RGC Resources (RGCO) 10-K3 Dec 202020 FY Annual reportFinancial data

Company Profile

Cover

Cover - USD ($)	12 Months Ended
Cover - USD ($)	Sep. 30, 2020	Nov. 25, 2020	Mar. 31, 2020
Cover [Abstract]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Sep. 30, 2020
Document Transition Report	false
Entity File Number	000-26591
Entity Registrant Name	RGC Resources, Inc.
Amendment Flag	false
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	FY
Entity Central Index Key	0001069533
Current Fiscal Year End Date	--09-30
Entity Incorporation, State or Country Code	VA
Entity Tax Identification Number	54-1909697
Entity Address, Address Line One	519 Kimball Ave., N.E.,
Entity Address, City or Town	Roanoke,
Entity Address, State or Province	VA
Entity Address, Postal Zip Code	24016
City Area Code	(540)
Local Phone Number	777-4427
Title of 12(b) Security	Common Stock, $5 Par Value
Trading Symbol	RGCO
Security Exchange Name	NASDAQ
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	true
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 219,692,926
Entity Common Stock, Shares Outstanding		8,170,701
Documents Incorporated by Reference	DOCUMENTS INCORPORATED BY REFERENCE: Portions of the RGC Resources, Inc. Proxy Statement for the 2021 Annual Meeting of Shareholders are incorporated by reference into Part III hereof.

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($)	Sep. 30, 2020	Sep. 30, 2019
CURRENT ASSETS:
Cash and cash equivalents	$ 291,066	$ 1,631,348
Accounts receivable, net	3,404,044	3,870,211
Materials and supplies	1,027,191	1,021,882
Gas in storage	5,708,761	6,448,307
Prepaid income taxes	647,623	1,157,980
Regulatory assets	2,503,314	1,521,939
Other	854,562	733,525
Total current assets	14,436,561	16,385,192
UTILITY PROPERTY:
In service	258,342,372	237,786,964
Accumulated depreciation and amortization	(71,386,537)	(67,207,334)
In service, net	186,955,835	170,579,630
Construction work in progress	11,489,258	11,423,326
Utility plant, net	198,445,093	182,002,956
OTHER ASSETS:
Regulatory assets	10,970,094	12,178,853
Investment in unconsolidated affiliates	57,542,805	47,375,459
Other	284,954	411,236
Total other assets	68,797,853	59,965,548
TOTAL ASSETS	281,679,507	258,353,696
CURRENT LIABILITIES:
Dividends payable	1,428,268	1,339,522
Accounts payable	4,442,182	4,483,233
Capital contributions payable	2,512,437	5,024,824
Customer credit balances	1,587,061	880,295
Customer deposits	1,611,476	1,432,031
Accrued expenses	3,565,210	3,448,000
Interest rate swaps	533,795	147,556
Regulatory liabilities	890,313	4,877,603
Total current liabilities	16,570,742	21,633,064
LONG-TERM DEBT:
Notes payable	114,975,200	95,512,200
Line-of-credit	9,143,606	8,172,473
Less unamortized debt issuance costs	(299,175)	(313,315)
Long-term debt net of unamortized debt issuance costs	123,819,631	103,371,358
DEFERRED CREDITS AND OTHER LIABILITIES:
Interest rate swaps	1,689,761	746,785
Asset retirement obligations	7,180,982	6,788,683
Regulatory cost of retirement obligations	12,678,043	11,892,352
Benefit plan liabilities	6,149,527	6,912,105
Deferred income taxes	13,973,762	12,978,523
Regulatory liabilities	10,729,082	10,934,434
Total deferred credits and other liabilities	52,401,157	50,252,882
COMMITMENTS AND CONTINGENCIES (Note 12)
Stockholders’ Equity:
Common Stock, $5 par value; authorized 20,000,000 and 10,000,000 shares; issued and outstanding 8,160,058 and 8,073,264 shares in 2020 and 2019, respectively	40,800,290	40,366,320
Preferred stock, no par; authorized 5,000,000 shares; no shares issued and outstanding in 2020 and 2019	0	0
Capital in excess of par value	15,847,121	14,397,072
Retained earnings	35,688,510	30,821,917
Accumulated other comprehensive loss	(3,447,944)	(2,488,917)
Total stockholders’ equity	88,887,977	83,096,392
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$ 281,679,507	$ 258,353,696

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Sep. 30, 2020	Sep. 30, 2019
Statement of Financial Position [Abstract]
Common stock, par value (in usd per share)	$ 5	$ 5
Common stock, shares authorized	20,000,000	10,000,000
Common stock, shares issued	8,160,058	8,073,264
Common stock, shares outstanding	8,160,058	8,073,264
Preferred stock, no par value (in usd 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

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($)	12 Months Ended
Consolidated Statements of Income - USD ($)	Sep. 30, 2020	Sep. 30, 2019
OPERATING REVENUES:
Revenues	$ 63,075,391	$ 68,026,525
OPERATING EXPENSES:
Operations and maintenance	16,180,229	14,089,019
General taxes	2,194,789	2,066,794
Depreciation and amortization	7,890,725	7,454,274
Total operating expenses	50,557,209	56,431,061
OPERATING INCOME	12,518,182	11,595,464
Equity in earnings of unconsolidated affiliate	4,814,874	3,020,348
Other income, net	636,296	351,882
Interest expense	4,099,158	3,618,551
INCOME BEFORE INCOME TAXES	13,870,194	11,349,143
INCOME TAX EXPENSE	3,305,660	2,650,731
NET INCOME	$ 10,564,534	$ 8,698,412
EARNINGS PER COMMON SHARE:
Basic (in usd per share)	$ 1.30	$ 1.08
Diluted (in usd per share)	$ 1.30	$ 1.08
WEIGHTED AVERAGE SHARES OUTSTANDING:
Basic (in shares)	8,125,938	8,039,484
Diluted (in shares)	8,146,666	8,078,950
Gas Utility
OPERATING REVENUES:
Revenues	$ 62,408,925	$ 67,306,260
OPERATING EXPENSES:
Cost of sales	23,949,481	32,401,123
Non Utility
OPERATING REVENUES:
Revenues	666,466	720,265
OPERATING EXPENSES:
Cost of sales	$ 341,985	$ 419,851

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($)	12 Months Ended
Consolidated Statements of Comprehensive Income - USD ($)	Sep. 30, 2020	Sep. 30, 2019
Statement of Comprehensive Income [Abstract]
NET INCOME	$ 10,564,534	$ 8,698,412
Other comprehensive loss, net of tax:
Interest rate swaps	(987,076)	(894,761)
Defined benefit plans	28,049	(722,488)
OTHER COMPREHENSIVE LOSS, NET OF TAX	(959,027)	(1,617,249)
COMPREHENSIVE INCOME	$ 9,605,507	$ 7,081,163

Consolidated Statements of Stoc

Consolidated Statements of Stockholders' Equity - USD ($)	Total	Common Stock	Capital in Excess of Par Value	Retained Earnings	Accumulated Other Comprehensive Loss
Beginning balance 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	8,698,412			8,698,412
Other comprehensive loss	(1,617,249)				(1,617,249)
Exercise of stock options	412,179	157,540	254,639
Cash dividends declared	(5,314,544)			(5,314,544)
Issuance of common stock	1,334,482	235,705	1,098,777
Ending balance 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	10,564,534			10,564,534
Other comprehensive loss	(959,027)				(959,027)
Exercise of stock options	439,508	149,960	289,548
Stock option grants	81,380		81,380
Cash dividends declared	(5,697,941)			(5,697,941)
Issuance costs	(147,517)		(147,517)
Issuance of common stock	1,510,648	284,010	1,226,638
Ending balance at Sep. 30, 2020	$ 88,887,977	$ 40,800,290	$ 15,847,121	$ 35,688,510	$ (3,447,944)

Consolidated Statements of St_2

Consolidated Statements of Stockholders' Equity (Parenthetical) - $ / shares	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Statement of Stockholders' Equity [Abstract]
Dividends declared (in usd per share)	$ 0.70	$ 0.66
Issuance of stock (in shares)	56,802	47,141
Options exercised (in shares)	29,992	31,508

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($)	12 Months Ended
Consolidated Statements of Cash Flows - USD ($)	Sep. 30, 2020	Sep. 30, 2019
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$ 10,564,534	$ 8,698,412
Adjustments to reconcile net income to net cash provided by operations:
Depreciation and amortization	8,126,427	7,600,852
Cost of retirement of utility plant, net	(544,696)	(443,586)
Stock option grants	81,380	0
Equity in earnings of unconsolidated affiliate	(4,814,874)	(3,020,348)
Allowance for funds used during construction	330,208	0
Deferred income taxes	1,122,303	684,028
Other noncash items, net	1,837,089	488,202
Changes in assets and liabilities which provided (used) cash:
Accounts receivable and customer deposits, net	53,213	(122,165)
Inventories and gas in storage	734,237	1,070,896
Regulatory and other assets	(677,488)	(156,799)
Accounts payable, customer credit balances and accrued expenses, net	659,276	(2,745,377)
Regulatory liabilities	(3,987,290)	2,643,589
Total adjustments	2,259,369	5,999,292
Net cash provided by operating activities	12,823,903	14,697,704
CASH FLOWS FROM INVESTING ACTIVITIES:
Expenditures for utility property	(22,916,339)	(21,884,317)
Investment in unconsolidated affiliate	(7,864,859)	(20,965,907)
Proceeds from disposal of utility property	60,187	20,219
Net cash used in investing activities	(30,721,011)	(42,830,005)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings under line-of-credit	24,341,134	33,735,144
Repayments under line-of-credit	(23,370,002)	(32,923,688)
Proceeds from issuance of unsecured notes	19,463,000	56,269,000
Retirement of notes payable	0	(24,000,000)
Debt issuance expenses	(70,750)	(93,104)
Proceeds from issuance of stock	1,802,639	1,746,661
Cash dividends paid	(5,609,195)	(5,217,775)
Net cash provided by financing activities	16,556,826	29,516,238
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(1,340,282)	1,383,937
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	1,631,348	247,411
CASH AND CASH EQUIVALENTS AT END OF YEAR	291,066	1,631,348
Cash paid during the year for:
Interest	3,845,382	3,328,130
Income taxes	$ 1,673,000	$ 2,287,000

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
Summary of Significant Accounting Policies	Sep. 30, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Summary of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Principles of Consolidation —RGC Resources, Inc. is an energy services company primarily engaged in the sale and distribution of natural gas. The consolidated financial statements include the accounts of Resources and its wholly owned subsidiaries: Roanoke Gas, Diversified Energy and Midstream. Roanoke Gas is a natural gas utility, which distributes and sells natural gas to approximately 62,000 residential, commercial and industrial customers within its service areas in Roanoke, Virginia and the surrounding localities. The Company’s business is seasonal in nature as a majority of natural gas sales are for space heating during the winter season. Roanoke Gas is regulated by the SCC. Midstream is a wholly-owned subsidiary created primarily to invest in the Mountain Valley Pipeline project. Diversified Energy is inactive. The Company follows accounting and reporting standards established by the FASB and the SEC. Under the rules for smaller reporting companies, certain disclosures previously required are reduced or eliminated. As it has met the qualifications under the definition of smaller reporting company, the Company has used the smaller reporting company exceptions. Rate Regulated Basis of Accounting —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 and liabilities included in the Company’s consolidated balance sheets as of September 30, 2020 and 2019 are as follows: September 30 2020 2019 Assets: Current Assets: Regulatory assets: Accrued WNA revenues $ — $ 569,558 Under-recovery of gas costs 1,733,718 — Under-recovery of SAVE Plan revenues 108,550 — ESAC assets — 265,392 Accrued pension and postretirement medical 576,731 602,674 Other deferred expenses 84,315 84,315 Total current 2,503,314 1,521,939 Utility Property: In service: Other 11,945 11,945 Construction work in progress: AFUDC 330,208 — Other Assets: Regulatory assets: Premium on early retirement of debt 1,598,620 1,712,808 Accrued pension and postretirement medical 9,156,546 9,414,695 ESAC assets — 756,803 Other deferred expenses 214,928 294,547 Total non-current 10,970,094 12,178,853 Total regulatory assets $ 13,815,561 $ 13,712,737 Liabilities and Stockholders' Equity: Current Liabilities: Regulatory liabilities: Over-recovery of gas costs $ — $ 161,837 WNA 601,784 — Over-recovery of SAVE Plan revenues — 574,181 Rate refund — 3,827,588 Excess deferred income taxes 205,353 205,353 Other deferred liabilities 83,176 108,644 Total current 890,313 4,877,603 Deferred Credits and Other Liabilities: Asset retirement obligations 7,180,982 6,788,683 Regulatory cost of retirement obligations 12,678,043 11,892,352 Regulatory liabilities: Excess deferred income taxes 10,729,082 10,934,434 Total non-current $ 30,588,107 $ 29,615,469 Total regulatory liabilities $ 31,478,420 $ 34,493,072 Amortization of regulatory assets of $1,106,511 and $368,011 for the years ended September 30, 2020 and 2019, respectively, is included in operations and maintenance expense on the consolidated statements of income. See Note 3 for information on accelerated ESAC amortization. As of September 30, 2020, the Company had regulatory assets in the amount of $13,803,616 on which the Company did not earn a return during the recovery period. Utility Plant and Depreciation —Utility plant is stated at original cost and includes direct labor and materials, contractor costs, and all allocable overhead charges. The Company applies the group method of accounting, where the costs of like assets are aggregated and depreciated by applying a rate based on the average expected useful life of the assets. In accordance with Company policy, expenditures for depreciable assets with a life greater than one year are capitalized, along with any upgrades or improvements to existing assets, when they significantly improve or extend the original expected useful life of an asset. Expenditures for maintenance, repairs, and minor renewals and betterments are expensed as incurred. The original cost of depreciable property retired is removed from utility plant and charged to accumulated depreciation. The cost of asset removals, less salvage, is charged to “regulatory cost of retirement obligations” or “asset retirement obligations” as explained under Asset Retirement Obligations below. Utility plant is composed of the following major classes of assets: September 30 2020 2019 Distribution and transmission $ 227,753,620 $ 209,171,339 LNG storage 14,798,453 13,417,077 General and miscellaneous 15,790,299 15,198,548 Total utility plant in service $ 258,342,372 $ 237,786,964 Provisions for depreciation are computed principally at composite straight-line rates over a range of periods. Rates are determined by depreciation studies which are required to be performed at least every 5 years on the regulated utility assets of Roanoke Gas. In September 2019, the SCC staff approved the Company's most recent depreciation study. The SCC directed the Company to implement the new rates retroactive to October 1, 2018. As a result of the new rates, the composite weighted-average depreciation rate was 3.30% and 3.31% for the years ended September 30, 2020 and 2019, respectively. The implementation of the new depreciation rates reduced total depreciation expense by $32,570 for fiscal 2019 and increased net income by $24,187 or less than $0.01 per share. The composite rates are composed of two components, one based on average service life and one based on cost of retirement. As a result, the Company accrues the estimated cost of retirement of long-lived assets through depreciation expense. These retirement costs are not a legal obligation but rather the result of cost-based regulation and are accounted for under the provisions of FASB ASC No. 980. Such amounts are classified as a regulatory liability. The Company reviews long-lived assets and certain identifiable intangibles for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. These reviews have not identified any impairments which would have a material effect on the results of operations or financial condition. In fiscal 2020, Roanoke Gas implemented the application of AFUDC related to infrastructure investments associated with two gate stations that will interconnect with the MVP. This treatment allows capitalizing both the equity and debt financing costs during the construction phases. For the year ended September 30, 2020, the Company capitalized $81,629 of debt financing costs and $248,579 of equity financing costs, thereby affecting the interest expense and other income, net lines, respectively, of the related consolidated statements of income. See Note 3 for further information. Asset Retirement Obligations —FASB ASC No. 410, Asset Retirement and Environmental Obligations , requires entities to record the fair value of a liability for an ARO when there exists a legal obligation for the retirement of the asset. When the liability is initially recorded, the entity capitalizes the cost, thereby increasing the carrying amount of the underlying asset. In subsequent periods, the liability is accreted, and the capitalized cost is depreciated over the useful life of the underlying asset. The Company has recorded AROs for its future legal obligations related to purging and capping its distribution mains and services upon retirement, although the timing of such retirements is uncertain. The Company’s composite depreciation rates include a component to provide for the cost of retirement of assets. As a result, the Company accrues the estimated cost of retirement of its utility plant through depreciation expense and creates a corresponding regulatory liability. The costs of retirement considered in the development of the depreciation component include those costs associated with the legal liability. Therefore, the ARO is reclassified from the regulatory cost of retirement obligation. If the legal obligations were to exceed the regulatory liability provided for in the depreciation rates, the Company would establish a regulatory asset for such difference with the anticipation of future recovery through rates charged to customers. The following is a summary of the AROs: Years Ended September 30 2020 2019 Beginning balance $ 6,788,683 $ 6,417,948 Liabilities incurred 165,524 177,646 Liabilities settled (150,345) (177,755) Accretion 377,120 370,844 Ending balance $ 7,180,982 $ 6,788,683 Cash, Cash Equivalents and Short-Term Investments —From time to time, the Company will have balances on deposit at banks in excess of the amount insured by the FDIC. The Company has not experienced any losses on these accounts and does not consider these amounts to be at credit risk. As of September 30, 2020, the Company did not have any bank deposits in excess of the FDIC insurance limits. For purposes of the consolidated statements of cash flows, the Company considers all highly liquid debt instruments purchased with an original maturity of three months or less to be cash equivalents. Customer Receivables and Allowance for Doubtful Accounts —Accounts receivable include amounts billed to customers for natural gas sales and related services and gas sales occurring subsequent to normal billing cycles but before the end of the period. The Company provides an estimate for losses on these receivables by utilizing historical information, current account balances, account aging and current economic conditions. Customer accounts are charged off annually when deemed uncollectible or when turned over to a collection agency for action. A reconciliation of changes in the allowance for doubtful accounts is as follows: Years Ended September 30 2020 2019 Beginning balance $ 110,743 $ 103,573 Provision for doubtful accounts 556,112 220,039 Recoveries of accounts written off 139,113 96,614 Accounts written off (102,828) (309,483) Ending balance $ 703,140 $ 110,743 Due to the impact of COVID-19 on businesses and individuals, both bad debt expense and associated allowance for doubtful accounts increased significantly over prior years. See Note 3 for additional information, including regulatory restrictions, that contributed to the increase. Financing Receivables —Financing receivables represent a contractual right to receive money either on demand, or on fixed or determinable dates, and are recognized as assets on the entity’s balance sheet. Trade receivables, resulting from the sale of natural gas and other services to customers, are the Company's primary type of financing receivables. These receivables are short-term in nature with a provision for uncollectible balances included in the consolidated financial statements. Inventories —Natural gas in storage and materials and supplies inventories are recorded at average cost. Natural gas storage injections are priced at the purchase cost at the time of injection and storage withdrawals are priced at the weighted average cost of gas in storage. Materials and supplies are removed from inventory at average cost. Unbilled Revenues —The Company bills its natural gas customers on a monthly cycle; however, the billing cycle period for most customers does not coincide with the accounting periods used for financial reporting. As the Company recognizes revenue when gas is delivered, an accrual is made to estimate revenues for natural gas delivered to customers but not billed during the accounting period. The amounts of unbilled revenue receivable included in accounts receivable on the consolidated balance sheets at September 30, 2020 and 2019 were $1,041,518 and $1,236,384, respectively. Income Taxes —Income taxes are accounted for using the asset and liability method. Under the asset and liability method, deferred tax assets and liabilities are recognized for the estimated future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates in effect for the years in which those temporary differences are expected to be recovered or settled. A valuation allowance against deferred tax assets is provided if it is more likely than not the deferred tax asset will not be realized. The Company and its subsidiaries file state and federal consolidated income tax returns. Debt Expenses —Debt issuance expenses are deferred and amortized over the lives of the debt instruments. The unamortized balances are offset against the carrying value of long-term debt. Over/Under-Recovery of Natural Gas Costs —Pursuant to the provisions of the Company’s PGA clause, the SCC provides the Company with a method of passing along to its customers increases or decreases in natural gas costs incurred by its regulated operations, including gains and losses on natural gas derivative hedging instruments. On at least a quarterly basis, the Company files a PGA rate adjustment request with the SCC to increase or decrease the gas cost component of its rates, based 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 the projections used in establishing the PGA rate, the Company may either over-recover or under-recover its actual gas costs during the period. Any 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 deferral period, the balance of the net deferred charge or credit is amortized over an ensuing 12-month period as amounts are reflected in customer bills. Fair Value —Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between willing market participants at the measurement date. The Company determines fair value based on the following fair value hierarchy which prioritizes each input to the valuation methods into one of the following three broad 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 which require the Company to develop its own assumptions. The fair value hierarchy gives the highest priority to unadjusted quoted prices in active markets (Level 1) and the lowest priority to unobservable inputs (Level 3). All fair value disclosures are categorized within one of the three categories in the hierarchy. See fair value disclosures below and in Notes 9 and 13. Use of Estimates —The preparation of consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent 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. Excise and Sales Taxes —Certain excise and sales taxes imposed by the state and local governments in the Company’s service territory are collected by the Company from its customers. These taxes are accounted for on a net basis and therefore are not included as revenues in the Company’s consolidated income statements. Earnings Per Share —Basic EPS and diluted EPS are calculated by dividing net income by the weighted-average common shares outstanding during the period and the weighted-average common shares outstanding during the period plus dilutive potential common shares, respectively. Dilutive potential common shares are calculated in accordance with the treasury stock method, which assumes that proceeds from the exercise of all options are used to repurchase common stock at market value. The amount of shares remaining after the proceeds are exhausted represents the potentially dilutive effect of the securities. A reconciliation of basic and diluted EPS is presented below: Years Ended September 30 2020 2019 Net Income $ 10,564,534 $ 8,698,412 Weighted-average common shares 8,125,938 8,039,484 Effect of dilutive securities: Options to purchase common stock 20,728 39,466 Diluted average common shares 8,146,666 8,078,950 Earnings Per Share of Common Stock: Basic $ 1.30 $ 1.08 Diluted $ 1.30 $ 1.08 Business and Credit Concentrations — The primary business of the Company is the distribution of natural gas to residential, commercial and industrial customers in its service territories. No sales to individual customers accounted for more than 5% of total revenue in any period or amounted to more than 5% of total accounts receivable. Roanoke Gas currently holds the only franchises and CPCNs to distribute natural gas in its service area. These franchises are effective through January 1, 2036. The Company's current CPCNs in Virginia are exclusive and are intended for perpetual duration. Roanoke Gas is served directly by two primary pipelines that provide all of the natural gas supplied to the Company’s customers. Depending upon weather conditions and the level of customer demand, failure of one or both of these transmission pipelines could have a major adverse impact on the Company. Derivative and Hedging Activities —FASB ASC No. 815, Derivatives and Hedging , requires the recognition of all derivative instruments as assets or liabilities in the Company’s consolidated balance sheet and measurement of those instruments at fair value. The Company’s hedging and derivatives policy allows management to enter into derivatives for the purpose of managing the commodity and financial market risks of its business operations. The Company’s hedging and derivatives policy specifically prohibits the use of derivatives for speculative purposes. The key market risks that the Company may hedge against include the price of natural gas and the cost of borrowed funds. The Company historically has entered into collars, swaps and caps for the purpose of hedging the price of natural gas in order to provide price stability during the winter months. The fair value of these instruments is recorded in the consolidated balance sheets with the offsetting entry to either under- or over-recovery of gas costs. Net income and other comprehensive income are not affected by the change in market value as any cost incurred or benefit received from these instruments is recoverable or refunded through the PGA as the SCC allows for full recovery of prudent costs associated with natural gas purchases. At September 30, 2020 and 2019, the Company had no outstanding derivative instruments for the purchase of natural gas. The Company has three interest rate swaps associated with its variable rate debt. Roanoke Gas has a swap on its $7,000,000 term note that effectively converts the variable interest rate into a 2.30% fixed interest rate. In June 2019, Midstream entered into two variable-rate term notes in the amount of $14,000,000 and $10,000,000 with corresponding swap agreements to convert the variable interest rates into fixed rates of 3.24% and 3.14%, respectively. All swaps qualify as a cash flow hedge with changes in fair value reported in other comprehensive income. Any cash flows from interest rate swaps are classified as interest expense. No portion of the swaps were deemed ineffective during the period. See Notes 7 and 13 for additional information on the swaps and fair value. Non-Cash Activity — A non-cash decrease in unconsolidated affiliate and corresponding decrease in capital contributions payable of $2,512,387 and $5,117,942 occurred for the fiscal years ended September 30, 2020 and 2019, respectively. Other Comprehensive Income (Loss) — A summary of other comprehensive income is provided below: Before Tax Tax Net of Tax Year Ended September 30, 2020: Interest rate swaps: Unrealized losses $ (1,594,126) $ 410,328 $ (1,183,798) Transfer of realized losses to interest expense 264,911 (68,189) 196,722 Net interest rate swaps (1,329,215) 342,139 (987,076) Defined benefit plans: Net loss arising during period $ (52,669) $ 13,557 $ (39,112) Amortization of actuarial losses 90,441 (23,280) 67,161 Net defined benefit plans 37,772 (9,723) 28,049 Other comprehensive loss $ (1,291,443) $ 332,416 $ (959,027) Year Ended September 30, 2019: Interest rate swaps: Unrealized losses $ (1,117,595) $ 287,669 $ (829,926) Transfer of realized gains to interest expense (87,309) 22,474 (64,835) Net interest rate swaps (1,204,904) 310,143 (894,761) Defined benefit plans: Net loss arising during period $ (962,612) $ 247,777 $ (714,835) Amortization of actuarial gains (10,305) 2,652 (7,653) Net defined benefit plans (972,917) 250,429 (722,488) Other comprehensive loss $ (2,177,821) $ 560,572 $ (1,617,249) The amortization of actuarial gains or losses are included as a component of net periodic pension and postretirement benefit costs under other income, net. Composition of AOCI: Interest Rate Defined Benefit Accumulated Balance September 30, 2018 230,624 (1,102,292) (871,668) Other comprehensive loss (894,761) (722,488) (1,617,249) Balance September 30, 2019 (664,137) (1,824,780) (2,488,917) Other comprehensive income (loss) (987,076) 28,049 (959,027) Balance September 30, 2020 $ (1,651,213) $ (1,796,731) $ (3,447,944) The reclassification related to the interest rate swap was charged to regulatory liability to offset the adjustment made when revaluing the deferred tax liability of the interest rate swap for the reduction in corporate income tax rates. Recently Adopted Accounting Standards 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. Under prior GAAP, the presentation and cash flows arising from a lease by a lessee primarily depended on its classification as a finance or operating lease. 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. This lease calls for quarterly payments in the amount of $3,240 and is set to expire in September 2021. As the value of this lease obligation was determined to be de minimis and the Company has not entered into any additional lease obligations, 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 hedges 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 new guidance did not have a material effect on the Company's consolidated financial statements. Recently Issued Accounting Standards 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 affect financial position, results of operations or cash flows. In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848) - Facilitation of the Effects of Reference Rate Reform on Financial Reporting. This ASU provides temporary optional guidance to ease the potential burden in accounting for and recognizing the effects of reference rate change on financial reporting. The new guidance applies specifically to contracts and hedging relationships that reference LIBOR, or any other referenced rate that is expected to be discontinued due to reference rate reform. The new guidance is effective for the Company through December 31, 2022. Management has not yet completed its evaluation of the new guidance; however, as the Company has several contracts and hedging relationships that currently reference LIBOR, this new guidance could impact the Company's financial position, results of operations, or cash flows for the period through which the ASU is effective.

