new non-gas base rates ~~effective~~on January 1, 2023. Management expects to restart the SAVE Plan and Rider in fiscal 2024 in order to incorporate new qualified SAVE infrastructure investment incurred but not reflected in the new non-gas base rates.

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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 ~~six~~nine months ended ~~March 31,~~June 30, 2023, the Company accrued approximately ~~$2,800,000~~$290,000 and ~~$2,612,000~~$2,902,000 in additional revenues under the WNA model for weather that was ~~28%~~18% and 15% warmer than normal, respectively, compared to approximately ~~$556,000~~$194,000 and ~~$1,800,000~~$1,994,000 in additional revenues for weather that was 7%14% and 13% warmer than normal for the ~~corresponding period~~respective periods last year. The ~~current~~most recent WNA year ended on March 31, 2023, and the $2.8 million WNA balance ~~will be collected from customers beginning~~is being billed over a three month period that began in May 2023.

The Company also has an approved rate structure that mitigates 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 increased by approximately ~~$118,000~~$55,000 and ~~$312,000,~~$366,000, respectively, for the three and ~~six~~nine month periods ended ~~March 31,~~June 30, 2023, compared to the corresponding periods last year, as ~~much~~the higher natural gas commodity prices ~~more than doubled~~paid for during last summer's storage injections resulted in elevated storage costs. The cost of natural gas delivered into storage during the ~~average price~~current year is approximately half of ~~gas in storage. Natural gas commodity futures~~the prices ~~have declined significantly,~~experienced during fiscal 2022, which should ~~reduce~~moderate the level of ~~increases~~increase in ICC revenues for the remainder of the current fiscal year asand result in lower ~~priced natural gas is delivered into storage during the summer fill season.~~ICC revenues in fiscal 2024.

In March 2023, Roanoke Gas began the operation of the RNG facility to produce commercial quality RNG for delivery into its distribution system through a cooperative agreement with the Western Virginia Water Authority. With SCC approval, Roanoke Gas is allowed to recover the costs associated with the investment in RNG facilities and the related operating costs. The RNG recovery mechanism is similar to the SAVE Rider where an RNG Rider is added to customer bills to recover these costs. The customer benefits from this program through the monetization of environmental credits generated through the production of RNG, which are returned to customers through the RNG Rider. See the Regulatory section for more information.

The cost of natural gas is a pass-through cost and 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, with the SCC. Once SCC approval is received, the Company adjusts the gas cost component of its rates. 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 an ensuing 12-month period as amounts are reflected in customer billings.

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 consolidated income statement 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 more useful and relevant measure to analyze financial performance. The term gross utility margin is not intended to represent or replace operating income, 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. The following results of operations analyses will reference gross utility margin.

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RGC RESOURCES, INC. AND SUBSIDIARIES

Three Months Ended ~~March 31,~~June 30, 2023:

Net income increased by ~~$30,836,315~~$94,289 for the three months ended ~~March 31,~~June 30, 2023, compared to the same period last year, primarily due to the ~~impairment~~implementation of the Company's investment in the LLC recorded during the second quarter of fiscal 2022. Excluding the after tax effect of the impairment, net income would have increased by approximately $1,264,000 over the same period last year.new non-gas base rates effective January 1, 2023 and AFUDC on MVP.

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

	Three Months Ended March 31,				Increase/						Three Months Ended June 30,
	2023		2022		(Decrease)			Percentage			2023		2022		Decrease			Percentage
Operating Revenues
Gas Utility	$	38,000,977	$	29,499,219	$	8,501,758			29	%	$	13,631,856	$	17,226,649	$	(3,594,793	)		(21	)%
Non Utility		28,680		30,464		(1,784	)		(6	)%		28,389		33,250		(4,861	)		(15	)%
Total Operating Revenues	$	38,029,657	$	29,529,683	$	8,499,974			29	%	$	13,660,245	$	17,259,899	$	(3,599,654	)		(21	)%
Delivered Volumes
Regulated Natural Gas (DTH)
Residential and Commercial		2,560,500		3,221,562		(661,062	)		(21	)%		881,001		897,316		(16,315	)		(2	)%
Transportation and Interruptible		888,307		1,020,460		(132,153	)		(13	)%		1,007,287		1,058,104		(50,817	)		(5	)%
Total Delivered Volumes		3,448,807		4,242,022		(793,215	)		(19	)%		1,888,288		1,955,420		(67,132	)		(3	)%
HDD		1,487		1,918		(431	)		(22	)%		272		288		(16	)		(6	)%

Total operating revenues for the three months ended ~~March 31,~~June 30, 2023, compared to the same period last year, ~~increased~~decreased by ~~29%~~21% due to ~~higher~~significantly lower natural gas commodity prices more than offsetting the implementation of a non-gas base rate increase and higher ICC ~~revenues, offset by a reduction in delivered volumes.~~revenues. Natural gas commodity prices averaged ~~nearly $7.00~~approximately $3.00 per dekatherm during the quarter compared to ~~$3.60~~$7.40 per dekatherm for the corresponding quarter in the prior year. ~~However, during the quarter, the high commodity prices began to retreat and~~Accordingly, the Company adjusted the PGA component of its rates ~~accordingly.~~to reflect the reduction in natural gas costs. As discussed above, Roanoke Gas placed new non-gas base rates into effect for natural gas service rendered on or after January 1, 2023, subject to refund. These new non-gas base rates ~~will~~are expected to generate approximately $8.55 million in additional annual revenues, ~~and includes~~including revenues previously ~~recorded~~recognized through the SAVE Plan and Rider. Approximately 75% of the non-gas base rate increase was allocated to the volumetric component; and as such, a ~~larger~~greater portion of the ~~rate~~ increase ~~was~~will be recognized during the ~~quarter~~winter heating season due to the ~~volume of gas consumption.~~higher energy demands. SAVE Plan revenues declined as the SAVE Rider was reset due to the incorporation of these revenues into the new non-gas base rates. ~~Management expects the~~The SAVE Plan and Rider toshould resume in fiscal 2024. Additionally, ICC revenues increased due to higher commodity prices of gas in storage. ~~As total~~Total heating degree days decreased by ~~22%~~6% from the same period last year resulting in a 2% decline in the weather sensitive residential and commercial ~~deliveries declined by 21%.~~ After accounting for the application of the WNA model for the effect of weather variation from normal, the WNA adjusted residential and commercial volumes would have only decreased by approximately 3% compared to the WNA adjusted volumes for the same period last year.deliveries. Transportation and interruptible volumes declined by ~~13%~~5% as the single, multi-fuel customer that had been utilizing natural gas as its primary fuel source reduced its consumption during the quarter.

	Three Months Ended March 31,									Three Months Ended June 30,
	2023		2022		Increase		Percentage			2023		2022		Increase / (Decrease)			Percentage
Gross Utility Margin
Gas Utility Revenues	$	38,000,977	$	29,499,219	$	8,501,758		29	%	$	13,631,856	$	17,226,649	$	(3,594,793	)		(21	)%
Cost of Gas - Utility		21,285,057		14,923,575		6,361,482		43	%		5,003,371		9,221,968		(4,218,597	)		(46	)%
Gross Utility Margin	$	16,715,920	$	14,575,644	$	2,140,276		15	%	$	8,628,485	$	8,004,681	$	623,804			8	%

Gross utility margin increased from the same period last year primarily as a result of the aforementioned implementation of new non-gas base ~~rates. Although total residential~~rates, WNA and ~~commercial natural gas deliveries decreased substantially from last year~~RNG revenue, offset by the reduction in SAVE revenues. The WNA adjusted volumetric margin increased by approximately $654,000 and base charge revenues increased by approximately $466,000 due to ~~warmer weather,~~ the ~~WNA adjusted volumes~~non-gas base rate increase. However, SAVE revenues decreased by approximately $820,000 as these revenues are now reflected ~~only a small decrease as~~in the ~~WNA mechanism normalized the impact of weather on the delivered volumes for both periods. In addition,~~increased volumetric and base charge rates. As less than half of the revenues collected through the fixed charge SAVE Rider were incorporated into the new customer base charge ~~increase with the remainder included in the volumetric rate component. As a result of this proposed rate design,~~rates, more of the revenues previously recognized through the SAVE Plan ~~related revenues~~monthly charge are incorporated into the ~~new non-gas base rates will be recognized as part of~~weather sensitive volumetric ~~sales during the heating season and less will recognized during the summer months.~~rates. The RNG Rider, implemented earlier this year, contributed an additional $283,000 to margin.

