Chesapeake Utilities (CPK) 10-K 22 Feb 23 2022 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2022	Feb. 17, 2023	Jun. 30, 2022
Cover [Abstract]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2022
Document Transition Report	false
Entity File Number	001-11590
Entity Registrant Name	CHESAPEAKE UTILITIES CORP
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	51-0064146
Entity Address, Address Line One	500 Energy Lane
Entity Address, City or Town	Dover
Entity Address, State or Province	DE
Entity Address, Postal Zip Code	19901
City Area Code	302
Local Phone Number	734-6799
Title of 12(b) Security	Common Stock—par value per share $0.4867
Trading Symbol	CPK
Security Exchange Name	NYSE
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 2.2
Entity Common Stock, Shares Outstanding		17,741,418
Documents Incorporated by Reference	Portions of the Chesapeake Utilities Corporation Proxy Statement for the 2023 Annual Meeting of Shareholders are incorporated by reference in Part II and Part III hereof
Entity Central Index Key	0000019745
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	FY
Amendment Flag	false
ICFR Auditor Attestation Flag	true
Document Information [Line Items]
Entity Common Stock, Shares Outstanding		17,741,418

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2022
Auditor [Line Items]
Auditor Name	Baker Tilly US, LLP
Auditor Location	Philadelphia, Pennsylvania
Auditor Firm ID	23

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Operating Revenues
Regulated Energy	$ 429,424	$ 383,920	$ 352,746
Unregulated Energy	280,750	206,869	152,526
Other	(29,470)	(20,821)	(17,074)
Total operating revenues	680,704	569,968	488,198
Operating Expenses
Natural gas and electricity costs	127,172	100,737	91,994
Propane and natural gas costs	133,334	86,213	45,944
Operations	164,505	148,294	142,055
Maintenance	18,176	16,793	15,587
Gain from a settlement	0	0	(130)
Depreciation and amortization	68,973	62,661	58,117
Other taxes	25,611	24,158	21,908
Total operating expenses	537,771	438,856	375,475
Operating Income	142,933	131,112	112,723
Other income, net	5,051	1,721	3,222
Interest charges	24,356	20,135	21,765
Income from Continuing Operations Before Income Taxes	123,628	112,698	94,180
Income Taxes on Continuing Operations	33,832	29,231	23,538
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent	89,796	83,467	70,642
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	0	(1)	686
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax	0	0	170
Net Income (Loss) Attributable to Parent	$ 89,796	$ 83,466	$ 71,498
Weighted Average Common Shares Outstanding:
Basic (in shares)	17,722,227	17,558,078	16,711,579
Diluted (in shares)	17,804,294	17,633,029	16,770,735
Earnings Per Share of Common Stock:
Income (Loss) from Continuing Operations, Per Basic Share	$ 5.07	$ 4.75	$ 4.23
Discontinued Operation, Income (Loss) from Discontinued Operation, Net of Tax, Per Basic Share	0	0	0.05
Basic (in usd per share)	5.07	4.75	4.28
Earnings Per Share, Diluted [Abstract]
Income (Loss) from Continuing Operations, Per Diluted Share	5.04	4.73	4.21
Discontinued Operation, Income (Loss) from Discontinued Operation, Net of Tax, Per Diluted Share	0	0
Diluted (in usd per share)	$ 5.04	$ 4.73	$ 4.26

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Comprehensive Income [Abstract]
Net Income	$ 89,796	$ 83,466	$ 71,498
Employee Benefits, net of tax:
Reclassifications of amortization of prior service credit and actuarial (gain) loss, net of tax of $18, $550 and $150, respectively	57	1,616	365
Net gain (loss), net of tax of $243, $93, and $(209), respectively	705	262	(578)
Cash Flow Hedges, net of tax:
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), after Reclassification and Tax, Parent		0	16
Total Other Comprehensive Income (Loss)	(2,682)	4,168	3,402
Comprehensive Income	87,114	87,634	74,900
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(2,453)	(3,169)
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	2,453	3,169
Reclassifications of amortization of prior service credit and actuarial (gain) loss, net of tax of $18, $550 and $150, respectively	57	1,616	365
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	(705)	(262)	578
Other Comprehensive Income (Loss), before Reclassifications, before Tax	(229)	7,337
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), after Reclassification and Tax, Parent		0	16
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent
Cash Flow Hedges, net of tax:
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	35	28	(44)
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(35)	(28)	44
Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Cash Flow Hedges, net of tax:
Net (loss) gain on commodity contract cash flow hedges, net of tax of $(369), $2,702 and $2,063, respectively		7,075	5,400
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(2,545)	(4,813)	(1,757)
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	2,545	4,813	1,757
Other Comprehensive Income (Loss), before Reclassifications, before Tax	(934)	7,075
Net (loss) gain on commodity contract cash flow hedges, net of tax of $(369), $2,702 and $2,063, respectively		7,075	$ 5,400
Accumulated (Gain) Loss from Interest Rate Swap Cash Flows Hedges
Cash Flow Hedges, net of tax:
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		28
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		(28)
Other Comprehensive Income (Loss), before Reclassifications, before Tax	$ 0	$ 0

Consolidated Statements of Co_2

Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Comprehensive Income [Abstract]
Tax expense recognized on the amortization of prior service cost	$ 18,000	$ 550,000	$ (18,000)
Tax expense recognized on the net gain (loss)	243,000	93,000	(41,000)
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax	(369,000)	2,702,000	2,063,000
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Interest Rate Swaps During Period, Tax	0	0	0
Accumulated Other Comprehensive Income (Loss) [Line Items]
Tax expense recognized on the amortization of prior service cost	18,000	550,000	(18,000)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, Tax	(243,000)	(93,000)	41,000
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax	(369,000)	2,702,000	2,063,000
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Interest Rate Swaps During Period, Tax	0	0	0
Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Statement of Comprehensive Income [Abstract]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	(963,000)	(1,838,000)	(671,000)
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	(963,000)	(1,838,000)	(671,000)
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent
Statement of Comprehensive Income [Abstract]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	(12,000)	12,000	(16,000)
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	$ (12,000)	$ 12,000	$ (16,000)

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Operating Activities
Net Income	$ 89,796	$ 83,466	$ 71,498
Adjustments to reconcile net income to net operating cash:
Depreciation and amortization	68,973	62,661	58,117
Depreciation and accretion included in operations expenses	11,044	10,228	9,599
Deferred income taxes, net	23,705	26,658	24,709
Gain on sale of discontinued operations	0	0	(200)
Realized (loss) on sale of assets/commodity contracts	(7,532)	(9,026)	(6,243)
Unrealized loss (gain) on investments/commodity contracts	1,817	(1,464)	(1,482)
Employee benefits and compensation	(1,111)	(53)	207
Share-based compensation	6,438	5,945	4,829
Changes in assets and liabilities:
Accounts receivable and accrued revenue	(11,159)	(1,634)	(7,426)
Propane inventory, storage gas and other inventory	(7,847)	(9,517)	1,709
Regulatory assets/liabilities, net	(38,671)	(18,464)	(4,973)
Prepaid expenses and other current assets	9,124	(1,520)	2,424
Accounts payable and other accrued liabilities	2,724	8,285	4,941
Income taxes receivable	14,919	(4,575)	7,165
Customer deposits and refunds	664	3,176	2,238
Accrued compensation	(1,231)	1,198	(2,473)
Other assets and liabilities, net	(2,771)	(4,860)	(5,723)
Net cash provided by operating activities	158,882	150,504	158,916
Investing Activities
Property, plant and equipment expenditures	(128,276)	(186,924)	(165,511)
Proceeds from sale of assets	3,860	1,033	8,080
Acquisitions, net of cash acquired	(11,766)	(36,371)	(22,231)
Proceeds from the sale of discontinued operations	0	0	200
Environmental expenditures	(266)	(761)	(2,169)
Net cash used in investing activities	(136,448)	(223,023)	(181,631)
Financing Activities
Common stock dividends	(35,147)	(31,537)	(27,161)
Payments for Repurchase of Common Stock	4,534	15,851	22,627
Proceeds from issuance of common stock, net of expenses	0	0	60,980
Payment, Tax Withholding, Share-based Payment Arrangement	(2,838)	(1,478)	(977)
Change in cash overdrafts due to outstanding checks	955	(1,154)	(825)
Net borrowings (repayments) under line of credit agreements	(20,608)	46,647	(71,637)
Proceeds from issuance of long-term debt	49,859	59,478	89,822
Repayment of long-term debt and finance lease obligation	(17,961)	(13,811)	(53,600)
Net cash (used in) provided by financing activities	(21,206)	73,996	19,229
Net (Decrease) Increase in Cash and Cash Equivalents	1,228	1,477	(3,486)
Cash and Cash Equivalents — Beginning of Period	4,976	3,499	6,985
Cash and Cash Equivalents — End of Period	$ 6,204	$ 4,976	$ 3,499

