10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For Quarterly Period Ended December 31, 2019

Commission File Number 000-26591

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

VIRGINIA	54-1909697
(State or Other Jurisdiction of Incorporation or Organization)	(I.R.S. Employer Identification No.)
519 Kimball Ave., N.E., Roanoke, VA	24016
(Address of Principal Executive Offices)	(Zip Code)

(540) 777-4427

(Registrant’s Telephone Number, Including Area Code)

None

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

____________________________________________________ 

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

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

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

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

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

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

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

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

Class	Outstanding at January 31, 2020
Common Stock, $5 Par Value	8,112,424

GLOSSARY OF TERMS

AFUDC	Allowance for Funds Used During Construction
AOCI/AOCL	Accumulated Other Comprehensive Income (Loss)
ARO	Asset Retirement Obligation
ARP	Alternative Revenue Program, regulatory or rate recovery mechanisms approved by the SCC that allow for the adjustment of revenues for certain broad, external factors, or for additional billings if the entity achieves certain performance targets.
ASC	Accounting Standards Codification
ASU	Accounting Standards Update as issued by the FASB
Company	RGC Resources, Inc. or Roanoke Gas Company
CPCN	Certificate of Public Convenience
Diversified Energy	Diversified Energy Company, a wholly-owned subsidiary of Resources
DRIP	Dividend Reinvestment and Stock Purchase Plan of RGC Resources, Inc.
DTH	Decatherm
EPS	Earnings Per Share
ERISA	Employee Retirement Income Security Act of 1974
ESAC	Eligible Safety Activity Costs, a Virginia natural gas utility’s operation and maintenance expenditures that are related to the development, implementation, or execution of the natural gas utility’s integrity management plan or programs and measures implemented to comply with regulations issued by the SCC or a federal regulatory body with jurisdiction over pipeline safety.
FASB	Financial Accounting Standards Board
FDIC	Federal Deposit Insurance Corporation
FERC	Federal Energy Regulatory Commission
Fourth Circuit	U.S. Fourth Circuit Court of Appeals
GAAP	U.S. Generally Accepted Accounting Principles
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 and postretirement plans’ 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 the Mountain Valley Pipeline and MVP Southgate.
LNG	Liquefied natural gas, the cryogenic liquid form of natural gas of which Roanoke Gas operates and maintains a plant capable of producing and storing up to 200,000 dth of natural gas in liquid form.
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 natural gas pipeline project intended to connect the Equitran's 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.
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.
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
RSPD	RGC Resources, Inc. Restricted Stock Plan for Outside Directors
RSPO	RGC Resources, Inc. Restricted Stock Plan
SAVE	Steps to Advance Virginia's Energy Plan, a regulatory mechanism that allows natural gas utilities to recover the investment in eligible infrastructure replacement projects without the filing of a formal non-gas rate application.
SAVE Plan	Steps to Advance Virginia's Energy Plan, a regulatory mechanism to recover the related depreciation and expenses and return on rate base of eligible infrastructure replacement projects on a prospective basis without the filing of a formal application for increases in non-gas base rates.
SAVE Rider	Steps to Advance Virginia's Energy Rider, the rate component of the SAVE Plan as approved by the SCC that is billed monthly to the natural gas utility’s customers to recover the costs associated with eligible infrastructure projects including the related depreciation and expenses and return on rate base of the investment.
SCC	Virginia State Corporation Commission, the regulatory body with oversight responsibilities of the utility operations of Roanoke Gas.
SEC	U.S. Securities and Exchange Commission
Southgate	Mountain Valley Pipeline, LLC’s Southgate project, which extends 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
TCJA	Tax Cuts and Jobs Act of 2017
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.

RGC RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

	Unaudited
	December 31, 2019			September 30, 2019
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	1,012,347		$	1,631,348
Accounts receivable (less allowance for uncollectibles of $253,076 and $110,743, respectively)	10,084,224			3,870,211
Materials and supplies	968,299			1,021,882
Gas in storage	6,015,628			6,448,307
Prepaid income taxes	128,892			1,157,980
Regulatory assets	1,453,285			1,521,939
Other	1,576,689			733,525
Total current assets	21,239,364			16,385,192
UTILITY PROPERTY:
In service	241,063,157			237,786,964
Accumulated depreciation and amortization	(68,559,129		)	(67,207,334		)
In service, net	172,504,028			170,579,630
Construction work in progress	12,886,980			11,423,326
Utility plant, net	185,391,008			182,002,956
OTHER ASSETS:
Regulatory assets	11,807,353			12,178,853
Investment in unconsolidated affiliates	49,375,781			47,375,459
Other	369,107			411,236
Total other assets	61,552,241			59,965,548
TOTAL ASSETS	$	268,182,613		$	258,353,696

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RGC RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

	Unaudited
	December 31, 2019			September 30, 2019
LIABILITIES AND STOCKHOLDERS’ EQUITY
CURRENT LIABILITIES:
Dividends payable	$	1,419,236		$	1,339,522
Accounts payable	4,730,021			4,483,233
Capital contributions payable	891,903			5,024,824
Customer credit balances	821,643			880,295
Customer deposits	1,549,435			1,432,031
Accrued expenses	2,434,189			3,448,000
Interest rate swaps	87,761			147,556
Regulatory liabilities	5,569,732			4,877,603
Total current liabilities	17,503,920			21,633,064
LONG-TERM DEBT:
Notes payable	111,204,200			95,512,200
Line-of-credit	2,925,766			8,172,473
Less unamortized debt issuance costs	(357,187		)	(313,315		)
Long-term debt, net	113,772,779			103,371,358
DEFERRED CREDITS AND OTHER LIABILITIES:
Interest rate swaps	452,347			746,785
Asset retirement obligations	6,844,857			6,788,683
Regulatory cost of retirement obligations	12,098,472			11,892,352
Benefit plan liabilities	6,928,648			6,912,105
Deferred income taxes	13,404,111			12,978,523
Regulatory liabilities	10,818,344			10,934,434
Total deferred credits and other liabilities	50,546,779			50,252,882
STOCKHOLDERS’ EQUITY:
Common stock, $5 par value; authorized 10,000,000 shares; issued and outstanding 8,091,317 and 8,073,264 shares, respectively	40,456,585			40,366,320
Preferred stock, no par, authorized 5,000,000 shares; no shares issued and outstanding	—			—
Capital in excess of par value	14,702,006			14,397,072
Retained earnings	33,409,617			30,821,917
Accumulated other comprehensive loss	(2,209,073		)	(2,488,917		)
Total stockholders’ equity	86,359,135			83,096,392
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$	268,182,613		$	258,353,696

See notes to condensed consolidated financial statements.

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RGC RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

FOR THE THREE-MONTH PERIODS ENDED DECEMBER 31, 2019 AND 2018

UNAUDITED

	Three Months Ended December 31,
	2019		2018
OPERATING REVENUES:
Gas utilities	$	19,625,606	$	21,036,581
Other	159,847		180,166
Total operating revenues	19,785,453		21,216,747
OPERATING EXPENSES:
Cost of gas - utility	8,177,806		11,906,459
Cost of sales - non utility	76,456		110,703
Operations and maintenance	3,917,470		3,521,999
General taxes	543,237		507,889
Depreciation and amortization	1,988,505		1,905,475
Total operating expenses	14,703,474		17,952,525
OPERATING INCOME	5,081,979		3,264,222
Equity in earnings of unconsolidated affiliate	1,094,086		563,049
Other income (expense), net	157,643		125,886
Interest expense	1,085,185		816,782
INCOME BEFORE INCOME TAXES	5,248,523		3,136,375
INCOME TAX EXPENSE	1,241,587		702,213
NET INCOME	$	4,006,936	$	2,434,162
BASIC EARNINGS PER COMMON SHARE	$	0.50	$	0.30
DILUTED EARNINGS PER COMMON SHARE	$	0.49	$	0.30
DIVIDENDS DECLARED PER COMMON SHARE	$	0.1750	$	0.1650

See notes to condensed consolidated financial statements.

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME FOR THE THREE-MONTH PERIODS ENDED DECEMBER 31, 2019 AND 2018

UNAUDITED

	Three Months Ended December 31,
	2019		2018
NET INCOME	$	4,006,936	$	2,434,162
Other comprehensive income (loss), net of tax:
Interest rate swaps	263,053		(81,403		)
Defined benefit plans	16,791		(1,913		)
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX	279,844		(83,316		)
COMPREHENSIVE INCOME	$	4,286,780	$	2,350,846

See notes to condensed consolidated financial statements.

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CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY

FOR THE THREE-MONTH PERIODS ENDED DECEMBER 31, 2019 AND 2018

UNAUDITED

	Three Months Ended December 31, 2019
	Common Stock		Capital in Excess of Par Value		Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Total Stockholders' Equity
Balance - September 30, 2019	$	40,366,320	$	14,397,072	$	30,821,917		$	(2,488,917	)	$	83,096,392
Net Income	—		—		4,006,936			—			4,006,936
Other comprehensive income	—		—		—			279,844			279,844
Cash dividends declared ($0.175 per share)	—		—		(1,419,236		)	—			(1,419,236		)
Issuance of common stock (18,053 shares)	90,265		304,934		—			—			395,199
Balance - December 31, 2019	$	40,456,585	$	14,702,006	$	33,409,617		$	(2,209,073	)	$	86,359,135

	Three Months Ended December 31, 2018
	Common Stock		Capital in Excess of Par Value		Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Total Stockholders' Equity
Balance - September 30, 2018	$	39,973,075	$	13,043,656	$	27,438,049		$	(871,668	)	$	79,583,112
Net Income	—		—		2,434,162			—			2,434,162
Other comprehensive loss	—		—		—			(83,316		)	(83,316		)
Cash dividends declared ($0.165 per share)	—		—		(1,322,335		)	—			(1,322,335		)
Issuance of common stock (17,035 shares)	85,175		262,942		—			—			348,117
Balance - December 31, 2018	$	40,058,250	$	13,306,598	$	28,549,876		$	(954,984	)	$	80,959,740

See notes to condensed consolidated financial statements.

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

FOR THE THREE-MONTH PERIODS ENDED DECEMBER 31, 2019 AND 2018

UNAUDITED

	Three Months Ended December 31,
	2019			2018
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	4,006,936		$	2,434,162
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	2,047,695			1,940,472
Cost of retirement of utility plant, net	(170,224		)	(50,093		)
Equity in earnings of unconsolidated affiliate	(1,094,086		)	(563,049		)
Changes in assets and liabilities which used cash, exclusive of changes and noncash transactions shown separately	(3,972,358		)	(6,061,666		)
Net cash provided by (used in) operating activities	817,963			(2,300,174		)
CASH FLOWS FROM INVESTING ACTIVITIES:
Expenditures for utility property	(5,849,460		)	(5,691,011		)
Investment in unconsolidated affiliate	(5,039,157		)	(10,142,766		)
Proceeds from disposal of utility property	12,881			249
Net cash used in investing activities	(10,875,736		)	(15,833,528		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from issuance of unsecured notes	15,692,000			10,344,000
Borrowings under line-of-credit	9,784,533			13,760,363
Repayments under line-of-credit	(15,031,241		)	(5,319,582		)
Debt issuance expenses	(62,198		)	—
Proceeds from issuance of stock	395,199			348,117
Cash dividends paid	(1,339,521		)	(1,235,798		)
Net cash provided by financing activities	9,438,772			17,897,100
NET DECREASE IN CASH AND CASH EQUIVALENTS	(619,001		)	(236,602		)
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	1,631,348			247,411
CASH AND CASH EQUIVALENTS AT END OF YEAR	$	1,012,347		$	10,809
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest	$	1,243,093		$	1,101,028
Income taxes	—			—

See notes to condensed consolidated financial statements.

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RGC RESOURCES, INC. AND SUBSIDIARIES

CONDENSED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

UNAUDITED

1. Basis of Presentation

Resources is an energy services company primarily engaged in the sale and distribution of natural gas. The condensed consolidated financial statements include the accounts of Resources and its wholly-owned subsidiaries: Roanoke Gas, 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 present fairly Resources' financial position as of December 31, 2019 and the results of its operations, comprehensive income, changes in stockholders' equity and cash flows for the three months ended December 31, 2019 and 2018. The results of operations for the three months ended December 31, 2019 are not indicative of the results to be expected for the fiscal year ending September 30, 2020 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 as permitted under the rules and regulations of the Securities and Exchange Commission. Pursuant to those rules, certain information and note disclosures normally included in the annual financial statements prepared in accordance with generally accepted accounting principles have been condensed or omitted, although the Company believes that the disclosures are adequate to make the information not misleading. Therefore, the 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, 2019. The September 30, 2019 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 in Form 10-K for the year ended September 30, 2019. Newly adopted and newly issued accounting standards are discussed below.

Recently Issued or Adopted Accounting Standards

In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) that affects any entity that enters into contracts with customers for the transfer of goods or services or transfer of non-financial assets. This guidance supersedes the revenue recognition requirements in Topic 605, Revenue Recognition, and most industry-specific guidance. The core principle of the new guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers. To achieve that core principle, an entity should apply the following steps: (1) identify the contract with the customer, (2) identify the performance obligations in the contract, (3) determine the transaction price, (4) allocate the transaction price to the performance obligations in the contract, and (5) recognize revenue when, or as, the entity satisfies the performance obligation. Subsequently issued ASUs provided additional guidance to assist in the implementation of the new revenue standard. The standard was effective for the Company's annual reporting period ending September 30, 2019 and interim periods within that annual period.

The Company adopted ASU 2014-09 and all amendments effective October 1, 2018 with no significant impact to revenues recognized and no significant changes to the Company’s related business processes, systems or internal controls over financial reporting. See Note 2 for further information.

In February 2016, the FASB issued ASU 2016-02, Leases. This ASU leaves the accounting for leases mostly unchanged for lessors, with the exception of targeted improvements for consistency; however, the new guidance requires lessees to recognize assets and liabilities for leases with terms of more than 12 months. The ASU also revises the definition of a lease as a contract, or part of a contract, that conveys the right to control the use of identified property, plant or equipment for a period of time in exchange for consideration. Consistent with current GAAP, the presentation and cash flows arising from a lease by a lessee will primarily depend on its classification as a finance or operating lease. In contrast, the new ASU requires both types of leases to be recognized on the balance sheet. In addition, the new guidance includes quantitative and

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RGC RESOURCES, INC. AND SUBSIDIARIES

qualitative disclosure requirements to aid financial statement users in better understanding the amount, timing and uncertainty of cash flows arising from leases. In January 2018, the FASB issued ASU 2018-01, which provides a practical expedient that allows entities the option of not evaluating existing land easements under the new lease standard for those easements that were entered into prior to adoption. New or modified land easements will require evaluation on a prospective basis. The new guidance is effective for the Company for the annual reporting period ending September 30, 2020 and interim periods within that annual period.

The Company adopted ASU 2016-02 and related guidance effective October 1, 2019. At the time of adoption, the Company had one operating lease. The value of the lease obligation under the new guidance would be approximately $25,000, which falls below the Company's $50,000 aggregate threshold for recording leases under the new standard. If at a future point, the total value of all leases exceeded this threshold, the Company would recognize the leases in accordance with current guidance in addition to providing the required disclosures. The current operating lease has a term of 2 years with quarterly payments in the amount of $3,240 until the lease terminates in September 2021. This new guidance does not have a material effect on the Company's financial position, results of operations or cash flows.

In August 2017, the FASB issued ASU 2017-12, Derivatives and Hedging: Targeted Improvements to Accounting For Hedging Activities. The ASU is meant to simplify recognition and presentation guidance in an effort to improve financial reporting of cash flow and fair value hedging relationships to better portray the economic results of an entity's risk management activities. This is achieved through changes to both the designation and measurement guidance for qualifying hedging relationships, as well as changes to the presentation of hedge results. The Company adopted the new guidance effective October 1, 2019. As the Company currently has only cash flow hedges and no portion of these swaps were deemed ineffective during the periods presented, this new guidance does not have a material effect on the Company's financial position, results of operations or cash flows.

In August 2018, the FASB issued ASU 2018-15, Intangibles - Goodwill and Other - Internal-Use Software (Subtopic 350-40): Customer's Accounting for Implementation Costs incurred in a Cloud Computing Arrangement that is a Service Contract. This ASU reduces the complexity of accounting for costs of implementing a cloud computing service arrangement and aligns the following requirements to capitalize implementation costs: 1) those incurred in a hosting arrangement that is a service contract, and 2) those incurred to develop or obtain internal-use software, including hosting arrangements that include an internal software license. The Company adopted the new guidance effective October 1, 2019. The adoption of this new guidance does not currently have a material effect on the Company's consolidated financial statements. However, as the ASU changes the treatment of certain contracts by allowing related implementation costs to be capitalized and amortized over time, rather than directly expensed; there could be a significant impact on the Company's financial position, results of operations and cash flow in the future.

In August 2018, the FASB issued ASU 2018-14, Compensation - Retirement Benefits - Defined Benefit Plans - General (Subtopic 715-20) - Disclosure Framework - Changes to the Disclosure Requirements for Defined Benefit Plans. This ASU modifies disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The new guidance is effective for the Company for the annual reporting period ending September 30, 2021. Early adoption is permitted. Management has not completed its evaluation of the new guidance; however, the ASU only modifies disclosure requirements and will not effect financial position, results of operations or cash flows.

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.

2. Revenue

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

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

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RGC RESOURCES, INC. AND SUBSIDIARIES

	Three months ended December 31, 2019						Three months ended December 31, 2018
	Gas utility		Non utility		Total operating revenues		Gas utility			Non utility		Total operating revenues
Natural Gas (Billed and Unbilled):
Residential	$	12,290,361	$	—	$	12,290,361	$	13,012,592		$	—	$	13,012,592
Commercial	5,729,218		—		5,729,218		7,342,702			—		7,342,702
Industrial and Transportation	1,326,085		—		1,326,085		1,226,137			—		1,226,137
Revenue reductions (TCJA) (1)	—		—		—		(523,881		)	—		(523,881		)
Other	215,998		159,847		375,845		226,492			180,166		406,658
Total contracts with customers	19,561,662		159,847		19,721,509		21,284,042			180,166		21,464,208
Alternative Revenue Programs	63,944		—		63,944		(247,461		)	—		(247,461		)
Total operating revenues	$	19,625,606	$	159,847	$	19,785,453	$	21,036,581		$	180,166	$	21,216,747
(1) Accrued refund associated with excess revenue collected in tariff rates associated with the reduction in federal income tax rates. See Note 4 for more information.

Gas utility revenues

Substantially all of Roanoke Gas’ revenues are derived from rates authorized by the SCC as reflected in 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 commodity (the cost of natural gas sold to customers) and delivery (transporting natural gas through the Company’s distribution system to customers). The sale and/or delivery of natural gas to customers results in the satisfaction of the Company’s performance obligation over time as natural gas is delivered.

All customers are billed monthly based on consumption as measured by metered usage. 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 above. 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. Non-utility (unregulated) activities provided by the Company include contract paving and other services. Regarding these activities, the customer is invoiced monthly based on services provided. 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, and the SAVE Plan over/under collection mechanism, which adjusts revenues for the differences between SAVE Plan revenues billed to customers in the current tariff rates and the revenue earned, as calculated based on the timing and extent of infrastructure replacement completed during the period. These amounts are ultimately collected from, or returned to, customers through future changes to tariff rates.

9

RGC RESOURCES, INC. AND SUBSIDIARIES

Customer Accounts Receivable

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
	Trade accounts receivable (1)		Unbilled revenue (1)		Customer credit balances			Customer deposits
Balance at September 30, 2019	$	2,590,702	$	1,236,384	$	880,295		$	1,432,031
Balance at December 31, 2019	6,278,383		3,690,130		821,643			1,549,435
Increase (decrease)	$	3,687,681	$	2,453,746	$	(58,652	)	$	117,404
(1) Included in accounts receivable in the condensed consolidated balance sheet. Amounts shown net of reserve for bad debts.

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

3. Income Taxes

On December 22, 2017, TCJA became law. The TCJA's most significant impact was the reduction of the maximum corporate federal income tax rate from 35% to 21% beginning January 1, 2018.

Under the provisions of ASC 740 - Income Taxes, the deferred tax assets and liabilities of the Company were revalued to reflect the reduction in the federal tax rate. For unregulated entities, the revaluation of excess deferred income taxes flowed through income tax expense in the period of change. For rate regulated entities such as Roanoke Gas, these excess deferred taxes were originally recovered from its customers based on billing rates derived using a federal income tax rate of 34%. As a result, these net excess deferred taxes must be returned to customers. The Company began refunding these excess deferred taxes in fiscal 2018. As the refunds should have no effect on the income of the Company, the consolidated income statements reflect both a reduction in revenues and a corresponding reduction in income taxes associated with the flow back of these net excess deferred taxes. The result is a lowering of the effective tax rate for the Company.