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

		Three Months Ended March 31,				Increase/			Three Months Ended June 30,				Increase/
	2023		2022		(Decrease)			2023		2022		(Decrease)
Customer Base Charge	$	4,060,891	$	3,666,318	$	394,573		$	4,116,124	$	3,650,419	$	465,705
ICC		216,037		98,511		117,526			138,850		84,258		54,592
SAVE Plan		—		743,992		(743,992	)		—		820,297		(820,297	)
Volumetric		9,509,996		9,470,897		39,099			3,769,708		3,211,907		557,801
WNA		2,799,101		556,404		2,242,697			289,887		193,517		96,370
RNG		83,009		—		83,009			282,606		—		282,606
Other Revenues		46,886		39,522		7,364			31,310		44,283		(12,973	)
Total	$	16,715,920	$	14,575,644	$	2,140,276		$	8,628,485	$	8,004,681	$	623,804

Operations and maintenance expenses ~~decreased~~increased by ~~$151,279,~~$252,275, or 4%7%, from the same period last year primarily due ~~to greater capitalization of overheads and lower bad debt expense, net of~~ higher compensation costs and contracted ~~services. Total~~services, increased corporate insurance and reduced level of capitalized construction overheads, partially offset by lower bad debt expense. Compensation costs and contracted services increased by approximately ~~$134,000~~$122,000 due to ~~higher~~increased staffing and inflationary impact on salaries and costs. Corporate insurance premiums increased by approximately $38,000 due to market conditions. Total capitalized construction overheads declined by approximately $115,000 due to a reduction in direct construction expenditures related to Roanoke Gas capital ~~projects.~~projects compared to the same period last year. Bad debt expense decreased by approximately ~~$169,000~~$111,000 as the prior year reflected higher delinquent balances after emerging from legislative imposed COVID restrictions. ~~Compensation costs and contracted services increased by approximately $194,000 due~~Year end write-offs are expected to ~~the inflationary impact on salary and contractor costs.~~be at elevated levels; however, collection activities are beginning to return to pre-COVID patterns.

General taxes ~~decreased~~increased by ~~$9,024,~~$9,058, or 1%2%, primarily due to increase in payroll taxes related to staffing and compensation, net of lower property taxes associated with reductions in the assessed values of property reported by the SCC more than offsetting an increase in gross utility property.

Depreciation expense increased by ~~$150,837,~~$201,219, or 7%9%, on a comparable increase in utility property balances.

~~Impairment~~Equity in earnings of unconsolidated ~~affiliates includes $39,822,213 for an other-than-temporary write down of the Company's investment in~~affiliate increased by $519,247 as AFUDC was recognized by the LLC ~~as a result~~in June 2023 associated with the resumption of construction activities on the Company's valuation assessment during the prior fiscal year. See Equity Investment in Mountain Valley Pipeline for more information regarding the Company's investment in the LLC and its ongoing valuation assessments.MVP.

Other income, net decreased by ~~$222,686,~~$214,416, or ~~65%~~97%, primarily due to an increase of approximately ~~$376,000~~$375,000 in the non-service cost components of net periodic benefit costs arising from the effect of much higher interest rates on the actuarial expense calculation. Roanoke Gas also recognized approximately ~~$75,000~~$99,000 in ~~AFUDC~~interest income related to ~~the RNG project during the current period.~~higher investment returns on available cash and interest received on corporate income tax refunds.

Interest expense increased by ~~$292,018,~~$321,352, or ~~26%~~29%, as the weighted-average interest rate on total debt increased from ~~2.98%~~3.32% during the ~~second~~third quarter of fiscal 2022 to ~~3.94%~~3.98% during the ~~second~~third quarter of fiscal 2023, while total daily average debt outstanding ~~declined~~increased by nearly 5%6%. The increase in the weighted-average interest rate was primarily associated with Roanoke Gas' variable rate line-of-credit and Midstream's credit facility.

Roanoke Gas' interest expense increased by ~~$59,308~~$60,364 primarily due to the increase in the interest rate on the variable rate line-of-credit and the ~~issuance~~funding of the delayed draw note in 2022.

Midstream's interest expense increased by ~~$232,710~~$260,988 primarily due to rising interest rates on its credit facility. Total average outstanding debt ~~during~~increased by $2.3 million over the same quarter ~~declined by $6.2 million~~last year due to ~~the equity infusions from Resources and installment payments on amortizing debt, net of~~ the funding of MVP and Southgate.

Income tax expense increased by ~~$10,622,540~~$47,483 due to the ~~prior year impairment of the Company's investment~~increase in ~~the LLC.~~pre-tax income. The effective tax rate was 23.8% and ~~26.1%~~22.0% for the three month periods ended ~~March 31,~~June 30, 2023 and 2022, respectively. ~~Excluding the impairment and the associated tax, the effective tax rate would have been 24.0% for the second quarter of fiscal 2022.~~ The effective tax rate is below the combined statutory state and federal rate due to the amortization of excess deferred taxes and R&D tax credits.

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~~Six~~Nine Months Ended ~~March 31,~~June 30, 2023:

Net income increased by ~~$30,508,191~~$30,602,480 from a ~~$20,909,900~~$20,317,373 net loss position to a ~~$9,598,291~~$10,285,107 net income position for the ~~six~~nine months ended ~~March 31,~~June 30, 2023, compared to the same period last year, due to the prior year impairment of the Company's investment in the LLC. Excluding the after tax effect of the impairment, net income would have increased by approximately ~~$936,000~~$1,031,000 over the same period last year.

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

	Six Months Ended March 31,				Increase/						Nine Months Ended June 30,				Increase/
	2023		2022		(Decrease)			Percentage			2023		2022		(Decrease)			Percentage
Operating Revenues
Gas Utility	$	71,253,744	$	52,730,874	$	18,522,870			35	%	$	84,885,600	$	69,957,523	$	14,928,077			21	%
Non Utility		58,248		61,889		(3,641	)		(6	)%		86,637		95,139		(8,502	)		(9	)%
Total Operating Revenues	$	71,311,992	$	52,792,763	$	18,519,229			35	%	$	84,972,237	$	70,052,662	$	14,919,575			21	%
Delivered Volumes
Regulated Natural Gas (DTH)
Residential and Commercial		4,993,739		5,132,292		(138,553	)		(3	)%		5,874,740		6,029,608		(154,868	)		(3	)%
Transportation and Interruptible		1,763,608		1,797,901		(34,293	)		(2	)%		2,770,895		2,856,005		(85,110	)		(3	)%
Total Delivered Volumes		6,757,347		6,930,193		(172,846	)		(2	)%		8,645,635		8,885,613		(239,978	)		(3	)%
HDD		3,010		3,079		(69	)		(2	)%		3,282		3,367		(85	)		(3	)%