Revenue

Revenue	12 Months Ended
Revenue	Sep. 30, 2020
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 for the years ended September 30: 2020 Gas utility Non-utility Total operating revenues Natural Gas (Billed and Unbilled): Residential $ 37,022,219 $ — $ 37,022,219 Commercial 18,387,674 — 18,387,674 Industrial and Transportation 5,188,069 — 5,188,069 Other 489,943 666,466 1,156,409 Total contracts with customers 61,087,905 666,466 61,754,371 Alternative Revenue Programs 1,321,020 — 1,321,020 Total operating revenues $ 62,408,925 $ 666,466 $ 63,075,391 2019 Gas utility Non-utility Total operating revenues Natural Gas (Billed and Unbilled): Residential $ 39,519,618 $ — $ 39,519,618 Commercial 22,562,265 — 22,562,265 Industrial and Transportation 4,770,657 — 4,770,657 Revenue reductions (TCJA) (1) (523,881) — (523,881) Other 592,156 720,265 1,312,421 Total contracts with customers 66,920,815 720,265 67,641,080 Alternative Revenue Programs 385,445 — 385,445 Total operating revenues $ 67,306,260 $ 720,265 $ 68,026,525 (1) Accrued refund associated with excess revenue collected in tariff rates associated with the reduction in federal income tax rates. Gas utility revenues Substantially all of Roanoke Gas’ revenues are derived from rates authorized by the SCC through its tariffs. Based on its evaluation, the Company has concluded that these tariff-based revenues fall within the scope of ASC 606. Tariff rates represent the transaction price. Performance obligations created under these tariff-based sales include commodity (the cost of natural gas sold to customers) and delivery (transporting natural gas through the Company’s distribution system to customers). The delivery of natural gas to customers results in the satisfaction of the Company’s respective performance obligations over time. All customers are billed monthly based on consumption as measured by metered usage. 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 similar 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 and the revenues 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 rate changes approved by the SCC. Customer Accounts Receivable Accounts receivable, as reflected in the 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 September 30, 2019 $ 2,590,702 $ 1,236,384 $ 880,295 $ 1,432,031 September 30, 2020 2,343,492 1,041,518 1,587,061 1,611,476 Increase (decrease) $ (247,210) $ (194,866) $ 706,766 $ 179,445 (1) Included in "Accounts receivable, net" in the consolidated balance sheet. Amounts shown net of reserve for bad debts.

Regulatory Matters

Regulatory Matters	12 Months Ended
Regulatory Matters	Sep. 30, 2020
Regulated Operations [Abstract]
Regulatory Matters	REGULATORY MATTERS The SCC exercises regulatory authority over the natural gas operations of Roanoke Gas. Such regulation encompasses terms, conditions and rates to be charged to customers for natural gas service, safety standards, service extension, and depreciation. On October 10, 2018, Roanoke Gas filed a general rate case application requesting an increase in annual customer non-gas base rates. This application incorporated into the non-gas rate 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 previously recovered through the SAVE Rider. The new non-gas rates were placed in effect on an interim basis for service rendered on or after January 1, 2019, subject to refund pending audit and final order by the SCC. On January 24, 2020, the SCC issued its 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 provided for a 9.44% return on equity. In addition, the final order directed the Company to write-down a portion of the ESAC assets deemed not eligible for recovery. As a result, ESAC regulatory assets were written down approximately $317,000 in the first quarter of fiscal 2020. In March 2020, the Company completed the refund of $3.8 million for revenues collected from the interim rates in excess of the final approved rates, including interest. The final order did not provide for a return on Roanoke Gas infrastructure investments associated with two gate stations that will interconnect with the MVP; however, the order did provide for the ability to defer financing costs related to these investments for consideration of future recovery. The Company is deferring these costs through the application of AFUDC, which capitalizes both the equity and debt financing costs during the construction phases. Roanoke Gas applied AFUDC treatment retroactively to January 1, 2019, the date new non-gas rates became effective. The January 1, 2019 date was affirmed by the Commission in its October 1, 2020 order in the Company’s 2019 annual informational filing docket. Amounts capitalized are disclosed in the Utility Plant and Depreciation section of Note 1. In 2020, Roanoke Gas accelerated amortization of the $525,000 remaining balance of its ESAC assets. This acceleration was the result of the Company's earnings test for fiscal 2020. The SCC requires regulated utilities with certain regulatory assets to perform and submit an annual earnings test. The Company's earnings test is required for its fiscal year ended September 30, 2020 and must be filed with the SCC in January 2021. Specific to ESAC assets, if the results indicate that earnings exceed the mid-point of its authorized return on equity range, the Company must write-down certain regulatory assets to the point where the actual return for the period falls to the mid-point. As Roanoke Gas' fiscal 2020 unadjusted earnings exceeded the mid-point, the Company accelerated amortization of the related ESAC assets. On March 16, 2020, in response to the COVID-19 pandemic, the SCC issued an order applicable to all utilities operating in Virginia to suspend disconnection of service for non-payment by any customer until May 15, 2020, which was subsequently extended to October 5, 2020. These moratorium orders prohibited utilities from disconnecting any customer for non-payment of natural gas service and also prohibited utilities from assessing late payment fees. As a result, the amount of current receivables and future billings that may ultimately become uncollectible will likely increase. In October 2020, during the special session of the Virginia General Assembly, HB5005 was enacted and extended the moratorium until the Governor determines that the economic and public health conditions have improved such that the prohibition does not need to be in place, or until at least 60 days after such declared state of emergency ends, whichever is sooner. Therefore, the Company has increased its provision for uncollectible accounts, based on information currently available and the expected continued aging of its accounts receivable at September 30, 2020. These estimates are subject to revision as the financial impact of COVID-19 continues to ripple through the economy. As referenced in Note 8, 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, 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. As of September 30, 2020, Roanoke Gas had approximately $11,000,000 remaining in the net regulatory liability related to these excess deferred income taxes, the majority of which will be refunded over a 28 year period per IRS normalization requirements. The Company transitioned to a corporate federal income tax rate of 21% and a combined 25.74% state and federal tax rate in fiscal 2019. In January 2018, the SCC issued a directive requiring the accrual of a regulatory liability for excess revenues collected from customers attributable to the higher federal income tax rate, included as a component of customer billing rates, until such time as the SCC approved revised billing rates incorporating the lower tax rate. The Company refunded the excess revenues associated with the change in the tax rate over a 12-month period ended December 2019. In June 2019, the Company submitted its updated depreciation study with the SCC staff. The depreciation study, which is based on average remaining service life, resulted in an overall composite weighted-average depreciation rate of 3.31% for fiscal 2019. In September 2019, the SCC staff approved the depreciation study filing and instructed the Company to implement the new rates retroactive to October 1, 2018. As a result, the Company recorded a $32,570 reduction in annual depreciation expense for the fiscal year ended September 30, 2019. See Note 1 for more information.

Segment Information

Segment Information	12 Months Ended
Segment Information	Sep. 30, 2020
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 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: Gas Utility Investment in Affiliates Parent and Other Consolidated Total For the Year Ended September 30, 2020: Operating revenues $ 62,408,925 $ — $ 666,466 $ 63,075,391 Depreciation 7,890,725 — — 7,890,725 Operating income (loss) 12,429,613 (220,194) 308,763 12,518,182 Equity in earnings — 4,814,874 — 4,814,874 Interest expense 2,730,822 1,368,336 — 4,099,158 Income before income taxes 10,350,946 3,233,233 286,015 13,870,194 As of September 30, 2020: Total assets $ 211,994,364 $ 57,660,105 $ 12,025,038 $ 281,679,507 Gross additions to utility property 22,916,339 — — 22,916,339 Gross investment in MVP and Southgate — 7,864,859 — 7,864,859 Gas Utility Investment in Affiliates Parent and Other Consolidated Total For the Year Ended September 30, 2019: Operating revenues $ 67,306,260 $ — $ 720,265 $ 68,026,525 Depreciation 7,454,274 — — 7,454,274 Operating income (loss) 11,458,679 (153,149) 289,934 11,595,464 Equity in earnings — 3,020,348 — 3,020,348 Interest expense 2,404,518 1,214,033 — 3,618,551 Income before income taxes 9,400,869 1,657,988 290,286 11,349,143 As of September 30, 2019: Total assets $ 195,969,019 $ 47,429,368 $ 14,955,309 $ 258,353,696 Gross additions to utility property 21,884,317 — — 21,884,317 Gross investment in MVP and Southgate — 20,965,907 — 20,965,907

Other Investments

Other Investments	12 Months Ended
Other Investments	Sep. 30, 2020
Other Investments [Abstract]
Other Investments	OTHER INVESTMENTS In October 2015, Midstream, acquired a 1% equity interest in the LLC. In November 2019, the Company's Board of Directors approved a pro-rata increase in Midstream's participation that will increase its equity interest to approximately 1.03% at the MVP's completion. Once in service, the MVP will transport approximately 2 million dth of natural gas per day. Pipeline construction has been delayed due to regulatory and legal challenges that have restricted the recent focus to maintenance and restoration activities. As a result, the projected cost is expected to range from $5.8 to $6.0 billion, with Midstream's total cash contributions expected to range from $60 and $62 million. The managing partner extended the estimated in-service date to the second half of calendar 2021. The Company is utilizing the equity method to account for the transactions related to the MVP investment and recognizes earnings in proportion to its investment. In April 2018, the LLC announced the MVP Southgate project, which is an approximately 75 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 $2.1 million. The Southgate in-service date is currently targeted for calendar year 2022. Funding for Midstream's investments in the LLC for both the MVP and Southgate projects is 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 Company will participate in the earnings generated from the transportation of natural gas through both pipelines proportionate to its level of investment once the pipelines are placed in service. The investments in the LLC are included in the consolidated financial statements as follows: September 30 Balance Sheet location: 2020 2019 Other Assets: MVP $ 57,183,063 $ 47,055,426 Southgate 359,742 320,033 Investment in unconsolidated affiliates $ 57,542,805 $ 47,375,459 Current Liabilities: MVP $ 2,501,883 $ 4,958,260 Southgate 10,554 66,564 Capital contributions payable $ 2,512,437 $ 5,024,824 Years ended September 30 Income Statement location: 2020 2019 Equity in earnings of unconsolidated affiliate $ 4,814,874 $ 3,020,348 September 30 2020 2019 Undistributed earnings, net of income taxes, of MVP in retained earnings $ 6,842,702 $ 3,267,176 The change in the investment in unconsolidated affiliates is provided below: September 30 2020 2019 Cash investment $ 7,864,859 $ 20,965,907 Change in accrued capital calls (2,512,387) (5,117,942) Equity in earnings of unconsolidated affiliate 4,814,874 3,020,348 Change in investment in unconsolidated affiliates $ 10,167,346 $ 18,868,313 Summary unaudited financial statements of MVP are presented below. Southgate financial statements, which are accounted for under the cost method, are not included: Income Statements Years Ended September 30, 2020 2019 AFUDC $ 479,586,911 $ 295,430,776 Net Other Income 714,128 5,655,644 Net Income $ 480,301,039 $ 301,086,420 Balance Sheets September 30 2020 2019 Assets: Current Assets $ 513,713,429 $ 485,323,892 Construction Work in Progress 5,536,248,668 4,675,267,389 Other Assets 4,597,441 13,190,816 Total Assets $ 6,054,559,538 $ 5,173,782,097 Liabilities and Equity: Current Liabilities $ 187,581,804 $ 466,776,233 Noncurrent Liabilities 245,000 — Capital 5,866,732,734 4,707,005,864 Total Liabilities and Equity $ 6,054,559,538 $ 5,173,782,097

Line-of-Credit

Line-of-Credit	12 Months Ended
Line-of-Credit	Sep. 30, 2020
Debt Disclosure [Abstract]
Line-of-Credit	LINE-OF-CREDIT In March 2020, Roanoke Gas renewed its unsecured line-of-credit agreement, which was scheduled to expire March 31, 2021. The new agreement is for a two-year term expiring March 31, 2022 with a maximum borrowing limit of $28,000,000. Amounts drawn against the agreement are considered to be non-current, as the balance under the line-of-credit is not subject to repayment within the next 12-month period. The agreement has a variable interest rate based on 30-day LIBOR plus 100 basis points, an availability fee of 15 basis points and provides multi-tiered borrowing limits associated with the seasonal borrowing demands of the Company. The Company's total available borrowing limits for the remaining term are as follows: As of Available September 30, 2020 $ 19,000,000 March 1, 2021 15,000,000 July 20, 2021 20,000,000 September 20, 2021 28,000,000 A summary of the line-of-credit follows: September 30 2020 2019 Available line-of-credit at year-end $ 19,000,000 $ 22,000,000 Outstanding balance at year-end 9,143,606 8,172,473 Highest month-end balance outstanding 12,983,210 15,801,798 Average daily balance 3,286,033 6,049,527 Average rate of interest during year on outstanding balances 2.16 % 3.40 % Interest rate at year-end 1.15 % 3.02 % Interest rate on unused line-of-credit 0.15 % 0.15 %

Long-Term Debt

Long-Term Debt	12 Months Ended
Long-Term Debt	Sep. 30, 2020
Debt Disclosure [Abstract]
Long-Term Debt	LONG-TERM DEBT In December 2019, Midstream entered into the Third Amendment to its 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 provide additional financing for the investment in the MVP. In December 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 provided funding for Roanoke Gas' capital budget. Roanoke Gas also 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, which effectively convert the interest rates to 3.24% and 3.14%, respectively. Long-term debt consists of the following: September 30 2020 2019 Principal Unamortized Debt Issuance Costs Principal Unamortized Debt Issuance Costs Roanoke Gas: Unsecured senior notes payable, at 4.26%, due on September 18, 2034 $ 30,500,000 $ 135,157 $ 30,500,000 $ 144,811 Unsecured term note payable, at 30-day LIBOR plus 0.90%, November 1, 2021 7,000,000 3,613 7,000,000 6,948 Unsecured term notes payable, at 3.58% due on October 2, 2027 8,000,000 33,712 8,000,000 38,528 Unsecured term notes payable at 4.41%, due on March 28, 2031 10,000,000 32,892 10,000,000 36,272 Unsecured term notes payable at 3.60%, due on December 6, 2029 10,000,000 32,585 — — Midstream: Unsecured term notes payable, at 30-day LIBOR plus 1.35% due December 29, 2022 25,475,200 38,728 16,012,200 59,504 Unsecured term note payable, at 30-day LIBOR plus 1.15%, due June 12, 2026 14,000,000 13,844 14,000,000 16,252 Unsecured term note payable, at 30-day LIBOR plus 1.20%, due June 1, 2024 10,000,000 8,644 10,000,000 11,000 Total notes payable $ 114,975,200 $ 299,175 $ 95,512,200 $ 313,315 Line-of-credit, at 30-day LIBOR plus 1.00%, due March 31, 2022 9,143,606 — 8,172,473 — Total long-term debt $ 124,118,806 $ 299,175 $ 103,684,673 $ 313,315 Debt issuance costs are amortized over the life of the related debt. As of September 30, 2020 and 2019, the Company also had an unamortized loss on the early retirement of debt of $1,598,620 and $1,712,808, respectively, which has been deferred as a regulatory asset and is being amortized over a 20 year period. All of the debt agreements set forth certain representations, warranties and covenants to which the Company is subject, including financial covenants that require the ratio of long-term debt to long-term capitalization to not exceed 65%. 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 September 30, 2020 and September 30, 2019. The aggregate annual maturities of long-term debt for the next five years ending after September 30, 2020 are as follows: Year Ending September 30 Maturities 2021 $ — 2022 16,268,606 2023 25,975,200 2024 9,375,000 2025 — Thereafter 72,500,000 Total $ 124,118,806

Income Taxes

Income Taxes	12 Months Ended
Income Taxes	Sep. 30, 2020
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES As a result of the TCJA enacted in January 2018, the Company's statutory federal income tax rate is 21% in fiscal 2020 and 2019, respectively. Under the provisions of ASC 740 - Income Taxes , the deferred tax assets and liabilities of the Company were revalued in fiscal 2018 to reflect the reduction in the corporate federal income tax rate. The result of this revaluation was a reduction in the net deferred tax liability of approximately $9 million, including approximately $11.8 million reclassified to regulatory liability, a $3 million gross up to reflect pre-tax basis, and $0.26 million increase in income tax expense related to unregulated operations for fiscal 2018. The excess deferred income taxes are reflected on a pretax basis to appropriately contemplate future tax consequences in the periods when the regulatory liability is settled. The excess deferred taxes related to the depreciable property is being returned to customers through reduced billings over the remaining weighted average useful life of the property with a corresponding reduction in income tax expense. The excess deferred taxes related to the other regulatory basis differences are being collected from customers over a five year period. The details of income tax expense are as follows: Years Ended September 30 2020 2019 Current income taxes: Federal $ 1,841,124 $ 1,698,215 State 342,233 268,488 Total current income taxes 2,183,357 1,966,703 Deferred income taxes: Federal 644,682 272,079 State 477,621 411,949 Total deferred income taxes 1,122,303 684,028 Total income tax expense $ 3,305,660 $ 2,650,731 Income tax expense for the years ended September 30, 2020 and 2019 differed from amounts computed by applying the U.S. federal income tax rate to earnings before income taxes due to the following: Years Ended September 30 2020 2019 Income before income taxes $ 13,870,194 $ 11,349,143 Corporate federal income tax rate 21.0 % 21.0 % Income tax expense computed at the federal statutory rate $ 2,912,741 $ 2,383,320 State income taxes, net of federal income tax benefit 647,685 537,545 Net amortization of excess deferred taxes on regulated operations (162,228) (212,896) Tax benefit recognized on stock compensation (114,984) (96,499) Other, net 22,446 39,261 Total income tax expense $ 3,305,660 $ 2,650,731 The tax effects of temporary differences that give rise to the deferred tax assets and deferred tax liabilities are as follows: September 30 2020 2019 Deferred tax assets: Allowance for uncollectibles $ 180,986 $ 28,503 Accrued pension and postretirement medical benefits 651,356 782,592 Regulatory effect of change in federal income tax rate 2,814,525 2,867,383 Accrued vacation 140,635 150,882 Over-recovery of gas costs — 23,979 Cost of gas held in storage 604,962 590,495 Deferred compensation 992,605 803,979 Interest rate swaps 572,343 230,204 Rate refund — 130,063 Other 97,564 261,125 Total gross deferred tax assets 6,054,976 5,869,205 Deferred tax liabilities: Utility plant 18,310,474 18,132,022 MVP investment 1,693,075 705,193 Other 25,189 10,513 Total gross deferred tax liabilities 20,028,738 18,847,728 Net deferred tax liability $ 13,973,762 $ 12,978,523 FASB ASC No. 740 - Income Taxes provides for the determination of whether tax benefits claimed or expected to be claimed on a tax return should be recognized in the financial statements. The Company has evaluated its tax positions and accordingly has not identified any significant uncertain tax positions. The Company’s policy is to classify interest associated with uncertain tax positions as interest expense in the financial statements. Penalties are netted against other income. The Company files a consolidated federal income tax return and state income tax returns in Virginia and West Virginia. The federal returns and the state returns for both Virginia and West Virginia for the tax years ended prior to September 30, 2017 are no longer subject to examination.