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Property, Plant and Equipment
Regulated Energy	$ 1,802,999	$ 1,720,287
Unregulated Energy	393,215	357,259
Other businesses and eliminations	29,890	35,418
Total property, plant and equipment	2,226,104	2,112,964
Accumulated depreciation	462,926	417,479
Construction Work in Progress	47,295	49,393
Net property, plant and equipment	1,810,473	1,744,878
Current Assets
Cash and cash equivalents	6,204	4,976
Accounts Receivable, before Allowance for Credit Loss, Current	65,758	61,623
Allowance for uncollectible accounts	2,877	3,141
Trade receivables, net	62,881	58,482
Accrued Revenue	29,206	22,513
Propane inventory, at average cost	9,365	11,644
Other inventory, at average cost	16,896	9,345
Regulatory assets	41,439	19,794
Storage gas prepayments	6,364	3,691
Income taxes receivable	2,541	17,460
Prepaid expenses	15,865	17,121
Derivative assets, at fair value	2,787	4,277
Other current assets	428	1,033
Total current assets	193,976	170,336
Deferred Charges and Other Assets
Goodwill	46,213	44,708
Other intangible assets, net	17,859	13,192
Investments, Fair Value Disclosure	10,576	12,095
Operating Lease, Right-of-Use Asset	14,421	10,139
Regulatory assets	108,214	104,173
Receivables and other deferred charges	12,323	12,549
Total deferred charges and other assets	210,588	199,655
Total Assets	2,215,037	2,114,869
Stockholders’ equity
Preferred stock, par value $0.01 per share (authorized 2,000,000 shares), no shares issued and outstanding	0	0
Common stock, par value $0.4867 per share (authorized 50,000,000 shares)	8,635	8,593
Additional paid-in capital	380,036	371,162
Retained earnings	445,509	393,072
Accumulated other comprehensive income (loss)	(1,379)	1,303
Deferred compensation obligation	7,060	7,240
Treasury Stock, Value	(7,060)	(7,240)
Total stockholders’ equity	832,801	774,130
Long-term debt, net of current maturities	578,388	549,903
Total capitalization	1,411,189	1,324,033
Current Liabilities
Current portion of long-term debt	21,483	17,962
Short-term borrowing	202,157	221,634
Accounts payable	61,496	52,628
Customer deposits and refunds	37,152	36,488
Accrued interest	3,349	2,775
Dividends payable	9,492	8,466
Accrued compensation	14,660	15,505
Regulatory liabilities	5,031	2,312
Derivative liabilities, at fair value	585	704
Other accrued liabilities	13,618	17,920
Total current liabilities	369,023	376,394
Deferred Credits and Other Liabilities
Deferred income taxes	256,167	233,550
Regulatory liabilities	142,989	142,488
Environmental liabilities	3,272	3,538
Other pension and benefit costs	16,965	24,120
Operating Lease, Liability, Noncurrent	12,392	8,571
Deferred investment tax credits and other liabilities	1,410	2,136
Total deferred credits and other liabilities	434,825	414,442
Commitments and Contingencies
Total Capitalization and Liabilities	2,215,037	2,114,869
Regulated Energy	1,802,999	1,720,287
Unregulated Energy	393,215	357,259
Other businesses and eliminations	29,890	35,418
Total property, plant and equipment	2,226,104	2,112,964
Accumulated depreciation	462,926	417,479
Construction Work in Progress	47,295	49,393
Net property, plant and equipment	1,810,473	1,744,878
Cash and cash equivalents	6,204	4,976
Accounts Receivable, before Allowance for Credit Loss, Current	65,758	61,623
Allowance for uncollectible accounts	2,877	3,141
Trade receivables, net	62,881	58,482
Accrued Revenue	29,206	22,513
Propane inventory, at average cost	9,365	11,644
Other inventory, at average cost	16,896	9,345
Regulatory assets	41,439	19,794
Storage gas prepayments	6,364	3,691
Income taxes receivable	2,541	17,460
Prepaid expenses	15,865	17,121
Derivative assets, at fair value	2,787	4,277
Other current assets	428	1,033
Disposal Group, Including Discontinued Operation, Assets, Current	193,976	170,336
Goodwill	46,213	44,708
Other intangible assets, net	17,859	13,192
Investments, Fair Value Disclosure	10,576	12,095
Energy Marketing Contracts Assets, Noncurrent	982	2,799
Operating Lease, Right-of-Use Asset	14,421	10,139
Regulatory assets	108,214	104,173
Receivables and other deferred charges	12,323	12,549
Deferred Charges And Other Assets	210,588	199,655
Total identifiable assets	2,215,037	2,114,869
Preferred stock, par value $0.01 per share (authorized 2,000,000 shares), no shares issued and outstanding	0	0
Common stock, par value $0.4867 per share (authorized 50,000,000 shares)	8,635	8,593
Additional paid-in capital	380,036	371,162
Retained earnings	445,509	393,072
Accumulated other comprehensive income (loss)	(1,379)	1,303
Deferred compensation obligation	7,060	7,240
Treasury Stock, Value	7,060	7,240
Stockholders' Equity Attributable to Parent	832,801	774,130
Long-term debt, net of current maturities	578,388	549,903
Total capitalization	1,411,189	1,324,033
Current portion of long-term debt	21,483	17,962
Short-term borrowing	202,157	221,634
Accounts payable	61,496	52,628
Customer deposits and refunds	37,152	36,488
Accrued interest	3,349	2,775
Dividends payable	9,492	8,466
Accrued compensation	14,660	15,505
Regulatory liabilities	5,031	2,312
Derivative liabilities, at fair value	585	704
Other accrued liabilities	13,618	17,920
Liabilities, Current	369,023	376,394
Deferred income taxes	256,167	233,550
Regulatory liabilities	142,989	142,488
Environmental liabilities	3,272	3,538
Other pension and benefit costs	16,965	24,120
Energy Marketing Contract Liabilities, Noncurrent	1,630	39
Operating Lease, Liability, Noncurrent	12,392	8,571
Deferred investment tax credits and other liabilities	1,410	2,136
Deferred Credits and Other Liabilities	434,825	414,442
Commitments and Contingencies
Liabilities and Equity	$ 2,215,037	$ 2,114,869

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Statement of Financial Position [Abstract]
Allowance for uncollectible accounts	$ 2,877	$ 3,141
Common stock, par value	$ 0.4867	$ 0.4867
Common stock, shares authorized	50,000,000	50,000,000
Preferred Stock, Shares Authorized	2,000,000	2,000,000
Preferred Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01