Total operating revenues for the ~~six~~nine months ended ~~March 31,~~June 30, 2023, compared to the same period last year, increased by ~~35%~~21% due to higher natural gas commodity prices during the first six months of fiscal 2023, the implementation of a non-gas rate increase net of reduction in SAVE revenues and higher ICC revenues ~~net~~and implementation of ~~a slight reduction in delivered volumes.~~the RNG Rider. Natural gas commodity prices averaged approximately ~~$7.00~~$6.45 per dekatherm during the current ~~period~~fiscal year compared to ~~$3.67~~$4.20 per dekatherm for the corresponding period last year. InAs discussed above, commodity prices during the third quarter of fiscal 2023 declined, reducing the overall period-over-period increase in price. The non-gas base rate increase implemented in January 2023 ~~Roanoke Gas implemented~~contributed to the increase in revenues with customer base charge revenues and volumetric revenues rising by approximately $1.66 million, net of a ~~non-gas rate increase, subject to refund, which is expected to provide approximately $8.5 million~~3% decline in ~~additional~~gas deliveries. SAVE revenues ~~including the revenue associated with qualified SAVE investments collected through the SAVE Rider. Additionally,~~ ~~ICC revenues increased~~declined due to ~~higher commodity prices~~the inclusion of ~~gas~~the cumulative SAVE investment in ~~storage.~~ ~~Residential~~the new non-gas base rates. Both residential and commercial deliveries decreased by 3% corresponding to ~~a 2%~~the comparable decline in heating degree days. The less weather sensitive transportation and interruptible volumes declined by 2%3% as ~~half~~two-thirds of the decline was attributable to a reduction in consumption by the single, multi-fuel customer that ~~had increased its~~has been utilizing natural gas ~~utilization during prior quarters.~~as its primary fuel source. The consumption pattern for this customer is based on several factors and therefore is subject to significant fluctuations in usage. ~~SAVE Plan~~Additionally, ICC revenues ~~declined~~increased due to higher average balances of natural gas in storage and a new revenue stream was added as a result of the ~~SAVE Plan and Rider were reset effective January 1, 2023.~~ new RNG facility.

	Six Months Ended March 31,									Nine Months Ended June 30,
	2023		2022		Increase		Percentage			2023		2022		Increase		Percentage
Gross Utility Margin
Gas Utility Revenues	$	71,253,744	$	52,730,874	$	18,522,870		35	%	$	84,885,600	$	69,957,523	$	14,928,077		21	%
Cost of Gas - Utility		42,089,210		26,239,980		15,849,230		60	%		47,092,581		35,461,948		11,630,633		33	%
Gross Utility Margin	$	29,164,534	$	26,490,894	$	2,673,640		10	%	$	37,793,019	$	34,495,575	$	3,297,444		10	%

Gross utility margin increased from the same period last year primarily as a result of the aforementioned higher non-gas base rates, net of SAVE, ~~and~~ higher ICC revenues and the addition of RNG revenues.

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

	Six Months Ended March 31,				Increase/			Nine Months Ended June 30,				Increase/
	2023		2022		(Decrease)			2023		2022		(Decrease)
Customer Base Charge	$	7,651,448	$	7,302,995	$	348,453		$	11,767,572	$	10,953,414	$	814,158
ICC		587,576		275,842		311,734			726,426		360,100		366,326
SAVE Plan		1,049,310		1,471,365		(422,055	)		1,049,310		2,291,662		(1,242,352	)
Volumetric		17,083,394		15,554,251		1,529,143			20,853,102		18,766,158		2,086,944
WNA		2,612,454		1,800,421		812,033			2,902,341		1,993,938		908,403
RNG		83,009		—		83,009			365,615		—		365,615
Other Revenues		97,343		86,020		11,323			128,653		130,303		(1,650	)
Total	$	29,164,534	$	26,490,894	$	2,673,640		$	37,793,019	$	34,495,575	$	3,297,444

Operations and maintenance expenses increased by ~~$78,920,~~$331,195, or 1%3%, over the same period last year primarily due to higher compensation costs and contracted services and corporate insurance ~~net of~~premiums, partially offset by greater capitalized overheads and lower bad debt expense. Compensation costs and contracted services increased by approximately ~~$552,000~~$478,000 due to increased staffing and the effects of inflation on salary and ~~contractor costs.~~contracted services. Corporate insurance premiums related to property and liability insurance increased by approximately ~~$66,000~~$103,000 due to insurance market conditions. Total capitalized construction overheads increased by approximately ~~$401,000~~$172,000 due to higher direct construction expenditures related to Roanoke Gas capital ~~projects and timing of LNG production.~~projects. Bad debt expense declined by approximately ~~$113,000~~$223,000 as customer delinquencies ~~improved.~~continued to reflect improvement.

General taxes decreased by ~~$23,183,~~$14,125, or 2%1%, primarily due to lower property taxes associated with reductions in the assessed values of property reported by the SCC more than offsetting an increase in ~~gross utility property.~~payroll taxes related to staffing and compensation.

Depreciation expense increased by ~~$299,684,~~$500,903, or 7%, on ~~a comparable increase~~increases in utility property balances.

Equity in earnings of unconsolidated affiliate ~~decreased~~increased by ~~$67,583 due to~~$451,664 as AFUDC associated with the ~~absence~~resumption of construction activities ~~during~~on the ~~current fiscal year. See Equity Investment in Mountain Valley Pipeline section below for additional information.~~MVP was recognized.

Impairment of unconsolidated affiliates includes $39,822,213 for an other-than-temporary write down of the Company's investment in the LLC as a result of the Company's valuation assessment during the prior fiscal year. See Equity Investment in Mountain Valley Pipeline for more information regarding the Company's investment in the LLC.

Other income, net decreased by ~~$470,519,~~$684,935, or ~~71%~~77%, primarily due to an increase of approximately ~~$752,000~~$1,127,000 in the non-service cost components of net periodic benefit costs arising from the effect of much higher interest rates on the actuarial expense calculation. Roanoke Gas also recognized approximately ~~$156,000~~$146,000 in AFUDC related to the RNG project during the current ~~period.~~period and approximately $131,000 in interest income related to higher investment returns on available cash and interest received on corporate income tax refunds.

Interest expense increased by ~~$556,326,~~$877,678, or ~~25%~~27%, primarily due to the increase in the interest rates on the Company's variable rate debt including Roanoke Gas' line-of-credit and Midstream's credit facility. Total daily average debt ~~declined~~decreased by 4%approximately $1.1 million from the same period last year.

Roanoke Gas' interest expense increased by ~~$117,011~~$177,375 primarily due to the increase in the interest rate on the variable rate line-of-credit and the ~~issuance~~funding of the delayed draw note in 2022.

Midstream's interest expense increased by ~~$439,315~~$700,303 due to rising interest rates on its credit facility more than offsetting a ~~$5.1~~$2.6 million decline in the average daily debt balance outstanding due to the ~~$10~~approximate $4.3 million equity infusion from Resources ~~in March 2022.~~during fiscal 2023.

Income tax expense increased by ~~$10,533,690~~$10,581,173 as a result of the recognition of the impairment in March 2022 on the Company's investment in the LLC. The effective tax rate was ~~23.6%~~23.7% and ~~26.6%~~26.7% for the ~~six~~nine month periods ended ~~March 31,~~June 30, 2023 and 2022, respectively. Excluding the impairment and the associated tax, the effective tax rate would have been ~~23.7%~~23.6% for the ~~six~~nine month period ended ~~March 31,~~June 30, 2022. The effective tax rate is below the combined statutory state and federal rate due to the amortization of excess deferred taxes and R&D tax credits.

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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, 2022.

Asset Management

Roanoke Gas uses a third-party asset manager to oversee its pipeline transportation, storage rights and gas supply inventories and deliveries. In return for being able to utilize 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. The current asset management agreement ends March 31, 2025.