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
Employee Benefit Plans	Sep. 30, 2020
Retirement Benefits [Abstract]
Employee Benefit Plans	EMPLOYEE BENEFIT PLANS The Company sponsors both a noncontributory pension plan and a postretirement plan. The pension plan covers all employees hired prior to January 2017 and benefits fully vest after 5 years of credited service. Benefits paid to retirees are based on age at retirement, years of service and average compensation. Effective January 1, 2017, a "soft freeze" to the pension plan was implemented, and employees hired on or after that date are no longer eligible to participate. Commensurate with the "soft freeze" in the pension plan, the Company amended its 401(k) Plan, allowing management to authorize a discretionary contribution to the 401(k) account for those employees hired on or after January 1, 2017. The amount, if any, of this discretionary contribution would be determined each year and would be applied to the eligible employees at the end of the calendar year. This Company contribution would be in addition to any employee elected deferrals and employer match as provided for under the 401(k) Plan. The postretirement plan provides certain health care, supplemental retirement and life insurance benefits to retired employees who meet specific age and service requirements. Employees hired prior to January 1, 2000 are eligible to participate in the postretirement plan. Employees must have a minimum of 10 years of service and retire after attaining the age of 55 in order to vest in the postretirement plan. Retiree contributions to the plan are based on the number of years of service to the Company as determined under the pension plan. Employers who sponsor defined benefit plans must recognize the funded status of defined benefit pension and other postretirement plans as an asset or liability in their statements of financial position and recognize changes in that funded status in the year in which the changes occur through comprehensive income. For pension plans, the benefit obligation is the projected benefit obligation, and for other postretirement plans, the benefit obligation is the accumulated benefit obligation. The Company established a regulatory asset for the portion of the obligation expected to be recovered in rates in future periods. The regulatory asset is adjusted for the recognition of actuarial gains and losses. The portion of the obligation attributable to the unregulated operations of the holding company is recognized in other comprehensive income. The following tables set forth the benefit obligation, fair value of plan assets, the funded status of the plans, amounts recognized in the Company’s consolidated financial statements and the assumptions used: Pension Plan Postretirement Plan 2020 2019 2020 2019 Accumulated benefit obligation $ 34,821,069 $ 30,927,973 $ 17,925,409 $ 18,030,399 Change in benefit obligation: Benefit obligation at beginning of year $ 35,550,987 $ 28,850,299 $ 18,030,399 $ 16,207,322 Service cost 691,602 537,268 167,879 132,882 Interest cost 1,062,227 1,166,728 531,480 648,944 Actuarial loss (gain) 3,620,400 5,901,915 (325,269) 1,530,522 Benefit payments, net of retiree contributions (927,214) (905,223) (479,080) (489,271) Benefit obligation at end of year $ 39,998,002 $ 35,550,987 $ 17,925,409 $ 18,030,399 Change in fair value of plan assets: Fair value of plan assets at beginning of year $ 33,586,671 $ 28,184,697 $ 13,082,610 $ 12,924,957 Actual return on plan assets, net of taxes 4,198,174 3,907,197 1,112,723 346,924 Employer contributions 800,000 2,400,000 400,000 300,000 Benefit payments, net of retiree contributions (927,214) (905,223) (479,080) (489,271) Fair value of plan assets at end of year $ 37,657,631 $ 33,586,671 $ 14,116,253 $ 13,082,610 Funded status $ (2,340,371) $ (1,964,316) $ (3,809,156) $ (4,947,789) Amounts recognized in the consolidated balance sheet consist of: Noncurrent liabilities $ (2,340,371) $ (1,964,316) $ (3,809,156) $ (4,947,789) Amounts recognized in accumulated other comprehensive loss: Net actuarial loss, net of tax $ 1,181,744 $ 1,047,063 $ 614,987 $ 777,717 Total amounts included in other comprehensive loss, net of tax $ 1,181,744 $ 1,047,063 $ 614,987 $ 777,717 Amounts deferred to a regulatory asset: Net actuarial loss $ 6,977,944 $ 6,356,201 $ 2,755,333 $ 3,661,168 Amounts recognized as regulatory assets $ 6,977,944 $ 6,356,201 $ 2,755,333 $ 3,661,168 The Company expects that approximately $80,000 before tax, of AOCI will be recognized in net periodic benefit costs in fiscal 2021 and approximately $577,000 of amounts deferred as regulatory assets will be amortized and recognized in net periodic benefit costs in fiscal 2021. The following table details the actuarial assumptions used in determining the projected benefit obligations and net benefit cost of the pension and the accumulated benefit obligations and net benefit cost of the postretirement plan: Pension Plan Postretirement Plan 2020 2019 2020 2019 Assumptions used to determine benefit obligations: Discount rate 2.47 % 3.03 % 2.44 % 3.00 % Expected rate of compensation increase 4.00 % 4.00 % N/A N/A Assumptions used to determine benefit costs: Discount rate 3.03 % 4.11 % 3.00 % 4.09 % Expected long-term rate of return on plan assets 5.50 % 5.50 % 4.26 % 4.30 % Expected rate of compensation increase 4.00 % 4.00 % N/A N/A To develop the expected long-term rate of return on assets assumption, the Company, with input from the Plans' actuaries and investment advisors, considered the historical returns and the future expectations for returns for each asset class, as well as the target asset allocation of each plan’s portfolio. Components of net periodic benefit cost are as follows: Pension Plan Postretirement Plan 2020 2019 2020 2019 Service cost $ 691,602 $ 537,268 $ 167,879 $ 132,882 Interest cost 1,062,227 1,166,728 531,480 648,944 Expected return on plan assets (1,836,623) (1,549,437) (550,394) (547,218) Recognized loss 455,744 158,599 237,371 123,805 Net periodic benefit cost $ 372,950 $ 313,158 $ 386,336 $ 358,413 Service cost is included in operation and maintenance expense of the consolidated income statement. All other components of net periodic benefit costs are included in the other income, net line. The assumed health care cost trend rates used in measuring the accumulated benefit obligation for the postretirement plan are presented below: Pre 65 Post 65 2020 2019 2020 2019 Health care cost trend rate assumed for next year 7.00 % 7.00 % 5.20 % 5.20 % Rate to which the cost trend is assumed to decline (the ultimate trend rate) 5.50 % 5.50 % 5.20 % 5.20 % Year that the rate reaches the ultimate trend rate 2023 2022 2020 2019 The health care cost trend rate assumptions could have a significant effect on the amounts reported. A change of 1% would have the following effects: 1% Increase 1% Decrease Effect on total service and interest cost components $ 132,000 $ (105,000) Effect on accumulated postretirement benefit obligation 3,042,000 (2,454,000) The primary objectives of both plans' investment policies are to maintain investment portfolios that diversify risk through prudent asset allocation parameters, achieve asset returns that meet or exceed the corresponding actuarial assumptions, achieve asset returns that are competitive with like institutions employing similar investment strategies and meet expected future benefits in both the short-term and long-term. In 2020, the Company revised its targeted pension plan investment allocation by rebalancing the assets from a 40% equity allocation to a 30% equity allocation. This change in investment allocation corresponds with the Company's strategy to continue to match the duration of the pension plan's assets with its liabilities. This change in investment allocation will continue to reduce investment risk and volatility in asset performance while providing for some asset growth. As a result, the Company's assumed long- term rate of return on pension assets for fiscal 2021 was adjusted down to 5.4%. The investment policy continues to provide for a range of investment allocations to allow for continued flexibility in responding to market conditions. The Company’s target and actual asset allocation in the pension and postretirement plans as of September 30, 2020 and 2019 were: Pension Plan Postretirement Plan Target 2020 2019 Target 2020 2019 Asset category: Equity securities 30 % 30 % 40 % 50 % 51 % 49 % Debt securities 70 % 69 % 59 % 50 % 48 % 50 % Cash — % 1 % 1 % — % 1 % 1 % Other — % — % — % — % — % — % The assets of the plans are invested in mutual funds. The Company uses the fair value hierarchy described in Note 1 to classify these assets. The mutual funds are included under Level 1 in the fair value hierarchy as their fair values are determined based on individual prices for each security that comprises the mutual funds. The common and collective trust funds are included under Level 2. The following tables contains the fair value classifications of the plans' assets: Pension Plan Fair Value Level 1 Level 2 Level 3 Asset Class: Cash $ 339,287 $ 339,287 $ — $ — Common and Collective Trust and Pooled Funds: Bonds Liability Driven Investment 26,038,966 — 26,038,966 — Equities Domestic Large Cap Growth 3,462,841 — 3,462,841 — Domestic Large Cap Value 3,351,694 — 3,351,694 — Domestic Small/Mid Cap Core 1,665,005 — 1,665,005 — Foreign Large Cap Value 1,473,427 — 1,473,427 — Mutual Funds: Equities Foreign Large Cap Growth 1,047,274 1,047,274 — — Foreign Large Cap Value 279,137 279,137 — — Total $ 37,657,631 $ 1,665,698 $ 35,991,933 $ — Pension Plan Fair Value Level 1 Level 2 Level 3 Asset Class: Cash $ 371,780 $ 371,780 $ — $ — Common and Collective Trust and Pooled Funds: Bonds Liability Driven Investment 19,702,561 — 19,702,561 — Equities Domestic Large Cap Growth 4,069,197 — 4,069,197 — Domestic Large Cap Value 4,055,518 — 4,055,518 — Domestic Small/Mid Cap Core 2,032,084 — 2,032,084 — Foreign Large Cap Value 1,783,990 — 1,783,990 — Mutual Funds: Equities Foreign Large Cap Growth 1,227,981 1,227,981 — — Foreign Large Cap Value 343,560 343,560 — — Total $ 33,586,671 $ 1,943,321 $ 31,643,350 $ — Postretirement Plan Fair Value Level 1 Level 2 Level 3 Asset Class: Cash $ 73,908 $ 73,908 $ — $ — Mutual Funds Bonds Domestic Fixed Income 6,163,808 6,163,808 — — Foreign Fixed Income 638,709 638,709 — — Equities Domestic Large Cap Growth 2,197,839 2,197,839 — — Domestic Large Cap Value 2,119,433 2,119,433 — — Domestic Small/Mid Cap Growth 262,726 262,726 — — Domestic Small/Mid Cap Value 235,216 235,216 — — Domestic Small/Mid Cap Core 552,607 552,607 — — Foreign Large Cap Growth 548,967 548,967 — — Foreign Large Cap Value 1,224,420 1,224,420 — — Foreign Large Cap Core 77,471 77,471 — — Other 21,149 — 21,149 — Total $ 14,116,253 $ 14,095,104 $ 21,149 $ — Postretirement Plan Fair Value Level 1 Level 2 Level 3 Asset Class: Cash $ 66,860 $ 66,860 $ — $ — Mutual Funds Bonds Domestic Fixed Income 5,987,248 5,987,248 — — Foreign Fixed Income 611,196 611,196 — — Equities Domestic Large Cap Growth 1,909,836 1,909,836 — — Domestic Large Cap Value 1,931,615 1,931,615 — — Domestic Small/Mid Cap Growth 210,251 210,251 — — Domestic Small/Mid Cap Value 214,034 214,034 — — Domestic Small/Mid Cap Core 464,526 464,526 — — Foreign Large Cap Growth 489,286 489,286 — — Foreign Large Cap Value 1,098,992 1,098,992 — — Foreign Large Cap Core 70,782 70,782 — — Other 27,984 — 27,984 — Total $ 13,082,610 $ 13,054,626 $ 27,984 $ — Each mutual fund or common collective trust fund has been categorized based on its primary investment strategy. The Company expects to contribute $500,000 to its pension plan and $400,000 to its postretirement plan in fiscal 2021. The following table reflects expected future benefit payments: Fiscal year ending September 30 Pension Postretirement 2021 $ 1,043,787 $ 568,170 2022 1,133,470 605,966 2023 1,221,341 666,049 2024 1,320,157 678,659 2025 1,416,485 684,989 2026-2030 8,355,472 3,637,984 The Company sponsors a 401k Plan covering all employees who elect to participate. Employees may contribute from 1% to 50% of their annual compensation to the 401k Plan, limited to a maximum annual amount as set periodically by the IRS. The Company matches 100% of the participant’s first 4% of contributions and 50% on the next 2% of contributions. The Company also provided discretionary contributions for those employees hired on or after January 1, 2017. The following table reflects the Company's contributions: Years Ended September 30, 2020 2019 Matching contribution $ 364,773 $ 348,369 Discretionary contribution 18,313 21,829

Common Stock Options

Common Stock Options	12 Months Ended
Common Stock Options	Sep. 30, 2020
Share-based Payment Arrangement [Abstract]
Common Stock Options	COMMON STOCK OPTIONS The KESOP provides for the issuance of common stock options to officers and certain other full-time salaried employees to acquire shares of the Company’s common stock. As of September 30, 2020, the number of shares available for future grants was 23,000. FASB ASC No. 718 - Compensation - Stock Compensation requires that compensation expense be recognized for the issuance of equity instruments to employees. During the fiscal year ended 2020, the Board approved stock option grants to certain officers. As required by the KESOP, each option's exercise price per share equaled the fair value of the Company's common stock on the grant date. Pursuant to the plan, the options vest over a six-month period and are exercisable over a ten-year period from the date of issuance. As the Company's stock options are not traded on the open market, the fair value of each grant is estimated on the date of grant using the Black-Scholes option pricing model including the following assumptions: Years Ended September 30, 2020 2019 Expected volatility 31.53% N/A Expected dividends 2.74% N/A Expected exercise term (years) 7.00 N/A Risk-free interest rate 0.51% N/A The underlying methods regarding each assumption are as follows: Expected volatility is based on the historical volatility of the daily closing price of the Company's common stock. Expected dividend rate is based on historical dividend payout trends. Expected exercise term is based on the average time historical option grants were outstanding before being exercised. Risk-free interest rate is based on the 7-year Treasury rate on the date of option grant. Forfeitures are recognized when they occur. Stock option transactions under the Company's plans are summarized below. Number of Shares Weighted- Average Exercise Price Weighted- Average Remaining Contractual Terms (years) Aggregate Intrinsic Value 1 Options outstanding, September 30, 2018 100,000 14.34 6.6 1,237,286 Options granted — — Options exercised (31,508) 13.08 Options expired — — Options forfeited — — Options outstanding, September 30, 2019 68,492 14.91 6.2 981,170 Options granted 13,000 27.87 Options exercised (29,992) 14.65 Options expired — — Options forfeited — — Options outstanding, September 30, 2020 51,500 $ 18.34 6.4 $ 320,797 Vested and exercisable at September 30, 2020 51,500 $ 18.34 6.4 $ 320,797 1 Aggregate intrinsic value includes only those options where the exercise price is below the market price. Years Ended September 30, 2020 2019 Weighted-average grant date option fair value $ 6.26 $ — Stock option expense 81,380 — Intrinsic value of options exercised 411,638 456,002 Proceeds from exercise of stock options 439,509 412,179 Dividend Reinvestment and Stock Purchase Plan The Company offers a DRIP Plan to shareholders of record for the reinvestment of dividends and the purchase of up to $100,000 per year in additional shares of common stock of the Company. Under the DRIP, the Company issued 28,191 and 26,716 shares in 2020 and 2019, respectively. As of September 30, 2020, the Company had 362,322 shares of stock available for issuance under the DRIP. Restricted Stock Plan for Outside Directors The Board of Directors of the Company implemented the RSPD in 1997. Under the RSPD, each director may elect annually to have up to 100% of his or her fees paid in shares of common stock ("Director Restricted Stock"); however, a minimum of 40% of the monthly retainer fee must be paid to each non-employee director of Resources in shares of Director Restricted Stock until such time as the director has accumulated at least 10,000 shares. The number of shares of Director Restricted Stock awarded each month is determined based on the closing sales price of Resources' common stock on the NASDAQ Global Market on the first business day of the month. The Director Restricted Stock issued under the Plan vests only in the case of a participant's death, disability, retirement, or in the event of a change in control of Resources. The Director Restricted Stock may not be sold, transferred, assigned or pledged by the participant until the shares have vested under the terms of the Plan. The shares of Director Restricted Stock will be forfeited to Resources by a participant's voluntary resignation during his or her term on the Board or removal for cause as a director. The Company assumes all directors will complete their term and there will be no forfeiture of the Director Restricted Stock. Since the inception of the RSPD, no director has forfeited any shares of Director Restricted Stock. The Company recognizes as compensation the market value of the Director Restricted Stock in the period it is issued. The following table reflects the director compensation activity pursuant to the Plan: 2020 2019 Shares Weighted-Average Fair Value on Date of Grant Shares Weighted-Average Fair Value on Date of Grant Beginning of year balance 104,680 $ 12.51 98,302 $ 11.51 Granted 9,193 26.28 6,378 27.93 Vested (14,803) 10.68 — — Forfeited — — — — End of year balance 99,070 $ 14.06 104,680 $ 12.51 The fair market value of the Director Restricted Stock included in compensation during fiscal 2020 and 2019 was $241,617 and $178,100, respectively. No Director Restricted Stock was forfeited during fiscal 2020 or 2019. As of September 30, 2020, the Company had 52,029 shares available for issuance under the RSPD. RGC Resources, Inc. Restricted Stock Plan The Board of Directors of the Company implemented the RSPO in 2017 following approval by the shareholders at the Company's annual meeting held in February 2017. Under the RSPO, the Compensation Committee of the Board of Directors may grant shares of common stock ("Officer Restricted Stock") that vest over time to key employees and officers for the purpose of attracting and retaining those individuals essential to the operation and growth of the Company. The RSPO provides for certain restrictions and non-transferability requirements until minimum levels of ownership are obtained. Such restrictions may continue beyond the vesting period. The Company assumes all officers will complete their requirements and there will be no forfeiture of the Officer Restricted Stock. The following table reflects the officer compensation activity pursuant to the RSPO: 2020 2019 Shares Weighted-Average Fair Value on Date of Grant Shares Weighted-Average Fair Value on Date of Grant Beginning of year balance 10,185 $ 28.65 6,734 $ 26.33 Granted 14,951 28.17 10,227 29.80 Vested (18,321) 28.30 (6,776) 28.08 Forfeited — — — — End of year balance 6,815 $ 28.55 10,185 $ 28.65 The fair market value of the Officer Restricted Stock included as compensation during fiscal 2020 and 2019 was $450,677 and $282,365, respectively. As of September 30, 2020, the Company had 413,718 shares available for issuance under the RSPO. Stock Bonus Plan Shares from the Stock Bonus Plan may be issued to certain employees and management personnel in recognition of their performance and service. Under the Stock Bonus Plan, the Company issued no shares in 2020 and 2019. As of September 30, 2020 the Company had 4,785 shares of stock available for issuance under the Stock Bonus Plan. The Stock Bonus Plan is currently inactive.