A reconciliation of income tax expense from applying the federal statutory rates in effect for each period to total income tax expense is presented below:

	Three Months Ended December 31,
	2019			2018
Income before income taxes	$	5,248,523		$	3,136,375
Corporate federal tax rate	21.00		%	21.00		%
Income tax expense computed at the federal statutory rate	$	1,102,190		$	658,639
State income taxes, net of federal tax benefit	250,037			150,589
Net amortization of excess deferred taxes on regulated operations	(86,208		)	(86,208		)
Other, net	(24,432		)	(20,807		)
Total income tax expense	$	1,241,587		$	702,213
Effective tax rate	23.7		%	22.4		%

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RGC RESOURCES, INC. AND SUBSIDIARIES

4. Rates and Regulatory Matters

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

On October 10, 2018, Roanoke Gas filed a general rate application requesting an annual increase in customer non-gas base rates of $10.5 million. This application incorporates into the non-gas base rates the impact of tax reform, non-SAVE utility plant investment, increased operating costs, recovery of regulatory assets associated with eligible safety activity costs and SAVE Plan investments and related costs that were previously recovered through the SAVE Rider. The new non-gas base rates were placed in effect for service rendered on or after January 1, 2019, subject to refund pending audit and final order by the SCC. On June 28, 2019, the SCC staff issued their report and recommendation for an annual non-gas rate increase of $6.5 million. On August 14th and 15th, the SCC conducted a hearing on the rate application with the hearing examiner's report issued on November 19, 2019 and subsequently revised on November 26, 2019. The revised report recommended an annual non-gas base rate increase of approximately $7.1 million. On January 24, 2020, the SCC issued their final order on the general rate application. Under the provisions of this order, Roanoke Gas was granted an annualized non-gas rate increase of $7.25 million and was required to write-down a portion of the ESAC assets not subject to recovery in the final order. As a result, management revised its estimate of the rate refund accrual to reflect the award included in the final order. Management also wrote down $317,191 in additional ESAC regulatory assets to comply with the order. The Company is in the process of submitting the rates to the SCC for approval, which will provide for the $7.25 million in additional non-gas revenue. Once approved, the Company will proceed with refunding the excess revenues to its customers. The total accrued rate refund balance is included in Note 14.

As referenced in Note 3, the TCJA reduced the federal corporate tax rate to 21%. The Company revalued its deferred tax assets and liabilities to reflect the new federal tax rate. Under the provisions of ASC 740, the corresponding adjustment to deferred income taxes generally flows directly to income tax expense. For rate regulated entities such as Roanoke Gas, these excess deferred taxes were originally recovered from its customers based on billing rates derived using a federal income tax rate of 34%. Therefore, the adjustment to the net deferred tax liabilities of Roanoke Gas, to the extent such net deferred tax liabilities are attributable to rate base or cost of service for customers, are refundable to customers. Roanoke Gas began accounting for the refund of these excess deferred taxes in fiscal 2018 along with reflecting a corresponding reduction in income tax expense. Most of the net regulatory liability will be refunded over a 28 year period per IRS normalization requirements. See Note 14 for the remaining balances related to excess deferred taxes.

5. Other Investments

In October 2015, Midstream, acquired an initial 1% equity interest in the Mountain Valley Pipeline, LLC.

The LLC was established to construct and operate a natural gas pipeline originating in northern West Virginia and extending through south central Virginia. Once completed, the pipeline will have the capacity to transport approximately 2 million decatherms of natural gas per day.

Due to ongoing delays primarily attributable to the actions of the Fourth Circuit and FERC, which have suspended previously approved permits allowing for water crossings and access through national forest lands, completing the pipeline has been delayed. Current activity on the pipeline is limited to maintenance and restoration activities. The LLC's managing partner believes they have submitted all of the information required for the suspended permits to be approved and is awaiting approval. As a result, the projected cost of the MVP project has grown to between $5.3 and $5.5 billion with a projected in-service date in late calendar 2020. Midstream's estimated total cash contribution is between $53 and $55 million. The Company is utilizing the equity method to account for the transactions and activity of the investment in MVP and is participating in the earnings in proportion to its level of investment.

In April 2018, the LLC announced the Southgate project, which is an approximately 74 mile pipeline extending from the MVP mainline in Virginia to delivery points in North Carolina. Midstream is a less than 1% investor in the project, which is being accounted for under the cost method. Total project cost is estimated to be nearly $500 million, of which Midstream's portion is estimated to be approximately $2.5 million. The Southgate in-service date is currently targeted for calendar year 2021, subject to any further delays in the completion of the MVP mainline.

Funding for Midstream's investments in the LLC for both the MVP and Southgate projects are being provided through two variable rate unsecured promissory notes under a non-revolving credit agreement, maturing in December 2022, and two additional notes issued in June 2019. See Note 7 for a schedule of debt instruments.

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RGC RESOURCES, INC. AND SUBSIDIARIES

The investments in the LLC are included in the condensed consolidated financial statements as follows:

Balance Sheet location of Other Investments:	December 31, 2019		September 30, 2019
Other Assets:
MVP	$	49,055,748	$	47,055,426
Southgate	320,033		320,033
Investment in unconsolidated affiliates	$	49,375,781	$	47,375,459

Current Liabilities:
MVP	$	891,903	$	4,958,260
Southgate	—		66,564
Capital contributions payable	$	891,903	$	5,024,824

	Three Months Ended
Income Statement location of Other Investments:	December 31, 2019		December 31, 2018
Equity in earnings of unconsolidated affiliate	$	1,094,086	$	563,049

	December 31, 2019		September 30, 2019
Undistributed earnings, net of income taxes, of MVP in retained earnings	$	4,079,644	$	3,267,176

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

	Three Months Ended
	December 31, 2019			December 31, 2018
Cash investment	$	5,039,157		$	10,142,766
Change in accrued capital calls	(4,132,921		)	(6,395,680		)
Equity in earnings of unconsolidated affiliates	1,094,086			563,049
Change in investment in unconsolidated affiliates	$	2,000,322		$	4,310,135

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

	Income Statements
	Three Months Ended
	December 31, 2019		December 31, 2018
AFUDC	$	110,025,474	$	54,184,516
Net Other Income	$	734,182	$	2,562,792
Net Income	$	110,759,656	$	56,747,308

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RGC RESOURCES, INC. AND SUBSIDIARIES

	Balance Sheets
	December 31, 2019		September 30, 2019
Assets:
Current Assets	$	243,577,729	$	485,323,892
Construction Work in Progress	4,941,631,920		4,675,267,389
Other Assets	9,923,000		13,190,816
Total Assets	$	5,195,132,649	$	5,173,782,097
Liabilities and Equity:
Current Liabilities	$	223,678,580	$	466,776,233
Capital	4,971,454,069		4,707,005,864
Total Liabilities and Equity	$	5,195,132,649	$	5,173,782,097

6. 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 three interest rate swaps associated with its variable rate debt. Roanoke Gas has a swap agreement that effectively converts the $7,000,000 term note based on LIBOR into fixed-rate debt with a 2.30% effective interest rate. Midstream has two swap agreements corresponding to the $14,000,000 variable rate term note issued on June 12, 2019 and the $10,000,000 variable rate term note issued on June 13, 2019. The swap agreements convert these two notes into fixed rate instruments with effective interest rates of 3.24% and 3.14%, 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.

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

7. Long-Term Debt

On December 23, 2019, Midstream entered into the Third Amendment to Credit Agreement ("Amendment") and amendments to the related Promissory Notes ("Notes") with the corresponding banks. The Amendment modified the original Credit Agreement and prior amendments between Midstream and the banks by increasing the total borrowing capacity to $41,000,000 from its previous limit of $26,000,000 and extending the maturity date to December 29, 2022. The Amendment retained all of the other provisions contained in the previous credit agreements and amendments including the interest rate on the Notes based on 30-day LIBOR plus 1.35%. The additional limits under the Amendment will be used to finance the investment in the MVP.

On December 6, 2019, Roanoke Gas entered into unsecured notes in the aggregate principal amount of $10,000,000. These notes have a 10-year term with a fixed interest rate of 3.60%. Proceeds from these notes will be used to fund Roanoke Gas' capital budget.

Roanoke Gas has other unsecured notes at varying fixed interest rates as well as a variable-rate note with interest based on 30-day LIBOR plus 90 basis points. The variable rate note is hedged by a swap agreement, which converts the debt into a fixed-rate instrument with an annual interest rate of 2.30%. Midstream has two other variable rate notes in the amounts of $14,000,000 and $10,000,000 that are hedged by swap agreements that effectively convert the interest rates to 3.24% and 3.14%, respectively.

All of the 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.

13

All of the debt agreements, except for the line-of-credit, provide for priority indebtedness to not exceed 15% of consolidated total assets. The Company was in compliance with all debt covenants as of December 31, 2019 and September 30, 2019.

Long-term debt consists of the following:

	December 31, 2019				September 30, 2019
	Principal		Unamortized Debt Issuance Costs		Principal		Unamortized Debt Issuance Costs
Roanoke Gas Company:
Unsecured senior notes payable, at 4.26% due on September 18, 2034	$	30,500,000	$	142,398	$	30,500,000	$	144,811
Unsecured term note payable, at 30-day LIBOR plus 0.90%, due November 1, 2021	7,000,000		6,114		7,000,000		6,948
Unsecured term notes payable, at 3.58% due on October 2, 2027	8,000,000		37,324		8,000,000		38,528
Unsecured term notes payable, at 4.41% due on March 28, 2031	10,000,000		35,242		10,000,000		36,272
Unsecured term notes payable, at 3.60% due on December 6, 2029	10,000,000		32,445		—		—
RGC Midstream, LLC:
Unsecured term notes payable, at 30-day LIBOR plus 1.35%, due December 29, 2022	21,704,200		77,603		16,012,200		59,504
Unsecured term note payable, at 30-day LIBOR plus 1.15%, due June 12, 2026	14,000,000		15,650		14,000,000		16,252
Unsecured term note payable, at 30-day LIBOR plus 1.20%, due June 1, 2024	10,000,000		10,411		10,000,000		11,000
Total notes payable	$	111,204,200	$	357,187	$	95,512,200	$	313,315
Line-of-credit, at 30-day LIBOR plus 1.00%, due March 31, 2021	$	2,925,766	$	—	$	8,172,473	$	—
Total long-term debt	$	114,129,966	$	357,187	$	103,684,673	$	313,315

8. Other Comprehensive Income

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

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RGC RESOURCES, INC. AND SUBSIDIARIES

	Before-Tax Amount			Tax (Expense) or Benefit			Net-of-Tax Amount
Three Months Ended December 31, 2019
Interest rate swaps:
Unrealized gains	$	350,693		$	(90,269	)	$	260,424
Transfer of realized losses to interest expense	3,540			(911		)	2,629
Net interest rate swap	354,233			(91,180		)	263,053
Defined benefit plans:
Amortization of actuarial losses	22,610			(5,819		)	16,791
Other comprehensive income	$	376,843		$	(96,999	)	$	279,844
Three Months Ended December 31, 2018
Interest rate swap:
Unrealized losses	$	(93,956	)	$	24,184		$	(69,772	)
Transfer of realized gains to interest expense	(15,662		)	4,031			(11,631		)
Net interest rate swap	(109,618		)	28,215			(81,403		)
Defined benefit plans:
Amortization of actuarial gains	(2,576		)	663			(1,913		)
Other comprehensive loss	$	(112,194	)	$	28,878		$	(83,316	)

The amortization of actuarial gains and losses is included as a component of net periodic pension and postretirement benefit costs under other income (expense), net.

Reconciliation of Other Accumulated Comprehensive Income (Loss)

	Accumulated Other Comprehensive Income (Loss)
Balance at September 30, 2019	$	(2,488,917	)
Other comprehensive income	279,844
Balance at December 31, 2019	$	(2,209,073	)

9. Commitments and Contingencies

Roanoke Gas currently holds the only franchises and/or 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.

10. Earnings Per Share

Basic earnings per common share for the three months ended December 31, 2019 and 2018 were calculated by dividing net income by the weighted average common shares outstanding during the period. Diluted earnings per common share were

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RGC RESOURCES, INC. AND SUBSIDIARIES

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 December 31,
	2019		2018
Net Income	$	4,006,936	$	2,434,162
Weighted average common shares	8,081,837		8,003,736
Effect of dilutive securities:
Options to purchase common stock	31,948		48,261
Diluted average common shares	8,113,785		8,051,997
Earnings Per Share of Common Stock:
Basic	$	0.50	$	0.30
Diluted	$	0.49	$	0.30

11. Employee Benefit Plans

The Company has both a pension plan and a postretirement plan. The pension plan covers substantially all of the Company’s employees hired before January 1, 2017 and provides retirement income based on years of service and employee compensation. The postretirement plan 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
	December 31,
	2019			2018
Components of net periodic pension cost:
Service cost	$	172,902		$	134,317
Interest cost	265,557			291,682
Expected return on plan assets	(459,156		)	(387,359		)
Recognized loss	113,936			39,650
Net periodic pension cost	$	93,239		$	78,290

	Three Months Ended
	December 31,
	2019			2018
Components of postretirement benefit cost:
Service cost	$	41,970		$	33,221
Interest cost	132,869			162,236
Expected return on plan assets	(137,599		)	(136,805		)
Recognized loss	59,343			30,951
Net postretirement benefit cost	$	96,583		$	89,603

The components of net periodic benefit cost, other than the service cost component, are included in other income (expense), net in the condensed consolidated statements of income as prescribed under ASU 2017-07. Service cost is included in operations and maintenance expense in the condensed consolidated statements of income.

The table below reflects the Company's actual contributions made fiscal year-to-date and the expected contributions to be made during the balance of the current fiscal year.

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RGC RESOURCES, INC. AND SUBSIDIARIES

	Fiscal Year-to-Date Contributions		Remaining Fiscal Year Contributions
Defined benefit pension plan	$	—	$	800,000
Postretirement medical plan	—		400,000
Total	$	—	$	1,200,000

12. Fair Value Measurements

FASB ASC No. 820, Fair Value Measurements and Disclosures, established a fair value hierarchy that prioritizes each input to the valuation method used to measure fair value of financial and nonfinancial assets and liabilities that are measured and reported on a fair value basis into one of the following three levels:

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

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

Level 3 – Unobservable inputs for the asset or liability where there is little, if any, market activity for the asset or liability at the measurement date.

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 as of December 31, 2019 and September 30, 2019:

	Fair Value Measurements - December 31, 2019
	Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Liabilities:
Natural gas purchases	$	955,372	$	—	$	955,372	$	—
Interest rate swaps	540,108		—		540,108		—
Total	$	1,495,480	$	—	$	1,495,480	$	—
	Fair Value Measurements - September 30, 2019
	Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Liabilities:
Natural gas purchases	$	397,757	$	—	$	397,757	$	—
Interest rate swaps	894,341		—		894,341		—
Total	$	1,292,098	$	—	$	1,292,098	$	—

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.

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RGC RESOURCES, INC. AND SUBSIDIARIES

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 December 31, 2019 and September 30, 2019, the Company had recorded in accounts payable the estimated fair value of the liability valued at the corresponding first of month index prices for which the liability is expected to be settled.

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

The carrying value of cash and cash equivalents, accounts receivable, 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 as of December 31, 2019 and September 30, 2019:

	Fair Value Measurements - December 31, 2019
	Carrying Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Liabilities:
Notes payable	$	111,204,200	$	—	$	—	$	117,472,116
Total	$	111,204,200	$	—	$	—	$	117,472,116
	Fair Value Measurements - September 30, 2019
	Carrying Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Liabilities:
Notes payable	$	95,512,200	$	—	$	—	$	100,900,952
Total	$	95,512,200	$	—	$	—	$	100,900,952

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.

FASB 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. As of December 31, 2019 and September 30, 2019, no single customer accounted for more than 5% of the total accounts receivable balance. The Company maintains certain credit standards with its customers and requires a customer deposit if such evaluation warrants.

13. 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.

The reportable segments disclosed herein are defined as follows:

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RGC RESOURCES, INC. AND SUBSIDIARIES

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

Investment in Affiliates - The investment in affiliates segment reflects the income generated through the activities of the Company's investment in the MVP and Southgate projects.

Parent and Other - Parent and other include the unregulated activities of the Company as well as certain corporate eliminations.

Information related to the segments of the Company are provided below:

	Three Months Ended December 31, 2019
	Gas Utility	Investment in Affiliates		Parent and Other	Consolidated Total
Operating revenues	19,625,606	—		159,847	19,785,453
Depreciation	1,988,505	—		—	1,988,505
Operating income (loss)	5,041,485	(38,591	)	79,085	5,081,979
Equity in earnings	—	1,094,086		—	1,094,086
Interest expense	718,853	366,332		—	1,085,185
Income before income taxes	4,478,882	690,354		79,287	5,248,523

	Three Months Ended December 31, 2018
	Gas Utility	Investment in Affiliates		Parent and Other	Consolidated Total
Operating revenues	21,036,581	—		180,166	21,216,747
Depreciation	1,905,475	—		—	1,905,475
Operating income (loss)	3,230,825	(33,887	)	67,284	3,264,222
Equity in earnings	—	563,049		—	563,049
Interest expense	576,239	240,543		—	816,782
Income before income taxes	2,778,921	290,095		67,359	3,136,375

	December 31, 2019
	Gas Utility	Investment in Affiliates	Parent and Other	Consolidated Total
Total assets	204,771,371	49,674,141	13,737,101	268,182,613
	September 30, 2019
	Gas Utility	Investment in Affiliates	Parent and Other	Consolidated Total
Total assets	195,969,019	47,429,368	14,955,309	258,353,696

14. Regulatory Assets and Liabilities

The Company’s regulated operations follow the accounting and reporting requirements of FASB ASC No. 980, Regulated Operations. The economic effects of regulation can result in a regulated company deferring costs that have been or are expected to be recovered from customers in a period different from the period in which the costs would be charged to expense by an unregulated enterprise. When this situation occurs, costs are deferred as assets in the consolidated balance sheet (regulatory assets) and recorded as expenses when such amounts are reflected in rates. Additionally, regulators can

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RGC RESOURCES, INC. AND SUBSIDIARIES

impose liabilities upon a regulated company for amounts previously collected from customers and for current collection in rates of costs that are expected to be incurred in the future (regulatory liabilities). In the event the provisions of FASB ASC No. 980 no longer apply to any or all regulatory assets or liabilities, the Company would write off such amounts and include them in the consolidated statements of income and comprehensive income in the period which FASB ASC No. 980 no longer applied.

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

	December 31, 2019		September 30, 2019
Assets:
Current Assets:
Regulatory assets:
WNA	$	736,156	$	569,558
ESAC assets	180,809		265,392
Accrued pension and postretirement medical	452,005		602,674
Other deferred expenses	84,315		84,315
Total current	1,453,285		1,521,939
Utility Property:
In service:
Other	11,945		11,945
Other Assets:
Regulatory assets:
Premium on early retirement of debt	1,684,261		1,712,808
Accrued pension and postretirement medical	9,414,695		9,414,695
ESAC assets	416,676		756,803
Other deferred expenses	291,721		294,547
Total non-current	11,807,353		12,178,853
Total regulatory assets	$	13,272,583	$	13,712,737

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

	December 31, 2019		September 30, 2019
Liabilities and Stockholders' Equity:
Current Liabilities:
Regulatory liabilities:
Over-recovery of gas costs	$	1,077,563	$	161,837
Over-recovery of SAVE Plan revenues	539,529		574,181
Rate refund	3,618,396		3,827,588
Excess deferred income taxes	205,353		205,353
Other deferred liabilities	128,891		108,644
Total current	5,569,732		4,877,603
Deferred Credits and Other Liabilities:
Asset retirement obligations	6,844,857		6,788,683
Regulatory cost of retirement obligations	12,098,472		11,892,352
Regulatory Liabilities:
Excess deferred income taxes	10,818,344		10,934,434
Total non-current	29,761,673		29,615,469
Total regulatory liabilities	$	35,331,405	$	34,493,072

As of December 31, 2019 and September 30, 2019, the Company had regulatory assets in the amount of $13,260,638 and $13,700,792, respectively, on which the Company did not earn a return during the recovery period.

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15. Subsequent Events

On January 24, 2020, the SCC issued their final order on the Company's non-gas rate increase. The Company has adjusted it's provision for rate refund based on the authorized rate increase of $7.25 million and reflected all adjustments directed in the order in the condensed consolidated financial statements for the quarter ended December 31, 2019. See Note 4 for additional information.