Equity Investment in Mountain Valley Pipeline

In October 2017, FERC issued the CPCN for the MVP ~~project. In~~project, and in the first quarter of calendar 2018, the LLC ~~received limited notice from FERC to proceed with certain construction activities and~~ commenced construction.

~~Recent construction activity has been limited based on legal and regulatory challenges. Although certain permits and authorizations were received, the~~The MVP project has been subject to repeated, significant delays and cost increases resulting from legal challenges and regulatory setbacks, particularly in respect to litigation in the Fourth Circuit, including, on January 25, 2022, the Fourth Circuit’s vacatur and remanding on specific issues of the LLC's then authorizations related to the Jefferson National Forest (JNF) received from the Bureau of Land Management and the U.S. Forest Service (USFS) and on February 3, 2022, the Fourth Circuit’s vacatur and remanding on specific issues of the then Biological Opinion and Incidental Take Statement issued by the United States Department of the Interior's Fish and Wildlife Service (FWS) for the MVP project.

Given ongoing litigation and regulatory matters, the LLC filed a request on June 24, 2022 with the FERC for an extension of time to complete the project for an additional four years (relative to a prior obtained extension) through October 13, 2026. The request was granted on August 23, 2022.Circuit.

Notwithstanding prior setbacks, ~~and ongoing risks, including the risk posed by pending and future legal challenges in the Fourth Circuit,~~ the LLC ~~continues~~continued to engage in pursuing the authorizations necessary under applicable law from the relevant agencies to complete the MVP project, including the new authorizations relating to the JNF and an Individual Permit from the Huntington, Pittsburgh and Norfolk Districts of the U.S. Army Corps of Engineers to effect approximately 300 water crossings utilizing open cut techniques. In April 2022, the MVP obtained the FERC’s authorization to amend the Certificate to utilize alternative trenchless construction methods to effect approximately 120 water crossings. Onon February 28, 2023, the ~~FWS issued~~U.S. Department of the Interior’s Fish and Wildlife Service (FWS) issuing a new Biological Opinion and Incidental Take Statement for the MVP project. On October 25, 2022 and January 24, 2023, oral arguments were held in the Fourth Circuit relating to the Section 401 water quality certification approvals received in December 2021 from the West Virginia Department of Environmental Protection and the Virginia Department of Environmental Quality, respectively (such approvals, the WVDEP State 401 Approval and the VADEQ State 401 Approval), each in connection with the MVP project. The oral arguments were conducted by the same panel of Fourth Circuit judges as have appeared, and overruled permitting agencies, in numerous prior matters relating to the MVP. Although on March 29, 2023, the Fourth Circuit panel denied project opponents’ challenge to the VADEQ State 401 Approval, on April 3, 2023, the panel, consistent with its posture during the oral argument, vacated the WVDEP State 401 Approval based on the panel’s view that certain aspects of the WVDEP State 401 Approval did not reflect sufficient explanation by the WVDEP and that certain additional requirements should have been incorporated into the WVDEP State 401 Approval. Relating to the JNF, on April 13, 2023, the USFS issued the final Supplemental Environmental Impact Statement regarding the MVP project. On April 27, 2023, project opponents sought a stay in the Fourth Circuit of the new Biological Opinion and Incidental Take Statement(2023 BiOp) for the MVP project and asin May 2023, the U.S. Forest Service and Bureau of ~~the date of the filing of this Quarterly Report on Form 10-Q, that proceeding is ongoing.~~

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~~In addition~~Land Management issuing authorizations related to ~~those requested authorizations that remain outstanding described~~MVP’s segment in the paragraph above, including that the WVDEP must issue a new Section 401 approval, and other relevant regulatory matters, the LLC in order to complete the project needs to continue to have available the necessary orders previously issued by the FERC and receive authorization from the FERC to complete construction work in the portion of the project route currently remaining subject to the FERC’s previous stop work order and in the JNF.

~~The LLC’s managing partner publicly disclosed on May 2, 2023 that based on its interactions~~Jefferson National Forest (JNF). In conjunction with the ~~agencies and, in the case~~pursuit of ~~the WVDEP State 401 Approval, also its view of the steps it believes necessary to address the Fourth Circuit panel’s vacatur,~~outstanding authorizations, the LLC’s managing partner expects the agencies will issue the requisite authorizations by the early summer 2023 and believes that the agencies are producing authorizations that address points raised by the Fourth Circuit and exceed standards for the issuance of such authorizations. Given that, the LLC’s managing partner recognizes that there continue to be a number of upcoming regulatory and litigation milestones that (together with the timing thereof) will determine whether the LLC may recommence forward construction in 2023 (potentially with the goal of completing the project by end of calendar 2023) or that will prevent such construction and/or completion in 2023. However, the LLC's managing partner acknowledges the narrowed path to complete the project by the end of calendar 2023 in light of various risks (the impacts of which are not known or reasonably estimable), including ongoing and anticipated litigation in the Fourth Circuit relating to MVP project authorizations within the Fourth Circuit’s jurisdiction since the LLC's managing partner perceives continued hostility and risk posed by the Fourth Circuit panel to MVP project-related authorizations.

~~There also are potential, future legislative developments that may impact MVP forward construction or completion timing, as the LLC continues to urge~~primary interest owner urged the United States Congress to expeditiously pass, and for there to be enacted, federal energy infrastructure permitting reform legislation that specifically requires the completion of the MVP project.

On June 3, 2023 the FRA was signed into law. The bipartisan legislation, among other things, ratified and approved all permits and authorizations necessary for the construction and initial operation of the MVP, directed the applicable federal officials and agencies to maintain such authorizations, required the Secretary of the Army to issue not later than June 24, 2023 all permits or verifications necessary to complete construction of the MVP and allow for the MVP’s operation and maintenance, and divested courts of jurisdiction to review agency actions on approvals necessary for MVP construction and initial operation.

Thereafter, on June 8, 2023, the West Virginia Department of Environmental Protection issued a new Section 401 water quality certification for the MVP project, ~~similar~~on June 23, 2023, the Huntington, Pittsburgh and Norfolk Districts of the U.S. Army Corps of Engineers issued the LLC an Individual Permit to ~~MVP-specific aspects of legislation proposed in 2022 by each of United States Senators Joseph Manchin~~effect approximately 300 water crossings utilizing open cut techniques, and, ~~Shelley Moore Capito and ideally in sufficient time for~~on June 28, 2023, the FERC authorized the LLC to ~~complete~~resume all construction activities in all MVP project locations, and the LLC recommenced forward construction activity.

Project opponents continue to challenge MVP project-related authorizations. In connection with such challenges, on July 10, 2023, the Fourth Circuit issued a stay decision to halt construction in ~~2023. However, while as~~the JNF. On July 11, 2023, the Fourth Circuit issued a stay of the ~~date~~2023 BiOp, effectively halting forward construction for the entirety of the ~~filing of this Quarterly Report on Form 10-Q,~~MVP project. On July 14, 2023, the LLC ~~believes that there remain prospects~~filed an emergency application in the SCOTUS to vacate both stay decisions issued by the Fourth Circuit.

On July 27, 2023, the SCOTUS vacated the Fourth Circuit stays of July 10, 2023 and ~~continuing significant bipartisan support for federal energy infrastructure permitting reform legislation favorable to the MVP project,~~July 11, 2023; the LLC ~~recognizes that~~subsequently resumed construction, with the intention to such date attempts to enact such legislation have failed and that differences between and within the Republican and Democratic parties continue to exist as to the scope and terms of any such reform, and such differences have impeded and could further impede the prospect of legislation being enacted, including in sufficient time for the LLC to complete construction in 2023.

~~The LLC’s managing partner believes that the LLC will~~ complete the four to five months of remaining construction activity as promptly as practicable, ~~once authorized and fully mobilized and~~with the target of year-end 2023.