Other Stock Plans

Other Stock Plans	12 Months Ended
Other Stock Plans	Sep. 30, 2020
Share-based Payment Arrangement [Abstract]
Other Stock Plans	COMMON STOCK OPTIONS The KESOP provides for the issuance of common stock options to officers and certain other full-time salaried employees to acquire shares of the Company’s common stock. As of September 30, 2020, the number of shares available for future grants was 23,000. FASB ASC No. 718 - Compensation - Stock Compensation requires that compensation expense be recognized for the issuance of equity instruments to employees. During the fiscal year ended 2020, the Board approved stock option grants to certain officers. As required by the KESOP, each option's exercise price per share equaled the fair value of the Company's common stock on the grant date. Pursuant to the plan, the options vest over a six-month period and are exercisable over a ten-year period from the date of issuance. As the Company's stock options are not traded on the open market, the fair value of each grant is estimated on the date of grant using the Black-Scholes option pricing model including the following assumptions: Years Ended September 30, 2020 2019 Expected volatility 31.53% N/A Expected dividends 2.74% N/A Expected exercise term (years) 7.00 N/A Risk-free interest rate 0.51% N/A The underlying methods regarding each assumption are as follows: Expected volatility is based on the historical volatility of the daily closing price of the Company's common stock. Expected dividend rate is based on historical dividend payout trends. Expected exercise term is based on the average time historical option grants were outstanding before being exercised. Risk-free interest rate is based on the 7-year Treasury rate on the date of option grant. Forfeitures are recognized when they occur. Stock option transactions under the Company's plans are summarized below. Number of Shares Weighted- Average Exercise Price Weighted- Average Remaining Contractual Terms (years) Aggregate Intrinsic Value 1 Options outstanding, September 30, 2018 100,000 14.34 6.6 1,237,286 Options granted — — Options exercised (31,508) 13.08 Options expired — — Options forfeited — — Options outstanding, September 30, 2019 68,492 14.91 6.2 981,170 Options granted 13,000 27.87 Options exercised (29,992) 14.65 Options expired — — Options forfeited — — Options outstanding, September 30, 2020 51,500 $ 18.34 6.4 $ 320,797 Vested and exercisable at September 30, 2020 51,500 $ 18.34 6.4 $ 320,797 1 Aggregate intrinsic value includes only those options where the exercise price is below the market price. Years Ended September 30, 2020 2019 Weighted-average grant date option fair value $ 6.26 $ — Stock option expense 81,380 — Intrinsic value of options exercised 411,638 456,002 Proceeds from exercise of stock options 439,509 412,179 Dividend Reinvestment and Stock Purchase Plan The Company offers a DRIP Plan to shareholders of record for the reinvestment of dividends and the purchase of up to $100,000 per year in additional shares of common stock of the Company. Under the DRIP, the Company issued 28,191 and 26,716 shares in 2020 and 2019, respectively. As of September 30, 2020, the Company had 362,322 shares of stock available for issuance under the DRIP. Restricted Stock Plan for Outside Directors The Board of Directors of the Company implemented the RSPD in 1997. Under the RSPD, each director may elect annually to have up to 100% of his or her fees paid in shares of common stock ("Director Restricted Stock"); however, a minimum of 40% of the monthly retainer fee must be paid to each non-employee director of Resources in shares of Director Restricted Stock until such time as the director has accumulated at least 10,000 shares. The number of shares of Director Restricted Stock awarded each month is determined based on the closing sales price of Resources' common stock on the NASDAQ Global Market on the first business day of the month. The Director Restricted Stock issued under the Plan vests only in the case of a participant's death, disability, retirement, or in the event of a change in control of Resources. The Director Restricted Stock may not be sold, transferred, assigned or pledged by the participant until the shares have vested under the terms of the Plan. The shares of Director Restricted Stock will be forfeited to Resources by a participant's voluntary resignation during his or her term on the Board or removal for cause as a director. The Company assumes all directors will complete their term and there will be no forfeiture of the Director Restricted Stock. Since the inception of the RSPD, no director has forfeited any shares of Director Restricted Stock. The Company recognizes as compensation the market value of the Director Restricted Stock in the period it is issued. The following table reflects the director compensation activity pursuant to the Plan: 2020 2019 Shares Weighted-Average Fair Value on Date of Grant Shares Weighted-Average Fair Value on Date of Grant Beginning of year balance 104,680 $ 12.51 98,302 $ 11.51 Granted 9,193 26.28 6,378 27.93 Vested (14,803) 10.68 — — Forfeited — — — — End of year balance 99,070 $ 14.06 104,680 $ 12.51 The fair market value of the Director Restricted Stock included in compensation during fiscal 2020 and 2019 was $241,617 and $178,100, respectively. No Director Restricted Stock was forfeited during fiscal 2020 or 2019. As of September 30, 2020, the Company had 52,029 shares available for issuance under the RSPD. RGC Resources, Inc. Restricted Stock Plan The Board of Directors of the Company implemented the RSPO in 2017 following approval by the shareholders at the Company's annual meeting held in February 2017. Under the RSPO, the Compensation Committee of the Board of Directors may grant shares of common stock ("Officer Restricted Stock") that vest over time to key employees and officers for the purpose of attracting and retaining those individuals essential to the operation and growth of the Company. The RSPO provides for certain restrictions and non-transferability requirements until minimum levels of ownership are obtained. Such restrictions may continue beyond the vesting period. The Company assumes all officers will complete their requirements and there will be no forfeiture of the Officer Restricted Stock. The following table reflects the officer compensation activity pursuant to the RSPO: 2020 2019 Shares Weighted-Average Fair Value on Date of Grant Shares Weighted-Average Fair Value on Date of Grant Beginning of year balance 10,185 $ 28.65 6,734 $ 26.33 Granted 14,951 28.17 10,227 29.80 Vested (18,321) 28.30 (6,776) 28.08 Forfeited — — — — End of year balance 6,815 $ 28.55 10,185 $ 28.65 The fair market value of the Officer Restricted Stock included as compensation during fiscal 2020 and 2019 was $450,677 and $282,365, respectively. As of September 30, 2020, the Company had 413,718 shares available for issuance under the RSPO. Stock Bonus Plan Shares from the Stock Bonus Plan may be issued to certain employees and management personnel in recognition of their performance and service. Under the Stock Bonus Plan, the Company issued no shares in 2020 and 2019. As of September 30, 2020 the Company had 4,785 shares of stock available for issuance under the Stock Bonus Plan. The Stock Bonus Plan is currently inactive.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
Commitments and Contingencies	Sep. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES Long-Term Contracts Due to the nature of the natural gas distribution business, Roanoke Gas enters into agreements with both suppliers and pipelines to contract for natural gas commodity purchases, storage capacity and pipeline delivery capacity. Roanoke Gas obtains most of its regulated natural gas supply through an asset management contract with a third party asset manager. Roanoke Gas utilizes an asset manager to optimize the use of its transportation, storage rights, and gas supply inventories which helps to ensure a secure and reliable source of natural gas. Under the current asset management contract, Roanoke Gas has designated the asset manager to act as agent for its storage capacity and all gas balances in storage. Roanoke Gas retains ownership of gas in storage. Under provisions of this contract, Roanoke Gas is obligated to purchase its winter storage requirements from the asset manager during the spring and summer injection periods at market price. The table below details the volumetric obligations as of September 30, 2020 for the remainder of the contract period. The current asset management contract was renewed in July 2020 for a one year period which will expire in March 2022. The contract was renewed at essentially the same terms and conditions as the prior agreement, except the utilization fee retained by Roanoke Gas was reduced. Year Natural Gas Contracts 2020-2021 2,090,972 2021-2022 295,866 Total 2,386,838 In addition to the volumetric commitment above, the Company also has a fixed price agreement to purchase approximately 1.3 million dth, from October 2020 to March 2021, at prices ranging from $2.17 to $2.62 per dth. Roanoke Gas also has contracts for pipeline and storage capacity which extend for various periods. These capacity costs and related fees are valued at tariff rates in place as of September 30, 2020. These rates may increase or decrease in the future based upon rate filings and rate orders granting a rate change to the pipeline or storage operator. Roanoke Gas expended approximately $21,881,000 and $30,317,000 under the asset management, pipeline and storage contracts in fiscal years 2020 and 2019, respectively. The table below details the pipeline and storage capacity commitments as of September 30, 2020 for the remainder of the contract period. Year Pipeline and 2020-2021 $ 11,048,798 2021-2022 10,284,092 2022-2023 7,403,271 2023-2024 5,743,826 2024-2025 3,167,937 Thereafter 888,426 Total $ 38,536,350 Roanoke Gas maintains franchise agreements granted by the local cities and towns served by the Company. Roanoke Gas renewed its franchise agreements with the City of Roanoke, the City of Salem and the Town of Vinton in 2016 for 20-year terms to expire in December 2035. Per these agreements, franchise fees increase at a rate of 3% annually throughout the term of the agreements. As of September 30, 2020, $2,294,588 in future obligations remain under the franchise agreements. Other Contracts The Company maintains other agreements in the ordinary course of business covering various lease, maintenance, equipment and service contracts. These agreements currently extend through December 2031 and are not material to the Company. Legal From time to time, the Company may become involved in litigation or claims arising out of its operations in the normal course of business. At the current time, the Company is not known to be a party to any legal proceedings that would be expected to have a materially adverse impact on its financial position, results of operations or cash flows. Environmental Matters Roanoke Gas operated an MGP as a source of fuel for lighting and heating until the early 1950’s. A by-product of operating the MGP was coal tar, and the potential exists for tar waste contaminants at the former plant site. While the Company does not currently recognize any commitments or contingencies related to environmental costs, should the Company ever be required to remediate the site, it will pursue all prudent and reasonable means to recover any related costs, including the use of insurance claims and regulatory approval for rate case recognition of expenses associated with any work required.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
Fair Value Measurements	Sep. 30, 2020
Fair Value Disclosures [Abstract]
Fair Value Measurements	FAIR VALUE MEASUREMENTS The following table summarizes the Company’s financial assets and liabilities that are measured at fair value on a recurring basis and the fair value measurements by level within the fair value hierarchy as defined in Note 1 as of September 30, 2020 and 2019, respectively: Fair Value Measurements - September 30, 2020 Fair Value Quoted Prices in Significant Other Significant Liabilities: Natural gas purchases $ 470,755 $ — $ 470,755 $ — Interest rate swaps 2,223,556 — 2,223,556 — Total $ 2,694,311 $ — $ 2,694,311 $ — Fair Value Measurements - September 30, 2019 Fair Value Quoted Prices in Significant Other Significant Liabilities: Natural gas purchases $ 397,757 $ — $ 397,757 $ — Interest rate swaps 894,341 — 894,341 — Total $ 1,292,098 $ — $ 1,292,098 $ — 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 the weighted average first of the month index prices corresponding to the month of the scheduled payment. At September 30, 2020 and 2019, the Company had recorded in accounts payable the estimated fair value of the liability determined on the corresponding first of month index prices for which the liability was expected to be settled. The Company’s non-financial assets and liabilities that are measured at fair value on a nonrecurring basis consist of its asset retirement obligations. The asset retirement obligations are measured at fair value at initial recognition based on expected future cash flows to settle the obligation. The carrying value of cash and cash equivalents, accounts receivable, borrowings under line-of-credit, accounts payable (with the exception of the timing difference under the asset management contract), customer credit balances and customer deposits is a reasonable estimate of fair value due to the shorter-term nature of these financial instruments. The following table summarizes the fair value of the Company’s financial assets and liabilities that are not adjusted to fair value in the consolidated financial statements as of September 30, 2020 and 2019. Fair Value Measurements - September 30, 2020 Carrying Quoted Prices in Significant Other Significant Liabilities: Notes payable $ 114,975,200 $ — $ — $ 124,740,970 Total $ 114,975,200 $ — $ — $ 124,740,970 Fair Value Measurements - September 30, 2019 Carrying Quoted Prices in Significant Other Significant 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 20-year Treasury rate or other Treasury instrument 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. The Company maintains certain credit standards with its customers and requires a customer deposit if such evaluation warrants.

Quarterly Financial Information

Quarterly Financial Information (Unaudited)	12 Months Ended
Quarterly Financial Information (Unaudited)	Sep. 30, 2020
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Information (Unaudited)	QUARTERLY FINANCIAL INFORMATION (UNAUDITED) Quarterly financial data for the years ended September 30, 2020 and 2019 is summarized as follows: 2020 First Second Third Fourth Operating revenues $ 19,785,453 $ 22,437,731 $ 11,071,918 $ 9,780,289 Operating income (loss) $ 5,081,979 $ 6,999,616 $ 1,335,663 $ (899,076) Net income (loss) $ 4,006,936 $ 5,680,316 $ 1,206,578 $ (329,296) Earnings (loss) per share of common stock: Basic $ 0.50 $ 0.70 $ 0.15 $ (0.04) Diluted $ 0.49 $ 0.70 $ 0.15 $ (0.04) 2019 First Second Third Fourth Operating revenues $ 21,216,747 $ 25,274,959 $ 11,682,950 $ 9,851,869 Operating income $ 3,264,222 $ 6,203,483 $ 1,637,057 $ 490,702 Net income $ 2,434,162 $ 4,670,090 $ 1,138,555 $ 455,605 Earnings per share of common stock: Basic $ 0.30 $ 0.58 $ 0.14 $ 0.06 Diluted $ 0.30 $ 0.58 $ 0.14 $ 0.06

Subsequent Events

Subsequent Events	12 Months Ended
Subsequent Events	Sep. 30, 2020
Subsequent Events [Abstract]
Subsequent Events	SUBSEQUENT EVENTSThe Company has evaluated subsequent events through the date the financial statements were issued. There were no other items not otherwise disclosed which would have materially impacted the Company’s consolidated financial statements.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
Summary of Significant Accounting Policies (Policies)	Sep. 30, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidation	Principles of Consolidation —RGC Resources, Inc. is an energy services company primarily engaged in the sale and distribution of natural gas. The consolidated financial statements include the accounts of Resources and its wholly owned subsidiaries: Roanoke Gas, Diversified Energy and Midstream. Roanoke Gas is a natural gas utility, which distributes and sells natural gas to approximately 62,000 residential, commercial and industrial customers within its service areas in Roanoke, Virginia and the surrounding localities. The Company’s business is seasonal in nature as a majority of natural gas sales are for space heating during the winter season. Roanoke Gas is regulated by the SCC. Midstream is a wholly-owned subsidiary created primarily to invest in the Mountain Valley Pipeline project. Diversified Energy is inactive. The Company follows accounting and reporting standards established by the FASB and the SEC. Under the rules for smaller reporting companies, certain disclosures previously required are reduced or eliminated. As it has met the qualifications under the definition of smaller reporting company, the Company has used the smaller reporting company exceptions.
Rate Regulated Basis of Accounting	Rate Regulated Basis of Accounting —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.
Utility Plant and Depreciation	Utility Plant and Depreciation —Utility plant is stated at original cost and includes direct labor and materials, contractor costs, and all allocable overhead charges. The Company applies the group method of accounting, where the costs of like assets are aggregated and depreciated by applying a rate based on the average expected useful life of the assets. In accordance with Company policy, expenditures for depreciable assets with a life greater than one year are capitalized, along with any upgrades or improvements to existing assets, when they significantly improve or extend the original expected useful life of an asset. Expenditures for maintenance, repairs, and minor renewals and betterments are expensed as incurred. The original cost of depreciable property retired is removed from utility plant and charged to accumulated depreciation. The cost of asset removals, less salvage, is charged to “regulatory cost of retirement obligations” or “asset retirement obligations” as explained under Asset Retirement Obligations below. Utility plant is composed of the following major classes of assets: September 30 2020 2019 Distribution and transmission $ 227,753,620 $ 209,171,339 LNG storage 14,798,453 13,417,077 General and miscellaneous 15,790,299 15,198,548 Total utility plant in service $ 258,342,372 $ 237,786,964 Provisions for depreciation are computed principally at composite straight-line rates over a range of periods. Rates are determined by depreciation studies which are required to be performed at least every 5 years on the regulated utility assets of Roanoke Gas. In September 2019, the SCC staff approved the Company's most recent depreciation study. The SCC directed the Company to implement the new rates retroactive to October 1, 2018. As a result of the new rates, the composite weighted-average depreciation rate was 3.30% and 3.31% for the years ended September 30, 2020 and 2019, respectively. The implementation of the new depreciation rates reduced total depreciation expense by $32,570 for fiscal 2019 and increased net income by $24,187 or less than $0.01 per share. The composite rates are composed of two components, one based on average service life and one based on cost of retirement. As a result, the Company accrues the estimated cost of retirement of long-lived assets through depreciation expense. These retirement costs are not a legal obligation but rather the result of cost-based regulation and are accounted for under the provisions of FASB ASC No. 980. Such amounts are classified as a regulatory liability. The Company reviews long-lived assets and certain identifiable intangibles for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. These reviews have not identified any impairments which would have a material effect on the results of operations or financial condition. In fiscal 2020, Roanoke Gas implemented the application of AFUDC related to infrastructure investments associated with two gate stations that will interconnect with the MVP. This treatment allows capitalizing both the equity and debt financing costs during the construction phases. For the year ended September 30, 2020, the Company capitalized $81,629 of debt financing costs and $248,579 of equity financing costs, thereby affecting the interest expense and other income, net lines, respectively, of the related consolidated statements of income. See Note 3 for further information.
Asset Retirement Obligations	Asset Retirement Obligations —FASB ASC No. 410, Asset Retirement and Environmental Obligations , requires entities to record the fair value of a liability for an ARO when there exists a legal obligation for the retirement of the asset. When the liability is initially recorded, the entity capitalizes the cost, thereby increasing the carrying amount of the underlying asset. In subsequent periods, the liability is accreted, and the capitalized cost is depreciated over the useful life of the underlying asset. The Company has recorded AROs for its future legal obligations related to purging and capping its distribution mains and services upon retirement, although the timing of such retirements is uncertain.
Cash, Cash Equivalents and Short-Term Investments	Cash, Cash Equivalents and Short-Term Investments —From time to time, the Company will have balances on deposit at banks in excess of the amount insured by the FDIC. The Company has not experienced any losses on these accounts and does not consider these amounts to be at credit risk. As of September 30, 2020, the Company did not have any bank deposits in excess of the FDIC insurance limits. For purposes of the consolidated statements of cash flows, the Company considers all highly liquid debt instruments purchased with an original maturity of three months or less to be cash equivalents.
Customer Receivables and Allowance for Doubtful Accounts	Customer Receivables and Allowance for Doubtful Accounts —Accounts receivable include amounts billed to customers for natural gas sales and related services and gas sales occurring subsequent to normal billing cycles but before the end of the period. The Company provides an estimate for losses on these receivables by utilizing historical information, current account balances, account aging and current economic conditions. Customer accounts are charged off annually when deemed uncollectible or when turned over to a collection agency for action.
Financing Receivables	Financing Receivables—Financing receivables represent a contractual right to receive money either on demand, or on fixed or determinable dates, and are recognized as assets on the entity’s balance sheet. Trade receivables, resulting from the sale of natural gas and other services to customers, are the Company's primary type of financing receivables. These receivables are short-term in nature with a provision for uncollectible balances included in the consolidated financial statements.
Inventories	Inventories —Natural gas in storage and materials and supplies inventories are recorded at average cost. Natural gas storage injections are priced at the purchase cost at the time of injection and storage withdrawals are priced at the weighted average cost of gas in storage. Materials and supplies are removed from inventory at average cost.
Unbilled Revenues	Unbilled Revenues—The Company bills its natural gas customers on a monthly cycle; however, the billing cycle period for most customers does not coincide with the accounting periods used for financial reporting. As the Company recognizes revenue when gas is delivered, an accrual is made to estimate revenues for natural gas delivered to customers but not billed during the accounting period.
Income Taxes	Income Taxes —Income taxes are accounted for using the asset and liability method. Under the asset and liability method, deferred tax assets and liabilities are recognized for the estimated future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates in effect for the years in which those temporary differences are expected to be recovered or settled. A valuation allowance against deferred tax assets is provided if it is more likely than not the deferred tax asset will not be realized. The Company and its subsidiaries file state and federal consolidated income tax returns.
Debt Expenses	Debt Expenses —Debt issuance expenses are deferred and amortized over the lives of the debt instruments. The unamortized balances are offset against the carrying value of long-term debt.
Over/Under-Recovery of Natural Gas Costs	Over/Under-Recovery of Natural Gas Costs —Pursuant to the provisions of the Company’s PGA clause, the SCC provides the Company with a method of passing along to its customers increases or decreases in natural gas costs incurred by its regulated operations, including gains and losses on natural gas derivative hedging instruments. On at least a quarterly basis, the Company files a PGA rate adjustment request with the SCC to increase or decrease the gas cost component of its rates, based 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 the projections used in establishing the PGA rate, the Company may either over-recover or under-recover its actual gas costs during the period. Any 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 deferral period, the balance of the net deferred charge or credit is amortized over an ensuing 12-month period as amounts are reflected in customer bills.
Fair Value	Fair Value —Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between willing market participants at the measurement date. The Company determines fair value based on the following fair value hierarchy which prioritizes each input to the valuation methods into one of the following three broad 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 which require the Company to develop its own assumptions. The fair value hierarchy gives the highest priority to unadjusted quoted prices in active markets (Level 1) and the lowest priority to unobservable inputs (Level 3). All fair value disclosures are categorized within one of the three categories in the hierarchy. See fair value disclosures below and in Notes 9 and 13.
Use of Estimates	Use of Estimates —The preparation of consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent 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.
Excise and Sales Taxes	Excise and Sales Taxes —Certain excise and sales taxes imposed by the state and local governments in the Company’s service territory are collected by the Company from its customers. These taxes are accounted for on a net basis and therefore are not included as revenues in the Company’s consolidated income statements.
Earnings Per Share	Earnings Per Share—Basic EPS and diluted EPS are calculated by dividing net income by the weighted-average common shares outstanding during the period and the weighted-average common shares outstanding during the period plus dilutive potential common shares, respectively. Dilutive potential common shares are calculated in accordance with the treasury stock method, which assumes that proceeds from the exercise of all options are used to repurchase common stock at market value. The amount of shares remaining after the proceeds are exhausted represents the potentially dilutive effect of the securities.
Business and Credit Concentrations	Business and Credit Concentrations — The primary business of the Company is the distribution of natural gas to residential, commercial and industrial customers in its service territories. No sales to individual customers accounted for more than 5% of total revenue in any period or amounted to more than 5% of total accounts receivable. Roanoke Gas currently holds the only franchises and CPCNs to distribute natural gas in its service area. These franchises are effective through January 1, 2036. The Company's current CPCNs in Virginia are exclusive and are intended for perpetual duration. Roanoke Gas is served directly by two primary pipelines that provide all of the natural gas supplied to the Company’s customers. Depending upon weather conditions and the level of customer demand, failure of one or both of these transmission pipelines could have a major adverse impact on the Company.
Derivative and Hedging Activities	Derivative and Hedging Activities —FASB ASC No. 815, Derivatives and Hedging , requires the recognition of all derivative instruments as assets or liabilities in the Company’s consolidated balance sheet and measurement of those instruments at fair value. The Company’s hedging and derivatives policy allows management to enter into derivatives for the purpose of managing the commodity and financial market risks of its business operations. The Company’s hedging and derivatives policy specifically prohibits the use of derivatives for speculative purposes. The key market risks that the Company may hedge against include the price of natural gas and the cost of borrowed funds.
Recently Adopted Accounting Standards and Recently Issued Accounting Standards	Recently Adopted Accounting Standards 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. Under prior GAAP, the presentation and cash flows arising from a lease by a lessee primarily depended on its classification as a finance or operating lease. 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. This lease calls for quarterly payments in the amount of $3,240 and is set to expire in September 2021. As the value of this lease obligation was determined to be de minimis and the Company has not entered into any additional lease obligations, 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 hedges 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 new guidance did not have a material effect on the Company's consolidated financial statements. Recently Issued Accounting Standards 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 affect financial position, results of operations or cash flows. In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848) - Facilitation of the Effects of Reference Rate Reform on Financial Reporting. This ASU provides temporary optional guidance to ease the potential burden in accounting for and recognizing the effects of reference rate change on financial reporting. The new guidance applies specifically to contracts and hedging relationships that reference LIBOR, or any other referenced rate that is expected to be discontinued due to reference rate reform. The new guidance is effective for the Company through December 31, 2022. Management has not yet completed its evaluation of the new guidance; however, as the Company has several contracts and hedging relationships that currently reference LIBOR, this new guidance could impact the Company's financial position, results of operations, or cash flows for the period through which the ASU is effective.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	12 Months Ended
Summary of Significant Accounting Policies (Tables)	Sep. 30, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Regulatory Assets	Regulatory assets and liabilities included in the Company’s consolidated balance sheets as of September 30, 2020 and 2019 are as follows: September 30 2020 2019 Assets: Current Assets: Regulatory assets: Accrued WNA revenues $ — $ 569,558 Under-recovery of gas costs 1,733,718 — Under-recovery of SAVE Plan revenues 108,550 — ESAC assets — 265,392 Accrued pension and postretirement medical 576,731 602,674 Other deferred expenses 84,315 84,315 Total current 2,503,314 1,521,939 Utility Property: In service: Other 11,945 11,945 Construction work in progress: AFUDC 330,208 — Other Assets: Regulatory assets: Premium on early retirement of debt 1,598,620 1,712,808 Accrued pension and postretirement medical 9,156,546 9,414,695 ESAC assets — 756,803 Other deferred expenses 214,928 294,547 Total non-current 10,970,094 12,178,853 Total regulatory assets $ 13,815,561 $ 13,712,737 Liabilities and Stockholders' Equity: Current Liabilities: Regulatory liabilities: Over-recovery of gas costs $ — $ 161,837 WNA 601,784 — Over-recovery of SAVE Plan revenues — 574,181 Rate refund — 3,827,588 Excess deferred income taxes 205,353 205,353 Other deferred liabilities 83,176 108,644 Total current 890,313 4,877,603 Deferred Credits and Other Liabilities: Asset retirement obligations 7,180,982 6,788,683 Regulatory cost of retirement obligations 12,678,043 11,892,352 Regulatory liabilities: Excess deferred income taxes 10,729,082 10,934,434 Total non-current $ 30,588,107 $ 29,615,469 Total regulatory liabilities $ 31,478,420 $ 34,493,072
Schedule of Regulatory Liabilities	Regulatory assets and liabilities included in the Company’s consolidated balance sheets as of September 30, 2020 and 2019 are as follows: September 30 2020 2019 Assets: Current Assets: Regulatory assets: Accrued WNA revenues $ — $ 569,558 Under-recovery of gas costs 1,733,718 — Under-recovery of SAVE Plan revenues 108,550 — ESAC assets — 265,392 Accrued pension and postretirement medical 576,731 602,674 Other deferred expenses 84,315 84,315 Total current 2,503,314 1,521,939 Utility Property: In service: Other 11,945 11,945 Construction work in progress: AFUDC 330,208 — Other Assets: Regulatory assets: Premium on early retirement of debt 1,598,620 1,712,808 Accrued pension and postretirement medical 9,156,546 9,414,695 ESAC assets — 756,803 Other deferred expenses 214,928 294,547 Total non-current 10,970,094 12,178,853 Total regulatory assets $ 13,815,561 $ 13,712,737 Liabilities and Stockholders' Equity: Current Liabilities: Regulatory liabilities: Over-recovery of gas costs $ — $ 161,837 WNA 601,784 — Over-recovery of SAVE Plan revenues — 574,181 Rate refund — 3,827,588 Excess deferred income taxes 205,353 205,353 Other deferred liabilities 83,176 108,644 Total current 890,313 4,877,603 Deferred Credits and Other Liabilities: Asset retirement obligations 7,180,982 6,788,683 Regulatory cost of retirement obligations 12,678,043 11,892,352 Regulatory liabilities: Excess deferred income taxes 10,729,082 10,934,434 Total non-current $ 30,588,107 $ 29,615,469 Total regulatory liabilities $ 31,478,420 $ 34,493,072
Schedule of Utility Plant	Utility plant is composed of the following major classes of assets: September 30 2020 2019 Distribution and transmission $ 227,753,620 $ 209,171,339 LNG storage 14,798,453 13,417,077 General and miscellaneous 15,790,299 15,198,548 Total utility plant in service $ 258,342,372 $ 237,786,964
Summary of Asset Retirement Obligation	The following is a summary of the AROs: Years Ended September 30 2020 2019 Beginning balance $ 6,788,683 $ 6,417,948 Liabilities incurred 165,524 177,646 Liabilities settled (150,345) (177,755) Accretion 377,120 370,844 Ending balance $ 7,180,982 $ 6,788,683
Reconciliation of Changes in Allowance for Doubtful Accounts	A reconciliation of changes in the allowance for doubtful accounts is as follows: Years Ended September 30 2020 2019 Beginning balance $ 110,743 $ 103,573 Provision for doubtful accounts 556,112 220,039 Recoveries of accounts written off 139,113 96,614 Accounts written off (102,828) (309,483) Ending balance $ 703,140 $ 110,743
Reconciliation of Basic and Diluted Earnings Per Share	A reconciliation of basic and diluted EPS is presented below: Years Ended September 30 2020 2019 Net Income $ 10,564,534 $ 8,698,412 Weighted-average common shares 8,125,938 8,039,484 Effect of dilutive securities: Options to purchase common stock 20,728 39,466 Diluted average common shares 8,146,666 8,078,950 Earnings Per Share of Common Stock: Basic $ 1.30 $ 1.08 Diluted $ 1.30 $ 1.08
Summary of Other Comprehensive Income (Loss)	A summary of other comprehensive income is provided below: Before Tax Tax Net of Tax Year Ended September 30, 2020: Interest rate swaps: Unrealized losses $ (1,594,126) $ 410,328 $ (1,183,798) Transfer of realized losses to interest expense 264,911 (68,189) 196,722 Net interest rate swaps (1,329,215) 342,139 (987,076) Defined benefit plans: Net loss arising during period $ (52,669) $ 13,557 $ (39,112) Amortization of actuarial losses 90,441 (23,280) 67,161 Net defined benefit plans 37,772 (9,723) 28,049 Other comprehensive loss $ (1,291,443) $ 332,416 $ (959,027) Year Ended September 30, 2019: Interest rate swaps: Unrealized losses $ (1,117,595) $ 287,669 $ (829,926) Transfer of realized gains to interest expense (87,309) 22,474 (64,835) Net interest rate swaps (1,204,904) 310,143 (894,761) Defined benefit plans: Net loss arising during period $ (962,612) $ 247,777 $ (714,835) Amortization of actuarial gains (10,305) 2,652 (7,653) Net defined benefit plans (972,917) 250,429 (722,488) Other comprehensive loss $ (2,177,821) $ 560,572 $ (1,617,249)
Components of Accumulated Comprehensive Income (Loss)	Composition of AOCI: Interest Rate Defined Benefit Accumulated Balance September 30, 2018 230,624 (1,102,292) (871,668) Other comprehensive loss (894,761) (722,488) (1,617,249) Balance September 30, 2019 (664,137) (1,824,780) (2,488,917) Other comprehensive income (loss) (987,076) 28,049 (959,027) Balance September 30, 2020 $ (1,651,213) $ (1,796,731) $ (3,447,944)