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

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

Forward-Looking Statements

This report contains forward-looking statements that relate to future transactions, events or expectations. In addition, Resources may publish forward-looking statements relating to such matters as anticipated financial performance, business prospects, technological developments, new products, research and development activities 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 2019 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.

The three-month earnings presented herein should not be considered as reflective of the Company’s consolidated financial results for the fiscal year ending September 30, 2020. The total revenues and margins realized during the first three 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 62,000 residential, commercial and industrial customers in Roanoke, Virginia and the surrounding localities through its Roanoke Gas subsidiary.

Resources also invests in the Mountain Valley Pipeline, an interstate pipeline currently under construction, as a more than 1% participant through its Midstream subsidiary in addition to providing certain unregulated services through its Roanoke Gas subsidiary. The unregulated operations of Roanoke Gas represent less than 2% of total revenues of Resources on an annual basis.

The Company’s utility operations are regulated by the SCC, which oversees the terms, conditions, and rates to be charged to customers for natural gas service, safety standards, extension of service, accounting and depreciation. The Company is also subject to federal regulation from the 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. The Company is also subject to other regulations which are not necessarily industry specific.

Over 98% of the Company’s annual revenues, excluding equity in earnings of MVP, are derived from the sale and delivery of natural gas to Roanoke Gas customers. The SCC authorizes the rates and fees the Company charges its customers for these services. These rates are designed to provide the Company with the opportunity to recover its gas and non-gas expenses and to earn a reasonable rate of return for shareholders based on normal weather.

On October 10, 2018, Roanoke Gas filed a general rate application requesting an annual increase in customer non-gas base rates. Roanoke Gas implemented the non-gas rates contained in its rate application for natural gas service rendered to customers on or after January 1, 2019. These non-gas rates are subject to refund pending audit, hearing and a final order issued by the SCC. Both the SCC staff and the hearing examiner on the case have completed their work and issued their reports in June and November, respectively. On January 24, 2020, the SCC issued the final order on the general rate application, granting Roanoke Gas an annualized increase in the non-gas base rates of $7.25 million. The order also directed the Company to write-down $317,191 of ESAC assets that were not subject to recovery under the final order. The Company has revised its rate refund accrual as of December 31, 2019 to reflect the rate award and ESAC write-down. The Company has designed non-gas

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rates to reflect the increased revenues and has submitted the new rates to the SCC for approval. Such rates may be adjusted by the SCC staff, which could result in minor changes to the rate refund reserve. The Company will continue to record a rate refund until such time as the final non-gas rates are approved and the refund to customers is completed.

In fiscal 2019, the Company completed the transition to the 21% federal statutory income tax rate as a result of the TCJA that was signed into law in December 2017. Between the enactment of the new tax rates and the Company's implementation of new non-gas rates effective January 1, 2019, the Company was recovering revenues based on a 34% federal income tax rate rather than a 21% federal tax rate. As a result, during this period, the Company recorded a provision for refund related to estimated excess revenues collected from customers for the difference in non-gas rates derived under the lower federal tax rate and the 34% rate in effect. For the three-month period ended December 31, 2018, the Company accrued a refund of approximately $524,000 related to these excess revenues for the effect of the different federal income tax rates on the non-gas billing rates. Beginning in January 2019, Roanoke Gas incorporated the effect of the 21% federal income tax rate with the implementation of new non-gas base rates, as filed in its general rate application, and began refunding the excess revenues associated with the change in the tax rate. The refund of the excess revenues related to the reduction in the federal income tax rate was completed in December 2019. The Company also recorded a regulatory liability related to the excess deferred income taxes on the regulated operations of Roanoke Gas. These excess deferred income taxes are being refunded to customers over a 28-year period. Additional information regarding the TCJA and non-gas base rate award is provided under the Regulatory and Tax Reform section below.

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 variations in weather and the cost of natural gas, the Company 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 increased infrastructure investment. These mechanisms include the SAVE Rider, WNA, ICC revenue and PGA.

The Company’s non-gas base rates provide for the recovery of non-gas related expenses and a reasonable return to shareholders. These rates are determined based on the filing of a formal non-gas rate application with the SCC utilizing historical and proforma information, including investment in natural gas facilities. Generally, investments related to extending service to new customers are recovered through the non-gas base rates currently in place, while the investment in replacing and upgrading existing infrastructure is not recoverable until a formal rate application is filed and approved. The SAVE Plan and Rider provides a mechanism through which the Company may recover on a prospective basis the related depreciation and expenses and provides a return on rate base for the related additional qualified capital investments until such time that a formal rate application is filed. As the Company has made significant SAVE qualified expenditures since the last non-gas base rate increase in 2013, SAVE Plan revenues have continued to increase each year. With the filing of the non-gas rate application, the SAVE Rider reset effective January 2019 as the prior revenues associated with the qualified SAVE Plan infrastructure investments were incorporated into the non-gas rates. Accordingly, SAVE Plan revenues declined by approximately $1,027,000 for the three-month period ended December 31, 2019 compared to the same period last year.

The WNA model reduces earnings volatility, related to weather variability in the heating season, by providing the Company a level of earnings protection when weather is warmer than normal and providing customers some price protection when the weather is colder than normal. The WNA is based on a weather measurement band around the most recent 30-year temperature average. Under the WNA, the Company recovers from its customers the lost margin (excluding gas costs) from the impact of weather that is warmer than normal or refunds the excess margin earned for weather that is colder than normal. The WNA mechanism used by the Company is based on a linear regression model that determines the value of a single heating degree day. For the three months ended December 31, 2019, the Company accrued approximately $167,000 in additional revenues under the WNA model for weather that was 4% warmer than normal compared to a reduction in revenue of approximately $157,000 for weather that was 3% colder than normal for the same period last year. The WNA year runs from April 1 to March 31 each year. Annually, following the end of the WNA year, customers are either billed for any margin shortfall or credited for any excess margin collected during the WNA year.

The Company also has an approved rate structure in place that mitigates the impact of financing costs associated with its natural gas inventory. Under this rate structure, Roanoke Gas recognizes revenue for the financing costs, or “carrying costs,” of its investment in natural gas inventory. This ICC factor applied to the cost of inventory is 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. During times of rising gas costs and rising inventory levels, the Company recognizes ICC revenues to offset higher financing costs associated with higher inventory balances. Conversely, during times of decreasing gas costs and lower inventory balances, the Company recognizes less carrying cost revenue as financing costs are lower. In addition, ICC revenues are impacted by the changes in the weighting of the components that are used to determine the weighted-average cost of capital. Total ICC revenues for the three months ended December 31, 2019 declined by approximately 14% from the same periods last year due to

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a combination of lower average price of gas in storage balances and a reduction in the ICC factor used in calculating these revenues.

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. The cost of natural gas is a pass-through cost and is independent of the non-gas base rates of the Company. This rate component, referred to as the PGA, allows the Company to pass along to its customers increases and decreases in natural gas costs incurred by its regulated operations. On a quarterly basis, or more frequently if necessary, the Company files a PGA rate adjustment request with the SCC to adjust the gas cost component of its tariff rates depending on projected price and activity. Once administrative approval is received, the Company adjusts the gas cost component of its rates to reflect the approved amount. As actual costs will differ from 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 those amounts are reflected in customer billings.

Cyber attacks are a constant threat to businesses and individuals. The Company remains focused on these threats and is committed to safeguarding its information technology systems. These systems contain confidential customer, vendor and employee information as well as important financial data. There is risk associated with unauthorized access of this information with a malicious intent to corrupt data, cause operational disruptions or compromise information. Management believes it has taken reasonable security measures to protect these systems from cyber attacks and similar incidents; however, there can be no guarantee that an incident will not occur. In the event of a cyber incident, the Company will execute its Security Incident Response Plan. The Company maintains cyber insurance to mitigate financial exposure that may result from a cyber incident.

Results of Operations

Three Months Ended December 31, 2019:

Net income increased by $1,572,774 for the three months ended December 31, 2019, compared to the same period last year. Quarterly performance improved significantly due to the impact of the rate increase and the earnings on the MVP investment, offsetting increases in operation and maintenance costs and interest expense.

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

	Three Months Ended December 31,
	2019		2018		Increase / (Decrease)			Percentage
Operating Revenues
Gas Utility	$	19,625,606	$	21,036,581	$	(1,410,975	)	(7	)%
Non utility	159,847		180,166		(20,319		)	(11	)%
Total Operating Revenues	$	19,785,453	$	21,216,747	$	(1,431,294	)	(7	)%
Delivered Volumes
Regulated Natural Gas (DTH)
Residential and Commercial	2,249,256		2,366,074		(116,818		)	(5	)%
Transportation and Interruptible	869,582		750,065		119,517			16	%
Total Delivered Volumes	3,118,838		3,116,139		2,699			—	%
Heating Degree Days (Unofficial)	1,440		1,560		(120		)	(8	)%

Total operating revenues for the three months ended December 31, 2019, compared to the same period last year, declined due to a 35% reduction in the commodity price of natural gas and reduced SAVE Plan revenue more than offsetting the net non-gas rate increase. The average commodity price of natural gas for the current quarter was $2.50 per decatherm compared to $3.85 per decatherm for the same period last year. Low natural gas prices are expected to continue due to abundant supplies, with futures prices for the remainder of the fiscal year averaging between $1.90 and $2.20 a decatherm. In addition, SAVE Plan revenues declined by $1,026,899 as the SAVE Rider reset January 1, 2019, and all qualifying SAVE Plan investments were included in rate base used to derive the new non-gas base rates. The prior year SAVE Plan revenues represented 5 years of SAVE investment while current year revenues represent only one year of qualifying investment. As noted above, the Company placed new non-gas base rates into effect for natural gas service rendered on or after January 1, 2019, subject to refund. The new rates incorporated revenues related to SAVE Plan activities through December 2018, as well as recovery of higher expenses and non-SAVE infrastructure additions since the last rate application. Total revenues have been adjusted by an estimate for refunds based on the SCC's final order. Net residential and commercial volume deliveries declined by 116,818

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decatherms on weather that was 8% warmer than normal. After adjusting for WNA, total residential and commercial volumes effectively increased by nearly 26,000 decatherms or more than 1%. In addition, the prior year included a reserve of $523,881 associated with the estimated excess revenues billed to customers as a result of the reduction in the corporate federal income tax rate. No such reserve was recorded during the current quarter due to the implementation of new non-gas base rates in January 2019. Non-utility revenue declined due to do lower demand for services during the quarter.

The Company's operations are affected by the cost of natural gas, as reflected in the condensed consolidated income statement under the line item cost of gas - utility. The cost of natural gas is passed through to customers at cost, 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. 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 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. Therefore, the following discussion of financial performance will reference gross utility margin as part of the analysis of the results of operations.

	Three Months Ended December 31,
	2019		2018		Increase / (Decrease)			Percentage
Gas Utility Margin
Utility Revenues	$	19,625,606	$	21,036,581	$	(1,410,975	)	(7	)%
Cost of Gas	8,177,806		11,906,459		(3,728,653		)	(31	)%
Gas Utility Margin	$	11,447,800	$	9,130,122	$	2,317,678		25	%

Gross utility margins increased from the same period last year primarily as a result of the implementation of higher non-gas base rates effective January 1, 2019. The non-gas base rate increase, net of estimated refund, accounted for more than $2,000,000 of the increase in margin through the customer base charge and the volumetric component in addition to customer growth. SAVE Plan revenues declined by $1,026,899 as all related SAVE investments were incorporated into the new non-gas base rates. WNA margin increased by nearly $324,000 as weather moved from colder than normal in the prior year to warmer than normal during the current quarter. Furthermore, the prior year included a reserve for excess revenues attributable to the reduction in income tax rates. The current year has no such adjustment as the new non-gas rates incorporate the effect of lower federal income tax rates.

When the Company filed its application for an increase in non-gas base rates, approximately 80% of the increase was reflected in the customer base charge to correspond with the fixed monthly billing under the SAVE Rider. The SCC staff report on the rate application recommended that only 20% of the non-gas base rate increase be allocated to customer base charge. The hearing examiner's report and subsequent final order supported this position. As a result, in June 2019, the Company revised its rate refund assumptions to reflect a rate design that would allocate 80% of the non-gas base rate increase to volumetric component and 20% to the customer base charge component. This revision results in an even greater level of earnings during the weather sensitive heating season due to the increased allocation to the weather sensitive component of non-gas rates and lower earnings in the non-heating season due to lower fixed rate revenues.

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

	Three Months Ended December 31,
	2019		2018			Increase / (Decrease)
Customer Base Charge	$	3,580,749	$	3,117,995		$	462,754
Carrying Cost	155,907		181,635			(25,728		)
SAVE Plan	180,613		1,207,512			(1,026,899		)
Volumetric	7,303,843		5,259,338			2,044,505
WNA	166,597		(157,334		)	323,931
Other Gas Revenues	60,091		44,857			15,234
Excess Revenue Refund	—		(523,881		)	523,881
Total	$	11,447,800	$	9,130,122		$	2,317,678

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Operation and maintenance expenses increased by $395,471, or 11%, from the same period last year related to the write-off of a portion of the ESAC regulatory assets, amortization of the remaining regulatory assets and higher corporate insurance costs, partially offset by higher capitalized overheads. Beginning in January 2019, concurrent with the implementation of new non-gas rates, the Company began amortizing certain regulatory assets for which recovery was included in the rate application. A total of $129,000 was charged to expense related to the amortization of these assets. In addition, the SCC issued their final order on the Company's non-gas rate increase, which directed the Company to write-down $317,000 of ESAC assets that were not subject to recovery in the final order. Corporate insurance expense increased by $71,000 due to higher premiums related to increased liability limits and higher deductible reserves. Capitalized overheads increased by $85,000 primarily due to timing of LNG production related to facility upgrades at the plant during the summer. The remaining difference relates to a variety of small increases and decreases in expenses.

The Company has plans to invest in several one-time maintenance projects during the balance of the current fiscal year, which may result in a significant increase in operation and maintenance expenses when compared to fiscal 2019.

General taxes increased by $35,348, or 7%, associated with higher property and payroll taxes. Property taxes continue to increase corresponding to higher utility property balances related to ongoing infrastructure replacement, system reinforcements and customer growth.

Depreciation expense increased by $83,030, or 4%, on an increase in utility plant investment.

Equity in earnings of unconsolidated affiliate increased by $531,037, or nearly double last year, due to AFUDC related to the increased construction activity and related investment in the MVP.

Other income (expense), net increased by $31,757 primarily due to the non-service components of net periodic benefit costs per the requirements of ASC 715 as amended by ASU 2017-07, Compensation - Retirement Benefits, which requires that components of net periodic benefit costs other than service cost be presented outside of income from operations. Lower interest costs and higher return on plan assets offset increased amortization of the actuarial loss. See Note 11 - Employee Benefit Plans for a breakdown of the components of net periodic benefit costs.

Interest expense increased by $268,403, or 33%, due to a 34% increase in total average debt outstanding between quarters. The higher borrowing levels derived from the ongoing investment in MVP and financing expenditures in support of Roanoke Gas' capital budget, partially offset by a slight reduction in the weighted average interest rate.

Roanoke Gas interest expense increased by $142,614 as total average debt outstanding increased by $9,500,000 associated with the issuance of two separate debt issuances offset by reductions in the line-of-credit balances. The average interest rate increased from 3.69% to 3.72% between periods.

Midstream interest expense increased by $125,789 as total average debt outstanding increased by $18,400,000 associated with cash investment in the MVP. The average interest rate decreased from 3.61% to 3.17% due to the decline in the variable interest rate on Midstream's credit facility and the entry into two separate notes with swap rates at 3.24% and 3.14%.

Income tax expense increased by $539,374 corresponding to an increase in taxable income. The effective tax rate was 23.7% and 22.4% for the three month periods ended December 31, 2019 and 2018, respectively. Both periods included the amortization of excess deferred taxes.

Critical Accounting Policies and Estimates

The consolidated financial statements of Resources are prepared in accordance with accounting principles generally accepted in the United States of America. 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.

The Company considers an estimate to be critical if it is material to the financial statements and requires assumptions to be made that were uncertain at the time the estimate was derived and changes in the estimate are reasonably likely to occur from period to period. The Company had recorded an estimate for customer refunds related to the implementation of the new non-gas base rates effective January 1, 2019. In January 2020, the Company received the final order on the non-gas base rate application that defined the approved annual rate increase. Management developed revised non-gas rates based on the amount of the increase specified in the order; however, the actual rates approved could vary and result in minor adjustments to the reserve.

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The Company adopted 2016-02, Leases,, and subsequent guidance and amendments effective October 1, 2019. The adoption of the ASU did not have a significant effect on the Company's results of operations, financial position or cash flows as the Company has only one lease, and management determined that the $25,000 value of the lease obligation to not be at a level material enough to warrant the the application of the guidance under the ASU. The Company does have easements for rights-of-way for its distribution system; however, all related costs associated with these have been paid in advance with no remaining obligation.

There have been no other changes to the critical accounting policies as reflected in the Company’s Annual Report on Form 10-K for the year ended September 30, 2019.

Asset Management

Roanoke Gas uses a third-party asset manager to manage 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.

Equity Investment in Mountain Valley Pipeline

On October 1, 2015, Midstream entered into an agreement to become a 1% member in the LLC. The purpose of the LLC is to construct and operate the MVP, a FERC-regulated natural gas pipeline connecting Equitran's gathering and transmission system in northern West Virginia to the Transco interstate pipeline in south central Virginia.

On November 19, 2019, the Company's Board of Directors approved a pro-rata increase in its participation in MVP, which will result in an estimated additional investment of $1.6 million above the current $53 to $55 million estimate. As a result of this increased participation, Midstream's equity interest will increase from 1.00% to approximately 1.03% by the time the pipeline is placed in service.

Management believes the investment in the LLC will be beneficial for the Company, its shareholders and southwest Virginia. In addition to Midstream's potential returns from its investment in the LLC, Roanoke Gas will benefit from an additional delivery source of natural gas into its distribution system. Currently, Roanoke Gas is served by two pipelines and an LNG peak-shaving facility. Damage to or interruption in supply from any of these sources, especially during the winter heating season, could have a significant impact on the Company's ability to serve its customers. A third pipeline would reduce the impact from such an event. In addition, the proposed pipeline path would provide the Company with a more economically feasible opportunity to provide natural gas service to currently unserved areas within the its certificated service territory.

The MVP project is currently 90% complete. Activity on the MVP is limited this time of year to maintaining the infrastructure currently in place and restoration activities. The LLC is waiting on the reissuance of water crossing permits that were rescinded by the Fourth Circuit as well as the permit to cross a section of the Jefferson National Forest. The LLC believes it has submitted all of the required documentation and information required to resolve the issues addressed by the Fourth Circuit. Currently, no action has been taken by the governmental agencies regarding the status, including the need for additional information, re-approval of the permits or rejection of the submissions. Until such time as approval is granted, activity on the pipeline will be limited as most of the pipeline work not encompassed in the revoked permits has been completed.

Assuming timely resolution of the permit issues above, the LLC projects an in-service date for the MVP in late calendar year 2020. The delays in completing the project combined with the increased costs will reduce the corresponding return on investment, absent a regulatory action that could provide for the recovery of these higher costs.

Midstream entered into the Third Amendment to Credit Agreement and amended the corresponding associated notes to increase the borrowing capacity under the credit facility from $26 million to $41 million and extend the maturity date to December 29, 2022. Under the amended agreement and notes, Midstream should have the needed financing to meet its funding requirements in the MVP. If the rescinded permits are not re-issued and approved in a reasonable time period, both the cost of the MVP and Midstream's capital contributions will increase above current estimates and the in-service date will be extended beyond 2020.

The current earnings from the MVP investment are attributable to AFUDC income generated by the deployment of capital in the design, engineering, materials procurement, project management and construction of the pipeline. AFUDC is an accounting method whereby the costs of debt and equity funds used to finance facility infrastructure are credited to income and charged to the cost of the project. The level of investment in MVP, as well as the AFUDC, will continue to grow as construction activities continue. When the pipeline is completed and placed into service, AFUDC will cease. Once operational, earnings will be

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derived from capacity charges for utilizing the pipeline. Continued delays in the project could ultimately result in future earnings from the operation of the pipeline to be below the level of AFUDC recognized.

In 2018, Midstream became a participant in Southgate, a project to construct a 74-mile pipeline extending from the MVP mainline at the Transco interconnect in Virginia to delivery points in North Carolina. Midstream is a less than 1% investor in the Southgate project and, based on current project cost estimates, will invest approximately $2.5 million in the project. Midstream's participation in the Southgate project is for investment purposes only. The Southgate in-service date is currently targeted for 2021.