Consolidated Statements of Stoc

Consolidated Statements of Stockholders' Equity - USD ($)		Total		Common Stock [Member]	Additional Paid-In Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Loss [Member]	Deferred Compensation [Member]	Treasury Stock [Member]
Shares, Issued	[1],[2]			16,403,776
Stockholders' Equity Attributable to Parent		$ 561,577,000	[2]	$ 7,984,000	$ 259,253,000	$ 300,607,000	$ (6,267,000)	$ 4,543,000	$ (4,543,000)
Net Income		71,498,000				71,498,000
Other comprehensive loss		3,402,000					3,402,000
Dividends		(29,106,000)				(29,106,000)
Stock Issued, Value, During The Period Shares Retirement Savings Plan And Dividend Reinvestment Plan				$ 498,000
Stock Issued During The Period Shares Retirement Savings Plan And Dividend Reinvestment Plan				1,023,609
Stock Issued During The Period Value Retirement Savings Plan And Dividend Reinvestment Plan		85,851,000			85,353,000
Share-based compensation, shares				34,456
Share-based compensation		3,893,000	[3],[4]	$ 17,000	3,876,000
Treasury stock activities		0						1,136,000	(1,136,000)
New Accounting Pronouncement of Change in Accounting Principle, Effect of Adoption		30,000				30,000
Shares, Issued	[1],[2]			17,461,841
Stockholders' Equity Attributable to Parent		697,085,000	[2]	$ 8,499,000	348,482,000	342,969,000	(2,865,000)	5,679,000	(5,679,000)
Net Income		83,466,000				83,466,000
Other comprehensive loss		4,168,000					4,168,000
Dividends		(33,363,000)				(33,363,000)
Stock Issued, Value, During The Period Shares Retirement Savings Plan And Dividend Reinvestment Plan				$ 72,000	18,176,000
Stock Issued During The Period Value Retirement Savings Plan And Dividend Reinvestment Plan		18,248,000
Share-based compensation, shares	[3],[4]			46,313
Share-based compensation		$ 4,526,000	[3],[4]	$ 22,000	4,504,000
Treasury stock activities								1,561,000	(1,561,000)
Stock Issued During Period, Shares, Dividend Reinvestment Plan		100,000		147,256
Stock Issued During Period, Value, Dividend Reinvestment Plan		$ 125.71
Shares, Issued	[1],[2]			17,655,410
Stockholders' Equity Attributable to Parent		774,130,000		$ 8,593,000	371,162,000	393,072,000	1,303,000	7,240,000	(7,240,000)
Net Income		89,796,000
Other comprehensive loss		(2,682,000)					(2,682,000)
Dividends		(37,359,000)				(37,359,000)
Stock Issued, Value, During The Period Shares Retirement Savings Plan And Dividend Reinvestment Plan		5,292,000		$ 19,000	5,273,000
Stock Issued During The Period Shares Retirement Savings Plan And Dividend Reinvestment Plan				39,418
Share-based compensation, shares	[3],[4]			46,590
Share-based compensation		$ 3,624,000	[3],[4]	$ 23,000	3,601,000
Treasury stock activities								(180,000)	180,000
Stock Issued During Period, Shares, Dividend Reinvestment Plan		100,000
Stock Issued During Period, Value, Dividend Reinvestment Plan		$ 136.26
Shares, Issued	[1],[2]			17,741,418
Stockholders' Equity Attributable to Parent		$ 832,801,000		$ 8,635,000	$ 380,036,000	$ 445,509,000	$ (1,379,000)	$ 7,060,000	$ (7,060,000)
[1]2,000,000 shares of preferred stock at $0.01 par value per share have been authorized. No shares have been issued or are outstanding; accordingly, no information has been included in the Consolidated Statements of Stockholders’ Equity.[2]Includes 108,143, 116,238 and 105,087 shares at December 31, 2022, 2021 and 2020, respectively, held in a Rabbi Trust related to our Non-Qualified Deferred Compensation Plan[3]Includes amounts for shares issued for directors’ compensation.[4]The shares issued under the SICP are net of shares withheld for employee taxes. For 2022, 2021 and 2020, we withheld 21,832, 14,020 and 10,319 shares, respectively, for taxes. (5) Includes shares issued under the Retirement Savings Plan, DRIP and/or ATM equity issuances, as applicable.

Consolidated Statements of St_2

Consolidated Statements of Stockholders' Equity Consolidated Statements of Stockholders' Equity (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Stockholders' Equity [Abstract]
Preferred Stock, Shares Authorized	2,000,000	2,000,000
Preferred Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Shares Held In Trust For Deferred Compensation Plan	108,143	116,238	105,087
Dividends Declared	$ 2.0850	$ 1.7250	$ 1.5850
Shares Issued Under Performance Incentive Plan Withheld For Employee Taxes	21,832	14,020	10,319

Organization and Basis of Prese

Organization and Basis of Presentation	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Organization and Basis of Presentation	O RGANIZATION AND B ASIS OF P RESENTATION Chesapeake Utilities, incorporated in 1947 in Delaware, is a diversified energy company engaged in regulated and unregulated energy businesses. Our regulated energy businesses consist of: (a) regulated natural gas distribution operations in central and southern Delaware, Maryland’s eastern shore and Florida; (b) regulated natural gas transmission operations on the Delmarva Peninsula, in Pennsylvania, Florida and in Ohio; and (c) regulated electric distribution operations serving customers in northeast and northwest Florida. Our unregulated energy businesses primarily include: (a) propane operations in the Mid-Atlantic region, North Carolina, South Carolina, and Florida; (b) our unregulated natural gas transmission/supply operation in central and eastern Ohio; (c) our CHP plant in Florida that generates electricity and steam; (d) our subsidiary, based in Florida, that provides CNG, LNG and RNG transportation and pipeline solutions, primarily to utilities and pipelines throughout the United States; and (e) project development activities related to our sustainable energy initiatives. Our consolidated financial statements include the accounts of Chesapeake Utilities and its wholly-owned subsidiaries. We do not have any ownership interest in investments accounted for using the equity method or any interest in a variable interest entity. All intercompany accounts and transactions have been eliminated in consolidation. We have assessed and, if applicable, reported on subsequent events through the date of issuance of these consolidated financial statements. Where necessary to improve comparability, prior period amounts have been reclassified to conform to current period presentation.
Covid-19 Effects	Effects of COVID-19 In March 2020, the CDC declared a national emergency due to the rapidly growing outbreak of COVID-19. In response to this declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the country imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to slow the spread of the illness. These restrictions significantly impacted economic conditions in the United States beginning in 2020 and to a lesser extent continued throughout 2022. Chesapeake Utilities is considered an “essential business,” which allowed us to continue operational activities and construction projects while social distancing restrictions were in place. At this time, restrictions have predominantly been lifted as vaccines have become widely available in the United States. Previously existing states of emergency in all of our service territories expired during the second and third quarters of 2021 eliminating a majority of restrictions initially implemented to slow the spread of the virus. The expiration of the states of emergency along with the settlement of our limited proceeding in Florida concluded our ability to defer incremental pandemic related costs for consideration through the applicable regulatory process. We adjusted our operating practices accordingly to ensure the safety of our operations and will take the necessary actions to comply with the CDC, and the Occupational and Safety and Health Administration, as new developments occur. Refer to Note 18 , Rates and Other Regulatory Activities , for further information on the regulated assets established as a result of the incremental expenses associated with COVID-19.