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The LLC’s managing partner publicly indicated that should construction be completed by calendar year-end 2023, the managing partner believes that the total project cost, excluding AFUDC, would be approximately $6.6 ~~billion (excluding AFUDC) if that completion is achieved~~billion.

Completion of the MVP project, and the timing and cost thereof, remains subject to a variety of risks, including, among other things, construction-related risks, as have been in ~~2023.~~certain cases and may be affected by factors such as weather, crew productivity, the need to apply complex construction techniques and adhere to permit requirements, continued project opposition, including physical interference with construction, and restrictions which may be in effect on construction at varying points and locations during the construction calendar. For example, certain bores could require greater construction time than projected. Further, since the recommencement of forward construction, project opponents also have increased actions intended to disrupt the MVP Joint Venture’s operations, including protesting construction efforts and acts of vandalism. Additionally, the ability to construct in certain areas of the project in the second half of 2023, including certain remaining water crossings, may be affected by restrictions imposed to protect endangered or threatened species. Further, there remains pending litigation relating to the project.

Management conducted an assessment of its investment in the LLC in accordance with the provisions of ASC 323, Investments - Equity Method and Joint Ventures. This assessment included a third-party valuation. As a result of its evaluations in fiscal 2022, management concluded that the investment in the LLC sustained other-than-temporary declines in fair value as of February 22, 2022 and as of September 30, 2022 and recorded pre-tax impairment losses of approximately $39.8 million and $15.3 million in its second and fourth quarter operating results, respectively. Management re-evaluated its investment as of ~~March 31,~~June 30, 2023 and concluded that its investment was fairly stated and no additional impairment was required. Management will continue monitoring the status of MVP for circumstances that may lead to future impairments, including ~~further delays or denials of necessary permits~~legal and ~~approvals.~~regulatory. If necessary, the amount and timing of any further impairment would be dependent on the specific circumstances, including changes to probabilities of completion, and changes in the assumed future cash flows, and discount rate at the time of evaluation.

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Midstream has utilized the $23 million of borrowing capacity under its non-revolving credit ~~facility, which matures in December 2023.~~facility. Effective November 1, 2021, the borrowing capacity under this credit facility was reduced to $33 million as $8 million of the outstanding balance was re-financed through a separate unsecured promissory note. Effective March 31, 2022, the borrowing capacity under the credit facility was further reduced to its current $23 million level as $10 million of the outstanding balance was paid. On July 28, 2023, the Company extended the non-revolving credit facility to December 31, 2024.See Note 9 for more information.

On May 4, 2023, Midstream agreed with the LLC’s managing partner and primary interest owner tothat the primary interest owner would make Midstream’s future capital contributions to the LLC up to the point of project in-service or cancellation, as a result of which Midstream's ownership interest percentage in the LLC as it relates to the MVP project has been and will be proportionately adjusted.

IfAdverse developments, whatever the ~~legal and regulatory challenges, including any future challenges, are not resolved in a timely manner~~cause, affecting the MVP project could increase project costs and/or ~~restrictions are imposed that impact future construction, the cost~~further delay completion of the ~~MVP may increase,~~project, and Midstream may incur further dilution accordingly. See Investment in Mountain Valley Pipeline, LLC Risk Factor under Item 1A of the Company's Form 10-K for the year ended September 30, 2022.

Regulatory

On December 2, 2022, Roanoke Gas filed an application with the SCC seeking an $8.55 million annual increase in its non-gas base rates, of which $4.05 million was being recovered through the SAVE Rider. Since the Company is seeking to recover the costs associated with its SAVE Plan through interim non-gas base rates effective January 1, 2023, the Company discontinued its SAVE Plan and Rider for the remainder of the current fiscal year.

On December 21, 2022, the SCC issued its Order for Notice and Hearing, which authorized the Company to put its proposed rates into effect, on an interim basis and subject to refund, on January 1, 2023, and set the matter for hearing. The Company expects final resolution of the rate case to occur in late calendar 2023 or early 2024.

The Company has recorded a provision for refund, including interest, associated with customer billings under the new non-gas rates. As the SCC audit is still in progress, the Company based its estimate for refund in part on the history of final awards in previous rate filings, as well as other factors. The amount of the accrued refund is an estimate, and the final order could result in a rate award that is either more or less than the amount currently reflected in the financial statements. Management will refine its estimates as more information becomes available.

In the final order from the last non-gas base rate increase, the SCC allowed Roanoke Gas to defer the related financing costs of two gate stations that would interconnect to MVP for possible future recovery. As a result, the Company began recognizing AFUDC during the second quarter of fiscal 2020 during the construction phases. Beginning January 2021, Roanoke Gas temporarily ceased recording AFUDC on these projects until such time as construction activities resume. The Company is assuming completion of its MVP related assets, and therefore is seeking rate recovery in the non-gas base rate filing and, if approved, will permanently stop accruing AFUDC on these assets.

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The Company filed an application with the SCC for a new five-year SAVE Plan and Rider on March 31, 2023 for recovery of costs associated with SAVE eligible investments. The Company’s proposal encompasses SAVE eligible investments beginning October 1, 2023. The application seeks recovery of costs associated with $8.5 million in SAVE eligible investments for the initial year ending September 30, 2024 and cumulative investments of $49.5 million over the five year SAVE Plan ending September 30, 2028.

On July 7, 2023, the Staff of the SCC filed its report on the Company’s SAVE Plan and Rider in which it recommended approval of the $49.5 million five-year plan with a revenue requirement of $366,000 beginning on October 1, 2023. The Company expects resolution of this matter in the fourth quarter of fiscal 2023.

On May 16, 2022, Roanoke Gas announced a cooperative agreement under which Roanoke Gas and the Western Virginia Water Authority will produce commercial quality RNG from biogas produced at the regional water pollution control plant. In August 2022, Roanoke Gas filed an application with the SCC seeking approval of a rate adjustment clause under which the Company will recover the costs associated with constructing, owning, operating and maintaining the renewable natural gas facility. The application was filed under Chapter 30 of Title 56 of the Code of Virginia. Chapter 30 allows the Company to accrue AFUDC on the RNG project. In connection with the RNG project, Roanoke Gas began accruing AFUDC in fiscal 2022 associated with construction of the facility. As of ~~March 31,~~June 30, 2023, the Company has recognized approximately ~~$273,000~~$260,000 of AFUDC revenue since inception of the RNG project. The Company received a final order from the SCC on January 23, 2023 approving the Company’s application. The RNG project became operational in March 2023. The Company began billing customers the RNG rate adjustment on March 1, 2023, at which time the Company ceased recording AFUDC.

On May 30, 2023, the Company filed an application with the SCC to update the RNG Rider with an effective date of October 1, 2023. The Company expects resolution of this matter in the fourth quarter of fiscal 2023.

On June 2, 2022, Roanoke Gas filed an application with the SCC to acquire certain natural gas distribution assets from a local housing authority. Under this application, the Company requested the approval to acquire such facilities at five separate apartment complexes, located in the Company’s service territory, that were under housing authority management. Under the proposed plan, the housing authority would renew existing natural gas distribution facilities to include mains, services and meter installations and then transfer ownership of these facilities to Roanoke Gas. In turn, Roanoke Gas would assume responsibility for the operation and maintenance of these assets and recognize a gain related to the asset acquisition equal to the cost associated with the renewal.

On July 19, 2022, the SCC approved the application and on August 4, 2022, the housing authority transferred the assets from two apartment complexes to Roanoke Gas. Roanoke Gas recorded these assets and recognized a pre-tax gain of approximately $219,000 during the Company’s fourth quarter of fiscal 2022. The housing authority expects to complete the upgrade and subsequent asset transfer at one more apartment complex in fiscal 2023. The authority is awaiting future funding to complete the two remaining apartment complexes. The timing of funding and the completion of the asset renewals for these two complexes is unknown at this time.