Revenue (Tables)

Revenue (Tables)	12 Months Ended
Revenue (Tables)	Sep. 30, 2020
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following tables summarize revenue by customer, product and income statement classification for the years ended September 30: 2020 Gas utility Non-utility Total operating revenues Natural Gas (Billed and Unbilled): Residential $ 37,022,219 $ — $ 37,022,219 Commercial 18,387,674 — 18,387,674 Industrial and Transportation 5,188,069 — 5,188,069 Other 489,943 666,466 1,156,409 Total contracts with customers 61,087,905 666,466 61,754,371 Alternative Revenue Programs 1,321,020 — 1,321,020 Total operating revenues $ 62,408,925 $ 666,466 $ 63,075,391 2019 Gas utility Non-utility Total operating revenues Natural Gas (Billed and Unbilled): Residential $ 39,519,618 $ — $ 39,519,618 Commercial 22,562,265 — 22,562,265 Industrial and Transportation 4,770,657 — 4,770,657 Revenue reductions (TCJA) (1) (523,881) — (523,881) Other 592,156 720,265 1,312,421 Total contracts with customers 66,920,815 720,265 67,641,080 Alternative Revenue Programs 385,445 — 385,445 Total operating revenues $ 67,306,260 $ 720,265 $ 68,026,525 (1) Accrued refund associated with excess revenue collected in tariff rates associated with the reduction in federal income tax rates.
Customer Receivables	The balances of customer receivables are provided below: Current Assets Current Liabilities Trade accounts receivable (1) Unbilled revenue (1) Customer credit balances Customer deposits September 30, 2019 $ 2,590,702 $ 1,236,384 $ 880,295 $ 1,432,031 September 30, 2020 2,343,492 1,041,518 1,587,061 1,611,476 Increase (decrease) $ (247,210) $ (194,866) $ 706,766 $ 179,445 (1) Included in "Accounts receivable, net" in the consolidated balance sheet. Amounts shown net of reserve for bad debts.

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
Segment Information (Tables)	Sep. 30, 2020
Segment Reporting [Abstract]
Information Related to Segments	Information related to the segments of the Company are provided below: Gas Utility Investment in Affiliates Parent and Other Consolidated Total For the Year Ended September 30, 2020: Operating revenues $ 62,408,925 $ — $ 666,466 $ 63,075,391 Depreciation 7,890,725 — — 7,890,725 Operating income (loss) 12,429,613 (220,194) 308,763 12,518,182 Equity in earnings — 4,814,874 — 4,814,874 Interest expense 2,730,822 1,368,336 — 4,099,158 Income before income taxes 10,350,946 3,233,233 286,015 13,870,194 As of September 30, 2020: Total assets $ 211,994,364 $ 57,660,105 $ 12,025,038 $ 281,679,507 Gross additions to utility property 22,916,339 — — 22,916,339 Gross investment in MVP and Southgate — 7,864,859 — 7,864,859 Gas Utility Investment in Affiliates Parent and Other Consolidated Total For the Year Ended September 30, 2019: Operating revenues $ 67,306,260 $ — $ 720,265 $ 68,026,525 Depreciation 7,454,274 — — 7,454,274 Operating income (loss) 11,458,679 (153,149) 289,934 11,595,464 Equity in earnings — 3,020,348 — 3,020,348 Interest expense 2,404,518 1,214,033 — 3,618,551 Income before income taxes 9,400,869 1,657,988 290,286 11,349,143 As of September 30, 2019: Total assets $ 195,969,019 $ 47,429,368 $ 14,955,309 $ 258,353,696 Gross additions to utility property 21,884,317 — — 21,884,317 Gross investment in MVP and Southgate — 20,965,907 — 20,965,907

Other Investments (Tables)

Other Investments (Tables)	12 Months Ended
Other Investments (Tables)	Sep. 30, 2020
Other Investments [Abstract]
Schedule of Other Investments	The investments in the LLC are included in the consolidated financial statements as follows: September 30 Balance Sheet location: 2020 2019 Other Assets: MVP $ 57,183,063 $ 47,055,426 Southgate 359,742 320,033 Investment in unconsolidated affiliates $ 57,542,805 $ 47,375,459 Current Liabilities: MVP $ 2,501,883 $ 4,958,260 Southgate 10,554 66,564 Capital contributions payable $ 2,512,437 $ 5,024,824 Years ended September 30 Income Statement location: 2020 2019 Equity in earnings of unconsolidated affiliate $ 4,814,874 $ 3,020,348 September 30 2020 2019 Undistributed earnings, net of income taxes, of MVP in retained earnings $ 6,842,702 $ 3,267,176 The change in the investment in unconsolidated affiliates is provided below: September 30 2020 2019 Cash investment $ 7,864,859 $ 20,965,907 Change in accrued capital calls (2,512,387) (5,117,942) Equity in earnings of unconsolidated affiliate 4,814,874 3,020,348 Change in investment in unconsolidated affiliates $ 10,167,346 $ 18,868,313
Summary Unaudited Financial Statements - Equity Method Investment	Summary unaudited financial statements of MVP are presented below. Southgate financial statements, which are accounted for under the cost method, are not included: Income Statements Years Ended September 30, 2020 2019 AFUDC $ 479,586,911 $ 295,430,776 Net Other Income 714,128 5,655,644 Net Income $ 480,301,039 $ 301,086,420 Balance Sheets September 30 2020 2019 Assets: Current Assets $ 513,713,429 $ 485,323,892 Construction Work in Progress 5,536,248,668 4,675,267,389 Other Assets 4,597,441 13,190,816 Total Assets $ 6,054,559,538 $ 5,173,782,097 Liabilities and Equity: Current Liabilities $ 187,581,804 $ 466,776,233 Noncurrent Liabilities 245,000 — Capital 5,866,732,734 4,707,005,864 Total Liabilities and Equity $ 6,054,559,538 $ 5,173,782,097

Line-of-Credit (Tables)

Line-of-Credit (Tables)	12 Months Ended
Line-of-Credit (Tables)	Sep. 30, 2020
Debt Disclosure [Abstract]
Summary of Available Limits Under Line of Credit Agreement	The Company's total available borrowing limits for the remaining term are as follows: As of Available September 30, 2020 $ 19,000,000 March 1, 2021 15,000,000 July 20, 2021 20,000,000 September 20, 2021 28,000,000
Summary of Line of Credit	A summary of the line-of-credit follows: September 30 2020 2019 Available line-of-credit at year-end $ 19,000,000 $ 22,000,000 Outstanding balance at year-end 9,143,606 8,172,473 Highest month-end balance outstanding 12,983,210 15,801,798 Average daily balance 3,286,033 6,049,527 Average rate of interest during year on outstanding balances 2.16 % 3.40 % Interest rate at year-end 1.15 % 3.02 % Interest rate on unused line-of-credit 0.15 % 0.15 %

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
Long-Term Debt (Tables)	Sep. 30, 2020
Debt Disclosure [Abstract]
Schedule of Long-Term Debt	Long-term debt consists of the following: September 30 2020 2019 Principal Unamortized Debt Issuance Costs Principal Unamortized Debt Issuance Costs Roanoke Gas: Unsecured senior notes payable, at 4.26%, due on September 18, 2034 $ 30,500,000 $ 135,157 $ 30,500,000 $ 144,811 Unsecured term note payable, at 30-day LIBOR plus 0.90%, November 1, 2021 7,000,000 3,613 7,000,000 6,948 Unsecured term notes payable, at 3.58% due on October 2, 2027 8,000,000 33,712 8,000,000 38,528 Unsecured term notes payable at 4.41%, due on March 28, 2031 10,000,000 32,892 10,000,000 36,272 Unsecured term notes payable at 3.60%, due on December 6, 2029 10,000,000 32,585 — — Midstream: Unsecured term notes payable, at 30-day LIBOR plus 1.35% due December 29, 2022 25,475,200 38,728 16,012,200 59,504 Unsecured term note payable, at 30-day LIBOR plus 1.15%, due June 12, 2026 14,000,000 13,844 14,000,000 16,252 Unsecured term note payable, at 30-day LIBOR plus 1.20%, due June 1, 2024 10,000,000 8,644 10,000,000 11,000 Total notes payable $ 114,975,200 $ 299,175 $ 95,512,200 $ 313,315 Line-of-credit, at 30-day LIBOR plus 1.00%, due March 31, 2022 9,143,606 — 8,172,473 — Total long-term debt $ 124,118,806 $ 299,175 $ 103,684,673 $ 313,315
Summary of Aggregate Annual Maturities of Long-Term Debt	The aggregate annual maturities of long-term debt for the next five years ending after September 30, 2020 are as follows: Year Ending September 30 Maturities 2021 $ — 2022 16,268,606 2023 25,975,200 2024 9,375,000 2025 — Thereafter 72,500,000 Total $ 124,118,806

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
Income Taxes (Tables)	Sep. 30, 2020
Income Tax Disclosure [Abstract]
Details of Income Tax Expense	The details of income tax expense are as follows: Years Ended September 30 2020 2019 Current income taxes: Federal $ 1,841,124 $ 1,698,215 State 342,233 268,488 Total current income taxes 2,183,357 1,966,703 Deferred income taxes: Federal 644,682 272,079 State 477,621 411,949 Total deferred income taxes 1,122,303 684,028 Total income tax expense $ 3,305,660 $ 2,650,731
Reconciliation of Income Tax Expense Based on Federal Statutory Rate	Income tax expense for the years ended September 30, 2020 and 2019 differed from amounts computed by applying the U.S. federal income tax rate to earnings before income taxes due to the following: Years Ended September 30 2020 2019 Income before income taxes $ 13,870,194 $ 11,349,143 Corporate federal income tax rate 21.0 % 21.0 % Income tax expense computed at the federal statutory rate $ 2,912,741 $ 2,383,320 State income taxes, net of federal income tax benefit 647,685 537,545 Net amortization of excess deferred taxes on regulated operations (162,228) (212,896) Tax benefit recognized on stock compensation (114,984) (96,499) Other, net 22,446 39,261 Total income tax expense $ 3,305,660 $ 2,650,731
Schedule of Deferred Tax Assets and Liabilities	The tax effects of temporary differences that give rise to the deferred tax assets and deferred tax liabilities are as follows: September 30 2020 2019 Deferred tax assets: Allowance for uncollectibles $ 180,986 $ 28,503 Accrued pension and postretirement medical benefits 651,356 782,592 Regulatory effect of change in federal income tax rate 2,814,525 2,867,383 Accrued vacation 140,635 150,882 Over-recovery of gas costs — 23,979 Cost of gas held in storage 604,962 590,495 Deferred compensation 992,605 803,979 Interest rate swaps 572,343 230,204 Rate refund — 130,063 Other 97,564 261,125 Total gross deferred tax assets 6,054,976 5,869,205 Deferred tax liabilities: Utility plant 18,310,474 18,132,022 MVP investment 1,693,075 705,193 Other 25,189 10,513 Total gross deferred tax liabilities 20,028,738 18,847,728 Net deferred tax liability $ 13,973,762 $ 12,978,523

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
Employee Benefit Plans (Tables)	Sep. 30, 2020
Retirement Benefits [Abstract]
Schedule of Changes in Benefit Obligations and Fair Value of Plan Assets, Funded Status of the Plan, and Amount Recognized in the Financial Statements	The following tables set forth the benefit obligation, fair value of plan assets, the funded status of the plans, amounts recognized in the Company’s consolidated financial statements and the assumptions used: Pension Plan Postretirement Plan 2020 2019 2020 2019 Accumulated benefit obligation $ 34,821,069 $ 30,927,973 $ 17,925,409 $ 18,030,399 Change in benefit obligation: Benefit obligation at beginning of year $ 35,550,987 $ 28,850,299 $ 18,030,399 $ 16,207,322 Service cost 691,602 537,268 167,879 132,882 Interest cost 1,062,227 1,166,728 531,480 648,944 Actuarial loss (gain) 3,620,400 5,901,915 (325,269) 1,530,522 Benefit payments, net of retiree contributions (927,214) (905,223) (479,080) (489,271) Benefit obligation at end of year $ 39,998,002 $ 35,550,987 $ 17,925,409 $ 18,030,399 Change in fair value of plan assets: Fair value of plan assets at beginning of year $ 33,586,671 $ 28,184,697 $ 13,082,610 $ 12,924,957 Actual return on plan assets, net of taxes 4,198,174 3,907,197 1,112,723 346,924 Employer contributions 800,000 2,400,000 400,000 300,000 Benefit payments, net of retiree contributions (927,214) (905,223) (479,080) (489,271) Fair value of plan assets at end of year $ 37,657,631 $ 33,586,671 $ 14,116,253 $ 13,082,610 Funded status $ (2,340,371) $ (1,964,316) $ (3,809,156) $ (4,947,789) Amounts recognized in the consolidated balance sheet consist of: Noncurrent liabilities $ (2,340,371) $ (1,964,316) $ (3,809,156) $ (4,947,789) Amounts recognized in accumulated other comprehensive loss: Net actuarial loss, net of tax $ 1,181,744 $ 1,047,063 $ 614,987 $ 777,717 Total amounts included in other comprehensive loss, net of tax $ 1,181,744 $ 1,047,063 $ 614,987 $ 777,717 Amounts deferred to a regulatory asset: Net actuarial loss $ 6,977,944 $ 6,356,201 $ 2,755,333 $ 3,661,168 Amounts recognized as regulatory assets $ 6,977,944 $ 6,356,201 $ 2,755,333 $ 3,661,168
Schedule of Actuarial Assumptions Used	The following table details the actuarial assumptions used in determining the projected benefit obligations and net benefit cost of the pension and the accumulated benefit obligations and net benefit cost of the postretirement plan: Pension Plan Postretirement Plan 2020 2019 2020 2019 Assumptions used to determine benefit obligations: Discount rate 2.47 % 3.03 % 2.44 % 3.00 % Expected rate of compensation increase 4.00 % 4.00 % N/A N/A Assumptions used to determine benefit costs: Discount rate 3.03 % 4.11 % 3.00 % 4.09 % Expected long-term rate of return on plan assets 5.50 % 5.50 % 4.26 % 4.30 % Expected rate of compensation increase 4.00 % 4.00 % N/A N/A
Schedule of Components of Net Periodic Benefit Cost	Components of net periodic benefit cost are as follows: Pension Plan Postretirement Plan 2020 2019 2020 2019 Service cost $ 691,602 $ 537,268 $ 167,879 $ 132,882 Interest cost 1,062,227 1,166,728 531,480 648,944 Expected return on plan assets (1,836,623) (1,549,437) (550,394) (547,218) Recognized loss 455,744 158,599 237,371 123,805 Net periodic benefit cost $ 372,950 $ 313,158 $ 386,336 $ 358,413
Summary of Assumed Health Care Cost Trend Rates Used	The assumed health care cost trend rates used in measuring the accumulated benefit obligation for the postretirement plan are presented below: Pre 65 Post 65 2020 2019 2020 2019 Health care cost trend rate assumed for next year 7.00 % 7.00 % 5.20 % 5.20 % Rate to which the cost trend is assumed to decline (the ultimate trend rate) 5.50 % 5.50 % 5.20 % 5.20 % Year that the rate reaches the ultimate trend rate 2023 2022 2020 2019
Effect of a 1% Change in Health Care Cost Trend Rate Assumptions	The health care cost trend rate assumptions could have a significant effect on the amounts reported. A change of 1% would have the following effects: 1% Increase 1% Decrease Effect on total service and interest cost components $ 132,000 $ (105,000) Effect on accumulated postretirement benefit obligation 3,042,000 (2,454,000)
Schedule of Target and Actual Asset Allocation	The Company’s target and actual asset allocation in the pension and postretirement plans as of September 30, 2020 and 2019 were: Pension Plan Postretirement Plan Target 2020 2019 Target 2020 2019 Asset category: Equity securities 30 % 30 % 40 % 50 % 51 % 49 % Debt securities 70 % 69 % 59 % 50 % 48 % 50 % Cash — % 1 % 1 % — % 1 % 1 % Other — % — % — % — % — % — %
Summary of Fair Value Classifications of Benefit Plan Assets	The following tables contains the fair value classifications of the plans' assets: Pension Plan Fair Value Level 1 Level 2 Level 3 Asset Class: Cash $ 339,287 $ 339,287 $ — $ — Common and Collective Trust and Pooled Funds: Bonds Liability Driven Investment 26,038,966 — 26,038,966 — Equities Domestic Large Cap Growth 3,462,841 — 3,462,841 — Domestic Large Cap Value 3,351,694 — 3,351,694 — Domestic Small/Mid Cap Core 1,665,005 — 1,665,005 — Foreign Large Cap Value 1,473,427 — 1,473,427 — Mutual Funds: Equities Foreign Large Cap Growth 1,047,274 1,047,274 — — Foreign Large Cap Value 279,137 279,137 — — Total $ 37,657,631 $ 1,665,698 $ 35,991,933 $ — Pension Plan Fair Value Level 1 Level 2 Level 3 Asset Class: Cash $ 371,780 $ 371,780 $ — $ — Common and Collective Trust and Pooled Funds: Bonds Liability Driven Investment 19,702,561 — 19,702,561 — Equities Domestic Large Cap Growth 4,069,197 — 4,069,197 — Domestic Large Cap Value 4,055,518 — 4,055,518 — Domestic Small/Mid Cap Core 2,032,084 — 2,032,084 — Foreign Large Cap Value 1,783,990 — 1,783,990 — Mutual Funds: Equities Foreign Large Cap Growth 1,227,981 1,227,981 — — Foreign Large Cap Value 343,560 343,560 — — Total $ 33,586,671 $ 1,943,321 $ 31,643,350 $ — Postretirement Plan Fair Value Level 1 Level 2 Level 3 Asset Class: Cash $ 73,908 $ 73,908 $ — $ — Mutual Funds Bonds Domestic Fixed Income 6,163,808 6,163,808 — — Foreign Fixed Income 638,709 638,709 — — Equities Domestic Large Cap Growth 2,197,839 2,197,839 — — Domestic Large Cap Value 2,119,433 2,119,433 — — Domestic Small/Mid Cap Growth 262,726 262,726 — — Domestic Small/Mid Cap Value 235,216 235,216 — — Domestic Small/Mid Cap Core 552,607 552,607 — — Foreign Large Cap Growth 548,967 548,967 — — Foreign Large Cap Value 1,224,420 1,224,420 — — Foreign Large Cap Core 77,471 77,471 — — Other 21,149 — 21,149 — Total $ 14,116,253 $ 14,095,104 $ 21,149 $ — Postretirement Plan Fair Value Level 1 Level 2 Level 3 Asset Class: Cash $ 66,860 $ 66,860 $ — $ — Mutual Funds Bonds Domestic Fixed Income 5,987,248 5,987,248 — — Foreign Fixed Income 611,196 611,196 — — Equities Domestic Large Cap Growth 1,909,836 1,909,836 — — Domestic Large Cap Value 1,931,615 1,931,615 — — Domestic Small/Mid Cap Growth 210,251 210,251 — — Domestic Small/Mid Cap Value 214,034 214,034 — — Domestic Small/Mid Cap Core 464,526 464,526 — — Foreign Large Cap Growth 489,286 489,286 — — Foreign Large Cap Value 1,098,992 1,098,992 — — Foreign Large Cap Core 70,782 70,782 — — Other 27,984 — 27,984 — Total $ 13,082,610 $ 13,054,626 $ 27,984 $ —
Schedule of Expected Future Benefit Payments	The following table reflects expected future benefit payments: Fiscal year ending September 30 Pension Postretirement 2021 $ 1,043,787 $ 568,170 2022 1,133,470 605,966 2023 1,221,341 666,049 2024 1,320,157 678,659 2025 1,416,485 684,989 2026-2030 8,355,472 3,637,984
Schedule of Employer Contributions	The following table reflects the Company's contributions: Years Ended September 30, 2020 2019 Matching contribution $ 364,773 $ 348,369 Discretionary contribution 18,313 21,829