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2022
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	S UMMARY OF S IGNIFICANT A CCOUNTING P OLICIES Use of Estimates The preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates in measuring assets and liabilities and related revenues and expenses. These estimates involve judgments about various future economic factors that are difficult to predict and are beyond our control; therefore, actual results could differ from these estimates. As additional information becomes available, or actual amounts are determined, recorded estimates are revised. Consequently, operating results can be affected by revisions to prior accounting estimates. Property, Plant and Equipment Property, plant and equipment are stated at original cost less accumulated depreciation or fair value, if impaired. Costs include direct labor, materials and third-party construction contractor costs, allowance for funds used during construction ("AFUDC"), and certain indirect costs related to equipment and employees engaged in construction. The costs of repairs and minor replacements are charged to expense as incurred, and the costs of major renewals and betterments are capitalized. Upon retirement or disposition of property within the regulated businesses, the gain or loss, net of salvage value, is charged to accumulated depreciation. Upon retirement or disposition of property owned by the unregulated businesses, the gain or loss, net of salvage value, is charged to income. A summary of property, plant and equipment by classification as of December 31, 2022 and 2021 is provided in the following table: As of December 31, (in thousands) 2022 2021 Property, plant and equipment Regulated Energy Natural gas distribution - Delmarva Peninsula and Florida $ 925,501 $ 859,627 Natural gas transmission - Delmarva Peninsula, Pennsylvania, Ohio and Florida 741,865 727,277 Electric distribution 135,633 133,383 Unregulated Energy Propane operations – Mid-Atlantic, North Carolina, South Carolina and Florida 185,090 176,095 Natural gas transmission and supply – Ohio 128,620 112,050 Electricity and steam generation 36,886 36,740 Mobile CNG and pipeline solutions 38,543 32,374 Renewable energy investments 4,076 — Other 29,890 35,418 Total property, plant and equipment 2,226,104 2,112,964 Less: Accumulated depreciation and amortization (462,926) (417,479) Plus: Construction work in progress 47,295 49,393 Net property, plant and equipment $ 1,810,473 $ 1,744,878 Contributions or Advances in Aid of Construction Customer contributions or advances in aid of construction reduce property, plant and equipment, unless the amounts are refundable to customers. Contributions or advances may be refundable to customers after a number of years based on the amount of revenues generated from the customers or the duration of the service provided to the customers. Refundable contributions or advances are recorded initially as liabilities. Non-refundable contributions reduce property, plant and equipment at the time of such determination. As of December 31, 2022 and 2021, the non-refundable contributions totaled $7.6 million and $6.3 million, respectively. AFUDC Some of the additions to our regulated property, plant and equipment include AFUDC, which represents the estimated cost of funds, from both debt and equity sources, used to finance the construction of major projects. AFUDC is capitalized in the applicable rate base for ratemaking purposes when the completed projects are placed in service. During the years ended December 31, 2022, 2021 and 2020, AFUDC totaled $0.1 million, $0.4 million and $0.7 million, respectively, which was reflected as a reduction of interest charges. Leases We have entered into lease arrangements for office space, land, equipment, pipeline facilities and warehouses. These leases enable us to conduct our business operations in the regions in which we operate. Our operating leases are included in operating lease right-of-use assets, other accrued liabilities, and operating lease - liabilities in our consolidated balance sheets. Right-of-use assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. Operating lease right-of-use assets and liabilities are recognized at commencement date based on the present value of lease payments over the lease term. Leases with an initial term of 12 months or less are not recorded on our balance sheet; we recognize lease expense for these leases on a straight-line basis over the lease term. Our leases do not provide an implicit lease rate, therefore, we utilize our incremental borrowing rate, as the basis to calculate the present value of future lease payments, at lease commencement. Our incremental borrowing rate represents the rate that we would have to pay to borrow funds on a collateralized basis over a similar term and in a similar economic environment. We have lease agreements with lease and non-lease components. At the adoption of ASC 842, we elected not to separate non-lease components from all classes of our existing leases. The non-lease components have been accounted for as part of the single lease component to which they are related. See Note 14, Leases, for additional information. Jointly-owned Pipelines Property, plant and equipment for our Florida natural gas transmission operation included $28.3 million of jointly owned assets at December 31, 2022, primarily comprised of the 26-mile Callahan intrastate transmission pipeline in Nassau County, Florida jointly-owned with Seacoast Gas Transmission. Peninsula Pipeline's ownership is 50 percent. Direct expenses for the jointly-owned pipeline are included in operating expenses of our consolidated statements of income. Accumulated depreciation for this pipeline totaled $1.5 million and $0.9 million at December 31, 2022 and 2021, respectively. Impairment of Long-lived Assets We periodically evaluate whether events or circumstances have occurred, which indicate that other long-lived assets may not be fully recoverable. The determination of whether an impairment has occurred is based on an estimate of undiscounted future cash flows attributable to the asset, compared to the carrying value of the asset. When such events or circumstances are present, we record an impairment loss equal to the excess of the asset's carrying value over its fair value, if any. Depreciation and Accretion Included in Operations Expenses We compute depreciation expense for our regulated operations by applying composite, annual rates, as approved by the respective regulatory bodies. The following table shows the average depreciation rates used for regulated operations during the years ended December 31, 2022, 2021 and 2020: 2022 2021 2020 Natural gas distribution – Delmarva Peninsula 2.5% 2.5% 2.5% Natural gas distribution – Florida 2.5% 2.5% 2.5% Natural gas transmission – Delmarva Peninsula 2.7% 2.7% 2.7% Natural gas transmission – Florida 2.4% 2.3% 2.3% Natural gas transmission – Ohio 5.0% N/A N/A Electric distribution 2.8% 2.8% 2.9% For our unregulated operations, we compute depreciation expense on a straight-line basis over the following estimated useful lives of the assets: Asset Description Useful Life Propane distribution mains 10-37 years Propane bulk plants and tanks 10-40 years Propane equipment, meters and meter installations 5-33 years Measuring and regulating station equipment 5-37 years Natural gas pipelines 45 years Natural gas right of ways Perpetual CHP plant 30 years Natural gas processing equipment 20-25 years Office furniture and equipment 3-10 years Transportation equipment 4-20 years Structures and improvements 5-45 years Other Various We report certain depreciation and accretion in operations expense, rather than as a depreciation and amortization expense, in the accompanying consolidated statements of income in accordance with industry practice and regulatory requirements. Depreciation and accretion included in operations expense consists of the accretion of the costs of removal for future retirements of utility assets, vehicle depreciation, computer software and hardware depreciation, and other minor amounts of depreciation expense. For the years ended December 31, 2022, 2021 and 2020, we reported $11.0 million, $10.2 million and $9.6 million, respectively, of depreciation and accretion in operations expenses. Regulated Operations We account for our regulated operations in accordance with ASC Topic 980, Regulated Operations, which includes accounting principles for companies whose rates are determined by independent third-party regulators. When setting rates, regulators often make decisions, the economics of which require companies to defer costs or revenues in different periods than may be appropriate for unregulated enterprises. When this situation occurs, a regulated company defers the associated costs as regulatory assets on the balance sheet and records them as expense on the income statement as it collects revenues. Further, regulators can also impose liabilities upon a regulated company, for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future, as regulatory liabilities. If we were required to terminate the application of these regulatory provisions to our regulated operations, all such deferred amounts would be recognized in the statement of income at that time, which could have a material impact on our financial position, results of operations and cash flows. We monitor our regulatory and competitive environments to determine whether the recovery of our regulatory assets continues to be probable. If we determined that recovery of these assets is no longer probable, we would write off the assets against earnings. We believe that the provisions of ASC Topic 980, Regulated Operations, continue to apply to our regulated operations and that the recovery of our regulatory assets is probable. Revenue Recognition Revenues for our natural gas and electric distribution operations are based on rates approved by the PSC in each state in which they operate. Customers’ base rates may not be changed without formal approval by these commissions. The PSCs, however, have authorized our regulated operations to negotiate rates, based on approved methodologies, with customers that have competitive alternatives. Eastern Shore’s revenues are based on rates approved by the FERC. The FERC has also authorized Eastern Shore to negotiate rates above or below the FERC-approved maximum rates, which customers can elect as an alternative to FERC-approved maximum rates. For regulated deliveries of natural gas and electricity, we read meters and bill customers on monthly cycles that do not coincide with the accounting periods used for financial reporting purposes. We accrue unbilled revenues for natural gas and electricity delivered, but not yet billed, at the end of an accounting period to the extent that they do not coincide. We estimate the amount of the unbilled revenue by jurisdiction and customer class. All of our regulated natural gas and electric distribution operations have fuel cost recovery mechanisms, except for two utilities that provide only unbundled delivery service (Chesapeake Utilities' CFG division and FPU's Indiantown division). These mechanisms allow us to adjust billing rates, without further regulatory approvals, to reflect changes in the cost of purchased fuel. Differences between the cost of fuel purchased and delivered are deferred and accounted for as either unrecovered fuel cost or amounts payable to customers. Generally, these deferred amounts are recovered or refunded within one year. We charge flexible rates to our natural gas distribution industrial interruptible customers who can use alternative fuels. Interruptible service imposes no contractual obligation to deliver or receive natural gas on a firm service basis. Our unregulated propane distribution businesses record revenue in the period the products are delivered and/or services are rendered for their bulk delivery customers. For propane customers with meters whose billing cycles do not coincide with our accounting periods, we accrue unbilled revenue for product delivered but not yet billed and bill customers at the end of an accounting period, as we do in our regulated energy businesses. Our Ohio natural gas transmission/supply operation recognizes revenues based on actual volumes of natural gas shipped using contractual rates based upon index prices that are published monthly. Eight Flags records revenues based on the amount of electricity and steam generated and sold to its customers. Our mobile compressed natural gas operation recognizes revenue for CNG services at the end of each calendar month for services provided during the month based on agreed upon rates for labor, equipment utilized, costs incurred for natural gas compression, miles driven, mobilization and demobilization fees. We report revenue taxes, such as gross receipts taxes, franchise taxes, and sales taxes, on a net basis. For our businesses with agreements that contain variable consideration, we use the invoice practical expedient method. We determined that the amounts invoiced to customers correspond directly with the value to our customers and our performance to date. Natural Gas, Electric and Propane Costs Natural gas, electric and propane costs include the direct costs attributable to the products sold or services provided to our customers. These costs include primarily the variable commodity cost of natural gas, electricity and propane, costs of pipeline capacity needed to transport and store natural gas, transmission costs for electricity, costs to gather and process natural gas, costs to transport propane to/from our storage facilities or our mobile CNG equipment to customer locations, and steam and electricity generation costs. Depreciation expense is not included in natural gas, electric and propane costs. Operations and Maintenance Expenses Operations and maintenance expenses include operations and maintenance salaries and benefits, materials and supplies, usage of vehicles, tools and equipment, payments to contractors, utility plant maintenance, customer service, professional fees and other outside services, insurance expense, minor amounts of depreciation, accretion of removal costs for future retirements of utility assets and other administrative expenses. Cash and Cash Equivalents Our policy is to invest cash in excess of operating requirements in overnight income-producing accounts. Such amounts are stated at cost, which approximates fair value. Investments with an original maturity of three months or less when purchased are considered cash equivalents. Accounts Receivable and Allowance for Credit Losses Accounts receivable consist primarily of amounts due for sales of natural gas, electricity and propane and transportation and distribution services to customers. An allowance for doubtful accounts is recorded against amounts due based upon our collections experiences and an assessment of our customers’ inability or reluctance to pay. If circumstances change, our estimates of recoverable accounts receivable may also change. Circumstances which could affect such estimates include, but are not limited to, customer credit issues, natural gas, electricity and propane prices and impacts from general economic conditions. Accounts receivable are written off when they are deemed to be uncollectible. Our estimate for expected credit losses has been developed by analyzing our portfolio of financial assets that present potential credit exposure risk. These assets consist solely of our trade receivables from customers and contract assets. The estimate is based on five years of historical collections experience, a review of current economic and operating conditions in our service territories, and an examination of economic indicators which provide a reasonable and supportable basis of potential future activity. Those indicators include metrics which we believe provide insight into the future collectability of our trade receivables such as unemployment rates and economic growth statistics in our service territories. When determining estimated credit losses, we analyze the balance of our trade receivables based on the underlying line of business. This includes an examination of trade receivables from our energy distribution, energy transmission, energy delivery services and propane operations businesses. Our energy distribution business consists of all our regulated distribution utility (natural gas and electric) operations on the Delmarva Peninsula and in Florida. These business units have the ability to recover their costs through the rate-making process, which can include consideration for amounts historically written off to be included in rate base. Therefore, they possess a mechanism to recover credit losses which we believe reduces their exposure to credit risk. Our energy transmission and energy delivery services business units consist of our natural gas pipelines and our mobile CNG delivery operations. The majority of customers served by these business units are regulated distribution utilities who also have the ability to recover their costs. We believe this cost recovery mechanism significantly reduces the amount of credit risk. Our propane operations are unregulated and do not have the same ability to recover their costs as our regulated operations. However, historically our propane operations have not had material write offs relative to the amount of revenues generated. Our estimate of expected credit losses reflects our anticipated losses associated with our trade receivables as a result of non-payment from our customers beginning the day the trade receivable is established. We believe the risk of loss associated with trade receivables classified as current presents the least amount of credit exposure risk and therefore, we assign a lower estimate to our current trade receivables. As our trade receivables age outside of their expected due date, our estimate increases. Our allowance for credit losses relative to the balance of our trade receivables has historically been immaterial as a result of on time payment activity from our customers. The table below illustrates the changes in the balance of our allowance for expected credit losses for the year ended December 31, 2022: (in thousands) Balance at December 31, 2021 $ 3,141 Additions: Provision for credit losses 1,550 Recoveries 172 Deductions: Write offs (1,986) Balance at December 31, 2022 $ 2,877 Inventories We use the average cost method to value propane, materials and supplies, and other merchandise inventory. If market prices drop below cost, inventory balances that are subject to price risk are adjusted to their net realizable value. There were no lower-of-cost-or-net realizable value adjustment for the years ended December 31, 2022, 2021 or 2020. Goodwill and Other Intangible Assets Goodwill is not amortized but is tested for impairment at least annually, or more frequently if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value. We use a present value technique based on discounted cash flows to estimate the fair value of our reporting units. An impairment charge is recognized if the carrying value of a reporting unit’s goodwill exceeds its fair value. The testing of goodwill for the years ended December 31, 2022, 2021 and 2020 indicated no goodwill impairment. Other intangible assets are amortized on a straight-line basis over their estimated economic useful lives. Other Deferred Charges Other deferred charges include issuance costs associated with short-term borrowings. These charges are amortized over the life of the related short-term debt borrowings. Asset Removal Cost As authorized by the appropriate regulatory body (state PSC or FERC), we accrue future asset removal costs associated with utility property, plant and equipment even if a legal obligation does not exist. Such accruals are provided for through depreciation expense and are recorded with corresponding credits to regulatory liabilities or assets. When we retire depreciable utility plant and equipment, we charge the associated original costs to accumulated depreciation and amortization, and any related removal costs incurred are charged to regulatory liabilities or assets. The difference between removal costs recognized in depreciation rates and the accretion and depreciation expense recognized for financial reporting purposes is a timing difference between recovery of these costs in rates and their recognition for financial reporting purposes. Accordingly, these differences are deferred as regulatory liabilities or assets. In the rate setting process, the regulatory liability or asset is excluded from the rate base upon which those utilities have the opportunity to earn their allowed rates of return. The costs associated with our asset retirement obligations are either currently being recovered in rates or are probable of recovery in future rates. Pension and Other Postretirement Plans Pension and other postretirement plan costs and liabilities are determined on an actuarial basis and are affected by numerous assumptions and estimates, including the fair value of plan assets, estimates of the expected returns on plan assets, assumed discount rates, the level of contributions made to the plans, and current demographic and actuarial mortality data. We review annually the estimates and assumptions underlying our pension and other postretirement plan costs and liabilities with the assistance of third-party actuarial firms. The assumed discount rates, expected returns on plan assets and the mortality assumption are the factors that generally have the most significant impact on our pension costs and liabilities. The assumed discount rates, health care cost trend rates and rates of retirement generally have the most significant impact on our postretirement plan costs and liabilities. The discount rates are utilized principally in calculating the actuarial present value of our pension and postretirement obligations and net pension and postretirement costs. When estimating our discount rates, we consider high-quality corporate bond rates, such as the Empower curve index and the FTSE Index, changes in those rates from the prior year and other pertinent factors, including the expected life of each of our plans and their respective payment options. The expected long-term rates of return on assets are utilized in calculating the expected returns on the plan assets component of our annual pension plan costs. We estimate the expected returns on plan assets by evaluating expected bond returns, asset allocations, the effects of active plan management, the impact of periodic plan asset rebalancing and historical performance. We also consider the guidance from our investment advisors in making a final determination of our expected rates of return on plan assets. We estimate the health care cost trend rates used in determining our postretirement net expense based upon actual health care cost experience, the effects of recently enacted legislation and general economic conditions. Our assumed rate of retirement is estimated based upon our annual reviews of participant census information as of the measurement date. The mortality assumption used for our pension and postretirement plans is reviewed periodically and is based on the actuarial table that best reflects the expected mortality of the plan participants. Income Taxes, Investment Tax Credit Adjustments and Tax-Related Contingency Deferred tax assets and liabilities are recorded for the income tax effect of temporary differences between the financial statement basis and tax basis of assets and liabilities and are measured using the enacted income tax rates in effect in the years in which the differences are expected to reverse. Deferred tax assets are recorded net of any valuation allowance when it is more likely than not that such income tax benefits will be realized. Investment tax credits on utility property have been deferred and are allocated to income ratably over the lives of the subject property. We account for uncertainty in income taxes in our consolidated financial statements only if it is more likely than not that an uncertain tax position is sustainable based on technical merits. Recognizable tax positions are then measured to determine the amount of benefit recognized in the consolidated financial statements. We recognize penalties and interest related to unrecognized tax benefits as a component of other income. We account for contingencies associated with taxes other than income when the likelihood of a loss is both probable and estimable. In assessing the likelihood of a loss, we do not consider the existence of current inquiries, or the likelihood of future inquiries, by tax authorities as a factor. Our assessment is based solely on our application of the appropriate statutes and the likelihood of a loss, assuming the proper inquiries are made by tax authorities. Financial Instruments We utilize financial instruments to mitigate commodity price risk associated with fluctuations of natural gas, electricity and propane and to mitigate interest rate risk. Our propane operations enter into derivative transactions, such as swaps, put options and call options in order to mitigate the impact of wholesale price fluctuations on inventory valuation and future purchase commitments. These transactions may be designated as fair value hedges or cash flow hedges, if they meet all of the accounting requirements pursuant to ASC Topic 815, Derivatives and Hedging, and we elect to designate the instruments as hedges. If designated as a fair value hedge, the value of the hedging instrument, such as a swap, future, or put option, is recorded at fair value, with the effective portion of the gain or loss of the hedging instrument effectively reducing or increasing the value of the hedged item. If designated as a cash flow hedge, the value of the hedging instrument, such as a swap or call option, is recorded at fair value with the effective portion of the gain or loss of the hedging instrument being recorded in comprehensive income. The ineffective portion of the gain or loss of a hedge is recorded in earnings. If the instrument is not designated as a fair value or cash flow hedge, or it does not meet the accounting requirements of a hedge under ASC Topic 815, Derivatives and Hedging , it is recorded at fair value with all gains or losses being recorded directly in earnings. Our natural gas, electric and propane operations enter into agreements with suppliers to purchase natural gas, electricity, and propane for resale to our respective customers. Purchases under these contracts, as well as distribution and sales agreements with counterparties or customers, either do not meet the definition of a derivative, or qualify for “normal purchases and normal sales” treatment under ASC Topic 815 Derivatives and Hedging , and are accounted for on an accrual basis. We manage interest rate risk by entering into derivative contracts to hedge the variability in cash flows attributable to changes in the short-term borrowing rates. We designate and account for the interest rate swaps as cash flows hedges. Accordingly, unrealized gains and losses associated with the interest rate swaps are recorded as a component of accumulated other comprehensive income (loss). When the interest rate swaps settle, the realized gain or loss will be recorded in the income statement and recognized as a component of interest charges. Recent Accounting Standards