~~In November 2021, Roanoke Gas received $859,000 in ARPA funds and applied the full amount to customer arrearages in December 2021.~~

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, investment in the LLC, the seasonal funding of its natural gas inventories and accounts receivables, payment of dividends and debt service. 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 ~~$1,727,059~~$282,192 for the ~~six-month~~nine-month period ended ~~March 31,~~June 30, 2023 compared to an increase of ~~$7,913,673~~$12,293,105 for the ~~six-month~~nine-month period ended ~~March 31,~~June 30, 2022. The following table summarizes the sources and uses of cash:

	Six Months Ended March 31,						Nine Months Ended June 30,
Cash Flow Summary	2023			2022			2023			2022
Net cash provided by operating activities	$	16,965,342		$	12,992,906		$	23,634,279		$	19,796,980
Net cash used in investing activities		(14,350,139	)		(14,278,880	)		(21,463,979	)		(21,723,386	)
Net cash provided by (used in) financing activities		(888,144	)		9,199,647			(1,888,108	)		14,219,511
Increase in cash and cash equivalents	$	1,727,059		$	7,913,673		$	282,192		$	12,293,105

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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, all 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 all contribute to higher cash levels. 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.

~~Table of Contents~~

~~RGC RESOURCES, INC. AND SUBSIDIARIES~~

Cash flows from operating activities for the ~~six~~nine months ended ~~March 31,~~June 30, 2023 increased by ~~$3,972,436~~$3,837,299 compared to the same period last year. The table below summarizes the significant components of operating cash flows:

	Six Months Ended March 31,						Increase/			Nine Months Ended June 30,						Increase/
Cash Flow From Operating Activities:	2023			2022			(Decrease)			2023			2022			(Decrease)
Net income (loss)	$	9,598,291		$	(20,909,900	)	$	30,508,191		$	10,285,107		$	(20,317,373	)	$	30,602,480
Non-cash adjustments:
Depreciation		4,954,167			4,656,829			297,338
Depreciation and amortization											7,431,251			6,933,866			497,385
Equity in earnings		(4,099	)		(71,682	)		67,583			(523,581	)		(71,917	)		(451,664	)
AFUDC		(198,308	)		—			(198,308	)		(184,619	)		—			(184,619	)
Impairment of unconsolidated affiliates		—			39,822,213			(39,822,213	)		—			39,822,213			(39,822,213	)
Changes in working capital and regulatory assets and liabilities:
Accounts receivable		(5,155,446	)		(6,517,364	)		1,361,918			289,188			(2,442,787	)		2,731,975
Gas in storage		12,037,790			5,803,496			6,234,294			8,720,497			67,695			8,652,802
Accounts payable		(1,696,080	)		(1,899,065	)		202,985
WNA		(2,612,454	)		(1,800,421	)		(812,033	)
Under-recovery of gas cost											1,765,182			4,688,356			(2,923,174	)
Supplier refunds		(1,789,519	)		2,660,147			(4,449,666	)		(2,186,721	)		2,663,834			(4,850,555	)
Deferred taxes		304,894			(10,052,645	)		10,357,539			122,252			(9,978,841	)		10,101,093
Other		1,526,106			1,301,298			224,808			(2,084,277	)		(1,568,066	)		(516,211	)
Net cash provided by operating activities	$	16,965,342		$	12,992,906		$	3,972,436		$	23,634,279		$	19,796,980		$	3,837,299

The average price of natural gas in storage at the beginning of fiscal 2023 was nearly twice the average price at the beginning of fiscal 2022. As natural gas balances were drawn down during the winter heating season, storage levels declined by $12 million ~~during the current six month period~~ compared to $5.8 million for the same period last year. In April, Roanoke Gas began delivering gas into storage to replenish the natural gas withdrawn. From April through June of the current fiscal year, approximately 250,000 more dekatherms of gas were delivered into storage but at less than 50% of the cost incurred during the same period last ~~year, even though approximately 160,000 fewer dekatherms were withdrawn.~~year. Accordingly, this ~~difference~~provided an additional $2.5 million in ~~storage values contributed~~operating cash to athe $6.2 million ~~increase in operating cash.~~realized during the withdrawal period. In March 2022, the Company received a $2.3 million supplier refund, resulting from a FERC rate case settlement, from one of the interstate pipelines that ~~supply~~supplies the Company with natural gas. In July 2022, the Company began refunding this balance along with other smaller refunds to customers over a 12-month period. The change from collecting supplier refunds during the prior period to refunding supplier refunds during the current period amounted to a ~~$4.4~~$4.9 million reduction in operating cash. Fiscal 2022 reflected a significant decrease in deferred tax liabilities related to the $10.2 million deferred tax asset recognized as a result of the impairment of the investment in the LLC, when compared to an approximate ~~$300,000~~$100,000 increase during the current period. When netted against the non-cash impairment charge, the combined amounts offset the prior year net loss, thereby making underling net income comparable between periods.

Cash Flows Used in Investing Activities:

Investing activities primarily consist of expenditures related to investment in 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 the demands of customer growth. The Company continued its focus on SAVE infrastructure replacement projects, including the replacement of pre-1973 first generation plastic pipe, and extending the natural gas distribution system ~~to unserved developments~~ within its ~~existing~~ service territory. The SAVE Plan and Rider were temporarily suspended beginning in January 2023 due to the implementation of new non-gas rates that incorporated all prior SAVE qualified infrastructure projects as well as the projected activity during the current fiscal year. Roanoke Gas expects to resume the SAVE Plan and Rider in fiscal 2024 to continue the recovery of new investments in qualified infrastructure projects. Roanoke Gas' total capital expenditures for the ~~six~~nine month period ended ~~March 31,~~June 30, 2023 were approximately ~~$12.9~~$19.4 million compared to ~~$10.8~~$17.4 million during the same period last year. Capital expenditures for fiscal 2023 are expected to be in the $21 - $23 million range. Midstream's investment in the LLC declined by approximately ~~$2.1~~$2.2 million as ~~no active construction activities occurred during the current fiscal year.~~ Midstream ~~will cease~~ceased future participation in capital calls following its May 2023 funding payment based on ~~the~~an agreement with the LLC's managing ~~partner to assume Midstream's future commitments.~~partner. Midstream will continue to be invested in the LLC; however, its participation percentage is expected to decline with no additional investment. See Equity Investment in Mountain Valley Pipeline for additional information.

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RGC RESOURCES, INC. AND SUBSIDIARIES

Cash Flows Provided by (Used in) Financing Activities:

Financing 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 ~~$900,000~~$1.9 million for the ~~six~~nine months ended ~~March 31,~~June 30, 2023, compared to ~~$9.2~~$14.2 million in cash flows provided by financing activities for the same period last year. The reduction in financing cash flows is primarily attributable to Resources' $27 million equity offering in March 2022 of which $12 million was invested in Roanoke Gas and $10 million in Midstream, as well as the issuance of Roanoke Gas' $15 million note in October 2021 and $5 million delayed draw note in April 2022 and Midstream's $8 million note in November 2021. These proceeds were used to pay down Roanoke Gas' line-of-credit and maturing $7 million note, and Midstream applied $18 million against its credit facility with the excess to provide funding for Roanoke's capital budget. During the current period, Resources issued a total of ~~102,812~~177,900 shares of common stock resulting in net proceeds of ~~$2.1~~$3.6 million, including ~~74,566~~127,852 shares through the ATM program in which Resources received ~~$1,630,000,~~$2,713,000, net of ~~fees, and~~fees. Resources infused $4.26 million into Midstream ~~borrowed~~in addition to the $1.1 million Midstream borrowed under its credit facility.