Regulatory and Tax Reform

On October 10, 2018, Roanoke Gas filed a general rate case application requesting an annual increase in customer non-gas base rates of approximately $10.5 million. This application incorporated into the non-gas base rates the impact of tax reform, non-SAVE utility plant investment, increased operating costs, recovery of regulatory assets, including all deferred ESAC related costs, and SAVE Plan investments and related costs previously recovered through the SAVE Rider. Approximately $4.7 million of the rate increase was attributable to moving the SAVE Plan related revenues into non-gas base rates. The new non-gas base rates were placed into effect for gas service rendered on or after January 1, 2019, subject to refund, pending audit by SCC staff, hearing and final order by the SCC.

On June 28, 2019, the SCC staff issued their report and recommendations related to the rate application. The SCC staff report included a recommendation for a non-gas rate increase of approximately $6.5 million. Management reviewed and responded to the SCC staff report through submission of rebuttal testimony to certain proposed adjustments included in the report. At the hearing held on August 14 and 15, the Company addressed specific differences with SCC staff, including the proposed return on equity, the exclusion of certain infrastructure items from rate base, changes in customer class rate design and the exclusion of a portion of the regulatory assets associated with ESAC costs. On November 19, 2019, the hearing examiner issued his report, which was subsequently revised on November 26, 2019. The revised report recommended an annual increase in non-gas base rates of more than $7.1 million in addition to allocating 80% of the increase to the volumetric component of rates with only about 20% associated with customer base charges. On January 24, 2020, the SCC issued their final order providing for an annual increase in non-gas base rates of $7.25 million, while maintaining the allocation of 80% of the increase to the volumetric component of rates. The non-gas rate award provided for a 9.44% return on equity, but excluded from recovery at the current time, a return on the investment of two interconnect stations with the MVP. In addition, the final order directed the Company to write-off a portion of the ESAC assets that were excluded from recovery under the rate award. As a result, the Company expensed an additional $317,000 of ESAC assets above the normal amortization amount. Management has proposed a rate design to reflect the increase of $7.25 million in non-gas rates and has submitted these rates to the SCC for approval. The SCC may approve the rates as submitted or require changes to the rates, which could result in minor adjustments to the refund. Once the final rates have been approved, the Company will proceed with completing the refunds to its customers. Management has provided for a cumulative refund in the amount of $3,618,000 consistent with the SCC order based on the non-gas rates that are currently pending approval. The refund accrual will cease once the approved rates are placed into effect.

The general rate case application incorporated the effects of tax reform, which reduced the federal tax rate for the Company from 34% to 21%. Roanoke Gas recorded two regulatory liabilities to account for this change in the federal tax rate. The first regulatory liability related to the excess deferred taxes associated with the regulated operations of Roanoke Gas. As Roanoke Gas had a net deferred tax liability, the reduction in the federal tax rate required the revaluation of these excess deferred income taxes to the 21% rate at which the deferred taxes are expected to reverse. The excess net deferred tax liability for Roanoke Gas' regulated operations was transferred to a regulatory liability, while the revaluation of excess deferred taxes on the unregulated operations of the Company were flowed into income tax expense in the first quarter of fiscal 2018. A majority of the regulatory liability for excess deferred taxes was attributable to accelerated tax depreciation related to utility property. In order to comply with the IRS normalization rules, these excess deferred income taxes must be flowed back to customers and through tax expense based on the average remaining life of the corresponding assets, which approximates 28 years. The corresponding balances related to the excess deferred taxes are included in the regulatory liability schedule in Note 14.

The second regulatory liability relates to the excess revenues collected from customers. The non-gas base rates used since the passage of the TCJA in December 2017 through December 2018 were derived from a 34% federal tax rate. As a result, the Company over-recovered from its customers the difference between the federal tax rate at 34% and the 24.3% blended rate in fiscal 2018 and 21% in fiscal 2019. To comply with an SCC directive issued in January 2018, Roanoke Gas recorded a refund for the excess revenues collected in fiscal 2018 and the first quarter of fiscal 2019. Starting with the implementation of the new non-gas base rates in January 2019, Roanoke Gas began returning the excess revenues to customers over a 12-month period. The refund of the excess revenues was completed in December 2019.

28

RGC RESOURCES, INC. AND SUBSIDIARIES

The Company continues to recover the costs of its infrastructure replacement program through its SAVE Plan. The original SAVE Plan was designed to facilitate the accelerated replacement of aging natural gas pipe by providing a mechanism for the Company to recover the related depreciation and expenses and return on rate base of the additional capital investment without the filing of a non-gas base rate application. Since the implementation and approval of the original SAVE Plan in 2012, the Company has modified, amended or updated it each year to incorporate various qualifying projects. In May 2019, the Company filed its most recent SAVE Plan and Rider, which continues the focus on the ongoing replacement of pre-1973 plastic pipe and the replacement of a natural gas transfer station. In September 2019, the SCC approved the updated SAVE Plan and Rider effective with the October 2019 billing cycle. The new SAVE Rider is designed to collect approximately $1.1 million in annual revenues, an increase from the approximate $500,000 in annual revenues under the prior SAVE rates. With the inclusion of all previous SAVE investment through December 31, 2018 into the rate application, the current SAVE Plan Rider reflects only the recovery of qualifying SAVE Plan investments made since the beginning of January 2019. In addition, the SAVE application includes a refund factor to return approximately $543,000 in SAVE revenue over-collections from 2018, primarily resulting from the effect of the reduction in the federal income tax rate.

Capital Resources and Liquidity

Due to the capital intensive nature of the utility business, as well as the related weather sensitivity, the Company’s primary capital needs are the funding of its utility plant capital projects, investment in the MVP, the seasonal funding of its natural gas inventories and accounts receivable and the payment of dividends. To meet these needs, the Company relies on its operating cash flows, line-of-credit agreement, long-term debt and equity capital.

Cash and cash equivalents decreased by $619,001 for the three-month period ended December 31, 2019, compared to a $236,602 decrease for the same period last year. The following table summarizes the sources and uses of cash:

	Three Months Ended December 31,
	2019			2018
Cash Flow Summary
Net cash provided by (used in) operating activities	$	817,963		$	(2,300,174	)
Net cash used in investing activities	(10,875,736		)	(15,833,528		)
Net cash provided by financing activities	9,438,772			17,897,100
Decrease in cash and cash equivalents	$	(619,001	)	$	(236,602	)

The seasonal nature of the natural gas business causes operating cash flows to fluctuate significantly during the year as well as from year to year. Factors, including weather, energy prices, natural gas storage levels and customer collections, contribute to working capital levels and the related cash flows. Generally, operating cash flows are positive during the second and third 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 quarters, operating cash flows generally decrease due to increases in natural gas storage levels, rising customer receivable balances and construction activity.

Cash flow provided by operations is primarily driven by net income, depreciation, reductions in natural gas storage inventory and increases in accounts receivable during the first three months of the fiscal year. Cash flow from operating activities increased by $3,118,137 over the same period last year primarily related to higher net income, net of equity in earnings, and the effect of lower natural gas prices on accounts receivable, gas in storage and accounts payable. Net income, excluding the non cash component of equity in earnings, contributed more than $1.0 million to the increase in cash provided by operations primarily as a result of the implementation of the non-gas base rate increase. However, significantly lower natural gas commodity prices have resulted in a reduced customer volumetric billing rate and lower total customer billings during the period more than offsetting the impact of the non-gas base rate increase. These lower commodity prices have resulted in smaller increases in both accounts receivable and accounts payable and their corresponding effect on operating cash. The decline in gas in storage was less during the current fiscal quarter compared to the same period last year due to a combination of lower average cost of gas in storage and less natural gas withdrawn from storage. A summary of the cash provided by operations is provided below:

29

RGC RESOURCES, INC. AND SUBSIDIARIES

	Three Months Ended December 31,
Cash Flow From Operating Activities:	2019			2018			Increase / (Decrease)
Net income	$	4,006,936		$	2,434,162		$	1,572,774
Depreciation	2,047,695			1,940,472			107,223
Equity in earnings	(1,094,086		)	(563,049		)	(531,037		)
Increase in accounts receivable	(6,356,346		)	(7,930,322		)	1,573,976
Decrease in gas in storage	432,679			1,465,609			(1,032,930		)
Increase in accounts payable	1,080,138			1,698,852			(618,714		)
Increase in regulatory liability and deferred taxes	904,628			601,435			303,193
Other	(203,681		)	(1,947,333		)	1,743,652
Net Cash Provided by Operations	$	817,963		$	(2,300,174	)	$	3,118,137

Investing activities are generally composed of expenditures related to investment in the Company's utility plant projects, which includes replacing aging natural gas pipe with new plastic or coated steel pipe, improvements to the LNG peak shaving plant and distribution system facilities, expanding the natural gas system to meet the demands of customer growth, as well as the continued investment in the MVP. The Company is continuing 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 the existing service territory. In addition, the Company is constructing two interconnect stations to access the MVP, which will provide additional gas supply to the Company's distribution system as well as provide access to currently unserved areas in Franklin County. Total capital expenditures for the first three months were $5.8 million, or about $160,000 more than the same period last year. Capital expenditures for fiscal 2020 are expected to be near last year's level of $21.9 million.

Investing cash flows also include the Company's continued funding of its participation in the MVP, with a total cash investment of just over $5 million for the three months ended December 31, 2019 compared to $10.1 million for the corresponding period last year. Total cash investment is expected to be in excess of $55 million for both the MVP and Southgate projects by the time they are placed into service.

Financing activities generally consist of long-term notes payable and line-of-credit borrowings and repayments, issuance of stock and the payment of dividends. Net cash flows provided by financing activities were $9.4 million for the current period compared to $17.9 million for the same period last year. The decrease in financing cash flows is primarily attributable to a reduced level of capital contributions by Midstream for the MVP investment and reduced working capital needs associated with lower natural gas commodity prices. Midstream borrowed $5.7 million during the current quarter to finance its investment in MVP compared to $10.3 million for the same period last year. Roanoke Gas also issued $10 million in fixed rate notes, which combined with improved operating cash flows provided funding for its capital expenditures and allowed for a reduction in Roanoke's line-of-credit balance. During the same period last year, Roanoke Gas financed its capital expenditures through borrowings under its line-of-credit.

On December 23, 2019, Midstream negotiated with the financial institutions that provided the credit facility used to finance its investment in the MVP. The result of these negotiations was an amendment to the credit agreement and corresponding notes. The amended agreement increased the total borrowing capacity under the credit facility to $41,000,000 from its previous limit of $26,000,000 and extending the maturity date to December 29, 2022. The increased limits will allow Midstream to continue funding its investment in MVP as a result of the higher projected cost and continues current financing of the project until the pipeline is placed in service. The amendment retained all of the other provisions contained in the previous credit agreements and amendments including the interest rate on the Notes based on 30-day LIBOR plus 1.35%.

On December 6, 2019, Roanoke Gas entered into unsecured notes in the aggregate principal amount of $10,000,000. These notes have a 10-year term with a fixed interest rate of 3.60%. Proceeds from these notes will be used to provide longer-term financing of Roanoke Gas' capital budget.

As of December 31, 2019, Resources' long-term capitalization ratio was 43% equity and 57% debt.

30

RGC RESOURCES, INC. AND SUBSIDIARIES

ITEM 3 – QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

The Company is exposed to market risks associated with interest rates and commodity prices. Interest rate risk is related to the Company’s outstanding variable rate debt including Roanoke Gas' line-of-credit and the Midstream credit facility. Commodity price risk is experienced by the Company’s regulated natural gas operations. The Company’s risk management policy, as authorized by the Company’s Board of Directors, allows management to enter into derivatives for the purpose of managing commodity and financial market risks of its business operations.

Interest Rate Risk

The Company is exposed to market risk related to changes in interest rates associated with its borrowing activities. At December 31, 2019, the Company had $2,925,766 outstanding under its variable rate line-of-credit with an average balance outstanding during the three-month period of $7,912,028. The Company also had $21,704,200 outstanding under Midstream's variable-rate term credit facility. A hypothetical 100 basis point increase in market interest rates applicable to the Company’s variable-rate debt outstanding during the three months ended December31, 2019 would have resulted in an increase of approximately $70,000 in interest expense for the period. The Company's other long-term debt is at fixed rates or is hedged with interest rate swaps.

Commodity Price Risk

The Company manages the price risk associated with purchases of natural gas by using a combination of LNG storage, underground storage gas, fixed price contracts, spot market purchases and derivative commodity instruments including futures, price caps, swaps and collars.

At December 31, 2019, the Company had no outstanding derivative instruments to hedge the price of natural gas. The Company had 2,223,303 decatherms of gas in storage, including LNG, at an average price of $2.71 per decatherm, compared to 1,956,955 decatherms at an average price of $3.15 per decatherm last year. The SCC currently allows for full recovery of prudent costs associated with natural gas purchases, as any additional costs or benefits associated with the settlement of derivative contracts and other price hedging techniques are passed through to customers when realized through the PGA mechanism.

31

RGC RESOURCES, INC. AND SUBSIDIARIES

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 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.

As of December 31, 2019, the Company completed an evaluation, under the supervision and with the participation of management, including the chief executive officer and the chief financial officer, of 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 December 31, 2019.

Management routinely reviews the Company’s internal control over financial reporting and makes changes, as necessary, to enhance the effectiveness of the internal controls over financial reporting. There were no changes in the internal controls over financial reporting during the fiscal quarter ended December 31, 2019, that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

32

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 from the risk factors previously disclosed in Resources' Annual Report on Form 10-K for the year ended September 30, 2019.

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

None.

ITEM 3 – DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4 – MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5 – OTHER INFORMATION

None.

ITEM 6 – EXHIBITS

Number	Description
10.1	Unsecured Note in the original principal amount of $5,000,000 by and between Roanoke Gas and Prudential Arizona Reinsurance Universal Company, dated December 6, 2019 (incorporated by reference to Exhibit 10.1 to the Registrant's Current Report on Form 8-K filed on December 9, 2019)
10.2	Unsecured Note in the original principal amount of $5,000,000 by and between Roanoke Gas and Prudential Arizona Reinsurance Universal Company, dated December 6, 2019 (incorporated by reference to Exhibit 10.2 to the Registrant's Current Report on Form 8-K filed on December 9, 2019)
10.3	Unconditional Guaranty Agreement by and between RGC Resources, Inc. and Prudential Investment Management and each Prudential Affiliate which is a party to the borrowings (incorporated by reference to Exhibit 10.3 to the Registrant's Current Report on Form 8-K filed on December 9, 2019)
10.4	Second Amendment to Private Shelf Agreement dated as of December 6, 2019 (incorporated by reference to Exhibit 10.4 to the Registrant's Current Report on Form 8-K filed on December 9, 2019)
10.5	Third Amendment to Credit Agreement between RGC Midstream, LLC and the lenders Atlantic Union Bank and Truist Bank dated December 23, 2019 (incorporated by reference to Exhibit 10.1 to the Registrant's Current Report on Form 8-K filed on December 23, 2019)
10.6	Amended and Restated Note in the principal amount of $24,600,000 in favor of Atlantic Union Bank due December 29, 2022 (incorporated by reference to Exhibit 10.2 to the Registrant's Current Report on Form 8-K filed on December 23, 2019)
10.7	Amended and Restated Note in the principal amount of $16,400,000 in favor of Truist Bank due December 29, 2022 (incorporated by reference to Exhibit 10.3 to the Registrant's Current Report on Form 8-K filed on December 23, 2019)
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	The following materials from the Registrant’s Quarterly Report on Form 10-Q for the quarter ended December 31, 2019, formatted in XBRL (eXtensible Business Reporting Language): (i) Condensed Consolidated Balance Sheets at December 31, 2019 and September 30, 2019, (ii) Condensed Consolidated Statements of Income for the three months ended December 31, 2019 and 2018; (iii) Condensed Consolidated Statements of Comprehensive Income for the three months ended December 31, 2019 and 2018; (iv) Condensed Consolidated Statements of Changes in Stockholders' Equity for the three months ended December 31, 2019 and 2018; (v) Condensed Consolidated Statements of Cash Flows for the three months ended December 31, 2019 and 2018, and (vi) Condensed Notes to Condensed Consolidated Financial Statements.

* 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.

33

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 there unto duly authorized.

		RGC Resources, Inc.
Date: February 5, 2020	By:	/s/ Paul W. Nester
		Paul W. Nester
		Vice President, Secretary, Treasurer and CFO

34

EX-31.1

RGC RESOURCES, INC. AND SUBSIDIARIES

EXHIBIT 31.1

CERTIFICATION

I, John S. D'Orazio, certify that:

1. I have reviewed this quarterly report on Form 10-Q of RGC Resources, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: February 5, 2020	/s/ John S. D'Orazio
	President and Chief Executive Officer
	(Principal Executive Officer)

EX-31.2

RGC RESOURCES, INC. AND SUBSIDIARIES

EXHIBIT 31.2

CERTIFICATION

I, Paul W. Nester, certify that:

1. I have reviewed this quarterly report on Form 10-Q of RGC Resources, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: February 5, 2020	/s/ Paul W. Nester
	Vice President, Secretary, Treasurer and Chief Financial Officer
	(Principal Financial Officer)

EX-32.1

RGC RESOURCES, INC. AND SUBSIDIARIES

Exhibit 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of RGC Resources, Inc. (the “Company”) on Form 10-Q for the period ended December 31, 2019 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, John S. D'Orazio, President and Chief Executive Officer of the Company, certify to my knowledge, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Company.

/s/ John S. D'Orazio

John S. D'Orazio

President and Chief Executive Officer

(Principal Executive Officer)

Date: February 5, 2020

EX-32.2

RGC RESOURCES, INC. AND SUBSIDIARIES

Exhibit 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of RGC Resources, Inc. (the “Company”) on Form 10-Q for the period ended December 31, 2019 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Paul W. Nester, Vice President, Secretary, Treasurer and Chief Financial Officer of the Company, certify to my knowledge, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Company.