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Earnings Per Share	3. E ARNINGS P ER S HARE The following table presents the calculation of our basic and diluted earnings per share: For the Year Ended December 31, 2022 2021 2020 (in thousands, except shares and per share data) Calculation of Basic Earnings Per Share: Income from Continuing Operations $ 89,796 $ 83,467 $ 70,642 Income/(Loss) from Discontinued Operations — (1) 856 Net Income $ 89,796 $ 83,466 $ 71,498 Weighted average shares outstanding 17,722,227 17,558,078 16,711,579 Earnings Per Share from Continuing Operations $ 5.07 $ 4.75 $ 4.23 Earnings Per Share from Discontinued Operations — — 0.05 Basic Earnings Per Share $ 5.07 $ 4.75 $ 4.28 Calculation of Diluted Earnings Per Share: Reconciliation of Denominator: Weighted average shares outstanding — Basic 17,722,227 17,558,078 16,711,579 Effect of dilutive securities — Share-based compensation 82,067 74,951 59,156 Adjusted denominator — Diluted 17,804,294 17,633,029 16,770,735 Earnings Per Share from Continuing Operations $ 5.04 $ 4.73 $ 4.21 Earnings Per Share from Discontinued Operations — — 0.05 Diluted Earnings Per Share $ 5.04 $ 4.73 $ 4.26