Common Stock Options (Tables)

Common Stock Options (Tables)	12 Months Ended
Common Stock Options (Tables)	Sep. 30, 2020
Share-based Payment Arrangement [Abstract]
Schedule of Fair Value of Stock Options	As the Company's stock options are not traded on the open market, the fair value of each grant is estimated on the date of grant using the Black-Scholes option pricing model including the following assumptions: Years Ended September 30, 2020 2019 Expected volatility 31.53% N/A Expected dividends 2.74% N/A Expected exercise term (years) 7.00 N/A Risk-free interest rate 0.51% N/A
Schedule of Stock Option Transactions	Stock option transactions under the Company's plans are summarized below. Number of Shares Weighted- Average Exercise Price Weighted- Average Remaining Contractual Terms (years) Aggregate Intrinsic Value 1 Options outstanding, September 30, 2018 100,000 14.34 6.6 1,237,286 Options granted — — Options exercised (31,508) 13.08 Options expired — — Options forfeited — — Options outstanding, September 30, 2019 68,492 14.91 6.2 981,170 Options granted 13,000 27.87 Options exercised (29,992) 14.65 Options expired — — Options forfeited — — Options outstanding, September 30, 2020 51,500 $ 18.34 6.4 $ 320,797 Vested and exercisable at September 30, 2020 51,500 $ 18.34 6.4 $ 320,797 1 Aggregate intrinsic value includes only those options where the exercise price is below the market price. Years Ended September 30, 2020 2019 Weighted-average grant date option fair value $ 6.26 $ — Stock option expense 81,380 — Intrinsic value of options exercised 411,638 456,002 Proceeds from exercise of stock options 439,509 412,179

Other Stock Plans (Tables)

Other Stock Plans (Tables)	12 Months Ended
Other Stock Plans (Tables)	Sep. 30, 2020
Share-based Payment Arrangement [Abstract]
Director Compensation Activity	The following table reflects the director compensation activity pursuant to the Plan: 2020 2019 Shares Weighted-Average Fair Value on Date of Grant Shares Weighted-Average Fair Value on Date of Grant Beginning of year balance 104,680 $ 12.51 98,302 $ 11.51 Granted 9,193 26.28 6,378 27.93 Vested (14,803) 10.68 — — Forfeited — — — — End of year balance 99,070 $ 14.06 104,680 $ 12.51
Officer Compensation Activity	The following table reflects the officer compensation activity pursuant to the RSPO: 2020 2019 Shares Weighted-Average Fair Value on Date of Grant Shares Weighted-Average Fair Value on Date of Grant Beginning of year balance 10,185 $ 28.65 6,734 $ 26.33 Granted 14,951 28.17 10,227 29.80 Vested (18,321) 28.30 (6,776) 28.08 Forfeited — — — — End of year balance 6,815 $ 28.55 10,185 $ 28.65

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
Commitments and Contingencies (Tables)	Sep. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
Schedule of Volumetric and Pipeline and Storage Capacity Obligations	The table below details the volumetric obligations as of September 30, 2020 for the remainder of the contract period. The current asset management contract was renewed in July 2020 for a one year period which will expire in March 2022. The contract was renewed at essentially the same terms and conditions as the prior agreement, except the utilization fee retained by Roanoke Gas was reduced. Year Natural Gas Contracts 2020-2021 2,090,972 2021-2022 295,866 Total 2,386,838 Year Pipeline and 2020-2021 $ 11,048,798 2021-2022 10,284,092 2022-2023 7,403,271 2023-2024 5,743,826 2024-2025 3,167,937 Thereafter 888,426 Total $ 38,536,350

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
Fair Value Measurements (Tables)	Sep. 30, 2020
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 and the fair value measurements by level within the fair value hierarchy as defined in Note 1 as of September 30, 2020 and 2019, respectively: Fair Value Measurements - September 30, 2020 Fair Value Quoted Prices in Significant Other Significant Liabilities: Natural gas purchases $ 470,755 $ — $ 470,755 $ — Interest rate swaps 2,223,556 — 2,223,556 — Total $ 2,694,311 $ — $ 2,694,311 $ — Fair Value Measurements - September 30, 2019 Fair Value Quoted Prices in Significant Other Significant 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 consolidated financial statements as of September 30, 2020 and 2019. Fair Value Measurements - September 30, 2020 Carrying Quoted Prices in Significant Other Significant Liabilities: Notes payable $ 114,975,200 $ — $ — $ 124,740,970 Total $ 114,975,200 $ — $ — $ 124,740,970 Fair Value Measurements - September 30, 2019 Carrying Quoted Prices in Significant Other Significant Liabilities: Notes payable $ 95,512,200 $ — $ — $ 100,900,952 Total $ 95,512,200 $ — $ — $ 100,900,952

Quarterly Financial Informati_2

Quarterly Financial Information (Unaudited) (Tables)	12 Months Ended
Quarterly Financial Information (Unaudited) (Tables)	Sep. 30, 2020
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Data	Quarterly financial data for the years ended September 30, 2020 and 2019 is summarized as follows: 2020 First Second Third Fourth Operating revenues $ 19,785,453 $ 22,437,731 $ 11,071,918 $ 9,780,289 Operating income (loss) $ 5,081,979 $ 6,999,616 $ 1,335,663 $ (899,076) Net income (loss) $ 4,006,936 $ 5,680,316 $ 1,206,578 $ (329,296) Earnings (loss) per share of common stock: Basic $ 0.50 $ 0.70 $ 0.15 $ (0.04) Diluted $ 0.49 $ 0.70 $ 0.15 $ (0.04) 2019 First Second Third Fourth Operating revenues $ 21,216,747 $ 25,274,959 $ 11,682,950 $ 9,851,869 Operating income $ 3,264,222 $ 6,203,483 $ 1,637,057 $ 490,702 Net income $ 2,434,162 $ 4,670,090 $ 1,138,555 $ 455,605 Earnings per share of common stock: Basic $ 0.30 $ 0.58 $ 0.14 $ 0.06 Diluted $ 0.30 $ 0.58 $ 0.14 $ 0.06

Summary of Significant Accoun_4

Summary of Significant Accounting Policies (Narrative) (Details) $ / shares in Units, customer in Thousands	12 Months Ended
	Sep. 30, 2020USD ($)pipelinecustomerinstrument_helddebt_instrument	Sep. 30, 2019USD ($)instrument_held$ / shares	Oct. 01, 2019USD ($)lease	Jun. 30, 2019USD ($)	Jun. 30, 2019	Jun. 30, 2019instrument_held	Jun. 30, 2019debt_instrument
Summary Of Significant Accounting Policies [Line Items]
Number of customers \| customer	62
Amortization	$ 1,106,511	$ 368,011
Remaining amount of regulatory assets that did not earn a return during the recovery period	$ 13,803,616
Regulatory utility assets provision, review period	5 years
Composite weighted-average depreciation rate	3.30%	3.31%
Effect of change in deprecation rate on depreciation expense		$ (32,570)
Effect of change in depreciation rate on net income		$ 24,187
Effect of change in deprecation rate on EPS (in usd per share) \| $ / shares		$ 0.01
Capitalized debt financing costs	$ 81,629
Capitalized equity financing costs	248,579
Unbilled revenue	$ 1,041,518	$ 1,236,384
Deferred charges, amortization period	12 months
Number of pipelines \| pipeline	2
Change in accrued capital calls	$ 2,512,387	$ 5,117,942
Number of operating lease \| lease			1
Quarterly lease payments			$ 3,240
Roanoke Gas \| Unsecured Debt \| Unsecured term note payable, at 30-day LIBOR plus 0.90%, November 1, 2021
Summary Of Significant Accounting Policies [Line Items]
Debt instrument, face amount	$ 7,000,000
Fixed rate related to interest rate swap	2.30%
RGC Midstream, LLC
Summary Of Significant Accounting Policies [Line Items]
Number of notes	2					2	2
RGC Midstream, LLC \| Unsecured Debt \| Unsecured term note payable, at 30-day LIBOR plus 1.15%, due June 12, 2026
Summary Of Significant Accounting Policies [Line Items]
Debt instrument, face amount				$ 14,000,000
Fixed rate related to interest rate swap					3.24%
RGC Midstream, LLC \| Unsecured Debt \| Unsecured term note payable, at 30-day LIBOR plus 1.20%, due June 1, 2024
Summary Of Significant Accounting Policies [Line Items]
Debt instrument, face amount				$ 10,000,000
Fixed rate related to interest rate swap					3.14%
Natural Gas
Summary Of Significant Accounting Policies [Line Items]
Number of derivative instruments \| instrument_held	0	0
Interest Rate Swap
Summary Of Significant Accounting Policies [Line Items]
Number of derivative instruments \| instrument_held	3

Summary of Significant Accoun_5

Summary of Significant Accounting Policies (Schedule of Regulatory Assets and Liabilities) (Details) - USD ($)	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Regulatory Assets [Line Items]
Current regulatory assets	$ 2,503,314	$ 1,521,939
Utility property in service, other	11,945	11,945
Construction work in progress - AFUDC	330,208	0
Noncurrent regulatory assets	10,970,094	12,178,853
Total regulatory assets	13,815,561	13,712,737
Regulatory Liabilities [Line Items]
Current regulatory liabilities	890,313	4,877,603
Asset retirement obligations	7,180,982	6,788,683	$ 6,417,948
Regulatory cost of retirement obligations	12,678,043	11,892,352
Noncurrent regulatory liabilities	10,729,082	10,934,434
Total non-current	30,588,107	29,615,469
Total regulatory liabilities	31,478,420	34,493,072
Over-recovery of gas costs
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	161,837
Accrued WNA revenues
Regulatory Liabilities [Line Items]
Current regulatory liabilities	601,784	0
Over-recovery of SAVE Plan revenues
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	574,181
Rate refund
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	3,827,588
Excess deferred income taxes
Regulatory Liabilities [Line Items]
Current regulatory liabilities	205,353	205,353
Noncurrent regulatory liabilities	10,729,082	10,934,434
Other deferred liabilities
Regulatory Liabilities [Line Items]
Current regulatory liabilities	83,176	108,644
Accrued WNA revenues
Regulatory Assets [Line Items]
Current regulatory assets	0	569,558
Under-recovery of gas costs
Regulatory Assets [Line Items]
Current regulatory assets	1,733,718	0
Under-recovery of SAVE Plan revenues
Regulatory Assets [Line Items]
Current regulatory assets	108,550	0
ESAC assets
Regulatory Assets [Line Items]
Current regulatory assets	0	265,392
Noncurrent regulatory assets	0	756,803
Total regulatory assets	525,000
Accrued pension and postretirement medical
Regulatory Assets [Line Items]
Current regulatory assets	576,731	602,674
Noncurrent regulatory assets	9,156,546	9,414,695
Premium on early retirement of debt
Regulatory Assets [Line Items]
Noncurrent regulatory assets	1,598,620	1,712,808
Other deferred expenses
Regulatory Assets [Line Items]
Current regulatory assets	84,315	84,315
Noncurrent regulatory assets	$ 214,928	$ 294,547

Summary of Significant Accoun_6

Summary of Significant Accounting Policies (Components of Utility Plant) (Details) - USD ($)	Sep. 30, 2020	Sep. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Distribution and transmission	$ 227,753,620	$ 209,171,339
LNG storage	14,798,453	13,417,077
General and miscellaneous	15,790,299	15,198,548
Total utility plant in service	$ 258,342,372	$ 237,786,964

Summary of Significant Accoun_7

Summary of Significant Accounting Policies (Summary of Asset Retirement Obligations) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance	$ 6,788,683	$ 6,417,948
Liabilities incurred	165,524	177,646
Liabilities settled	(150,345)	(177,755)
Accretion	377,120	370,844
Ending balance	$ 7,180,982	$ 6,788,683

Summary of Significant Accoun_8

Summary of Significant Accounting Policies (Reconciliation of Changes in Allowance for Doubtful Accounts) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	$ 110,743	$ 103,573
Provision for doubtful accounts	556,112	220,039
Recoveries of accounts written off	139,113	96,614
Accounts written off	(102,828)	(309,483)
Ending balance	$ 703,140	$ 110,743

Summary of Significant Accoun_9

Summary of Significant Accounting Policies (Reconciliation of Basic and Diluted Earnings Per Share) (Details) - USD ($)	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Net income	$ (329,296)	$ 1,206,578	$ 5,680,316	$ 4,006,936	$ 455,605	$ 1,138,555	$ 4,670,090	$ 2,434,162	$ 10,564,534	$ 8,698,412
Weighted-average common shares (in shares)									8,125,938	8,039,484
Effect of dilutive securities:
Options to purchase common stock (in shares)									20,728	39,466
Diluted average common shares (in shares)									8,146,666	8,078,950
Earnings Per Share of Common Stock:
Basic (in usd per share)	$ (0.04)	$ 0.15	$ 0.70	$ 0.50	$ 0.06	$ 0.14	$ 0.58	$ 0.30	$ 1.30	$ 1.08
Diluted (in usd per share)	$ (0.04)	$ 0.15	$ 0.70	$ 0.49	$ 0.06	$ 0.14	$ 0.58	$ 0.30	$ 1.30	$ 1.08

Summary of Significant Accou_10

Summary of Significant Accounting Policies (Summary of Other Comprehensive Income) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Accumulated Other Comprehensive Income (Loss) [Line Items]
Before Tax Amount, Other comprehensive loss	$ (1,291,443)	$ (2,177,821)
Tax (Expense) or Benefit, Other comprehensive loss	332,416	560,572
OTHER COMPREHENSIVE LOSS, NET OF TAX	(959,027)	(1,617,249)
Interest Rate Swaps
Accumulated Other Comprehensive Income (Loss) [Line Items]
Before Tax Amount, Other comprehensive loss before reclassification	(1,594,126)	(1,117,595)
Tax (Expense) or Benefit, Other comprehensive loss before reclassification	410,328	287,669
Net of Tax Amount, Other comprehensive loss before reclassification	(1,183,798)	(829,926)
Before Tax Amount, Reclassification	264,911	(87,309)
Tax (Expense) or Benefit, Reclassification	(68,189)	22,474
Net of Tax Amount, Reclassification	196,722	(64,835)
Before Tax Amount, Other comprehensive loss	(1,329,215)	(1,204,904)
Tax (Expense) or Benefit, Other comprehensive loss	342,139	310,143
OTHER COMPREHENSIVE LOSS, NET OF TAX	(987,076)	(894,761)
Defined Benefit Plans
Accumulated Other Comprehensive Income (Loss) [Line Items]
Before Tax Amount, Other comprehensive loss before reclassification	(52,669)	(962,612)
Tax (Expense) or Benefit, Other comprehensive loss before reclassification	13,557	247,777
Net of Tax Amount, Other comprehensive loss before reclassification	(39,112)	(714,835)
Before Tax Amount, Reclassification	90,441	(10,305)
Tax (Expense) or Benefit, Reclassification	(23,280)	2,652
Net of Tax Amount, Reclassification	67,161	(7,653)
Before Tax Amount, Other comprehensive loss	37,772	(972,917)
Tax (Expense) or Benefit, Other comprehensive loss	(9,723)	250,429
OTHER COMPREHENSIVE LOSS, NET OF TAX	$ 28,049	$ (722,488)

Summary of Significant Accou_11

Summary of Significant Accounting Policies (Components of Accumulated Comprehensive Income (Loss)) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Increase (Decrease) in Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	$ 83,096,392	$ 79,583,112
Other comprehensive income (loss)	(959,027)	(1,617,249)
Ending balance	88,887,977	83,096,392
Interest Rate Swaps
Increase (Decrease) in Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	(664,137)	230,624
Other comprehensive income (loss)	(987,076)	(894,761)
Ending balance	(1,651,213)	(664,137)
Defined Benefit Plans
Increase (Decrease) in Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	(1,824,780)	(1,102,292)
Other comprehensive income (loss)	28,049	(722,488)
Ending balance	(1,796,731)	(1,824,780)
Accumulated Other Comprehensive Income (Loss)
Increase (Decrease) in Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	(2,488,917)	(871,668)
Other comprehensive income (loss)	(959,027)	(1,617,249)
Ending balance	$ (3,447,944)	$ (2,488,917)

Revenue (Disaggregation of Reve

Revenue (Disaggregation of Revenue) (Details) - USD ($)	3 Months Ended								12 Months Ended
Revenue (Disaggregation of Revenue) (Details) - USD ($)	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019
Disaggregation of Revenue [Line Items]
Total contracts with customers									$ 61,754,371	$ 67,641,080
Revenue reductions (TCJA)										(523,881)
Alternative Revenue Programs									1,321,020	385,445
Revenues	$ 9,780,289	$ 11,071,918	$ 22,437,731	$ 19,785,453	$ 9,851,869	$ 11,682,950	$ 25,274,959	$ 21,216,747	63,075,391	68,026,525
Natural gas \| Residential customers
Disaggregation of Revenue [Line Items]
Total contracts with customers									37,022,219	39,519,618
Natural gas \| Commercial customers
Disaggregation of Revenue [Line Items]
Total contracts with customers									18,387,674	22,562,265
Natural gas \| Industrial and transportation customers
Disaggregation of Revenue [Line Items]
Total contracts with customers									5,188,069	4,770,657
Other
Disaggregation of Revenue [Line Items]
Total contracts with customers									1,156,409	1,312,421
Gas Utility
Disaggregation of Revenue [Line Items]
Total contracts with customers									61,087,905	66,920,815
Revenue reductions (TCJA)										(523,881)
Alternative Revenue Programs									1,321,020	385,445
Revenues									62,408,925	67,306,260
Gas Utility \| Natural gas \| Residential customers
Disaggregation of Revenue [Line Items]
Total contracts with customers									37,022,219	39,519,618
Gas Utility \| Natural gas \| Commercial customers
Disaggregation of Revenue [Line Items]
Total contracts with customers									18,387,674	22,562,265
Gas Utility \| Natural gas \| Industrial and transportation customers
Disaggregation of Revenue [Line Items]
Total contracts with customers									5,188,069	4,770,657
Gas Utility \| Other
Disaggregation of Revenue [Line Items]
Total contracts with customers									489,943	592,156
Non Utility
Disaggregation of Revenue [Line Items]
Total contracts with customers									666,466	720,265
Revenue reductions (TCJA)										0
Alternative Revenue Programs									0	0
Revenues									666,466	720,265
Non Utility \| Natural gas \| Residential customers
Disaggregation of Revenue [Line Items]
Total contracts with customers									0	0
Non Utility \| Natural gas \| Commercial customers
Disaggregation of Revenue [Line Items]
Total contracts with customers									0	0
Non Utility \| Natural gas \| Industrial and transportation customers
Disaggregation of Revenue [Line Items]
Total contracts with customers									0	0
Non Utility \| Other
Disaggregation of Revenue [Line Items]
Total contracts with customers									$ 666,466	$ 720,265

Revenue (Customer Accounts Rece

Revenue (Customer Accounts Receivable) (Details) - USD ($)	12 Months Ended
Revenue (Customer Accounts Receivable) (Details) - USD ($)	Sep. 30, 2020	Sep. 30, 2019
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable, net	$ 3,404,044	$ 3,870,211
Unbilled revenue	1,041,518	1,236,384
Increase (decrease) in unbilled revenue	(194,866)
Customer credit balances	1,587,061	880,295
Increase (decrease) in customer credit balances	706,766
Customer deposits	1,611,476	1,432,031
Increase (decrease) in customer deposits	179,445
Trade accounts receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable, net	2,343,492	$ 2,590,702
Increase (decrease) in trade accounts receivable	$ (247,210)