/s/ Paul W. Nester

Paul W. Nester

Vice President, Secretary, Treasurer and Chief Financial Officer

(Principal Financial Officer)

Date: February 5, 2020

XML

Commitments and Contingencies (Details)	3 Months Ended
	Dec. 31, 2019 pipeline
Commitments and Contingencies Disclosure [Abstract]
Number of pipelines serving Roanoke Gas	2

XML

Other Investments (Narrative) (Details) - RGC Midstream LLC [Member] Bcf in Millions, $ in Millions	1 Months Ended
	Apr. 30, 2018 USD ($) mi	Dec. 31, 2019 USD ($) debt_instrument	Jun. 12, 2019 instrument_held	Oct. 31, 2015 Bcf
Investment [Line Items]
Number of unsecured Promissory Notes funding the investment		2	2
MVP [Member]
Investment [Line Items]
Equity interest percentage				1.00%
Pipeline capacity per day (in bcf) | Bcf				2
MVP [Member] | Minimum [Member]
Investment [Line Items]
Total project cost		$ 5,300.0
Total estimated investment		53.0
MVP [Member] | Maximum [Member]
Investment [Line Items]
Total project cost		5,500.0
Total estimated investment		$ 55.0
Southgate [Member]
Investment [Line Items]
Length of planned natural gas pipeline (in miles) | mi	74
Estimated total MVP Southgate pipeline cost projection	$ 500.0
Estimated investment in MVP Southgate	$ 2.5
Southgate [Member] | Southgate [Member]
Investment [Line Items]
Ownership percentage (less than)	1.00%

XML

Long-Term Debt (Narrative) (Details)			3 Months Ended
	Dec. 23, 2019 USD ($)	Dec. 06, 2019 USD ($)	Dec. 31, 2019 USD ($) debt_instrument	Sep. 30, 2019 USD ($)	Jun. 13, 2019 USD ($)	Jun. 12, 2019 USD ($) instrument_held
Debt Instrument [Line Items]
Maximum percentage of Consolidated Long Term Indebtedness to Consolidated Total Capitalization			65.00%
Roanoke Gas [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 3.60%, due December 6, 2029 [Member]
Debt Instrument [Line Items]
Debt instrument, borrowing amount		$ 10,000,000
Debt term		10 years
Stated percentage rate		3.60%	3.60%
Maximum percentage of Priority Indebtedness to Consolidated Total Assets			15.00%
Roanoke Gas [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 4.41%, due March 28, 2031 [Member]
Debt Instrument [Line Items]
Stated percentage rate			4.41%
Roanoke Gas [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 0.90%, due November 1, 2021 [Member]
Debt Instrument [Line Items]
Debt instrument, borrowing amount			$ 7,000,000
Effective interest rate			2.30%
Maximum percentage of Priority Indebtedness to Consolidated Total Assets			15.00%
Roanoke Gas [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 0.90%, due November 1, 2021 [Member] | 30-day LIBOR [Member]
Debt Instrument [Line Items]
Variable rate basis points (as a percent)			0.90%
Roanoke Gas [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 3.58%, due October 2, 2027 [Member]
Debt Instrument [Line Items]
Stated percentage rate			3.58%
Roanoke Gas [Member] | Line of Credit [Member] | Line of Credit, at 30-day LIBOR plus 1.00%, due March 31, 2021 [Member] | 30-day LIBOR [Member]
Debt Instrument [Line Items]
Variable rate basis points (as a percent)			1.00%
RGC Midstream LLC [Member]
Debt Instrument [Line Items]
Debt instrument, number of instruments			2			2
RGC Midstream LLC [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 1.35%, due December 29, 2022 [Member]
Debt Instrument [Line Items]
Debt instrument, borrowing amount	$ 41,000,000			$ 26,000,000
Maximum percentage of Priority Indebtedness to Consolidated Total Assets			15.00%
RGC Midstream LLC [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 1.35%, due December 29, 2022 [Member] | 30-day LIBOR [Member]
Debt Instrument [Line Items]
Variable rate basis points (as a percent)	1.35%		1.35%
RGC Midstream LLC [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 1.15%, due June 12, 2026 [Member]
Debt Instrument [Line Items]
Debt instrument, borrowing amount			$ 14,000,000			$ 14,000,000
Effective interest rate			3.24%			3.24%
Maximum percentage of Priority Indebtedness to Consolidated Total Assets			15.00%
RGC Midstream LLC [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 1.15%, due June 12, 2026 [Member] | 30-day LIBOR [Member]
Debt Instrument [Line Items]
Variable rate basis points (as a percent)			1.15%
RGC Midstream LLC [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 1.20%, due June 1, 2024 [Member]
Debt Instrument [Line Items]
Debt instrument, borrowing amount			$ 10,000,000		$ 10,000,000
Effective interest rate			3.14%		3.14%
Maximum percentage of Priority Indebtedness to Consolidated Total Assets			15.00%
RGC Midstream LLC [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 1.20%, due June 1, 2024 [Member] | 30-day LIBOR [Member]
Debt Instrument [Line Items]
Variable rate basis points (as a percent)			1.20%

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Revenue (Tables)

3 Months Ended

Dec. 31, 2019

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

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

	Three months ended December 31, 2019						Three months ended December 31, 2018
	Gas utility		Non utility		Total operating revenues		Gas utility			Non utility		Total operating revenues
Natural Gas (Billed and Unbilled):
Residential	$	12,290,361	$	—	$	12,290,361	$	13,012,592		$	—	$	13,012,592
Commercial	5,729,218		—		5,729,218		7,342,702			—		7,342,702
Industrial and Transportation	1,326,085		—		1,326,085		1,226,137			—		1,226,137
Revenue reductions (TCJA) (1)	—		—		—		(523,881		)	—		(523,881		)
Other	215,998		159,847		375,845		226,492			180,166		406,658
Total contracts with customers	19,561,662		159,847		19,721,509		21,284,042			180,166		21,464,208
Alternative Revenue Programs	63,944		—		63,944		(247,461		)	—		(247,461		)
Total operating revenues	$	19,625,606	$	159,847	$	19,785,453	$	21,036,581		$	180,166	$	21,216,747
(1) Accrued refund associated with excess revenue collected in tariff rates associated with the reduction in federal income tax rates. See Note 4 for more information.

Schedule of Customer Accounts Receivable

The balances of customer receivables are provided below:

	Current Assets				Current Liabilities
	Trade accounts receivable (1)		Unbilled revenue (1)		Customer credit balances			Customer deposits
Balance at September 30, 2019	$	2,590,702	$	1,236,384	$	880,295		$	1,432,031
Balance at December 31, 2019	6,278,383		3,690,130		821,643			1,549,435
Increase (decrease)	$	3,687,681	$	2,453,746	$	(58,652	)	$	117,404
(1) Included in accounts receivable in the condensed consolidated balance sheet. Amounts shown net of reserve for bad debts.

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Segment Information

3 Months Ended

Dec. 31, 2019

Segment Reporting [Abstract]

Segment Information

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.

The reportable segments disclosed herein are defined as follows:

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

Investment in Affiliates - The investment in affiliates segment reflects the income generated through the activities of the Company's investment in the MVP and Southgate projects.

Parent and Other - Parent and other include the unregulated activities of the Company as well as certain corporate eliminations.

Information related to the segments of the Company are provided below:

	Three Months Ended December 31, 2019
	Gas Utility	Investment in Affiliates		Parent and Other	Consolidated Total
Operating revenues	19,625,606	—		159,847	19,785,453
Depreciation	1,988,505	—		—	1,988,505
Operating income (loss)	5,041,485	(38,591	)	79,085	5,081,979
Equity in earnings	—	1,094,086		—	1,094,086
Interest expense	718,853	366,332		—	1,085,185
Income before income taxes	4,478,882	690,354		79,287	5,248,523

	Three Months Ended December 31, 2018
	Gas Utility	Investment in Affiliates		Parent and Other	Consolidated Total
Operating revenues	21,036,581	—		180,166	21,216,747
Depreciation	1,905,475	—		—	1,905,475
Operating income (loss)	3,230,825	(33,887	)	67,284	3,264,222
Equity in earnings	—	563,049		—	563,049
Interest expense	576,239	240,543		—	816,782
Income before income taxes	2,778,921	290,095		67,359	3,136,375

	December 31, 2019
	Gas Utility	Investment in Affiliates	Parent and Other	Consolidated Total
Total assets	204,771,371	49,674,141	13,737,101	268,182,613
	September 30, 2019
	Gas Utility	Investment in Affiliates	Parent and Other	Consolidated Total
Total assets	195,969,019	47,429,368	14,955,309	258,353,696

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Other Comprehensive Income (Tables)

3 Months Ended

Dec. 31, 2019

Equity [Abstract]

Summary of Other Comprehensive Income and Loss

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

	Before-Tax Amount			Tax (Expense) or Benefit			Net-of-Tax Amount
Three Months Ended December 31, 2019
Interest rate swaps:
Unrealized gains	$	350,693		$	(90,269	)	$	260,424
Transfer of realized losses to interest expense	3,540			(911		)	2,629
Net interest rate swap	354,233			(91,180		)	263,053
Defined benefit plans:
Amortization of actuarial losses	22,610			(5,819		)	16,791
Other comprehensive income	$	376,843		$	(96,999	)	$	279,844
Three Months Ended December 31, 2018
Interest rate swap:
Unrealized losses	$	(93,956	)	$	24,184		$	(69,772	)
Transfer of realized gains to interest expense	(15,662		)	4,031			(11,631		)
Net interest rate swap	(109,618		)	28,215			(81,403		)
Defined benefit plans:
Amortization of actuarial gains	(2,576		)	663			(1,913		)
Other comprehensive loss	$	(112,194	)	$	28,878		$	(83,316	)

Reconciliation of Other Accumulated Other Comprehensive Income (Loss)

Reconciliation of Other Accumulated Comprehensive Income (Loss)

	Accumulated Other Comprehensive Income (Loss)
Balance at September 30, 2019	$	(2,488,917	)
Other comprehensive income	279,844
Balance at December 31, 2019	$	(2,209,073	)

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Income Taxes (Reconciliation of Income Tax Expense Based on Federal Statutory Rate) (Details) - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Income before income taxes	$ 5,248,523	$ 3,136,375
Corporate federal tax rate	21.00%	21.00%
Income tax expense computed at the federal statutory rate	$ 1,102,190	$ 658,639
State income taxes, net of federal tax benefit	250,037	150,589
Net amortization of excess deferred taxes on regulated operations	(86,208)	(86,208)
Other, net	(24,432)	(20,807)
Total income tax expense	$ 1,241,587	$ 702,213
Effective tax rate	23.70%	22.40%

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Earnings Per Share (Tables)

3 Months Ended

Dec. 31, 2019

Earnings Per Share [Abstract]

Schedule of Basic and Diluted Earnings Per Share Reconciliation

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

	Three Months Ended December 31,
	2019		2018
Net Income	$	4,006,936	$	2,434,162
Weighted average common shares	8,081,837		8,003,736
Effect of dilutive securities:
Options to purchase common stock	31,948		48,261
Diluted average common shares	8,113,785		8,051,997
Earnings Per Share of Common Stock:
Basic	$	0.50	$	0.30
Diluted	$	0.49	$	0.30

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Regulatory Assets and Liabilities (Tables)

3 Months Ended

Dec. 31, 2019

Regulatory Assets and Liabilities [Abstract]

Schedule of Regulatory Assets

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

	December 31, 2019		September 30, 2019
Assets:
Current Assets:
Regulatory assets:
WNA	$	736,156	$	569,558
ESAC assets	180,809		265,392
Accrued pension and postretirement medical	452,005		602,674
Other deferred expenses	84,315		84,315
Total current	1,453,285		1,521,939
Utility Property:
In service:
Other	11,945		11,945
Other Assets:
Regulatory assets:
Premium on early retirement of debt	1,684,261		1,712,808
Accrued pension and postretirement medical	9,414,695		9,414,695
ESAC assets	416,676		756,803
Other deferred expenses	291,721		294,547
Total non-current	11,807,353		12,178,853
Total regulatory assets	$	13,272,583	$	13,712,737

Schedule of Regulatory Liabilities

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

	December 31, 2019		September 30, 2019
Liabilities and Stockholders' Equity:
Current Liabilities:
Regulatory liabilities:
Over-recovery of gas costs	$	1,077,563	$	161,837
Over-recovery of SAVE Plan revenues	539,529		574,181
Rate refund	3,618,396		3,827,588
Excess deferred income taxes	205,353		205,353
Other deferred liabilities	128,891		108,644
Total current	5,569,732		4,877,603
Deferred Credits and Other Liabilities:
Asset retirement obligations	6,844,857		6,788,683
Regulatory cost of retirement obligations	12,098,472		11,892,352
Regulatory Liabilities:
Excess deferred income taxes	10,818,344		10,934,434
Total non-current	29,761,673		29,615,469
Total regulatory liabilities	$	35,331,405	$	34,493,072

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Commitments and Contingencies

3 Months Ended

Dec. 31, 2019

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Roanoke Gas currently holds the only franchises and/or 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.

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Other Investments

3 Months Ended

Dec. 31, 2019

Equity Method Investments and Joint Ventures [Abstract]

Other Investments

Other Investments

In October 2015, Midstream, acquired an initial 1% equity interest in the Mountain Valley Pipeline, LLC.

The LLC was established to construct and operate a natural gas pipeline originating in northern West Virginia and extending through south central Virginia. Once completed, the pipeline will have the capacity to transport approximately 2 million decatherms of natural gas per day.

Due to ongoing delays primarily attributable to the actions of the Fourth Circuit and FERC, which have suspended previously approved permits allowing for water crossings and access through national forest lands, completing the pipeline has been delayed. Current activity on the pipeline is limited to maintenance and restoration activities. The LLC's managing partner believes they have submitted all of the information required for the suspended permits to be approved and is awaiting approval. As a result, the projected cost of the MVP project has grown to between $5.3 and $5.5 billion with a projected in-service date in late calendar 2020. Midstream's estimated total cash contribution is between $53 and $55 million. The Company is utilizing the equity method to account for the transactions and activity of the investment in MVP and is participating in the earnings in proportion to its level of investment.

In April 2018, the LLC announced the Southgate project, which is an approximately 74 mile pipeline extending from the MVP mainline in Virginia to delivery points in North Carolina. Midstream is a less than 1% investor in the project, which is being accounted for under the cost method. Total project cost is estimated to be nearly $500 million, of which Midstream's portion is estimated to be approximately $2.5 million. The Southgate in-service date is currently targeted for calendar year 2021, subject to any further delays in the completion of the MVP mainline.

Funding for Midstream's investments in the LLC for both the MVP and Southgate projects are being provided through two variable rate unsecured promissory notes under a non-revolving credit agreement, maturing in December 2022, and two additional notes issued in June 2019. See Note 7 for a schedule of debt instruments.

The investments in the LLC are included in the condensed consolidated financial statements as follows:

Balance Sheet location of Other Investments:	December 31, 2019		September 30, 2019
Other Assets:
MVP	$	49,055,748	$	47,055,426
Southgate	320,033		320,033
Investment in unconsolidated affiliates	$	49,375,781	$	47,375,459

Current Liabilities:
MVP	$	891,903	$	4,958,260
Southgate	—		66,564
Capital contributions payable	$	891,903	$	5,024,824

	Three Months Ended
Income Statement location of Other Investments:	December 31, 2019		December 31, 2018
Equity in earnings of unconsolidated affiliate	$	1,094,086	$	563,049

	December 31, 2019		September 30, 2019
Undistributed earnings, net of income taxes, of MVP in retained earnings	$	4,079,644	$	3,267,176

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

	Three Months Ended
	December 31, 2019			December 31, 2018
Cash investment	$	5,039,157		$	10,142,766
Change in accrued capital calls	(4,132,921		)	(6,395,680		)
Equity in earnings of unconsolidated affiliates	1,094,086			563,049
Change in investment in unconsolidated affiliates	$	2,000,322		$	4,310,135

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

	Income Statements
	Three Months Ended
	December 31, 2019		December 31, 2018
AFUDC	$	110,025,474	$	54,184,516
Net Other Income	$	734,182	$	2,562,792
Net Income	$	110,759,656	$	56,747,308

	Balance Sheets
	December 31, 2019		September 30, 2019
Assets:
Current Assets	$	243,577,729	$	485,323,892
Construction Work in Progress	4,941,631,920		4,675,267,389
Other Assets	9,923,000		13,190,816
Total Assets	$	5,195,132,649	$	5,173,782,097
Liabilities and Equity:
Current Liabilities	$	223,678,580	$	466,776,233
Capital	4,971,454,069		4,707,005,864
Total Liabilities and Equity	$	5,195,132,649	$	5,173,782,097

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Regulatory Assets and Liabilities (Schedule of Regulatory Assets) (Details) - USD ($)	Dec. 31, 2019	Sep. 30, 2019
Regulatory Assets [Line Items]
Current regulatory assets	$ 1,453,285	$ 1,521,939
Utility property in service, other	11,945	11,945
Noncurrent regulatory assets	11,807,353	12,178,853
Total regulatory assets	13,272,583	13,712,737
WNA
Regulatory Assets [Line Items]
Current regulatory assets	736,156	569,558
ESAC Assets
Regulatory Assets [Line Items]
Current regulatory assets	180,809	265,392
Noncurrent regulatory assets	416,676	756,803
Accrued pension and postretirement medical
Regulatory Assets [Line Items]
Current regulatory assets	452,005	602,674
Noncurrent regulatory assets	9,414,695	9,414,695
Other deferred expenses
Regulatory Assets [Line Items]
Current regulatory assets	84,315	84,315
Noncurrent regulatory assets	291,721	294,547
Premium on early retirement of debt
Regulatory Assets [Line Items]
Noncurrent regulatory assets	$ 1,684,261	$ 1,712,808

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Employee Benefit Plans (Schedule of Actual and Expected Employer Contributions) (Details)	3 Months Ended
	Dec. 31, 2019 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Fiscal Year-to-Date Contributions	$ 0
Remaining Fiscal Year Contributions	1,200,000
Defined Benefit Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fiscal Year-to-Date Contributions	0
Remaining Fiscal Year Contributions	800,000
Postretirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fiscal Year-to-Date Contributions	0
Remaining Fiscal Year Contributions	$ 400,000

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Condensed Consolidated Statements of Cash Flows - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$ 4,006,936	$ 2,434,162
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	2,047,695	1,940,472
Cost of retirement of utility plant, net	(170,224)	(50,093)
Equity in earnings of unconsolidated affiliate	(1,094,086)	(563,049)
Changes in assets and liabilities which used cash, exclusive of changes and noncash transactions shown separately	(3,972,358)	(6,061,666)
Net cash provided by (used in) operating activities	817,963	(2,300,174)
CASH FLOWS FROM INVESTING ACTIVITIES:
Expenditures for utility property	(5,849,460)	(5,691,011)
Investment in unconsolidated affiliate	(5,039,157)	(10,142,766)
Proceeds from disposal of utility property	12,881	249
Net cash used in investing activities	(10,875,736)	(15,833,528)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from issuance of unsecured notes	15,692,000	10,344,000
Borrowings under line-of-credit	9,784,533	13,760,363
Repayments under line-of-credit	(15,031,241)	(5,319,582)
Debt issuance expenses	(62,198)	0
Proceeds from issuance of stock	395,199	348,117
Cash dividends paid	(1,339,521)	(1,235,798)
Net cash provided by financing activities	9,438,772	17,897,100
NET DECREASE IN CASH AND CASH EQUIVALENTS	(619,001)	(236,602)
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	1,631,348	247,411
CASH AND CASH EQUIVALENTS AT END OF YEAR	1,012,347	10,809
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Interest	1,243,093	1,101,028
Income taxes	$ 0	$ 0

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Condensed Consolidated Statements of Income - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
OPERATING REVENUES:
Operating revenues	$ 19,785,453	$ 21,216,747
OPERATING EXPENSES:
Operations and maintenance	3,917,470	3,521,999
General taxes	543,237	507,889
Depreciation and amortization	1,988,505	1,905,475
Total operating expenses	14,703,474	17,952,525
OPERATING INCOME	5,081,979	3,264,222
Equity in earnings of unconsolidated affiliate	1,094,086	563,049
Other income (expense), net	157,643	125,886
Interest expense	1,085,185	816,782
INCOME BEFORE INCOME TAXES	5,248,523	3,136,375
INCOME TAX EXPENSE	1,241,587	702,213
NET INCOME	$ 4,006,936	$ 2,434,162
BASIC EARNINGS PER COMMON SHARE (in dollars per share)	$ 0.50	$ 0.30
DILUTED EARNINGS PER COMMON SHARE (in dollars per share)	0.49	0.30
DIVIDENDS DECLARED PER COMMON SHARE (in dollars per share)	$ 0.175	$ 0.165
Gas Utility [Member]
OPERATING REVENUES:
Operating revenues	$ 19,625,606	$ 21,036,581
OPERATING EXPENSES:
Cost of gas and sales	8,177,806	11,906,459
Non Utility [Member]
OPERATING REVENUES:
Operating revenues	159,847	180,166
OPERATING EXPENSES:
Cost of gas and sales	$ 76,456	$ 110,703

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Employee Benefit Plans (Tables)

3 Months Ended

Dec. 31, 2019

Retirement Benefits [Abstract]

Schedule of Components of Net Periodic Pension and Postretirement Benefit Cost

Net pension plan and postretirement plan expense is detailed as follows:

	Three Months Ended
	December 31,
	2019			2018
Components of net periodic pension cost:
Service cost	$	172,902		$	134,317
Interest cost	265,557			291,682
Expected return on plan assets	(459,156		)	(387,359		)
Recognized loss	113,936			39,650
Net periodic pension cost	$	93,239		$	78,290

	Three Months Ended
	December 31,
	2019			2018
Components of postretirement benefit cost:
Service cost	$	41,970		$	33,221
Interest cost	132,869			162,236
Expected return on plan assets	(137,599		)	(136,805		)
Recognized loss	59,343			30,951
Net postretirement benefit cost	$	96,583		$	89,603

Summary of Employer Contributions to Defined Benefit Plans

The table below reflects the Company's actual contributions made fiscal year-to-date and the expected contributions to be made during the balance of the current fiscal year.