Acquisitions

Acquisitions	12 Months Ended
	Dec. 31, 2022
Business Combinations [Abstract]
Acquisitions	ACQUISITIONS Acquisition of Davenport Energy In June 2022, Sharp acquired the propane operating assets of Davenport Energy's Siler City, North Carolina propane division for approximately $2.0 million. Through this acquisition, the Company expands its operating footprint further into North Carolina, where customers will be served by Sharp Energy’s Diversified Energy division. Sharp added approximately 850 customers, and expected distribution of approximately 0.4 million gallons of propane annually. We recorded $1.5 million in property plant and equipment, $0.5 million in goodwill, and immaterial amounts associated with customer relationships and non-compete agreements, all of which are deductible for income tax purposes. The amounts recorded in conjunction with the acquisition are preliminary, and subject to adjustment based on contractual provisions and finalization prior to the first anniversary of the transaction closing. The financial results associated with this acquisition will be included within the Company's propane distribution operations within its Unregulated Energy segment. Acquisition of Diversified Energy In December 2021, Sharp acquired the propane operating assets of Diversified Energy for approximately $37.5 million, net of cash acquired. We initially recorded a $2.1 million liability related to the seller's adherence to various provisions contained in the purchase agreement which was released upon passage of the first anniversary of the transaction closing. Included with the acquisition, was approximately $1.7 million of working capital from the Seller consisting predominantly of accounts receivable and propane inventory. We accounted for this acquisition as a business combination within our Unregulated Energy Segment beginning in the fourth quarter of 2021. In January 2022, we recorded a post-closing true-up of $0.8 million related to the provision for working capital valuation at the time of closing. In connection with this acquisition, we recorded $23.1 million in property plant and equipment, $6.2 million in intangible assets associated with customer relationships and non-compete agreements and $5.9 million in goodwill, all of which are deductible for income tax purposes. There were multiple strategic benefits to this acquisition including it: (i) expands our propane service territory into North Carolina and South Carolina, (ii) builds upon our existing propane presence in Virginia and Pennsylvania, and (iii) includes an established customer base with opportunities for future growth. Through this acquisition, the Company added approximately 19,000 residential, commercial and agricultural customers, along with expected distribution of approximately 10.0 million gallons of propane annually. These acquisitions generated operating revenue and operating income of $26.0 million and $1.0 million, respectively, for the year ended December 31, 2022. For the year ended December 31, 2021, the acquisitions generated operating revenue and operating income of $1.4 million and $0.3 million, respectively. Acquisition of Planet Found Energy Development In October 2022, we acquired Planet Found Energy Development, LLC ("Planet Found") for $9.5 million. In connection with this acquisition, we recorded a $0.9 million liability which is subject to the seller's adherence to various provisions contained in the purchase agreement through the first anniversary of the transaction closing. We accounted for this acquisition as a business combination within our Unregulated Energy Segment beginning in the fourth quarter of 2022. Planet Found's farm scale anaerobic digestion pilot system and technology produces biogas from 1,200 tons of poultry litter annually, which can be used to create renewable energy in the form of electricity or upgraded to renewable natural gas. The transaction will accelerate our efforts in converting poultry waste to renewable, sustainable energy while simultaneously improving the local environments in our service territories. At December 31, 2022, the operating revenues and operating income of Planet Found were not material to our consolidated results.