Notes 8 and 9 provide details on the Company's line-of-credit and borrowing activity.

The current interest rate environment is expected to continue to result in higher interest expense associated with the Company's variable-rate debt or the issuance of any new debt until such time as interest rates decline.

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 as ~~necessary.~~necessary if such a need would arise.

Based on the agreement with the LLC's managing partner to assume future capital contributions related to the MVP, as described above in the Equity Investment in Mountain Valley Pipeline section, Midstream's future cash requirements are reduced to regular monthly operating expenses, debt service and capital contributions to Southgate. ~~Unless refinanced,~~On July 28, 2023, Midstream extended the maturity date of its $23 million credit facility to December 31, 2024 with the current lenders. After considering the extension of the credit facility, Midstream's total ~~Midstream~~ debt service over the succeeding 12 months includes ~~$25.1~~$11.1 million to retire maturing debt and approximately $2.4 million in interest expense based on current interest rates. ~~$23 million of the maturing debt pertains~~Management is working with its lenders to ~~the credit facility due in December 2023, which management is seeking an extension~~negotiate extensions or refinancing ~~option~~options on the remaining current maturities until such time as ~~the~~ MVP is placed in ~~service.~~service and cash flows are generated. Management believes it will be able to meet Midstream's cash requirements.

As of ~~March 31,~~June 30, 2023, Resources' long-term capitalization ratio was 42% equity and 58% debt.

ITEM 3 – QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Not applicable.

ITEM 4 – 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 ~~March 31,~~June 30, 2023, 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 ~~March 31,~~June 30, 2023.

Management routinely reviews the Company’s internal control over financial reporting and makes changes, as necessary, to enhance the effectiveness of the internal controls. There were no control changes during the fiscal quarter ended ~~March 31,~~June 30, 2023, that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

3736

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RGC RESOURCES, INC. AND SUBSIDIARIES

Part II – Other Information

ITEM 1 – LEGAL PROCEEDINGS

No material proceedings.

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, 2022.

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

On May 4, 2023, Midstream entered into an agreement with the LLC’s managing partner and primary interest owner to make Midstream’s future capital contributions to the LLC up to the point of project in-service or cancellation, as a result of which Midstream's ownership interest percentage in the LLC as it relates to the MVP project will be proportionately adjusted.None.

3837

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ITEM 6 – EXHIBITS

Number						Description
~~1.1~~						At Market Issuance Sales Agreement, dated March 5, 2020, between RGC Resources, Inc. and Janney Montgomery Scott LLC, as agent (incorporated herein by reference to Exhibit 1.1 on Form 8-K as filed February 21, 2023)
10.1						~~Letter Agreement dated May 4, 2023, between MVP Holdco, LLC and RGC Midstream, LLC.~~
~~10.2~~						Promissory Note (Revolving Loan) in the principal amount of $25,000,000 by Roanoke Gas Company with Pinnacle Bank, dated March 24, 2023 (incorporated herein by reference to Exhibit 10.1 on Form 8-K as filed March 28, 2023).
~~10.3~~						Amended and Restated Promissory Note (Term Loan) in the principal amount of $10,000,000 by Roanoke Gas Company with Pinnacle Bank, dated March 24, 2023 (effective as of April 1, 2023) (incorporated herein by reference to Exhibit 10.2 on Form 8-K as filed March 28, 2023).
~~10.4~~						~~Amended and Restated Loan Agreement by and between Roanoke Gas Company and Pinnacle Bank, dated March 24, 202~~3 ~~(incorporated herein by reference to Exhibit 10.3 on Form 8-K as filed March 28, 2023).~~
~~10.5~~						~~Amended and Restated Guaranty Agreement by RGC Resources, Inc. with Pinnacle Bank, dated March 24, 2023(incorporated herein by reference to Exhibit 10.4 on Form 8-K as filed March 28, 2023).~~
~~10.6~~						Amended Swap Agreement by and between Roanoke Gas Company and Pinnacle Bank, dated April 3, 2023 (effective April 1, 2023) (incorporated herein by reference to Exhibit 10.1 on Form 8-K as filed April 4, 2023).
10.2						Change in Control Agreement between RGC Resources, Inc. and Mr. Paul W. Nester effective May 1, 2023 (incorporated herein by reference to Exhibit 10.1 on Form 8-K as filed April 27, 2023).
10.3						Change in Control Agreement between RGC Resources, Inc. and Mr. Jason A. Field effective May 1, 2023 (incorporated herein by reference to Exhibit 10.2 on Form 8-K as filed April 27, 2023).
10.4						Change in Control Agreement between RGC Resources, Inc. and Mr. Lawrence T. Oliver effective May 1, 2023 (incorporated herein by reference to Exhibit 10.3 on Form 8-K as filed April 27, 2023).
10.5						Change in Control Agreement between RGC Resources, Inc. and Mr. Carl J. Shockley, Jr. effective May 1, 2023 (incorporated herein by reference to Exhibit 10.4 on Form 8-K as filed April 27, 2023).
10.6						Change in Control Agreement between RGC Resources, Inc. and Mrs. C. Brooke Miles effective May 1, 2023 (incorporated herein by reference to Exhibit 10.5 on Form 8-K as filed April 27, 2023).
10.7						Letter Agreement dated May 4, 2023, between MVP Holdco, LLC and RGC Midstream, LLC (incorporated herein by reference to Exhibit 10.1 on Form 10-Q as filed May 5, 2023).
10.8						LIBOR Transition Notice and ISDA Swap Amendment between Atlantic Union Bank and RGC Midstream, LLC, executed June 28, 2023 (incorporated herein by reference to Exhibit 10.1 on Form 8-K as filed June 29, 2023).
10.9						Fifth Amendment to Credit Agreement between RGC Midstream, LLC and the lenders Atlantic Union Bank and Truist Bank dated July 28, 2023 (incorporated herein by reference to Exhibit 10.1 on Form 8-K as filed July 31, 2023).
14.1						Revised Code of Ethics (incorporated herein by reference to Exhibit 14.1 on Form 8-K as filed April 27, 2023).
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: ~~May 5,~~August 4, 2023	By:	/s/ Jason A. Field
		Jason A. Field
		Vice President, Chief Financial Officer and Treasurer
		(Principal Financial Officer)

4039

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)

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

Class	Outstanding at ~~April 30,~~July 31, 2023
Common Stock, $5 Par Value	~~9,924,848~~10,001,197

		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	25
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	3736
Item 4.	Controls and Procedures	3736
PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	3837
Item 1A.	Risk Factors	3837
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	3837
Item 3.	Defaults Upon Senior Securities	3837
Item 4.	Mine Safety Disclosures	3837
Item 5.	Other Information	3837
Item 6.	Exhibits	3938
Signatures		4039

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

ARPA		American Rescue Plan Act of 2021

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

CARES/CARES Act		The Coronavirus Aid, Relief, and Economic Security Act

Company		RGC Resources, Inc. or Roanoke Gas Company

COVID-19 or Coronavirus		A pandemic disease that causes respiratory illness similar to the flu with symptoms such as coughing, fever, and in more severe cases, difficulty in breathing

CPCN		Certificate of Public Convenience and Necessity

D.C. Circuit		U. S. Court of Appeals for the District of Columbia

Diversified Energy		Diversified Energy Company, a wholly-owned subsidiary of Resources

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

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

FERC		Federal Energy Regulatory Commission

Fourth Circuit		U.S. Fourth Circuit Court of Appeals

FRA		Fiscal Responsibility Act of 2023, bi-partisan legislation containing certain provisions specific to MVP