	Fiscal Year-to-Date Contributions		Remaining Fiscal Year Contributions
Defined benefit pension plan	$	—	$	800,000
Postretirement medical plan	—		400,000
Total	$	—	$	1,200,000

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Basis of Presentation (Details)	Dec. 31, 2019 USD ($)	Oct. 01, 2019 USD ($) lease
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating lease, term of contract	2 years
Quarterly operating lease obligation	$ 3,240
ASU 2016-02
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Number of operating leases | lease		1
Operating lease obligation		$ 25,000
Aggregate threshold for recording operating lease obligation		$ 50,000

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Rates and Regulatory Matters (Details) - Roanoke Gas Company [Member] - USD ($)					3 Months Ended
	Jan. 24, 2020	Nov. 26, 2019	Jun. 28, 2019	Oct. 10, 2018	Dec. 31, 2019
Regulatory Liabilities [Line Items]
Additional write down of ESAC regulatory assets					$ 317,191
Regulatory liability, refund period (in years)					28 years
General Rate Case [Member] | Virginia State Corporate Commission (SCC) [Member]
Regulatory Liabilities [Line Items]
Requested non-gas rates increase				$ 10,500,000
Recommended rate increase		$ 7,100,000	$ 6,500,000
Subsequent Event [Member] | General Rate Case [Member] | Virginia State Corporate Commission (SCC) [Member]
Regulatory Liabilities [Line Items]
Approved non-gas rate increase	$ 7,250,000

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Other Comprehensive Income

3 Months Ended

Dec. 31, 2019

Equity [Abstract]

Other Comprehensive Income

Other Comprehensive Income

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

	Before-Tax Amount			Tax (Expense) or Benefit			Net-of-Tax Amount
Three Months Ended December 31, 2019
Interest rate swaps:
Unrealized gains	$	350,693		$	(90,269	)	$	260,424
Transfer of realized losses to interest expense	3,540			(911		)	2,629
Net interest rate swap	354,233			(91,180		)	263,053
Defined benefit plans:
Amortization of actuarial losses	22,610			(5,819		)	16,791
Other comprehensive income	$	376,843		$	(96,999	)	$	279,844
Three Months Ended December 31, 2018
Interest rate swap:
Unrealized losses	$	(93,956	)	$	24,184		$	(69,772	)
Transfer of realized gains to interest expense	(15,662		)	4,031			(11,631		)
Net interest rate swap	(109,618		)	28,215			(81,403		)
Defined benefit plans:
Amortization of actuarial gains	(2,576		)	663			(1,913		)
Other comprehensive loss	$	(112,194	)	$	28,878		$	(83,316	)

The amortization of actuarial gains and losses is included as a component of net periodic pension and postretirement benefit costs under other income (expense), net.

Reconciliation of Other Accumulated Comprehensive Income (Loss)

	Accumulated Other Comprehensive Income (Loss)
Balance at September 30, 2019	$	(2,488,917	)
Other comprehensive income	279,844
Balance at December 31, 2019	$	(2,209,073	)

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Rates and Regulatory Matters

3 Months Ended

Dec. 31, 2019

Regulated Operations [Abstract]

Rates and Regulatory Matters

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; extension of service; and accounting and depreciation.

On October 10, 2018, Roanoke Gas filed a general rate application requesting an annual increase in customer non-gas base rates of $10.5 million. This application incorporates into the non-gas base rates the impact of tax reform, non-SAVE utility plant investment, increased operating costs, recovery of regulatory assets associated with eligible safety activity costs and SAVE Plan investments and related costs that were previously recovered through the SAVE Rider. The new non-gas base rates were placed in effect for service rendered on or after January 1, 2019, subject to refund pending audit and final order by the SCC. On June 28, 2019, the SCC staff issued their report and recommendation for an annual non-gas rate increase of $6.5 million. On August 14th and 15th, the SCC conducted a hearing on the rate application with the hearing examiner's report issued on November 19, 2019 and subsequently revised on November 26, 2019. The revised report recommended an annual non-gas base rate increase of approximately $7.1 million. On January 24, 2020, the SCC issued their final order on the general rate application. Under the provisions of this order, Roanoke Gas was granted an annualized non-gas rate increase of $7.25 million and was required to write-down a portion of the ESAC assets not subject to recovery in the final order. As a result, management revised its estimate of the rate refund accrual to reflect the award included in the final order. Management also wrote down $317,191 in additional ESAC regulatory assets to comply with the order. The Company is in the process of submitting the rates to the SCC for approval, which will provide for the $7.25 million in additional non-gas revenue. Once approved, the Company will proceed with refunding the excess revenues to its customers. The total accrued rate refund balance is included in Note 14.

As referenced in Note 3, the TCJA reduced the federal corporate tax rate to 21%. The Company revalued its deferred tax assets and liabilities to reflect the new federal tax rate. Under the provisions of ASC 740, the corresponding adjustment to deferred income taxes generally flows directly to income tax expense. For rate regulated entities such as Roanoke Gas, these excess deferred taxes were originally recovered from its customers based on billing rates derived using a federal income tax rate of 34%. Therefore, the adjustment to the net deferred tax liabilities of Roanoke Gas, to the extent such net deferred tax liabilities are attributable to rate base or cost of service for customers, are refundable to customers. Roanoke Gas began accounting for the refund of these excess deferred taxes in fiscal 2018 along with reflecting a corresponding reduction in income tax expense. Most of the net regulatory liability will be refunded over a 28 year period per IRS normalization requirements. See Note 14 for the remaining balances related to excess deferred taxes.

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Subsequent Events (Narrative) (Details) $ in Thousands	Jan. 24, 2020 USD ($)
General Rate Case [Member] | Roanoke Gas Company [Member] | Virginia State Corporate Commission (SCC) [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Approved non-gas rate increase	$ 7,250

XML

Document and Entity Information - shares	3 Months Ended
	Dec. 31, 2019	Jan. 31, 2020
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Dec. 31, 2019
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q1
Entity Registrant Name	RGC RESOURCES INC
Entity Central Index Key	0001069533
Current Fiscal Year End Date	--09-30
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Entity Small Business	true
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		8,112,424

XML

Condensed Consolidated Statements of Comprehensive Income - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Statement of Comprehensive Income [Abstract]
NET INCOME	$ 4,006,936	$ 2,434,162
Other comprehensive income (loss), net of tax:
Interest rate swaps	263,053
Interest rate swaps		(81,403)
Defined benefit plans	16,791	(1,913)
Other comprehensive income (loss), net of tax	279,844	(83,316)
COMPREHENSIVE INCOME	$ 4,286,780	$ 2,350,846

XML

Segment Information (Reconciliation of Segment Information to Consolidated) (Details) - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Sep. 30, 2019
Segment Reporting Information [Line Items]
Operating revenues	$ 19,785,453	$ 21,216,747
Depreciation	1,988,505	1,905,475
Operating income (loss)	5,081,979	3,264,222
Equity in earnings	1,094,086	563,049
Interest expense	1,085,185	816,782
Income before income taxes	5,248,523	3,136,375
Total assets	268,182,613		$ 258,353,696
Operating Segments | Gas Utility
Segment Reporting Information [Line Items]
Operating revenues	19,625,606	21,036,581
Depreciation	1,988,505	1,905,475
Operating income (loss)	5,041,485	3,230,825
Equity in earnings	0	0
Interest expense	718,853	576,239
Income before income taxes	4,478,882	2,778,921
Total assets	204,771,371		195,969,019
Operating Segments | Investment In Affiliates
Segment Reporting Information [Line Items]
Operating revenues	0	0
Depreciation	0	0
Operating income (loss)	(38,591)	(33,887)
Equity in earnings	1,094,086	563,049
Interest expense	366,332	240,543
Income before income taxes	690,354	290,095
Total assets	49,674,141		47,429,368
Parent and Other
Segment Reporting Information [Line Items]
Operating revenues	159,847	180,166
Depreciation	0	0
Operating income (loss)	79,085	67,284
Equity in earnings	0	0
Interest expense	0	0
Income before income taxes	79,287	$ 67,359
Total assets	$ 13,737,101		$ 14,955,309

XML

Basis of Presentation

3 Months Ended

Dec. 31, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

Basis of Presentation

Resources is an energy services company primarily engaged in the sale and distribution of natural gas. The condensed consolidated financial statements include the accounts of Resources and its wholly-owned subsidiaries: Roanoke Gas, 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 present fairly Resources' financial position as of December 31, 2019 and the results of its operations, comprehensive income, changes in stockholders' equity and cash flows for the three months ended December 31, 2019 and 2018. The results of operations for the three months ended December 31, 2019 are not indicative of the results to be expected for the fiscal year ending September 30, 2020 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 as permitted under the rules and regulations of the Securities and Exchange Commission. Pursuant to those rules, certain information and note disclosures normally included in the annual financial statements prepared in accordance with generally accepted accounting principles have been condensed or omitted, although the Company believes that the disclosures are adequate to make the information not misleading. Therefore, the 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, 2019. The September 30, 2019 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 in Form 10-K for the year ended September 30, 2019. Newly adopted and newly issued accounting standards are discussed below.

Recently Issued or Adopted Accounting Standards

In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) that affects any entity that enters into contracts with customers for the transfer of goods or services or transfer of non-financial assets. This guidance supersedes the revenue recognition requirements in Topic 605, Revenue Recognition, and most industry-specific guidance. The core principle of the new guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers. To achieve that core principle, an entity should apply the following steps: (1) identify the contract with the customer, (2) identify the performance obligations in the contract, (3) determine the transaction price, (4) allocate the transaction price to the performance obligations in the contract, and (5) recognize revenue when, or as, the entity satisfies the performance obligation. Subsequently issued ASUs provided additional guidance to assist in the implementation of the new revenue standard. The standard was effective for the Company's annual reporting period ending September 30, 2019 and interim periods within that annual period.

The Company adopted ASU 2014-09 and all amendments effective October 1, 2018 with no significant impact to revenues recognized and no significant changes to the Company’s related business processes, systems or internal controls over financial reporting. See Note 2 for further information.

In February 2016, the FASB issued ASU 2016-02, Leases. This ASU leaves the accounting for leases mostly unchanged for lessors, with the exception of targeted improvements for consistency; however, the new guidance requires lessees to recognize assets and liabilities for leases with terms of more than 12 months. The ASU also revises the definition of a lease as a contract, or part of a contract, that conveys the right to control the use of identified property, plant or equipment for a period of time in exchange for consideration. Consistent with current GAAP, the presentation and cash flows arising from a lease by a lessee will primarily depend on its classification as a finance or operating lease. In contrast, the new ASU requires both types of leases to be recognized on the balance sheet. In addition, the new guidance includes quantitative and qualitative disclosure requirements to aid financial statement users in better understanding the amount, timing and uncertainty of cash flows arising from leases. In January 2018, the FASB issued ASU 2018-01, which provides a practical expedient that allows entities the option of not evaluating existing land easements under the new lease standard for those easements that were entered into prior to adoption. New or modified land easements will require evaluation on a prospective basis. The new guidance is effective for the Company for the annual reporting period ending September 30, 2020 and interim periods within that annual period.

The Company adopted ASU 2016-02 and related guidance effective October 1, 2019. At the time of adoption, the Company had one operating lease. The value of the lease obligation under the new guidance would be approximately $25,000, which falls below the Company's $50,000 aggregate threshold for recording leases under the new standard. If at a future point, the total value of all leases exceeded this threshold, the Company would recognize the leases in accordance with current guidance in addition to providing the required disclosures. The current operating lease has a term of 2 years with quarterly payments in the amount of $3,240 until the lease terminates in September 2021. This new guidance does not have a material effect on the Company's financial position, results of operations or cash flows.

In August 2017, the FASB issued ASU 2017-12, Derivatives and Hedging: Targeted Improvements to Accounting For Hedging Activities. The ASU is meant to simplify recognition and presentation guidance in an effort to improve financial reporting of cash flow and fair value hedging relationships to better portray the economic results of an entity's risk management activities. This is achieved through changes to both the designation and measurement guidance for qualifying hedging relationships, as well as changes to the presentation of hedge results. The Company adopted the new guidance effective October 1, 2019. As the Company currently has only cash flow hedges and no portion of these swaps were deemed ineffective during the periods presented, this new guidance does not have a material effect on the Company's financial position, results of operations or cash flows.

In August 2018, the FASB issued ASU 2018-15, Intangibles - Goodwill and Other - Internal-Use Software (Subtopic 350-40): Customer's Accounting for Implementation Costs incurred in a Cloud Computing Arrangement that is a Service Contract. This ASU reduces the complexity of accounting for costs of implementing a cloud computing service arrangement and aligns the following requirements to capitalize implementation costs: 1) those incurred in a hosting arrangement that is a service contract, and 2) those incurred to develop or obtain internal-use software, including hosting arrangements that include an internal software license. The Company adopted the new guidance effective October 1, 2019. The adoption of this new guidance does not currently have a material effect on the Company's consolidated financial statements. However, as the ASU changes the treatment of certain contracts by allowing related implementation costs to be capitalized and amortized over time, rather than directly expensed; there could be a significant impact on the Company's financial position, results of operations and cash flow in the future.

In August 2018, the FASB issued ASU 2018-14, Compensation - Retirement Benefits - Defined Benefit Plans - General (Subtopic 715-20) - Disclosure Framework - Changes to the Disclosure Requirements for Defined Benefit Plans. This ASU modifies disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The new guidance is effective for the Company for the annual reporting period ending September 30, 2021. Early adoption is permitted. Management has not completed its evaluation of the new guidance; however, the ASU only modifies disclosure requirements and will not effect financial position, results of operations or cash flows.

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.

XML

Employee Benefit Plans (Schedule of Components of Net Periodic Pension and Postretirement Benefit Cost) (Details) - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 172,902	$ 134,317
Interest cost	265,557	291,682
Expected return on plan assets	(459,156)	(387,359)
Recognized loss	113,936	39,650
Net periodic/postretirement pension/benefit cost	93,239	78,290
Postretirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	41,970	33,221
Interest cost	132,869	162,236
Expected return on plan assets	(137,599)	(136,805)
Recognized loss	59,343	30,951
Net periodic/postretirement pension/benefit cost	$ 96,583	$ 89,603

XML

Other Investments (Schedule of Other Investments) (Details) - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Sep. 30, 2019
Other Assets:
Investment in unconsolidated affiliates	$ 49,375,781		$ 47,375,459
Current Liabilities:
Capital contributions payable	891,903		5,024,824
Income Statement location of Other Investments:
Equity in earnings of unconsolidated affiliate	1,094,086	$ 563,049
Undistributed earnings, net of income taxes, of MVP in retained earnings	4,079,644		3,267,176
Change in investment in unconsolidated affiliate [Abstract]
Cash investment	5,039,157	10,142,766
Change in accrued capital calls	(4,132,921)	(6,395,680)
Equity in earnings of unconsolidated affiliate	1,094,086	563,049
Change in investment in unconsolidated affiliates	2,000,322	$ 4,310,135
MVP [Member]
Other Assets:
MVP	49,055,748		47,055,426
Current Liabilities:
Capital contributions payable	891,903		4,958,260
Southgate [Member]
Other Assets:
Southgate	320,033		320,033
Current Liabilities:
Capital contributions payable	$ 0		$ 66,564

XML

Long-Term Debt (Schedule of Long-Term Debt) (Details) - USD ($)		3 Months Ended
	Dec. 23, 2019	Dec. 31, 2019	Dec. 06, 2019	Sep. 30, 2019
Debt Instrument [Line Items]
Notes payable		$ 111,204,200		$ 95,512,200
Principal		114,129,966		103,684,673
Unamortized Debt Issuance Costs		357,187		313,315
Notes Payable [Member]
Debt Instrument [Line Items]
Notes payable		111,204,200		95,512,200
Unamortized Debt Issuance Costs		357,187		313,315
Roanoke Gas Company [Member] | Unsecured Senior Notes [Member] | Unsecured Senior Notes Payable, at 4.26%, due on September 18, 2034 [Member]
Debt Instrument [Line Items]
Notes payable		30,500,000		30,500,000
Unamortized Debt Issuance Costs		$ 142,398		144,811
Stated percentage rate		4.26%
Roanoke Gas Company [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 0.90%, due November 1, 2021 [Member]
Debt Instrument [Line Items]
Notes payable		$ 7,000,000		7,000,000
Unamortized Debt Issuance Costs		$ 6,114		6,948
Roanoke Gas Company [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 0.90%, due November 1, 2021 [Member] | 30-day LIBOR [Member]
Debt Instrument [Line Items]
Variable rate basis points (as a percent)		0.90%
Roanoke Gas Company [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 3.58%, due October 2, 2027 [Member]
Debt Instrument [Line Items]
Notes payable		$ 8,000,000		8,000,000
Unamortized Debt Issuance Costs		$ 37,324		38,528
Stated percentage rate		3.58%
Roanoke Gas Company [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 4.41%, due March 28, 2031 [Member]
Debt Instrument [Line Items]
Notes payable		$ 10,000,000		10,000,000
Unamortized Debt Issuance Costs		$ 35,242		36,272
Stated percentage rate		4.41%
Roanoke Gas Company [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 3.60%, due December 6, 2029 [Member]
Debt Instrument [Line Items]
Notes payable		$ 10,000,000		0
Unamortized Debt Issuance Costs		$ 32,445		0
Stated percentage rate		3.60%	3.60%
Roanoke Gas Company [Member] | Line of Credit [Member] | Line of Credit, at 30-day LIBOR plus 1.00%, due March 31, 2021 [Member]
Debt Instrument [Line Items]
Line-of-credit		$ 2,925,766		8,172,473
Unamortized Debt Issuance Costs		$ 0		0
Roanoke Gas Company [Member] | Line of Credit [Member] | Line of Credit, at 30-day LIBOR plus 1.00%, due March 31, 2021 [Member] | 30-day LIBOR [Member]
Debt Instrument [Line Items]
Variable rate basis points (as a percent)		1.00%
RGC Midstream LLC [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 1.35%, due December 29, 2022 [Member]
Debt Instrument [Line Items]
Notes payable		$ 21,704,200		16,012,200
Unamortized Debt Issuance Costs		$ 77,603		59,504
RGC Midstream LLC [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 1.35%, due December 29, 2022 [Member] | 30-day LIBOR [Member]
Debt Instrument [Line Items]
Variable rate basis points (as a percent)	1.35%	1.35%
RGC Midstream LLC [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 1.15%, due June 12, 2026 [Member]
Debt Instrument [Line Items]
Notes payable		$ 14,000,000		14,000,000
Unamortized Debt Issuance Costs		$ 15,650		16,252
RGC Midstream LLC [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 1.15%, due June 12, 2026 [Member] | 30-day LIBOR [Member]
Debt Instrument [Line Items]
Variable rate basis points (as a percent)		1.15%
RGC Midstream LLC [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 1.20%, due June 1, 2024 [Member]
Debt Instrument [Line Items]
Notes payable		$ 10,000,000		10,000,000
Unamortized Debt Issuance Costs		$ 10,411		$ 11,000
RGC Midstream LLC [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 1.20%, due June 1, 2024 [Member] | 30-day LIBOR [Member]
Debt Instrument [Line Items]
Variable rate basis points (as a percent)		1.20%

XML

Earnings Per Share (Details) - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Earnings Per Share [Abstract]
Net Income	$ 4,006,936	$ 2,434,162
Weighted average common shares (in shares)	8,081,837	8,003,736
Effect of dilutive securities:
Options to purchase common stock (in shares)	31,948	48,261
Diluted average common shares (in shares)	8,113,785	8,051,997
Earnings Per Share of Common Stock:
Basic (in dollars per share)	$ 0.50	$ 0.30
Diluted (in dollars per share)	$ 0.49	$ 0.30

XML

Long-Term Debt (Tables)

3 Months Ended

Dec. 31, 2019

Debt Disclosure [Abstract]

Schedule of Long-Term Debt

Long-term debt consists of the following:

	December 31, 2019				September 30, 2019
	Principal		Unamortized Debt Issuance Costs		Principal		Unamortized Debt Issuance Costs
Roanoke Gas Company:
Unsecured senior notes payable, at 4.26% due on September 18, 2034	$	30,500,000	$	142,398	$	30,500,000	$	144,811
Unsecured term note payable, at 30-day LIBOR plus 0.90%, due November 1, 2021	7,000,000		6,114		7,000,000		6,948
Unsecured term notes payable, at 3.58% due on October 2, 2027	8,000,000		37,324		8,000,000		38,528
Unsecured term notes payable, at 4.41% due on March 28, 2031	10,000,000		35,242		10,000,000		36,272
Unsecured term notes payable, at 3.60% due on December 6, 2029	10,000,000		32,445		—		—
RGC Midstream, LLC:
Unsecured term notes payable, at 30-day LIBOR plus 1.35%, due December 29, 2022	21,704,200		77,603		16,012,200		59,504
Unsecured term note payable, at 30-day LIBOR plus 1.15%, due June 12, 2026	14,000,000		15,650		14,000,000		16,252
Unsecured term note payable, at 30-day LIBOR plus 1.20%, due June 1, 2024	10,000,000		10,411		10,000,000		11,000
Total notes payable	$	111,204,200	$	357,187	$	95,512,200	$	313,315
Line-of-credit, at 30-day LIBOR plus 1.00%, due March 31, 2021	$	2,925,766	$	—	$	8,172,473	$	—
Total long-term debt	$	114,129,966	$	357,187	$	103,684,673	$	313,315

XML

Basis of Presentation (Policies)

3 Months Ended

Dec. 31, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

Basis of Presentation

Resources is an energy services company primarily engaged in the sale and distribution of natural gas. The condensed consolidated financial statements include the accounts of Resources and its wholly-owned subsidiaries: Roanoke Gas, 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 present fairly Resources' financial position as of December 31, 2019 and the results of its operations, comprehensive income, changes in stockholders' equity and cash flows for the three months ended December 31, 2019 and 2018. The results of operations for the three months ended December 31, 2019 are not indicative of the results to be expected for the fiscal year ending September 30, 2020 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 as permitted under the rules and regulations of the Securities and Exchange Commission. Pursuant to those rules, certain information and note disclosures normally included in the annual financial statements prepared in accordance with generally accepted accounting principles have been condensed or omitted, although the Company believes that the disclosures are adequate to make the information not misleading. Therefore, the 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, 2019. The September 30, 2019 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 in Form 10-K for the year ended September 30, 2019. Newly adopted and newly issued accounting standards are discussed below.