Regulatory Matters (Details)

Regulatory Matters (Details) - USD ($)	Jan. 24, 2020	Sep. 30, 2020	Mar. 31, 2020	Sep. 30, 2020	Sep. 30, 2019
Public Utilities, General Disclosures [Line Items]
Regulatory assets		$ 13,815,561		$ 13,815,561	$ 13,712,737
Regulatory liabilities		10,729,082		$ 10,729,082	$ 10,934,434
Composite weighted-average depreciation rate				3.30%	3.31%
Effect of change in deprecation rate on depreciation expense					$ (32,570)
ESAC assets
Public Utilities, General Disclosures [Line Items]
Regulatory assets		525,000		$ 525,000
Excess deferred income taxes
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities		10,729,082		$ 10,729,082	$ 10,934,434
Roanoke Gas
Public Utilities, General Disclosures [Line Items]
Additional write down of ESAC regulatory assets			$ 317,000
Rate refund repaid			$ 3,800,000
Regulatory liability, refund period (in years)				28 years
General Rate Case \| Virginia State Corporate Commission (SCC) \| Roanoke Gas
Public Utilities, General Disclosures [Line Items]
Approved non-gas rate increase	$ 7,250,000
Approved return on equity (as a percent)	9.44%
SAVE Plan and Rider Filing \| Virginia State Corporate Commission (SCC) \| Roanoke Gas
Public Utilities, General Disclosures [Line Items]
Approved non-gas rate increase		2,300,000
Refund from over-collected balance		$ 73,000

Segment Information (Reconcilia

Segment Information (Reconciliation of Segment Income to Consolidated) (Details) - USD ($)	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019
Segment Reporting Information [Line Items]
Operating revenues	$ 9,780,289	$ 11,071,918	$ 22,437,731	$ 19,785,453	$ 9,851,869	$ 11,682,950	$ 25,274,959	$ 21,216,747	$ 63,075,391	$ 68,026,525
Depreciation									7,890,725	7,454,274
Operating income (loss)	(899,076)	$ 1,335,663	$ 6,999,616	$ 5,081,979	490,702	$ 1,637,057	$ 6,203,483	$ 3,264,222	12,518,182	11,595,464
Equity in earnings									4,814,874	3,020,348
Interest expense									4,099,158	3,618,551
Income before income taxes									13,870,194	11,349,143
Total assets	281,679,507				258,353,696				281,679,507	258,353,696
Gross additions to utility property									22,916,339	21,884,317
Gross investment in MVP and Southgate									7,864,859	20,965,907
Operating segments \| Gas Utility
Segment Reporting Information [Line Items]
Operating revenues									62,408,925	67,306,260
Depreciation									7,890,725	7,454,274
Operating income (loss)									12,429,613	11,458,679
Equity in earnings									0	0
Interest expense									2,730,822	2,404,518
Income before income taxes									10,350,946	9,400,869
Total assets	211,994,364				195,969,019				211,994,364	195,969,019
Gross additions to utility property									22,916,339	21,884,317
Gross investment in MVP and Southgate									0	0
Operating segments \| Investment in Affiliates
Segment Reporting Information [Line Items]
Operating revenues									0	0
Depreciation									0	0
Operating income (loss)									(220,194)	(153,149)
Equity in earnings									4,814,874	3,020,348
Interest expense									1,368,336	1,214,033
Income before income taxes									3,233,233	1,657,988
Total assets	57,660,105				47,429,368				57,660,105	47,429,368
Gross additions to utility property									0	0
Gross investment in MVP and Southgate									7,864,859	20,965,907
Parent and Other
Segment Reporting Information [Line Items]
Operating revenues									666,466	720,265
Depreciation									0	0
Operating income (loss)									308,763	289,934
Equity in earnings									0	0
Interest expense									0	0
Income before income taxes									286,015	290,286
Total assets	$ 12,025,038				$ 14,955,309				12,025,038	14,955,309
Gross additions to utility property									0	0
Gross investment in MVP and Southgate									$ 0	$ 0

Other Investments (Narrative) (

Other Investments (Narrative) (Details) - RGC Midstream, LLC $ in Millions	1 Months Ended
	Apr. 30, 2018USD ($)mi	Sep. 30, 2020USD ($)debt_instrument	Nov. 30, 2019	Jun. 30, 2019instrument_held	Jun. 30, 2019debt_instrument	Oct. 31, 2015Bcf
Investment [Line Items]
Number of notes		2		2	2
MVP Southgate Investment
Investment [Line Items]
Ownership percentage (less than)	1.00%
MVP Investment
Investment [Line Items]
Equity interest (as a percent)			1.03%			1.00%
Pipeline capacity (in bcf per day) \| Bcf						2
MVP Investment \| Minimum
Investment [Line Items]
Total project cost		$ 5,800
Total estimated investment		60
MVP Investment \| Maximum
Investment [Line Items]
Total project cost		6,000
Total estimated investment		$ 62
MVP Southgate Investment
Investment [Line Items]
Length, planned natural gas pipeline (in miles) \| mi	75
MVP Southgate Investment \| Maximum
Investment [Line Items]
Total project cost	$ 500
Total estimated investment	$ 2.1

Other Investments (Schedule of

Other Investments (Schedule of Other Investments) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Other Assets:
Investment in unconsolidated affiliates	$ 57,542,805	$ 47,375,459
Current Liabilities:
Capital contributions payable	2,512,437	5,024,824
Income Statement Location of Other Investments:
Equity in earnings of unconsolidated affiliate	4,814,874	3,020,348
Undistributed earnings, net of income taxes, of MVP in retained earnings	6,842,702	3,267,176
Change in investment in unconsolidated affiliate [Abstract]
Cash investment	7,864,859	20,965,907
Change in accrued capital calls	(2,512,387)	(5,117,942)
Equity in earnings of unconsolidated affiliate	4,814,874	3,020,348
Change in investment in unconsolidated affiliates	10,167,346	18,868,313
MVP Investment
Other Assets:
MVP	57,183,063	47,055,426
Current Liabilities:
Capital contributions payable	2,501,883	4,958,260
MVP Southgate Investment
Other Assets:
Southgate	359,742	320,033
Current Liabilities:
Capital contributions payable	$ 10,554	$ 66,564

Other Investments (Investment i

Other Investments (Investment in Unconsolidated Entity) (Details) - MVP - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Income Statement
AFUDC	$ 479,586,911	$ 295,430,776
Net Other Income	714,128	5,655,644
Net Income	480,301,039	301,086,420
Assets:
Current Assets	513,713,429	485,323,892
Construction Work in Progress	5,536,248,668	4,675,267,389
Other Assets	4,597,441	13,190,816
Total Assets	6,054,559,538	5,173,782,097
Liabilities and Equity:
Current Liabilities	187,581,804	466,776,233
Noncurrent Liabilities	245,000	0
Capital	5,866,732,734	4,707,005,864
Total Liabilities and Equity	$ 6,054,559,538	$ 5,173,782,097

Line-of-Credit (Narrative) (Det

Line-of-Credit (Narrative) (Details) - USD ($)	12 Months Ended
Line-of-Credit (Narrative) (Details) - USD ($)	Sep. 30, 2020	Sep. 30, 2019
Debt Instrument [Line Items]
Promissory Notes term	20 years
Line-of-credit, maximum borrowing limit	$ 19,000,000
Interest rate on unused line-of-credit (as a percent)	0.15%	0.15%
Debt covenant, maximum ratio of total long-term debt to total capitalization	65.00%
Roanoke Gas \| Line of Credit \| Line-of-credit, at 30-day LIBOR plus 1.00%, due March 31, 2022
Debt Instrument [Line Items]
Promissory Notes term	2 years
Line-of-credit, maximum borrowing limit	$ 28,000,000
Interest rate on unused line-of-credit (as a percent)	0.15%
Minimum interest coverage ratio	1.5
Debt covenant, maximum ratio of total long-term debt to total capitalization	65.00%
Roanoke Gas \| Line of Credit \| Line-of-credit, at 30-day LIBOR plus 1.00%, due March 31, 2022 \| 30-day LIBOR
Debt Instrument [Line Items]
Variable rate basis points (as a percent)	1.00%

Line-of-Credit (Summary of Avai

Line-of-Credit (Summary of Available Limits Under Line of Credit Agreement) (Details) - USD ($)	Sep. 20, 2021	Jul. 20, 2021	Mar. 01, 2021	Sep. 30, 2020
Short-term Debt [Line Items]
Available Line-of-Credit				$ 19,000,000
Forecast
Short-term Debt [Line Items]
Available Line-of-Credit	$ 28,000,000	$ 20,000,000	$ 15,000,000

Line-of-Credit (Summary of Line

Line-of-Credit (Summary of Line-of-Credit) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Debt Disclosure [Abstract]
Available line-of-credit at year-end	$ 19,000,000	$ 22,000,000
Outstanding balance at year-end	9,143,606	8,172,473
Highest month-end balance outstanding	12,983,210	15,801,798
Average daily balance	$ 3,286,033	$ 6,049,527
Average rate of interest during year on outstanding balances (as a percent)	2.16%	3.40%
Interest rate at year-end (as a percent)	1.15%	3.02%
Interest rate on unused line-of-credit (as a percent)	0.15%	0.15%

Long-Term Debt (Narrative) (Det

Long-Term Debt (Narrative) (Details)	1 Months Ended	12 Months Ended
Long-Term Debt (Narrative) (Details)	Dec. 31, 2019USD ($)	Sep. 30, 2020USD ($)debt_instrument	Sep. 30, 2019USD ($)	Jun. 30, 2019instrument_held	Jun. 30, 2019debt_instrument
Debt Instrument [Line Items]
Promissory Notes term		20 years
Unamortized loss on early retirement of debt deferred as regulatory asset		$ 1,598,620	$ 1,712,808
Unamortized loss on early retirement of debt, amortization period		20
Debt covenant, maximum ratio of total long-term debt to total capitalization		65.00%
RGC Midstream, LLC
Debt Instrument [Line Items]
Number of notes		2		2	2
RGC Midstream, LLC \| Unsecured Debt
Debt Instrument [Line Items]
Debt covenant, maximum ratio of priority indebtedness to total assets		15.00%
RGC Midstream, LLC \| Unsecured Debt \| Unsecured term notes payable, at 30-day LIBOR plus 1.35% due December 29, 2022
Debt Instrument [Line Items]
Debt instrument, face amount	$ 41,000,000		$ 26,000,000
RGC Midstream, LLC \| Unsecured Debt \| Unsecured term notes payable, at 30-day LIBOR plus 1.35% due December 29, 2022 \| 30-day LIBOR
Debt Instrument [Line Items]
Variable rate basis points (as a percent)	1.35%	1.35%	1.35%
RGC Midstream, LLC \| Unsecured Debt \| Unsecured term notes payable, at 30-day LIBOR plus 1.15%, due June 12, 2026
Debt Instrument [Line Items]
Debt instrument, face amount		$ 14,000,000
Fixed rate related to interest rate swap		3.24%
RGC Midstream, LLC \| Unsecured Debt \| Unsecured term notes payable, at 30-day LIBOR plus 1.20%, due June 1, 2024
Debt Instrument [Line Items]
Debt instrument, face amount		$ 10,000,000
Fixed rate related to interest rate swap		3.14%
Roanoke Gas \| Unsecured Debt
Debt Instrument [Line Items]
Debt covenant, maximum ratio of priority indebtedness to total assets		15.00%
Roanoke Gas \| Unsecured Debt \| Unsecured term notes payable at 3.60%, due on December 6, 2029
Debt Instrument [Line Items]
Debt instrument, face amount	$ 10,000,000
Promissory Notes term	10 years
Stated rate	3.60%	3.60%
Roanoke Gas \| Unsecured Debt \| Unsecured term note payable, at 30-day LIBOR plus 0.90%, November 1, 2021
Debt Instrument [Line Items]
Debt instrument, face amount		$ 7,000,000
Fixed rate related to interest rate swap		2.30%
Roanoke Gas \| Unsecured Debt \| Unsecured term note payable, at 30-day LIBOR plus 0.90%, November 1, 2021 \| 30-day LIBOR
Debt Instrument [Line Items]
Variable rate basis points (as a percent)		0.90%	0.90%
Roanoke Gas \| Unsecured Senior Notes
Debt Instrument [Line Items]
Debt covenant, maximum ratio of priority indebtedness to total assets		15.00%

Long-Term Debt (Schedule of Lon

Long-Term Debt (Schedule of Long-Term Debt) (Details) - USD ($)	1 Months Ended	12 Months Ended
	Dec. 31, 2019	Sep. 30, 2020	Sep. 30, 2019
Principal
Notes payable		$ 114,975,200	$ 95,512,200
Line-of-credit		9,143,606	8,172,473
Total		124,118,806	103,684,673
Unamortized Debt Issuance Costs		299,175	313,315
Notes Payable
Principal
Notes payable		114,975,200	95,512,200
Unamortized Debt Issuance Costs		$ 299,175	$ 313,315
Roanoke Gas \| Unsecured Senior Notes \| Unsecured senior notes payable, at 4.26%, due on September 18, 2034
Debt Instrument [Line Items]
Stated rate		4.26%	4.26%
Principal
Notes payable		$ 30,500,000	$ 30,500,000
Unamortized Debt Issuance Costs		135,157	144,811
Roanoke Gas \| Unsecured Debt \| Unsecured term note payable, at 30-day LIBOR plus 0.90%, November 1, 2021
Principal
Notes payable		7,000,000	7,000,000
Unamortized Debt Issuance Costs		$ 3,613	$ 6,948
Roanoke Gas \| Unsecured Debt \| Unsecured term note payable, at 30-day LIBOR plus 0.90%, November 1, 2021 \| 30-day LIBOR
Debt Instrument [Line Items]
Variable rate basis points (as a percent)		0.90%	0.90%
Roanoke Gas \| Unsecured Debt \| Unsecured term notes payable, at 3.58% due on October 2, 2027
Debt Instrument [Line Items]
Stated rate		3.58%	3.58%
Principal
Notes payable		$ 8,000,000	$ 8,000,000
Unamortized Debt Issuance Costs		$ 33,712	$ 38,528
Roanoke Gas \| Unsecured Debt \| Unsecured term notes payable at 4.41%, due on March 28, 2031
Debt Instrument [Line Items]
Stated rate		4.41%	4.41%
Principal
Notes payable		$ 10,000,000	$ 10,000,000
Unamortized Debt Issuance Costs		$ 32,892	36,272
Roanoke Gas \| Unsecured Debt \| Unsecured term notes payable at 3.60%, due on December 6, 2029
Debt Instrument [Line Items]
Stated rate	3.60%	3.60%
Principal
Notes payable		$ 10,000,000	0
Unamortized Debt Issuance Costs		32,585	0
Roanoke Gas \| Line of Credit \| Line-of-credit, at 30-day LIBOR plus 1.00%, due March 31, 2022
Principal
Line-of-credit		9,143,606	8,172,473
Unamortized Debt Issuance Costs		$ 0	0
Roanoke Gas \| Line of Credit \| Line-of-credit, at 30-day LIBOR plus 1.00%, due March 31, 2022 \| 30-day LIBOR
Debt Instrument [Line Items]
Variable rate basis points (as a percent)		1.00%
RGC Midstream, LLC \| Unsecured Debt \| Unsecured term notes payable, at 30-day LIBOR plus 1.35% due December 29, 2022
Principal
Notes payable		$ 25,475,200	16,012,200
Unamortized Debt Issuance Costs		$ 38,728	$ 59,504
RGC Midstream, LLC \| Unsecured Debt \| Unsecured term notes payable, at 30-day LIBOR plus 1.35% due December 29, 2022 \| 30-day LIBOR
Debt Instrument [Line Items]
Variable rate basis points (as a percent)	1.35%	1.35%	1.35%
RGC Midstream, LLC \| Unsecured Debt \| Unsecured term note payable, at 30-day LIBOR plus 1.15%, due June 12, 2026
Principal
Notes payable		$ 14,000,000	$ 14,000,000
Unamortized Debt Issuance Costs		$ 13,844	$ 16,252
RGC Midstream, LLC \| Unsecured Debt \| Unsecured term note payable, at 30-day LIBOR plus 1.15%, due June 12, 2026 \| 30-day LIBOR
Debt Instrument [Line Items]
Variable rate basis points (as a percent)		1.15%	1.15%
RGC Midstream, LLC \| Unsecured Debt \| Unsecured term note payable, at 30-day LIBOR plus 1.20%, due June 1, 2024
Principal
Notes payable		$ 10,000,000	$ 10,000,000
Unamortized Debt Issuance Costs		$ 8,644	$ 11,000
RGC Midstream, LLC \| Unsecured Debt \| Unsecured term note payable, at 30-day LIBOR plus 1.20%, due June 1, 2024 \| 30-day LIBOR
Debt Instrument [Line Items]
Variable rate basis points (as a percent)		1.20%	1.20%

Long-Term Debt (Summary of Aggr

Long-Term Debt (Summary of Aggregate Maturities of Long-Term Debt) (Details) - USD ($)	Sep. 30, 2020	Sep. 30, 2019
Maturities
2020	$ 0
2021	16,268,606
2022	25,975,200
2023	9,375,000
2024	0
Thereafter	72,500,000
Total	$ 124,118,806	$ 103,684,673

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details) - USD ($) $ in Thousands	12 Months Ended
Income Taxes (Narrative) (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Income Tax Disclosure [Abstract]
Corporate federal income tax rate	21.00%	21.00%
Deferred tax liability decrease, tax reform			$ 9,000
Regulatory liability - deferred income taxes, gross			11,800
Gross-up to pre-tax basis, tax reform			3,000
Revaluation of unregulated deferred taxes to 21%			$ 260

Income Taxes (Details of Income

Income Taxes (Details of Income Tax Expense) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Current income taxes:
Federal	$ 1,841,124	$ 1,698,215
State	342,233	268,488
Total current income taxes	2,183,357	1,966,703
Deferred income taxes:
Federal	644,682	272,079
State	477,621	411,949
Total deferred income taxes	1,122,303	684,028
Total income tax expense	$ 3,305,660	$ 2,650,731

Income Taxes (Reconciliation of

Income Taxes (Reconciliation of Income Tax Expense Based on Federal Statutory Rate) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Income Tax Disclosure [Abstract]
Income before income taxes	$ 13,870,194	$ 11,349,143
Corporate federal income tax rate	21.00%	21.00%
Income tax expense computed at the federal statutory rate	$ 2,912,741	$ 2,383,320
State income taxes, net of federal income tax benefit	647,685	537,545
Net amortization of excess deferred taxes on regulated operations	(162,228)	(212,896)
Tax benefit recognized on stock compensation	(114,984)	(96,499)
Other, net	22,446	39,261
Total income tax expense	$ 3,305,660	$ 2,650,731

Income Taxes (Schedule of Defer

Income Taxes (Schedule of Deferred Tax Assets and Liabilities) (Details) - USD ($)	Sep. 30, 2020	Sep. 30, 2019
Deferred tax assets:
Allowance for uncollectibles	$ 180,986	$ 28,503
Accrued pension and postretirement medical benefits	651,356	782,592
Regulatory effect of change in federal income tax rate	2,814,525	2,867,383
Accrued vacation	140,635	150,882
Over-recovery of gas costs	0	23,979
Cost of gas held in storage	604,962	590,495
Deferred compensation	992,605	803,979
Interest rate swaps	572,343	230,204
Rate refund	0	130,063
Other	97,564	261,125
Total gross deferred tax assets	6,054,976	5,869,205
Deferred tax liabilities:
Utility plant	18,310,474	18,132,022
MVP investment	1,693,075	705,193
Other	25,189	10,513
Total gross deferred tax liabilities	20,028,738	18,847,728
Net deferred tax liability	$ 13,973,762	$ 12,978,523

Employee Benefit Plans (Narrati

Employee Benefit Plans (Narrative) (Details) - USD ($)	12 Months Ended
Employee Benefit Plans (Narrative) (Details) - USD ($)	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Defined Benefit Plan Disclosure [Line Items]
Expected amount of AOCI recognized in net periodic benefit costs		$ 80,000
Expected amount of deferred regulatory assets to be recognized in net periodic benefit costs		$ 577,000
First Portion Match
Defined Benefit Plan Disclosure [Line Items]
Employers percentage match of employees match percentage		100.00%
Percentage of employee's gross pay that is matched by the employer		4.00%
Second Portion Match
Defined Benefit Plan Disclosure [Line Items]
Employers percentage match of employees match percentage		50.00%
Percentage of employee's gross pay that is matched by the employer		2.00%
Minimum
Defined Benefit Plan Disclosure [Line Items]
Employee contribution percent		1.00%
Maximum
Defined Benefit Plan Disclosure [Line Items]
Employee contribution percent		50.00%
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Years until benefits are fully vested		5 years
Plan assets, target allocation, percentage		30.00%	40.00%
Expected long-term rate of return on plan assets		5.50%	5.50%
Expected employer contributions in next fiscal year		$ 500,000
Pension Plan \| Forecast
Defined Benefit Plan Disclosure [Line Items]
Expected long-term rate of return on plan assets	5.40%
Postretirement Plan
Defined Benefit Plan Disclosure [Line Items]
Minimum service requirement for postretirement benefit vesting		10 years
Retirement age requirement, postretirement plan		55 years
Expected long-term rate of return on plan assets		4.26%	4.30%
Expected employer contributions in next fiscal year		$ 400,000