GAAP		Generally Accepted Accounting Principles in the United States

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

LIBOR		London Inter-Bank Offered Rate

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

MVP		Mountain Valley Pipeline, a FERC-regulated natural gas pipeline project intended to connect the ~~Equitran's~~Equitrans' gathering and transmission system in northern West Virginia to the Transco interstate pipeline in south central Virginia with a planned interconnect 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 credit		Research and development federal tax credit defined under Internal Revenue Code section 41 and the related regulations

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

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

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

RNG		Renewable natural gas

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 proposed and 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

SCOTUS		Supreme Court of the United States

SEC		U.S. Securities and Exchange Commission

SOFR		Secured Overnight Financing Rate

Southgate		Mountain Valley Pipeline, LLC’s Southgate project, which is a contemplated interstate pipeline that was approved by the FERC to extend from the MVP in south central Virginia to central North Carolina, of which Midstream holds less than a 1% investment

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

	March 31, 2023			September 30,			June 30, 2023			September 30,
	Unaudited			2022			Unaudited			2022
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	6,625,973		$	4,898,914		$	5,181,106		$	4,898,914
Accounts receivable (less allowance for credit losses of $777,900, and $371,271, respectively)		10,102,087			5,353,270
Accounts receivable (less allowance for credit losses of $760,027, and $371,271, respectively)								4,675,325			5,353,270
Materials and supplies		1,451,225			1,228,554			1,744,725			1,228,554
Gas in storage		4,878,861			16,916,651			8,196,154			16,916,651
Prepaid income taxes		3,121,921			3,087,755			1,557,309			3,087,755
Regulatory assets		3,149,676			1,877,468			1,807,709			1,877,468
Interest rate swaps		1,177,044			1,218,211			1,467,312			1,218,211
Other		1,853,248			967,496			1,125,290			967,496
Total current assets		32,360,035			35,548,319			25,754,930			35,548,319
UTILITY PROPERTY:
In service		298,450,074			290,940,683			301,644,749			290,940,683
Accumulated depreciation and amortization		(83,290,810	)		(80,242,946	)		(84,658,793	)		(80,242,946	)
In service, net		215,159,264			210,697,737			216,985,956			210,697,737
Construction work in progress		24,126,598			19,163,337			26,101,591			19,163,337
Utility property, net		239,285,862			229,861,074			243,087,547			229,861,074
OTHER NON-CURRENT ASSETS:
Regulatory assets		5,357,937			5,446,547			5,455,317			5,446,547
Investment in unconsolidated affiliates		15,097,075			13,773,075			15,625,337			13,773,075
Benefit plan assets		496,321			749,341			369,811			749,341
Deferred income taxes		902,502			1,057,079			840,665			1,057,079
Interest rate swaps		2,694,335			3,580,256			3,025,034			3,580,256
Other		258,155			293,552			607,443			293,552
Total other non-current assets		24,806,325			24,899,850			25,923,607			24,899,850
TOTAL ASSETS	$	296,452,222		$	290,309,243		$	294,766,084		$	290,309,243

	Six Months Ended March 31, 2023													Nine Months Ended June 30, 2023
	Common Stock		Capital in Excess of Par Value		Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Total Stockholders' Equity			Common Stock		Capital in Excess of Par Value		Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Total Stockholders' Equity
Balance - September 30, 2022	$	49,102,675	$	41,479,459	$	544,158		$	1,964,364		$	93,090,656		$	49,102,675	$	41,479,459	$	544,158		$	1,964,364		$	93,090,656
Net Income		—		—		3,256,405			—			3,256,405			—		—		3,256,405			—			3,256,405
Other comprehensive loss		—		—		—			(168,667	)		(168,667	)		—		—		—			(168,667	)		(168,667	)
Cash dividends declared ($0.1975 per share)		—		—		(1,957,369	)		—			(1,957,369	)		—		—		(1,957,369	)		—			(1,957,369	)
Issuance of common stock (31,245 shares)		156,225		512,757		—			—			668,982			156,225		512,757		—			—			668,982
Balance - December 31, 2022	$	49,258,900	$	41,992,216	$	1,843,194		$	1,795,697		$	94,890,007		$	49,258,900	$	41,992,216	$	1,843,194		$	1,795,697		$	94,890,007
Net Income		—		—		6,341,886			—			6,341,886			—		—		6,341,886			—			6,341,886
Other comprehensive loss		—		—		—			(490,526	)		(490,526	)		—		—		—			(490,526	)		(490,526	)
Cash dividends declared ($0.1975 per share)		—		—		(1,960,156	)		—			(1,960,156	)		—		—		(1,960,156	)		—			(1,960,156	)
Issuance of common stock (71,567 shares)		357,835		1,139,362		—			—			1,497,197			357,835		1,139,362		—			—			1,497,197
Balance - March 31, 2023	$	49,616,735	$	43,131,578	$	6,224,924		$	1,305,171		$	100,278,408		$	49,616,735	$	43,131,578	$	6,224,924		$	1,305,171		$	100,278,408
Net Income															—		—		686,816			—			686,816
Other comprehensive income															—		—		—			475,761			475,761
Cash dividends declared ($0.1975 per share)															—		—		(1,975,236	)		—			(1,975,236	)
Issuance of common stock (75,088 shares)															375,440		1,106,624		—			—			1,482,064
Balance - June 30, 2023														$	49,992,175	$	44,238,202	$	4,936,504		$	1,780,932		$	100,947,813

	Six Months Ended March 31, 2022													Nine Months Ended June 30, 2022
	Common Stock		Capital in Excess of Par Value		Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Total Stockholders' Equity			Common Stock		Capital in Excess of Par Value		Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Total Stockholders' Equity
Balance - September 30, 2021	$	41,875,460	$	19,705,387	$	39,656,296		$	(1,535,434	)	$	99,701,709		$	41,875,460	$	19,705,387	$	39,656,296		$	(1,535,434	)	$	99,701,709
Net Income		—		—		3,584,529			—			3,584,529			—		—		3,584,529			—			3,584,529
Other comprehensive income		—		—		—			351,083			351,083			—		—		—			351,083			351,083
Cash dividends declared ($0.195 per share)		—		—		(1,642,324	)		—			(1,642,324	)		—		—		(1,642,324	)		—			(1,642,324	)
Issuance of common stock (13,914 shares)		69,570		230,278		—			—			299,848			69,570		230,278		—			—			299,848
Balance - December 31, 2021	$	41,945,030	$	19,935,665	$	41,598,501		$	(1,184,351	)	$	102,294,845		$	41,945,030	$	19,935,665	$	41,598,501		$	(1,184,351	)	$	102,294,845
Net Loss		—		—		(24,494,429	)		—			(24,494,429	)		—		—		(24,494,429	)		—			(24,494,429	)
Other comprehensive income		—		—		—			1,524,308			1,524,308			—		—		—			1,524,308			1,524,308
Cash dividends declared ($0.195 per share)		—		—		(1,909,717	)		—			(1,909,717	)		—		—		(1,909,717	)		—			(1,909,717	)
Issuance of common stock (1,400,889 shares)		7,004,445		21,043,277		—			—			28,047,722			7,004,445		21,043,277		—			—			28,047,722
Balance - March 31, 2022	$	48,949,475	$	40,978,942	$	15,194,355		$	339,957		$	105,462,729		$	48,949,475	$	40,978,942	$	15,194,355		$	339,957		$	105,462,729
Net Income															—		—		592,527			—			592,527
Other comprehensive income															—		—		—			1,118,545			1,118,545
Cash dividends declared ($0.195 per share)															—		—		(1,912,178	)		—			(1,912,178	)
Issuance of common stock (14,520 shares)															72,600		248,401		—			—			321,001
Balance - June 30, 2022														$	49,022,075	$	41,227,343	$	13,874,704		$	1,458,502		$	105,582,624