Revenue Recognition Revenue Rec

Revenue Recognition Revenue Recognition (Notes)	12 Months Ended
	Dec. 31, 2022
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customer [Text Block]	R EVENUE R ECOGNITION For the year ended December 31, 2022 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Energy distribution Delaware natural gas division $ 82,176 $ — $ — $ 82,176 Florida natural gas division 40,036 — — 40,036 FPU electric distribution 81,714 — — 81,714 FPU natural gas distribution 115,834 — — 115,834 Maryland natural gas division 26,607 — — 26,607 Sandpiper natural gas/propane operations 21,278 — — 21,278 Elkton Gas 9,198 — — 9,198 Total energy distribution 376,843 — — 376,843 Energy transmission Aspire Energy — 56,225 — 56,225 Aspire Energy Express 1,377 — — 1,377 Eastern Shore 78,624 — — 78,624 Peninsula Pipeline 27,263 — — 27,263 Total energy transmission 107,264 56,225 — 163,489 Energy generation Eight Flags — 25,318 — 25,318 Propane operations Propane distribution operations — 188,412 — 188,412 Compressed Natural Gas Services Marlin Gas Services — 11,159 — 11,159 Other and eliminations Eliminations (54,683) (364) (29,778) (84,825) Other — — 308 308 Total other and eliminations (54,683) (364) (29,470) (84,517) Total operating revenues (1) $ 429,424 $ 280,750 $ (29,470) $ 680,704 (1) Total operating revenues for the year ended December 31, 2022, include other revenue (revenues from sources other than contracts with customers) of $0.5 million and $0.4 million for our Regulated and Unregulated Energy segments, respectively. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for Maryland division and Sandpiper and late fees. For the year ended December 31, 2021 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Energy distribution Delaware natural gas division $ 71,195 $ — $ — $ 71,195 Florida natural gas division 34,074 — — 34,074 FPU electric distribution 78,300 — — 78,300 FPU natural gas distribution 100,535 — — 100,535 Maryland natural gas division 22,449 — — 22,449 Sandpiper natural gas/propane operations 20,746 — — 20,746 Elkton Gas 7,105 — — 7,105 Total energy distribution 334,404 — — 334,404 Energy transmission Aspire Energy — 38,163 — 38,163 Aspire Energy Express 187 — — 187 Eastern Shore 76,911 — — 76,911 Peninsula Pipeline 26,630 — — 26,630 Total energy transmission 103,728 38,163 — 141,891 Energy generation Eight Flags — 18,652 — 18,652 Propane operations Propane distribution operations — 142,082 — 142,082 Compressed Natural Gas Services Marlin Gas Services — 8,315 — 8,315 Other and eliminations Eliminations (54,212) (343) (21,348) (75,903) Other — — 527 527 Total other and eliminations (54,212) (343) (20,821) (75,376) Total operating revenues (1) $ 383,920 $ 206,869 $ (20,821) $ 569,968 (1) Total operating revenues for the year ended December 31, 2021, include other revenue (revenues from sources other than contracts with customers of $0.2 million and $0.4 million for our Regulated and Unregulated Energy segments, respectively. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for Maryland division and Sandpiper and late fees. For the years ended December 31, 2020 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Energy distribution Delaware natural gas division $ 63,389 $ — $ — $ 63,389 Florida natural gas division 30,850 — — 30,850 FPU electric distribution 76,863 — — 76,863 FPU natural gas distribution 90,150 — — 90,150 Maryland natural gas division 21,853 — — 21,853 Sandpiper natural gas/propane operations 17,214 — — 17,214 Elkton Gas 2,399 — — 2,399 Total energy distribution 302,718 — — 302,718 Energy transmission Aspire Energy — 27,951 — 27,951 Aspire Energy Express 16 — — 16 Eastern Shore 75,117 — — 75,117 Peninsula Pipeline 23,080 — — 23,080 Total energy transmission 98,213 27,951 — 126,164 Energy generation Eight Flags — 16,147 — 16,147 Propane operations Propane distribution operations — 100,744 — 100,744 Compressed Natural Gas Services Marlin Gas Services — 7,818 — 7,818 Other and eliminations Eliminations (48,185) (134) (17,602) (65,921) Other — — 528 528 Total other and eliminations (48,185) (134) (17,074) (65,393) Total operating revenues (1) $ 352,746 $ 152,526 $ (17,074) $ 488,198 (1) Total operating revenues for the year ended December 31, 2020, include other revenue (revenues from sources other than contracts with customers) of $1.4 million and $0.2 million for our Regulated and Unregulated Energy segments, respectively. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for Maryland division and Sandpiper and late fees. Regulated Energy Segment The businesses within our Regulated Energy segment are regulated utilities whose operations and customer contracts are subject to rates approved by the respective state PSC or the FERC. Our energy distribution operations deliver natural gas or electricity to customers, and we bill the customers for both the delivery of natural gas or electricity and the related commodity, where applicable. In most jurisdictions, our customers are also required to purchase the commodity from us, although certain customers in some jurisdictions may purchase the commodity from a third-party retailer (in which case we provide delivery service only). We consider the delivery of natural gas or electricity and/or the related commodity sale as one performance obligation because the commodity and its delivery are highly interrelated with two-way dependency on one another. Our performance obligation is satisfied over time as natural gas or electricity is delivered and consumed by the customer. We recognize revenues based on monthly meter readings, which are based on the quantity of natural gas or electricity used and the approved rates. We accrue unbilled revenues for natural gas and electricity that have been delivered, but not yet billed, at the end of an accounting period, to the extent that billing and delivery do not coincide. Revenues for Eastern Shore are based on rates approved by the FERC. The FERC has also authorized Eastern Shore to negotiate rates above or below the FERC-approved maximum rates, which customers can elect as an alternative to the FERC-approved maximum rates. Eastern Shore's services can be firm or interruptible. Firm services are offered on a guaranteed basis and are available at all times unless prevented by force majeure or other permitted curtailments. Interruptible customers receive service only when there is available capacity or supply. Our performance obligation is satisfied over time as we deliver natural gas to the customers' locations. We recognize revenues based on capacity used or reserved and the fixed monthly charge. Peninsula Pipeline is engaged in natural gas intrastate transmission to third-party customers and certain affiliates in the State of Florida. Our performance obligation is satisfied over time as the natural gas is transported to customers. We recognize revenue based on rates approved by the Florida PSC and the capacity used or reserved. We accrue unbilled revenues for transportation services provided and not yet billed at the end of an accounting period. Aspire Energy Express is engaged in natural gas intrastate transmission in the State of Ohio. We currently serve the Guernsey power plant and our performance obligation is satisfied over time as the natural gas is transported to the plant. We recognize revenue based on rates approved by the Ohio PSC and the capacity used or reserved. We accrue unbilled revenues for transportation services provided and not yet billed at the end of an accounting period. Unregulated Energy Segment Revenues generated from the Unregulated Energy segment are not subject to any federal, state, or local pricing regulations. Aspire Energy primarily sources gas from hundreds of conventional producers and performs gathering and processing functions to maintain the quality and reliability of its gas for its wholesale customers. Aspire Energy's performance obligation is satisfied over time as natural gas is delivered to its customers. Aspire Energy recognizes revenue based on the deliveries of natural gas at contractually agreed upon rates (which are based upon an established monthly index price and a monthly operating fee, as applicable). For natural gas customers, we accrue unbilled revenues for natural gas that has been delivered, but not yet billed, at the end of an accounting period, to the extent that billing and delivery do not coincide with the end of the accounting period. Eight Flags' CHP plant, which is located on land leased from a customer, produces three sources of energy: electricity, steam and heated water. This customer purchases the steam (unfired and fired) and heated water, which are used in the customer’s production facility. Our electric distribution operation purchases the electricity generated by the CHP plant for distribution to its customers. Eight Flags' performance obligation is satisfied over time as deliveries of heated water, steam and electricity occur. Eight Flags recognizes revenues over time based on the amount of heated water, steam and electricity generated and delivered to its customers. For our propane distribution operations, we recognize revenue based upon customer type and service offered. Generally, for propane bulk delivery customers (customers without meters) and wholesale sales, our performance obligation is satisfied when we deliver propane to the customers' locations (point-in-time basis). We recognize revenue from these customers based on the number of gallons delivered and the price per gallon at the point-in-time of delivery. For our propane distribution customers with meters, we satisfy our performance obligation over time. We recognize revenue over time based on the amount of propane consumed and the applicable price per unit. For propane distribution metered customers, we accrue unbilled revenues for propane that is estimated to have been consumed, but not yet billed, at the end of an accounting period, to the extent that billing and delivery do not coincide with the end of the accounting period. Marlin Gas Services provides mobile CNG and pipeline solutions primarily to utilities and pipelines. Marlin Gas Services provides temporary hold services, pipeline integrity services, emergency services for damaged pipelines and specialized gas services for customers who have unique requirements. Marlin Gas Services' performance obligations are comprised of the compression of natural gas, mobilization of CNG equipment, utilization of equipment and on-site CNG support. Our performance obligations for the compression of natural gas, utilization of mobile CNG equipment and for the on-site CNG staff support are satisfied over time when the natural gas is compressed, equipment is utilized or as our staff provide support services to our customers. Our performance obligation for the mobilization of CNG equipment is satisfied at a point-in-time when the equipment is delivered to the customer project location. We recognize revenue for CNG services at the end of each calendar month for services provided during the month based on agreed upon rates for equipment utilized, costs incurred for natural gas compression, miles driven, mobilization and demobilization fees. Contract balances The timing of revenue recognition, customer billings and cash collections results in trade receivables, unbilled receivables (contract assets), and customer advances (contract liabilities) in our consolidated balance sheets. The balances of our trade receivables, contract assets, and contract liabilities as of December 31, 2022 and 2021 were as follows: Trade Receivables Contract Assets (Current) Contract Assets (Noncurrent) Contract Liabilities (Current) (in thousands) Balance at 12/31/2021 $ 56,277 $ 18 $ 4,806 $ 747 Balance at 12/31/2022 61,687 18 4,321 983 Increase (decrease) $ 5,410 $ — $ (485) $ 236 Our trade receivables are included in trade and other receivables in the consolidated balance sheets. Our non-current contract assets are included in receivables and other deferred charges in the consolidated balance sheet and relate to operations and maintenance costs incurred by Eight Flags that have not yet been recovered through rates for the sale of electricity to our electric distribution operation pursuant to a long-term service agreement. At times, we receive advances or deposits from our customers before we satisfy our performance obligation, resulting in contract liabilities. Contract liabilities are included in other accrued liabilities in the consolidated balance sheets and relate to non-refundable prepaid fixed fees for our propane distribution operation's retail offerings. Our performance obligation is satisfied over the term of the respective retail offering plan on a ratable basis. For the years ended December 31, 2022 and 2021, we recognized revenue of $1.2 million and $1.1 million, respectively. Remaining performance obligations Our businesses have long-term fixed fee contracts with customers in which revenues are recognized when performance obligations are satisfied over the contract term. Revenue for these businesses for the remaining performance obligations at December 31, 2022 are expected to be recognized as follows: (in thousands) 2023 2024 2025 2026 2027 2028 and thereafter Eastern Shore and Peninsula Pipeline $ 36,472 $ 33,148 $ 26,890 $ 23,444 $ 20,536 $ 167,663 Natural gas distribution operations 6,287 6,106 5,748 5,518 5,101 33,113 FPU electric distribution 652 652 275 275 275 275 Total revenue contracts with remaining performance obligations $ 43,411 $ 39,906 $ 32,913 $ 29,237 $ 25,912 $ 201,051