Employee Benefit Plans (Schedul

Employee Benefit Plans (Schedule of Changes in Benefit Obligations and Fair Value of Plan Assets, Funded Status of the Plan, and Amount Recognized in the Financial Statements) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Change in fair value of plan assets:
Noncurrent liabilities	$ (6,149,527)	$ (6,912,105)
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	34,821,069	30,927,973
Change in benefit obligation:
Benefit obligation at beginning of year	35,550,987	28,850,299
Service cost	691,602	537,268
Interest cost	1,062,227	1,166,728
Actuarial loss (gain)	3,620,400	5,901,915
Benefit payments, net of retiree contributions	(927,214)	(905,223)
Benefit obligation at end of year	39,998,002	35,550,987
Change in fair value of plan assets:
Fair value of plan assets at beginning of year	33,586,671	28,184,697
Actual return on plan assets, net of taxes	4,198,174	3,907,197
Employer contributions	800,000	2,400,000
Benefit payments, net of retiree contributions	(927,214)	(905,223)
Fair value of plan assets at end of year	37,657,631	33,586,671
Funded status	(2,340,371)	(1,964,316)
Noncurrent liabilities	(2,340,371)	(1,964,316)
Net actuarial loss, net of tax	1,181,744	1,047,063
Total amounts included in other comprehensive loss, net of tax	1,181,744	1,047,063
Net actuarial loss	6,977,944	6,356,201
Amounts recognized as regulatory assets	6,977,944	6,356,201
Postretirement Plan
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	17,925,409	18,030,399
Change in benefit obligation:
Benefit obligation at beginning of year	18,030,399	16,207,322
Service cost	167,879	132,882
Interest cost	531,480	648,944
Actuarial loss (gain)	(325,269)	1,530,522
Benefit payments, net of retiree contributions	(479,080)	(489,271)
Benefit obligation at end of year	17,925,409	18,030,399
Change in fair value of plan assets:
Fair value of plan assets at beginning of year	13,082,610	12,924,957
Actual return on plan assets, net of taxes	1,112,723	346,924
Employer contributions	400,000	300,000
Benefit payments, net of retiree contributions	(479,080)	(489,271)
Fair value of plan assets at end of year	14,116,253	13,082,610
Funded status	(3,809,156)	(4,947,789)
Noncurrent liabilities	(3,809,156)	(4,947,789)
Net actuarial loss, net of tax	614,987	777,717
Total amounts included in other comprehensive loss, net of tax	614,987	777,717
Net actuarial loss	2,755,333	3,661,168
Amounts recognized as regulatory assets	$ 2,755,333	$ 3,661,168

Employee Benefit Plans (Sched_2

Employee Benefit Plans (Schedule of Actuarial Assumptions Used) (Details)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Pension Plan
Assumptions used to determine benefit obligations:
Discount rate	2.47%	3.03%
Expected rate of compensation increase	4.00%	4.00%
Assumptions used to determine benefit costs:
Discount rate	3.03%	4.11%
Expected long-term rate of return on plan assets	5.50%	5.50%
Expected rate of compensation increase	4.00%	4.00%
Postretirement Plan
Assumptions used to determine benefit obligations:
Discount rate	2.44%	3.00%
Assumptions used to determine benefit costs:
Discount rate	3.00%	4.09%
Expected long-term rate of return on plan assets	4.26%	4.30%

Employee Benefit Plans (Sched_3

Employee Benefit Plans (Schedule of Components of Net Periodic Cost) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 691,602	$ 537,268
Interest cost	1,062,227	1,166,728
Expected return on plan assets	(1,836,623)	(1,549,437)
Recognized loss	455,744	158,599
Net periodic benefit cost	372,950	313,158
Postretirement Plan
Defined Benefit Plan Disclosure [Line Items]
Service cost	167,879	132,882
Interest cost	531,480	648,944
Expected return on plan assets	(550,394)	(547,218)
Recognized loss	237,371	123,805
Net periodic benefit cost	$ 386,336	$ 358,413

Employee Benefit Plans (Summary

Employee Benefit Plans (Summary of Assumed Health Care Cost Trend Rates Used) (Details)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Pre 65
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	7.00%	7.00%
Rate to which the cost trend is assumed to decline (the ultimate trend rate)	5.50%	5.50%
Year that the rate reaches the ultimate trend rate	2023	2022
Post 65
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	5.20%	5.20%
Rate to which the cost trend is assumed to decline (the ultimate trend rate)	5.20%	5.20%
Year that the rate reaches the ultimate trend rate	2020	2019

Employee Benefit Plans (Effect

Employee Benefit Plans (Effect of a 1% Change in Health Care Cost Trend Rate Assumptions) (Details) $ in Thousands	12 Months Ended
	Sep. 30, 2020USD ($)
1% Increase
Effect on total service and interest cost components	$ 132
Effect on accumulated postretirement benefit obligation	3,042
1% Decrease
Effect on total service and interest cost components	(105)
Effect on accumulated postretirement benefit obligation	$ (2,454)

Employee Benefit Plans (Sched_4

Employee Benefit Plans (Schedule of Target and Actual Asset Allocation) (Details)	Sep. 30, 2020	Sep. 30, 2019
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Target	30.00%	40.00%
Pension Plan \| Equity securities
Defined Benefit Plan Disclosure [Line Items]
Target	30.00%
Actual	30.00%	40.00%
Pension Plan \| Debt securities
Defined Benefit Plan Disclosure [Line Items]
Target	70.00%
Actual	69.00%	59.00%
Pension Plan \| Cash
Defined Benefit Plan Disclosure [Line Items]
Target	0.00%
Actual	1.00%	1.00%
Pension Plan \| Other
Defined Benefit Plan Disclosure [Line Items]
Target	0.00%
Actual	0.00%	0.00%
Postretirement Plan \| Equity securities
Defined Benefit Plan Disclosure [Line Items]
Target	50.00%
Actual	51.00%	49.00%
Postretirement Plan \| Debt securities
Defined Benefit Plan Disclosure [Line Items]
Target	50.00%
Actual	48.00%	50.00%
Postretirement Plan \| Cash
Defined Benefit Plan Disclosure [Line Items]
Target	0.00%
Actual	1.00%	1.00%
Postretirement Plan \| Other
Defined Benefit Plan Disclosure [Line Items]
Target	0.00%
Actual	0.00%	0.00%

Employee Benefit Plans (Summa_2

Employee Benefit Plans (Summary of Fair Value Classifications of Benefit Plan Assets ) (Details) - USD ($)	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	$ 37,657,631	$ 33,586,671	$ 28,184,697
Pension Plan \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	1,665,698	1,943,321
Pension Plan \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	35,991,933	31,643,350
Pension Plan \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Cash
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	339,287	371,780
Pension Plan \| Cash \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	339,287	371,780
Pension Plan \| Cash \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Cash \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Common and Collective Trust and Pooled Funds, Bonds, Liability Driven Investment
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	26,038,966	19,702,561
Pension Plan \| Common and Collective Trust and Pooled Funds, Bonds, Liability Driven Investment \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Common and Collective Trust and Pooled Funds, Bonds, Liability Driven Investment \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	26,038,966	19,702,561
Pension Plan \| Common and Collective Trust and Pooled Funds, Bonds, Liability Driven Investment \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Domestic Large Cap Growth
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	3,462,841	4,069,197
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Domestic Large Cap Growth \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Domestic Large Cap Growth \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	3,462,841	4,069,197
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Domestic Large Cap Growth \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Domestic Large Cap Value
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	3,351,694	4,055,518
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Domestic Large Cap Value \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Domestic Large Cap Value \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	3,351,694	4,055,518
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Domestic Large Cap Value \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Domestic Small/Mid Cap Core
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	1,665,005	2,032,084
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Domestic Small/Mid Cap Core \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Domestic Small/Mid Cap Core \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	1,665,005	2,032,084
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Domestic Small/Mid Cap Core \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Foreign Large Cap Value
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	1,473,427	1,783,990
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Foreign Large Cap Value \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Foreign Large Cap Value \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	1,473,427	1,783,990
Pension Plan \| Common and Collective Trust and Pooled Funds, Equities, Foreign Large Cap Value \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Mutual Funds, Equities, Foreign Large Cap Growth
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	1,047,274	1,227,981
Pension Plan \| Mutual Funds, Equities, Foreign Large Cap Growth \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	1,047,274	1,227,981
Pension Plan \| Mutual Funds, Equities, Foreign Large Cap Growth \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Mutual Funds, Equities, Foreign Large Cap Growth \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Mutual Funds, Equities, Foreign Large Cap Value
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	279,137	343,560
Pension Plan \| Mutual Funds, Equities, Foreign Large Cap Value \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	279,137	343,560
Pension Plan \| Mutual Funds, Equities, Foreign Large Cap Value \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Pension Plan \| Mutual Funds, Equities, Foreign Large Cap Value \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	14,116,253	13,082,610	$ 12,924,957
Postretirement Plan \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	14,095,104	13,054,626
Postretirement Plan \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	21,149	27,984
Postretirement Plan \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Cash
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	73,908	66,860
Postretirement Plan \| Cash \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	73,908	66,860
Postretirement Plan \| Cash \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Cash \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Bonds, Domestic Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	6,163,808	5,987,248
Postretirement Plan \| Mutual Funds, Bonds, Domestic Fixed Income \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	6,163,808	5,987,248
Postretirement Plan \| Mutual Funds, Bonds, Domestic Fixed Income \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Bonds, Domestic Fixed Income \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Bonds, Foreign Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	638,709	611,196
Postretirement Plan \| Mutual Funds, Bonds, Foreign Fixed Income \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	638,709	611,196
Postretirement Plan \| Mutual Funds, Bonds, Foreign Fixed Income \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Bonds, Foreign Fixed Income \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, Domestic Large Cap Growth
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	2,197,839	1,909,836
Postretirement Plan \| Mutual Funds, Equities, Domestic Large Cap Growth \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	2,197,839	1,909,836
Postretirement Plan \| Mutual Funds, Equities, Domestic Large Cap Growth \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, Domestic Large Cap Growth \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, , Domestic Large Cap Value
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	2,119,433	1,931,615
Postretirement Plan \| Mutual Funds, Equities, , Domestic Large Cap Value \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	2,119,433	1,931,615
Postretirement Plan \| Mutual Funds, Equities, , Domestic Large Cap Value \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, , Domestic Large Cap Value \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, Domestic Small Mid Cap Growth
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	262,726	210,251
Postretirement Plan \| Mutual Funds, Equities, Domestic Small Mid Cap Growth \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	262,726	210,251
Postretirement Plan \| Mutual Funds, Equities, Domestic Small Mid Cap Growth \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, Domestic Small Mid Cap Growth \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, Domestic Small Mid Cap Value
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	235,216	214,034
Postretirement Plan \| Mutual Funds, Equities, Domestic Small Mid Cap Value \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	235,216	214,034
Postretirement Plan \| Mutual Funds, Equities, Domestic Small Mid Cap Value \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, Domestic Small Mid Cap Value \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, Domestic Small Mid Cap Core
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	552,607	464,526
Postretirement Plan \| Mutual Funds, Equities, Domestic Small Mid Cap Core \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	552,607	464,526
Postretirement Plan \| Mutual Funds, Equities, Domestic Small Mid Cap Core \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, Domestic Small Mid Cap Core \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, Foreign Large Cap Growth
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	548,967	489,286
Postretirement Plan \| Mutual Funds, Equities, Foreign Large Cap Growth \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	548,967	489,286
Postretirement Plan \| Mutual Funds, Equities, Foreign Large Cap Growth \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, Foreign Large Cap Growth \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, Foreign Large Cap Value
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	1,224,420	1,098,992
Postretirement Plan \| Mutual Funds, Equities, Foreign Large Cap Value \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	1,224,420	1,098,992
Postretirement Plan \| Mutual Funds, Equities, Foreign Large Cap Value \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, Foreign Large Cap Value \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, Foreign Large Cap Core
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	77,471	70,782
Postretirement Plan \| Mutual Funds, Equities, Foreign Large Cap Core \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	77,471	70,782
Postretirement Plan \| Mutual Funds, Equities, Foreign Large Cap Core \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Equities, Foreign Large Cap Core \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Other
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	21,149	27,984
Postretirement Plan \| Mutual Funds, Other \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	0	0
Postretirement Plan \| Mutual Funds, Other \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	21,149	27,984
Postretirement Plan \| Mutual Funds, Other \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of benefit plan assets	$ 0	$ 0

Employee Benefit Plans (Sched_5

Employee Benefit Plans (Schedule of Expected Future Benefit Payments) (Details)	Sep. 30, 2020USD ($)
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
2021	$ 1,043,787
2022	1,133,470
2023	1,221,341
2024	1,320,157
2025	1,416,485
2026-2030	8,355,472
Postretirement Plan
Defined Benefit Plan Disclosure [Line Items]
2021	568,170
2022	605,966
2023	666,049
2024	678,659
2025	684,989
2026-2030	$ 3,637,984

Employee Benefit Plans (Sched_6

Employee Benefit Plans (Schedule of Employer Contributions) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Retirement Benefits [Abstract]
Matching contribution	$ 364,773	$ 348,369
Discretionary contribution	$ 18,313	$ 21,829

Common Stock Options (Narrative

Common Stock Options (Narrative) (Details)	12 Months Ended
Common Stock Options (Narrative) (Details)	Sep. 30, 2020shares
Share-based Payment Arrangement [Abstract]
Number of shares available for future grant	23,000
Award vesting period	6 months
Award expiration period	10 years
Expected exercise term (years)	7 years

Common Stock Options (Fair Valu

Common Stock Options (Fair Value Assumptions) (Details)	12 Months Ended
Common Stock Options (Fair Value Assumptions) (Details)	Sep. 30, 2020
Share-based Payment Arrangement [Abstract]
Expected volatility (as a percent)	31.53%
Expected dividends (as a percent)	2.74%
Expected exercise term (years)	7 years
Risk-free interest rate	0.51%

Common Stock Options (Schedule

Common Stock Options (Schedule of Stock Option Activity) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Number of Shares
Options outstanding, beginning balance (in shares)	68,492	100,000
Options granted (in shares)	13,000	0
Options exercised (in shares)	(29,992)	(31,508)
Options expired (in shares)	0	0
Options forfeited (in shares)	0	0
Options outstanding, ending balance (in shares)	51,500	68,492	100,000
Vested and exercisable at end of period (in shares)	51,500
Weighted- Average Exercise Price
Options outstanding, beginning balance (in usd per share)	$ 14.91	$ 14.34
Options granted (in usd per share)	27.87	0
Options exercised (in usd per share)	14.65	13.08
Options expired (in usd per share)	0	0
Options forfeited (in usd per share)	0	0
Options outstanding, ending balance (in usd per share)	18.34	$ 14.91	$ 14.34
Vested and exercisable at end of period (in usd per share)	$ 18.34
Options, Additional Disclosures
Weighted- Average Remaining Contractual Terms (years)	6 years 4 months 24 days	6 years 2 months 12 days	6 years 7 months 6 days
Weighted-Average Remaining Contractual Term, Vested and exercisable at end of period	6 years 4 months 24 days
Aggregate Intrinsic Value	$ 320,797	$ 981,170	$ 1,237,286
Aggregate Intrinsic Value, Vested and exercisable at end of period	$ 320,797
Weighted-average grant date option fair value (in usd per share)	$ 6.26	$ 0
Stock option expense	$ 81,380	$ 0
Intrinsic value of options exercised	411,638	456,002
Proceeds from exercise of stock options	$ 439,509	$ 412,179

Other Stock Plans (Narrative) (

Other Stock Plans (Narrative) (Details) - USD ($)	12 Months Ended
Other Stock Plans (Narrative) (Details) - USD ($)	Sep. 30, 2020	Sep. 30, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum amount shareholders can partake in the DRIP plan	$ 100,000
Number of shares issued under the DRIP	28,191	26,716
Shares of stock available for issuance under the DRIP Plan	362,322
Shares available for issuance	23,000
Restricted Stock Plan for Outside Directors \| Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum allowed percent of retainer fee that can be paid in common stock	100.00%
Minimum percentage of monthly retainer fee paid in shares of common stock	40.00%
Minimum number of shares that must be owned to avoid percentage of monthly retainer fee paid in shares of common stock	10,000
Value of shares issued under the plan	$ 241,617	$ 178,100
Number of shares forfeited during the period	0	0
Shares available for issuance	52,029
RGC Resources, Inc. Restricted Stock Plan \| Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Value of shares issued under the plan	$ 450,677	$ 282,365
Number of shares forfeited during the period	0	0
Shares available for issuance	413,718
Stock Bonus Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares available for issuance	4,785
Shares issued under the plan	0	0

Other Stock Plans (Director Com

Other Stock Plans (Director Compensation Activity) (Details) - Restricted Stock Plan for Outside Directors - Restricted Stock - $ / shares	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Shares
Beginning of year balance (in shares)	104,680	98,302
Granted (in shares)	9,193	6,378
Vested (in shares)	(14,803)	0
Forfeited (in shares)	0	0
End of year balance (in shares)	99,070	104,680
Weighted-Average Fair Value on Date of Grant
Beginning of year balance (in usd per share)	$ 12.51	$ 11.51
Granted (in usd per share)	26.28	27.93
Vested (in usd per share)	10.68	0
Forfeited (in usd per share)	0	0
End of year balance (in usd per share)	$ 14.06	$ 12.51

Other Stock Plans (Officer Comp

Other Stock Plans (Officer Compensation Activity) (Details) - RGC Resources, Inc. Restricted Stock Plan - Restricted Stock - $ / shares	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Shares
Beginning of year balance (in shares)	10,185	6,734
Granted (in shares)	14,951	10,227
Vested (in shares)	(18,321)	(6,776)
Forfeited (in shares)	0	0
End of year balance (in shares)	6,815	10,185
Weighted-Average Fair Value on Date of Grant
Beginning of year balance (in usd per share)	$ 28.65	$ 26.33
Granted (in usd per share)	28.17	29.80
Vested (in usd per share)	28.30	28.08
Forfeited (in usd per share)	0	0
End of year balance (in usd per share)	$ 28.55	$ 28.65

Commitments and Contingencies_2

Commitments and Contingencies (Narrative) (Details)	1 Months Ended	12 Months Ended
Commitments and Contingencies (Narrative) (Details)	Jul. 31, 2020	Sep. 30, 2020USD ($)$ / dekathermBcf	Sep. 30, 2019USD ($)
Commitments and Contingencies Disclosure [Abstract]
Asset management contract term	1 year
Minimum energy volume required (in dth) \| Bcf		1.3
Franchise agreement term		20 years
Franchise fee annual increase		3.00%
Franchise fee, total cost through end of agreement \| $		$ 2,294,588
Minimum
Product Information [Line Items]
Purchase price per energy volume (in usd per dth) \| $ / dekatherm		2.17
Maximum
Product Information [Line Items]
Purchase price per energy volume (in usd per dth) \| $ / dekatherm		2.62
Natural Gas Pipeline and Storage Capacity
Product Information [Line Items]
Cost of sales \| $		$ 21,881,000	$ 30,317,000

Commitments and Contingencies_3

Commitments and Contingencies (Schedule of Volumetric Obligations) (Details)	Sep. 30, 2020MMBTU
Commitments and Contingencies Disclosure [Abstract]
2020-2021	2,090,972
2021-2022	295,866
Total	2,386,838

Commitments and Contingencies_4

Commitments and Contingencies (Schedule of Pipeline and Storage Capacity Obligations) (Details)	Sep. 30, 2020USD ($)
Commitments and Contingencies Disclosure [Abstract]
2020-2021	$ 11,048,798
2021-2022	10,284,092
2022-2023	7,403,271
2023-2024	5,743,826
2024-2025	3,167,937
Thereafter	888,426
Total	$ 38,536,350

Fair Value Measurements (Schedu

Fair Value Measurements (Schedule of Fair Value of Financial Assets and Liabilities Measured on a Recurring Basis) (Details) - Estimate of Fair Value Measurement - USD ($)	Sep. 30, 2020	Sep. 30, 2019
Quoted Prices in Active Markets Level 1
Liabilities:
Total	$ 0	$ 0
Significant Other Observable Inputs Level 2
Liabilities:
Total	0	0
Significant Unobservable Inputs Level 3
Liabilities:
Total	124,740,970	100,900,952
Fair Value, Recurring
Liabilities:
Natural gas purchases	470,755	397,757
Total	2,694,311	1,292,098
Fair Value, Recurring \| Interest Rate Swap
Liabilities:
Interest rate swaps	2,223,556	894,341
Fair Value, Recurring \| Quoted Prices in Active Markets Level 1
Liabilities:
Natural gas purchases	0	0
Total	0	0
Fair Value, Recurring \| Quoted Prices in Active Markets Level 1 \| Interest Rate Swap
Liabilities:
Interest rate swaps	0	0
Fair Value, Recurring \| Significant Other Observable Inputs Level 2
Liabilities:
Natural gas purchases	470,755	397,757
Total	2,694,311	1,292,098
Fair Value, Recurring \| Significant Other Observable Inputs Level 2 \| Interest Rate Swap
Liabilities:
Interest rate swaps	2,223,556	894,341
Fair Value, Recurring \| Significant Unobservable Inputs Level 3
Liabilities:
Natural gas purchases	0	0
Total	0	0
Fair Value, Recurring \| Significant Unobservable Inputs Level 3 \| Interest Rate Swap
Liabilities:
Interest rate swaps	$ 0	$ 0

Fair Value Measurements (Summar

Fair Value Measurements (Summary of the Fair Value of Financial Assets and Liabilities Not Adjusted to Fair Value) (Details) - USD ($)	Sep. 30, 2020	Sep. 30, 2019
Reported Value Measurement
Liabilities:
Notes payable	$ 114,975,200	$ 95,512,200
Total	114,975,200	95,512,200
Estimate of Fair Value Measurement \| Quoted Prices in Active Markets Level 1
Liabilities:
Notes payable	0	0
Total	0	0
Estimate of Fair Value Measurement \| Significant Other Observable Inputs Level 2
Liabilities:
Notes payable	0	0
Total	0	0
Estimate of Fair Value Measurement \| Significant Unobservable Inputs Level 3
Liabilities:
Notes payable	124,740,970	100,900,952
Total	$ 124,740,970	$ 100,900,952

Fair Value Measurements (Narrat

Fair Value Measurements (Narrative) (Details)	12 Months Ended
Fair Value Measurements (Narrative) (Details)	Sep. 30, 2020
Fair Value Disclosures [Abstract]
Treasury rate, period	20 years

Quarterly Financial Informati_3

Quarterly Financial Information (Unaudited) (Details) - USD ($)	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019
Quarterly Financial Information Disclosure [Abstract]
Operating revenues	$ 9,780,289	$ 11,071,918	$ 22,437,731	$ 19,785,453	$ 9,851,869	$ 11,682,950	$ 25,274,959	$ 21,216,747	$ 63,075,391	$ 68,026,525
Operating income (loss)	(899,076)	1,335,663	6,999,616	5,081,979	490,702	1,637,057	6,203,483	3,264,222	12,518,182	11,595,464
Net income (loss)	$ (329,296)	$ 1,206,578	$ 5,680,316	$ 4,006,936	$ 455,605	$ 1,138,555	$ 4,670,090	$ 2,434,162	$ 10,564,534	$ 8,698,412
Earnings (loss) per share of common stock:
Basic (in usd per share)	$ (0.04)	$ 0.15	$ 0.70	$ 0.50	$ 0.06	$ 0.14	$ 0.58	$ 0.30	$ 1.30	$ 1.08
Diluted (in usd per share)	$ (0.04)	$ 0.15	$ 0.70	$ 0.49	$ 0.06	$ 0.14	$ 0.58	$ 0.30	$ 1.30	$ 1.08