Recently Issued or Adopted Accounting Standards

Recently Issued or Adopted Accounting Standards

In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) that affects any entity that enters into contracts with customers for the transfer of goods or services or transfer of non-financial assets. This guidance supersedes the revenue recognition requirements in Topic 605, Revenue Recognition, and most industry-specific guidance. The core principle of the new guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers. To achieve that core principle, an entity should apply the following steps: (1) identify the contract with the customer, (2) identify the performance obligations in the contract, (3) determine the transaction price, (4) allocate the transaction price to the performance obligations in the contract, and (5) recognize revenue when, or as, the entity satisfies the performance obligation. Subsequently issued ASUs provided additional guidance to assist in the implementation of the new revenue standard. The standard was effective for the Company's annual reporting period ending September 30, 2019 and interim periods within that annual period.

The Company adopted ASU 2014-09 and all amendments effective October 1, 2018 with no significant impact to revenues recognized and no significant changes to the Company’s related business processes, systems or internal controls over financial reporting. See Note 2 for further information.

In February 2016, the FASB issued ASU 2016-02, Leases. This ASU leaves the accounting for leases mostly unchanged for lessors, with the exception of targeted improvements for consistency; however, the new guidance requires lessees to recognize assets and liabilities for leases with terms of more than 12 months. The ASU also revises the definition of a lease as a contract, or part of a contract, that conveys the right to control the use of identified property, plant or equipment for a period of time in exchange for consideration. Consistent with current GAAP, the presentation and cash flows arising from a lease by a lessee will primarily depend on its classification as a finance or operating lease. In contrast, the new ASU requires both types of leases to be recognized on the balance sheet. In addition, the new guidance includes quantitative and qualitative disclosure requirements to aid financial statement users in better understanding the amount, timing and uncertainty of cash flows arising from leases. In January 2018, the FASB issued ASU 2018-01, which provides a practical expedient that allows entities the option of not evaluating existing land easements under the new lease standard for those easements that were entered into prior to adoption. New or modified land easements will require evaluation on a prospective basis. The new guidance is effective for the Company for the annual reporting period ending September 30, 2020 and interim periods within that annual period.

The Company adopted ASU 2016-02 and related guidance effective October 1, 2019. At the time of adoption, the Company had one operating lease. The value of the lease obligation under the new guidance would be approximately $25,000, which falls below the Company's $50,000 aggregate threshold for recording leases under the new standard. If at a future point, the total value of all leases exceeded this threshold, the Company would recognize the leases in accordance with current guidance in addition to providing the required disclosures. The current operating lease has a term of 2 years with quarterly payments in the amount of $3,240 until the lease terminates in September 2021. This new guidance does not have a material effect on the Company's financial position, results of operations or cash flows.

In August 2017, the FASB issued ASU 2017-12, Derivatives and Hedging: Targeted Improvements to Accounting For Hedging Activities. The ASU is meant to simplify recognition and presentation guidance in an effort to improve financial reporting of cash flow and fair value hedging relationships to better portray the economic results of an entity's risk management activities. This is achieved through changes to both the designation and measurement guidance for qualifying hedging relationships, as well as changes to the presentation of hedge results. The Company adopted the new guidance effective October 1, 2019. As the Company currently has only cash flow hedges and no portion of these swaps were deemed ineffective during the periods presented, this new guidance does not have a material effect on the Company's financial position, results of operations or cash flows.

In August 2018, the FASB issued ASU 2018-15, Intangibles - Goodwill and Other - Internal-Use Software (Subtopic 350-40): Customer's Accounting for Implementation Costs incurred in a Cloud Computing Arrangement that is a Service Contract. This ASU reduces the complexity of accounting for costs of implementing a cloud computing service arrangement and aligns the following requirements to capitalize implementation costs: 1) those incurred in a hosting arrangement that is a service contract, and 2) those incurred to develop or obtain internal-use software, including hosting arrangements that include an internal software license. The Company adopted the new guidance effective October 1, 2019. The adoption of this new guidance does not currently have a material effect on the Company's consolidated financial statements. However, as the ASU changes the treatment of certain contracts by allowing related implementation costs to be capitalized and amortized over time, rather than directly expensed; there could be a significant impact on the Company's financial position, results of operations and cash flow in the future.

In August 2018, the FASB issued ASU 2018-14, Compensation - Retirement Benefits - Defined Benefit Plans - General (Subtopic 715-20) - Disclosure Framework - Changes to the Disclosure Requirements for Defined Benefit Plans. This ASU modifies disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The new guidance is effective for the Company for the annual reporting period ending September 30, 2021. Early adoption is permitted. Management has not completed its evaluation of the new guidance; however, the ASU only modifies disclosure requirements and will not effect financial position, results of operations or cash flows.

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.

XML

Fair Value Measurements

3 Months Ended

Dec. 31, 2019

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Value Measurements

FASB ASC No. 820, Fair Value Measurements and Disclosures, established a fair value hierarchy that prioritizes each input to the valuation method used to measure fair value of financial and nonfinancial assets and liabilities that are measured and reported on a fair value basis into one of the following three levels:

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

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

Level 3 – Unobservable inputs for the asset or liability where there is little, if any, market activity for the asset or liability at the measurement date.

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 as of December 31, 2019 and September 30, 2019:

	Fair Value Measurements - December 31, 2019
	Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Liabilities:
Natural gas purchases	$	955,372	$	—	$	955,372	$	—
Interest rate swaps	540,108		—		540,108		—
Total	$	1,495,480	$	—	$	1,495,480	$	—
	Fair Value Measurements - September 30, 2019
	Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Liabilities:
Natural gas purchases	$	397,757	$	—	$	397,757	$	—
Interest rate swaps	894,341		—		894,341		—
Total	$	1,292,098	$	—	$	1,292,098	$	—

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.

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 December 31, 2019 and September 30, 2019, the Company had recorded in accounts payable the estimated fair value of the liability valued at the corresponding first of month index prices for which the liability is expected to be settled.

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

The carrying value of cash and cash equivalents, accounts receivable, 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 as of December 31, 2019 and September 30, 2019:

	Fair Value Measurements - December 31, 2019
	Carrying Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Liabilities:
Notes payable	$	111,204,200	$	—	$	—	$	117,472,116
Total	$	111,204,200	$	—	$	—	$	117,472,116
	Fair Value Measurements - September 30, 2019
	Carrying Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Liabilities:
Notes payable	$	95,512,200	$	—	$	—	$	100,900,952
Total	$	95,512,200	$	—	$	—	$	100,900,952

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.

FASB 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. As of December 31, 2019 and September 30, 2019, no single customer accounted for more than 5% of the total accounts receivable balance. The Company maintains certain credit standards with its customers and requires a customer deposit if such evaluation warrants.

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Derivatives and Hedging

3 Months Ended

Dec. 31, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives and Hedging

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 three interest rate swaps associated with its variable rate debt. Roanoke Gas has a swap agreement that effectively converts the $7,000,000 term note based on LIBOR into fixed-rate debt with a 2.30% effective interest rate. Midstream has two swap agreements corresponding to the $14,000,000 variable rate term note issued on June 12, 2019 and the $10,000,000 variable rate term note issued on June 13, 2019. The swap agreements convert these two notes into fixed rate instruments with effective interest rates of 3.24% and 3.14%, 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.

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

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Revenue

3 Months Ended

Dec. 31, 2019

Revenue from Contract with Customer [Abstract]

Revenue

Revenue

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

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

	Three months ended December 31, 2019						Three months ended December 31, 2018
	Gas utility		Non utility		Total operating revenues		Gas utility			Non utility		Total operating revenues
Natural Gas (Billed and Unbilled):
Residential	$	12,290,361	$	—	$	12,290,361	$	13,012,592		$	—	$	13,012,592
Commercial	5,729,218		—		5,729,218		7,342,702			—		7,342,702
Industrial and Transportation	1,326,085		—		1,326,085		1,226,137			—		1,226,137
Revenue reductions (TCJA) (1)	—		—		—		(523,881		)	—		(523,881		)
Other	215,998		159,847		375,845		226,492			180,166		406,658
Total contracts with customers	19,561,662		159,847		19,721,509		21,284,042			180,166		21,464,208
Alternative Revenue Programs	63,944		—		63,944		(247,461		)	—		(247,461		)
Total operating revenues	$	19,625,606	$	159,847	$	19,785,453	$	21,036,581		$	180,166	$	21,216,747
(1) Accrued refund associated with excess revenue collected in tariff rates associated with the reduction in federal income tax rates. See Note 4 for more information.

Gas utility revenues

Substantially all of Roanoke Gas’ revenues are derived from rates authorized by the SCC as reflected in 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 commodity (the cost of natural gas sold to customers) and delivery (transporting natural gas through the Company’s distribution system to customers). The sale and/or delivery of natural gas to customers results in the satisfaction of the Company’s performance obligation over time as natural gas is delivered.

All customers are billed monthly based on consumption as measured by metered usage. 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 above. 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. Non-utility (unregulated) activities provided by the Company include contract paving and other services. Regarding these activities, the customer is invoiced monthly based on services provided. 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, and the SAVE Plan over/under collection mechanism, which adjusts revenues for the differences between SAVE Plan revenues billed to customers in the current tariff rates and the revenue earned, as calculated based on the timing and extent of infrastructure replacement completed during the period. These amounts are ultimately collected from, or returned to, customers through future changes to tariff rates.

Customer Accounts Receivable

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
	Trade accounts receivable (1)		Unbilled revenue (1)		Customer credit balances			Customer deposits
Balance at September 30, 2019	$	2,590,702	$	1,236,384	$	880,295		$	1,432,031
Balance at December 31, 2019	6,278,383		3,690,130		821,643			1,549,435
Increase (decrease)	$	3,687,681	$	2,453,746	$	(58,652	)	$	117,404
(1) Included in accounts receivable in the condensed consolidated balance sheet. Amounts shown net of reserve for bad debts.

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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Earnings Per Share

3 Months Ended

Dec. 31, 2019

Earnings Per Share [Abstract]

Earnings Per Share

Earnings Per Share

Basic earnings per common share for the three months ended December 31, 2019 and 2018 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 December 31,
	2019		2018
Net Income	$	4,006,936	$	2,434,162
Weighted average common shares	8,081,837		8,003,736
Effect of dilutive securities:
Options to purchase common stock	31,948		48,261
Diluted average common shares	8,113,785		8,051,997
Earnings Per Share of Common Stock:
Basic	$	0.50	$	0.30
Diluted	$	0.49	$	0.30

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Segment Information (Tables)

3 Months Ended

Dec. 31, 2019

Segment Reporting [Abstract]

Information related to segments

Information related to the segments of the Company are provided below:

	Three Months Ended December 31, 2019
	Gas Utility	Investment in Affiliates		Parent and Other	Consolidated Total
Operating revenues	19,625,606	—		159,847	19,785,453
Depreciation	1,988,505	—		—	1,988,505
Operating income (loss)	5,041,485	(38,591	)	79,085	5,081,979
Equity in earnings	—	1,094,086		—	1,094,086
Interest expense	718,853	366,332		—	1,085,185
Income before income taxes	4,478,882	690,354		79,287	5,248,523

	Three Months Ended December 31, 2018
	Gas Utility	Investment in Affiliates		Parent and Other	Consolidated Total
Operating revenues	21,036,581	—		180,166	21,216,747
Depreciation	1,905,475	—		—	1,905,475
Operating income (loss)	3,230,825	(33,887	)	67,284	3,264,222
Equity in earnings	—	563,049		—	563,049
Interest expense	576,239	240,543		—	816,782
Income before income taxes	2,778,921	290,095		67,359	3,136,375

	December 31, 2019
	Gas Utility	Investment in Affiliates	Parent and Other	Consolidated Total
Total assets	204,771,371	49,674,141	13,737,101	268,182,613
	September 30, 2019
	Gas Utility	Investment in Affiliates	Parent and Other	Consolidated Total
Total assets	195,969,019	47,429,368	14,955,309	258,353,696

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Revenue (Customer Accounts Receivable) (Details) - USD ($)	3 Months Ended
	Dec. 31, 2019	Sep. 30, 2019
Revenue from Contract with Customer [Abstract]
Unbilled revenue	$ 3,690,130	$ 1,236,384
Increase (decrease) in Unbilled revenue	2,453,746
Customer credit balances	821,643	880,295
Increase (decrease) in Customer credit balances	(58,652)
Customer deposits	1,549,435	1,432,031
Increase (decrease) in Customer deposits	117,404
Capitalized Contract Cost [Line Items]
Trade accounts receivable	10,084,224	3,870,211
Trade Accounts Receivable [Member]
Capitalized Contract Cost [Line Items]
Trade accounts receivable	6,278,383	$ 2,590,702
Increase (decrease) in Trade accounts receivable	$ 3,687,681

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Condensed Consolidated Balance Sheets (Parenthetical) - USD ($)	Dec. 31, 2019	Sep. 30, 2019
Statement of Financial Position [Abstract]
Accounts receivable, allowance for uncollectibles	$ 253,076	$ 110,743
Common stock, par value (in dollars per share)	$ 5	$ 5
Common stock, shares authorized	10,000,000	10,000,000
Common stock, shares issued	8,091,317	8,073,264
Common stock, shares outstanding	8,091,317	8,073,264
Preferred stock, par value (in dollars per share)	$ 0	$ 0
Preferred stock, shares authorized	5,000,000	5,000,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0

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Condensed Consolidated Statements of Changes in Stockholders' Equity (Parenthetical) - $ / shares	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Statement of Stockholders' Equity [Abstract]
Dividends declared per share (in dollars per share)	$ 0.175	$ 0.165
Common stock issued (in shares)	18,053	17,035

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Regulatory Assets and Liabilities (Schedule of Regulatory Liabilities) (Details) - USD ($)	Dec. 31, 2019	Sep. 30, 2019
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 5,569,732	$ 4,877,603
Deferred Credits and Other Liabilities:
Asset retirement obligations	6,844,857	6,788,683
Regulatory cost of retirement obligations	12,098,472	11,892,352
Noncurrent regulatory liabilities - excess deferred income taxes	10,818,344	10,934,434
Total non-current	29,761,673	29,615,469
Total regulatory liabilities	35,331,405	34,493,072
Over-recovery of gas costs
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1,077,563	161,837
Over-recovery of SAVE Plan revenues
Regulatory Liabilities [Line Items]
Current regulatory liabilities	539,529	574,181
Rate Refund
Regulatory Liabilities [Line Items]
Current regulatory liabilities	3,618,396	3,827,588
Excess deferred income taxes
Regulatory Liabilities [Line Items]
Current regulatory liabilities	205,353	205,353
Other deferred liabilities
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 128,891	$ 108,644

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Fair Value Measurements (Schedule of Fair Value of Financial Assets and Liabilities Measured on a Recurring Basis) (Details) - Fair Value [Member] - USD ($)	Dec. 31, 2019	Sep. 30, 2019
Quoted Prices in Active Markets (Level 1) [Member]
Liabilities:
Total	$ 0	$ 0
Significant Other Observable Inputs (Level 2) [Member]
Liabilities:
Total	0	0
Significant Unobservable Inputs (Level 3) [Member]
Liabilities:
Total	117,472,116	100,900,952
Recurring [Member]
Liabilities:
Natural gas purchases	955,372	397,757
Total	1,495,480	1,292,098
Recurring [Member] | Interest Rate Swap [Member]
Liabilities:
Interest rate swap	540,108	894,341
Recurring [Member] | Quoted Prices in Active Markets (Level 1) [Member]
Liabilities:
Natural gas purchases	0	0
Total	0	0
Recurring [Member] | Quoted Prices in Active Markets (Level 1) [Member] | Interest Rate Swap [Member]
Liabilities:
Interest rate swap	0	0
Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member]
Liabilities:
Natural gas purchases	955,372	397,757
Total	1,495,480	1,292,098
Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member] | Interest Rate Swap [Member]
Liabilities:
Interest rate swap	540,108	894,341
Recurring [Member] | Significant Unobservable Inputs (Level 3) [Member]
Liabilities:
Natural gas purchases	0	0
Total	0	0
Recurring [Member] | Significant Unobservable Inputs (Level 3) [Member] | Interest Rate Swap [Member]
Liabilities:
Interest rate swap	$ 0	$ 0

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Derivatives and Hedging (Details)	Dec. 31, 2019 USD ($) instrument_held debt_instrument	Jun. 13, 2019 USD ($)	Jun. 12, 2019 USD ($) instrument_held
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of interest rate swaps associated with note(s) | instrument_held	3
Roanoke Gas Company [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 0.90%, due November 1, 2021 [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Debt instrument, borrowing amount	$ 7,000,000
Effective interest rate	2.30%
RGC Midstream LLC [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of interest rate swaps associated with note(s) | instrument_held	2
Debt instrument, number of instruments	2		2
RGC Midstream LLC [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 1.15%, due June 12, 2026 [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Debt instrument, borrowing amount	$ 14,000,000		$ 14,000,000
Effective interest rate	3.24%		3.24%
RGC Midstream LLC [Member] | Unsecured Term Notes [Member] | Unsecured Term Notes Payable, at 30-day LIBOR plus 1.20%, due June 1, 2024 [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Debt instrument, borrowing amount	$ 10,000,000	$ 10,000,000
Effective interest rate	3.14%	3.14%

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Other Comprehensive Income (Reconciliation of Accumulated Comprehensive Income (Loss)) (Details) - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Increase (Decrease) in Other Accumulated Comprehensive Income (Loss) [Roll Forward]
Balance at beginning of period	$ 83,096,392	$ 79,583,112
Other comprehensive income	279,844	(83,316)
Balance at end of period	86,359,135	80,959,740
Accumulated Other Comprehensive Income (Loss)
Increase (Decrease) in Other Accumulated Comprehensive Income (Loss) [Roll Forward]
Balance at beginning of period	(2,488,917)	(871,668)
Other comprehensive income	279,844	(83,316)
Balance at end of period	$ (2,209,073)	$ (954,984)

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Income Taxes (Tables)

3 Months Ended

Dec. 31, 2019

Income Tax Disclosure [Abstract]

Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]

A reconciliation of income tax expense from applying the federal statutory rates in effect for each period to total income tax expense is presented below:

	Three Months Ended December 31,
	2019			2018
Income before income taxes	$	5,248,523		$	3,136,375
Corporate federal tax rate	21.00		%	21.00		%
Income tax expense computed at the federal statutory rate	$	1,102,190		$	658,639
State income taxes, net of federal tax benefit	250,037			150,589
Net amortization of excess deferred taxes on regulated operations	(86,208		)	(86,208		)
Other, net	(24,432		)	(20,807		)
Total income tax expense	$	1,241,587		$	702,213
Effective tax rate	23.7		%	22.4		%

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Regulatory Assets and Liabilities

3 Months Ended

Dec. 31, 2019

Regulatory Assets and Liabilities [Abstract]

Regulatory Assets and Liabilities

Regulatory Assets and Liabilities

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

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

	December 31, 2019		September 30, 2019
Assets:
Current Assets:
Regulatory assets:
WNA	$	736,156	$	569,558
ESAC assets	180,809		265,392
Accrued pension and postretirement medical	452,005		602,674
Other deferred expenses	84,315		84,315
Total current	1,453,285		1,521,939
Utility Property:
In service:
Other	11,945		11,945
Other Assets:
Regulatory assets:
Premium on early retirement of debt	1,684,261		1,712,808
Accrued pension and postretirement medical	9,414,695		9,414,695
ESAC assets	416,676		756,803
Other deferred expenses	291,721		294,547
Total non-current	11,807,353		12,178,853
Total regulatory assets	$	13,272,583	$	13,712,737

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

	December 31, 2019		September 30, 2019
Liabilities and Stockholders' Equity:
Current Liabilities:
Regulatory liabilities:
Over-recovery of gas costs	$	1,077,563	$	161,837
Over-recovery of SAVE Plan revenues	539,529		574,181
Rate refund	3,618,396		3,827,588
Excess deferred income taxes	205,353		205,353
Other deferred liabilities	128,891		108,644
Total current	5,569,732		4,877,603
Deferred Credits and Other Liabilities:
Asset retirement obligations	6,844,857		6,788,683
Regulatory cost of retirement obligations	12,098,472		11,892,352
Regulatory Liabilities:
Excess deferred income taxes	10,818,344		10,934,434
Total non-current	29,761,673		29,615,469
Total regulatory liabilities	$	35,331,405	$	34,493,072

As of December 31, 2019 and September 30, 2019, the Company had regulatory assets in the amount of $13,260,638 and $13,700,792, respectively, on which the Company did not earn a return during the recovery period.

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Other Investments (Investment in Unconsolidated Entity) (Details) - Mountain Valley Pipeline LLC (Unconsolidated Entity) - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Sep. 30, 2019
Income Statement
AFUDC	$ 110,025,474	$ 54,184,516
Net Other Income	734,182	2,562,792
Net Income	110,759,656	$ 56,747,308
Assets:
Current Assets	243,577,729		$ 485,323,892
Construction Work in Progress	4,941,631,920		4,675,267,389
Other Assets	9,923,000		13,190,816
Total Assets	5,195,132,649		5,173,782,097
Liabilities and Equity:
Current Liabilities	223,678,580		466,776,233
Capital	4,971,454,069		4,707,005,864
Total Liabilities and Equity	$ 5,195,132,649		$ 5,173,782,097

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Other Comprehensive Income (Schedule of Other Comprehensive Income and Loss) (Details) - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Before-Tax Amount
Other comprehensive income (loss)	$ 376,843	$ (112,194)
Tax (Expense) or Benefit
Other comprehensive income	(96,999)	28,878
Net-of-Tax Amount
Other comprehensive income (loss), net of tax	279,844	(83,316)
Interest rate swap [Member]
Before-Tax Amount
Other comprehensive income (loss) before reclassifications	350,693
Reclassifications from accumulated other comprehensive income	3,540
Other comprehensive income (loss)	354,233
Tax (Expense) or Benefit
Other comprehensive income before reclassifications	(90,269)
Reclassifications from accumulated other comprehensive income	(911)
Other comprehensive income	(91,180)
Net-of-Tax Amount
Other comprehensive income (loss) before reclassifications	260,424
Reclassifications from accumulated other comprehensive income	2,629
Other comprehensive income (loss), net of tax	263,053
Interest rate swap [Member]
Before-Tax Amount
Other comprehensive income (loss) before reclassifications		(93,956)
Reclassifications from accumulated other comprehensive income		(15,662)
Other comprehensive income (loss)		(109,618)
Tax (Expense) or Benefit
Other comprehensive income before reclassifications		24,184
Reclassifications from accumulated other comprehensive income		4,031
Other comprehensive income		28,215
Net-of-Tax Amount
Other comprehensive income (loss) before reclassifications		(69,772)
Reclassifications from accumulated other comprehensive income		(11,631)
Other comprehensive income (loss), net of tax		(81,403)
Defined benefit plans [Member]
Before-Tax Amount
Other comprehensive income (loss)	22,610	(2,576)
Tax (Expense) or Benefit
Other comprehensive income	(5,819)	663
Net-of-Tax Amount
Other comprehensive income (loss), net of tax	$ 16,791	$ (1,913)

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Other Investments (Tables)

3 Months Ended

Dec. 31, 2019

Equity Method Investments and Joint Ventures [Abstract]

Schedule of Other Investments

The investments in the LLC are included in the condensed consolidated financial statements as follows:

Balance Sheet location of Other Investments:	December 31, 2019		September 30, 2019
Other Assets:
MVP	$	49,055,748	$	47,055,426
Southgate	320,033		320,033
Investment in unconsolidated affiliates	$	49,375,781	$	47,375,459

Current Liabilities:
MVP	$	891,903	$	4,958,260
Southgate	—		66,564
Capital contributions payable	$	891,903	$	5,024,824

	Three Months Ended
Income Statement location of Other Investments:	December 31, 2019		December 31, 2018
Equity in earnings of unconsolidated affiliate	$	1,094,086	$	563,049

	December 31, 2019		September 30, 2019
Undistributed earnings, net of income taxes, of MVP in retained earnings	$	4,079,644	$	3,267,176

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

	Three Months Ended
	December 31, 2019			December 31, 2018
Cash investment	$	5,039,157		$	10,142,766
Change in accrued capital calls	(4,132,921		)	(6,395,680		)
Equity in earnings of unconsolidated affiliates	1,094,086			563,049
Change in investment in unconsolidated affiliates	$	2,000,322		$	4,310,135

Summary Unaudited Financial Statements - Equity Method Investment

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

	Income Statements
	Three Months Ended
	December 31, 2019		December 31, 2018
AFUDC	$	110,025,474	$	54,184,516
Net Other Income	$	734,182	$	2,562,792
Net Income	$	110,759,656	$	56,747,308

	Balance Sheets
	December 31, 2019		September 30, 2019
Assets:
Current Assets	$	243,577,729	$	485,323,892
Construction Work in Progress	4,941,631,920		4,675,267,389
Other Assets	9,923,000		13,190,816
Total Assets	$	5,195,132,649	$	5,173,782,097
Liabilities and Equity:
Current Liabilities	$	223,678,580	$	466,776,233
Capital	4,971,454,069		4,707,005,864
Total Liabilities and Equity	$	5,195,132,649	$	5,173,782,097

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Subsequent Events

3 Months Ended

Dec. 31, 2019

Subsequent Events [Abstract]

Subsequent Events

Subsequent Events

On January 24, 2020, the SCC issued their final order on the Company's non-gas rate increase. The Company has adjusted it's provision for rate refund based on the authorized rate increase of $7.25 million and reflected all adjustments directed in the order in the condensed consolidated financial statements for the quarter ended December 31, 2019. See Note 4 for additional information.

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

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Employee Benefit Plans

3 Months Ended

Dec. 31, 2019

Retirement Benefits [Abstract]

Employee Benefit Plans

Employee Benefit Plans

The Company has both a pension plan and a postretirement plan. The pension plan covers substantially all of the Company’s employees hired before January 1, 2017 and provides retirement income based on years of service and employee compensation. The postretirement plan 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
	December 31,
	2019			2018
Components of net periodic pension cost:
Service cost	$	172,902		$	134,317
Interest cost	265,557			291,682
Expected return on plan assets	(459,156		)	(387,359		)
Recognized loss	113,936			39,650
Net periodic pension cost	$	93,239		$	78,290

	Three Months Ended
	December 31,
	2019			2018
Components of postretirement benefit cost:
Service cost	$	41,970		$	33,221
Interest cost	132,869			162,236
Expected return on plan assets	(137,599		)	(136,805		)
Recognized loss	59,343			30,951
Net postretirement benefit cost	$	96,583		$	89,603

The components of net periodic benefit cost, other than the service cost component, are included in other income (expense), net in the condensed consolidated statements of income as prescribed under ASU 2017-07. Service cost is included in operations and maintenance expense in the condensed consolidated statements of income.

The table below reflects the Company's actual contributions made fiscal year-to-date and the expected contributions to be made during the balance of the current fiscal year.

	Fiscal Year-to-Date Contributions		Remaining Fiscal Year Contributions
Defined benefit pension plan	$	—	$	800,000
Postretirement medical plan	—		400,000
Total	$	—	$	1,200,000

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Long-Term Debt

3 Months Ended

Dec. 31, 2019

Debt Disclosure [Abstract]

Long-Term Debt

Long-Term Debt

On December 23, 2019, Midstream entered into the Third Amendment to Credit Agreement ("Amendment") and amendments to the related Promissory Notes ("Notes") with the corresponding banks. The Amendment modified the original Credit Agreement and prior amendments between Midstream and the banks by increasing the total borrowing capacity to $41,000,000 from its previous limit of $26,000,000 and extending the maturity date to December 29, 2022. The Amendment retained all of the other provisions contained in the previous credit agreements and amendments including the interest rate on the Notes based on 30-day LIBOR plus 1.35%. The additional limits under the Amendment will be used to finance the investment in the MVP.

On December 6, 2019, Roanoke Gas entered into unsecured notes in the aggregate principal amount of $10,000,000. These notes have a 10-year term with a fixed interest rate of 3.60%. Proceeds from these notes will be used to fund Roanoke Gas' capital budget.

Roanoke Gas has other unsecured notes at varying fixed interest rates as well as a variable-rate note with interest based on 30-day LIBOR plus 90 basis points. The variable rate note is hedged by a swap agreement, which converts the debt into a fixed-rate instrument with an annual interest rate of 2.30%. Midstream has two other variable rate notes in the amounts of $14,000,000 and $10,000,000 that are hedged by swap agreements that effectively convert the interest rates to 3.24% and 3.14%, respectively.

All of the debt agreements set forth certain representations, warranties and covenants to which the Company is subject, including financial covenants that limit consolidated long-term indebtedness to not more than 65% of total capitalization. All of the debt agreements, except for the line-of-credit, provide for priority indebtedness to not exceed 15% of consolidated total assets. The Company was in compliance with all debt covenants as of December 31, 2019 and September 30, 2019.

Long-term debt consists of the following:

	December 31, 2019				September 30, 2019
	Principal		Unamortized Debt Issuance Costs		Principal		Unamortized Debt Issuance Costs
Roanoke Gas Company:
Unsecured senior notes payable, at 4.26% due on September 18, 2034	$	30,500,000	$	142,398	$	30,500,000	$	144,811
Unsecured term note payable, at 30-day LIBOR plus 0.90%, due November 1, 2021	7,000,000		6,114		7,000,000		6,948
Unsecured term notes payable, at 3.58% due on October 2, 2027	8,000,000		37,324		8,000,000		38,528
Unsecured term notes payable, at 4.41% due on March 28, 2031	10,000,000		35,242		10,000,000		36,272
Unsecured term notes payable, at 3.60% due on December 6, 2029	10,000,000		32,445		—		—
RGC Midstream, LLC:
Unsecured term notes payable, at 30-day LIBOR plus 1.35%, due December 29, 2022	21,704,200		77,603		16,012,200		59,504
Unsecured term note payable, at 30-day LIBOR plus 1.15%, due June 12, 2026	14,000,000		15,650		14,000,000		16,252
Unsecured term note payable, at 30-day LIBOR plus 1.20%, due June 1, 2024	10,000,000		10,411		10,000,000		11,000
Total notes payable	$	111,204,200	$	357,187	$	95,512,200	$	313,315
Line-of-credit, at 30-day LIBOR plus 1.00%, due March 31, 2021	$	2,925,766	$	—	$	8,172,473	$	—
Total long-term debt	$	114,129,966	$	357,187	$	103,684,673	$	313,315

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Income Taxes

3 Months Ended

Dec. 31, 2019

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

On December 22, 2017, TCJA became law. The TCJA's most significant impact was the reduction of the maximum corporate federal income tax rate from 35% to 21% beginning January 1, 2018.

Under the provisions of ASC 740 - Income Taxes, the deferred tax assets and liabilities of the Company were revalued to reflect the reduction in the federal tax rate. For unregulated entities, the revaluation of excess deferred income taxes flowed through income tax expense in the period of change. For rate regulated entities such as Roanoke Gas, these excess deferred taxes were originally recovered from its customers based on billing rates derived using a federal income tax rate of 34%. As a result, these net excess deferred taxes must be returned to customers. The Company began refunding these excess deferred taxes in fiscal 2018. As the refunds should have no effect on the income of the Company, the consolidated income statements reflect both a reduction in revenues and a corresponding reduction in income taxes associated with the flow back of these net excess deferred taxes. The result is a lowering of the effective tax rate for the Company.

A reconciliation of income tax expense from applying the federal statutory rates in effect for each period to total income tax expense is presented below:

	Three Months Ended December 31,
	2019			2018
Income before income taxes	$	5,248,523		$	3,136,375
Corporate federal tax rate	21.00		%	21.00		%
Income tax expense computed at the federal statutory rate	$	1,102,190		$	658,639
State income taxes, net of federal tax benefit	250,037			150,589
Net amortization of excess deferred taxes on regulated operations	(86,208		)	(86,208		)
Other, net	(24,432		)	(20,807		)
Total income tax expense	$	1,241,587		$	702,213
Effective tax rate	23.7		%	22.4		%

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Fair Value Measurements (Tables)

3 Months Ended

Dec. 31, 2019

Fair Value Disclosures [Abstract]

Schedule of Fair Value of Financial Assets and Liabilities Measured on a Recurring Basis

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 as of December 31, 2019 and September 30, 2019:

	Fair Value Measurements - December 31, 2019
	Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Liabilities:
Natural gas purchases	$	955,372	$	—	$	955,372	$	—
Interest rate swaps	540,108		—		540,108		—
Total	$	1,495,480	$	—	$	1,495,480	$	—
	Fair Value Measurements - September 30, 2019
	Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Liabilities:
Natural gas purchases	$	397,757	$	—	$	397,757	$	—
Interest rate swaps	894,341		—		894,341		—
Total	$	1,292,098	$	—	$	1,292,098	$	—

Summary of the Fair Value of Financial Assets and Liabilities Not Adjusted to 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 as of December 31, 2019 and September 30, 2019:

	Fair Value Measurements - December 31, 2019
	Carrying Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Liabilities:
Notes payable	$	111,204,200	$	—	$	—	$	117,472,116
Total	$	111,204,200	$	—	$	—	$	117,472,116
	Fair Value Measurements - September 30, 2019
	Carrying Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Liabilities:
Notes payable	$	95,512,200	$	—	$	—	$	100,900,952
Total	$	95,512,200	$	—	$	—	$	100,900,952

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Revenue (Disaggregation of Revenue) (Details) - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Total contracts with customers	$ 19,721,509	$ 21,464,208
Revenue reductions (TCJA)	0	(523,881)
Alternative Revenue Programs	63,944	(247,461)
Operating revenues	19,785,453	21,216,747
Natural Gas [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Total contracts with customers	12,290,361	13,012,592
Natural Gas [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Total contracts with customers	5,729,218	7,342,702
Natural Gas [Member] | Industrial and Transportation [Member]
Disaggregation of Revenue [Line Items]
Total contracts with customers	1,326,085	1,226,137
Other [Member]
Disaggregation of Revenue [Line Items]
Total contracts with customers	375,845	406,658
Gas Utility [Member]
Disaggregation of Revenue [Line Items]
Total contracts with customers	19,561,662	21,284,042
Revenue reductions (TCJA)	0	(523,881)
Alternative Revenue Programs	63,944	(247,461)
Operating revenues	19,625,606	21,036,581
Gas Utility [Member] | Natural Gas [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Total contracts with customers	12,290,361	13,012,592
Gas Utility [Member] | Natural Gas [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Total contracts with customers	5,729,218	7,342,702
Gas Utility [Member] | Natural Gas [Member] | Industrial and Transportation [Member]
Disaggregation of Revenue [Line Items]
Total contracts with customers	1,326,085	1,226,137
Gas Utility [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Total contracts with customers	215,998	226,492
Non Utility [Member]
Disaggregation of Revenue [Line Items]
Total contracts with customers	159,847	180,166
Revenue reductions (TCJA)	0	0
Alternative Revenue Programs	0	0
Operating revenues	159,847	180,166
Non Utility [Member] | Natural Gas [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Total contracts with customers	0	0
Non Utility [Member] | Natural Gas [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Total contracts with customers	0	0
Non Utility [Member] | Natural Gas [Member] | Industrial and Transportation [Member]
Disaggregation of Revenue [Line Items]
Total contracts with customers	0	0
Non Utility [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Total contracts with customers	$ 159,847	$ 180,166

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Regulatory Assets and Liabilities (Narrative) (Details) - USD ($)	Dec. 31, 2019	Sep. 30, 2019
Regulatory Assets and Liabilities [Abstract]
Remaining amount of regulatory assets that did not earn a return during the recovery period	$ 13,260,638	$ 13,700,792

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Fair Value Measurements (Summary of the Fair Value of Financial Assets and Liabilities Not Adjusted to Fair Value) (Details) - USD ($)	Dec. 31, 2019	Sep. 30, 2019
Carrying Value [Member]
Liabilities:
Notes payable	$ 111,204,200	$ 95,512,200
Total	111,204,200	95,512,200
Fair Value [Member] | Quoted Prices in Active Markets (Level 1) [Member]
Liabilities:
Notes payable	0	0
Total	0	0
Fair Value [Member] | Significant Other Observable Inputs (Level 2) [Member]
Liabilities:
Notes payable	0	0
Total	0	0
Fair Value [Member] | Significant Unobservable Inputs (Level 3) [Member]
Liabilities:
Notes payable	117,472,116	100,900,952
Total	$ 117,472,116	$ 100,900,952

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Condensed Consolidated Balance Sheets - USD ($)	Dec. 31, 2019	Sep. 30, 2019
CURRENT ASSETS:
Cash and cash equivalents	$ 1,012,347	$ 1,631,348
Accounts receivable (less allowance for uncollectibles of $253,076 and $110,743, respectively)	10,084,224	3,870,211
Materials and supplies	968,299	1,021,882
Gas in storage	6,015,628	6,448,307
Prepaid income taxes	128,892	1,157,980
Regulatory assets	1,453,285	1,521,939
Other	1,576,689	733,525
Total current assets	21,239,364	16,385,192
UTILITY PROPERTY:
In service	241,063,157	237,786,964
Accumulated depreciation and amortization	(68,559,129)	(67,207,334)
In service, net	172,504,028	170,579,630
Construction work in progress	12,886,980	11,423,326
Utility plant, net	185,391,008	182,002,956
OTHER ASSETS:
Regulatory assets	11,807,353	12,178,853
Investment in unconsolidated affiliates	49,375,781	47,375,459
Other	369,107	411,236
Total other assets	61,552,241	59,965,548
TOTAL ASSETS	268,182,613	258,353,696
CURRENT LIABILITIES:
Dividends payable	1,419,236	1,339,522
Accounts payable	4,730,021	4,483,233
Capital contributions payable	891,903	5,024,824
Customer credit balances	821,643	880,295
Customer deposits	1,549,435	1,432,031
Accrued expenses	2,434,189	3,448,000
Interest rate swaps	87,761	147,556
Regulatory liabilities	5,569,732	4,877,603
Total current liabilities	17,503,920	21,633,064
LONG-TERM DEBT:
Notes payable	111,204,200	95,512,200
Line-of-credit	2,925,766	8,172,473
Less unamortized debt issuance costs	(357,187)	(313,315)
Long-term debt, net	113,772,779	103,371,358
DEFERRED CREDITS AND OTHER LIABILITIES:
Interest rate swaps	452,347	746,785
Asset retirement obligations	6,844,857	6,788,683
Regulatory cost of retirement obligations	12,098,472	11,892,352
Benefit plan liabilities	6,928,648	6,912,105
Deferred income taxes	13,404,111	12,978,523
Regulatory liabilities	10,818,344	10,934,434
Total deferred credits and other liabilities	50,546,779	50,252,882
STOCKHOLDERS’ EQUITY:
Common stock, $5 par value; authorized 10,000,000 shares; issued and outstanding 8,091,317 and 8,073,264 shares, respectively	40,456,585	40,366,320
Preferred stock, no par, authorized 5,000,000 shares; no shares issued and outstanding	0	0
Capital in excess of par value	14,702,006	14,397,072
Retained earnings	33,409,617	30,821,917
Accumulated other comprehensive loss	(2,209,073)	(2,488,917)
Total stockholders’ equity	86,359,135	83,096,392
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$ 268,182,613	$ 258,353,696

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Condensed Consolidated Statements of Changes in Stockholders' Equity - USD ($)	Total	Common Stock	Capital in Excess of Par Value	Retained Earnings	Accumulated Other Comprehensive Income (Loss)
Balance at beginning of period at Sep. 30, 2018	$ 79,583,112	$ 39,973,075	$ 13,043,656	$ 27,438,049	$ (871,668)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	2,434,162			2,434,162
Other comprehensive income (loss)	(83,316)				(83,316)
Cash dividends declared	(1,322,335)			(1,322,335)
Issuance of common stock	348,117	85,175	262,942
Balance at end of period at Dec. 31, 2018	80,959,740	40,058,250	13,306,598	28,549,876	(954,984)
Balance at beginning of period at Sep. 30, 2019	83,096,392	40,366,320	14,397,072	30,821,917	(2,488,917)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	4,006,936			4,006,936
Other comprehensive income (loss)	279,844				279,844
Cash dividends declared	(1,419,236)			(1,419,236)
Issuance of common stock	395,199	90,265	304,934
Balance at end of period at Dec. 31, 2019	$ 86,359,135	$ 40,456,585	$ 14,702,006	$ 33,409,617	$ (2,209,073)