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Segment Information	S EGMENT I NFORMATION We use the management approach to identify operating segments. We organize our business around differences in regulatory environment and/or products or services, and the operating results of each segment are regularly reviewed by the chief decision maker (our Chief Executive Officer, or "CEO") in order to make decisions about resources and to assess performance. Our operations are entirely domestic and are comprised of two reportable segments: • Regulated Energy . Includes energy distribution and transmission services (natural gas distribution, natural gas transmission and electric distribution operations). All operations in this segment are regulated, as to their rates and services, by the PSC having jurisdiction in each operating territory or by the FERC in the case of Eastern Shore. • Unregulated Energy. Includes energy transmission, energy generation (the operations of our Eight Flags' CHP plant), propane distribution operations, mobile compressed natural gas distribution and pipeline solutions operations, and project development activities related to our sustainable energy initiatives. Also included in this segment are other unregulated energy services, such as energy-related merchandise sales and heating, ventilation and air conditioning, plumbing and electrical services. These operations are unregulated as to their rates and services. The remainder of our operations are presented as “Other businesses and eliminations,” which consists of unregulated subsidiaries that own real estate leased to Chesapeake Utilities, as well as certain corporate costs not allocated to other operations. The following table presents information about our reportable segments. For the Year Ended December 31, 2022 2021 2020 (in thousands) Operating Revenues, Unaffiliated Customers Regulated Energy $ 422,894 $ 381,879 $ 350,853 Unregulated Energy 257,810 188,089 137,345 Total operating revenues, unaffiliated customers $ 680,704 $ 569,968 $ 488,198 Intersegment Revenues (1) Regulated Energy $ 6,530 $ 2,041 $ 1,893 Unregulated Energy 22,940 18,780 15,181 Other businesses 308 527 528 Total intersegment revenues $ 29,778 $ 21,348 $ 17,602 Operating Income Regulated Energy $ 115,317 $ 106,174 $ 92,124 Unregulated Energy 27,350 24,427 20,664 Other businesses and eliminations 266 511 (65) Operating Income 142,933 131,112 112,723 Other income, net 5,051 1,721 3,222 Interest charges 24,356 20,135 21,765 Income from Continuing Operations before Income Taxes 123,628 112,698 94,180 Income Taxes on Continuing Operations 33,832 29,231 23,538 Income from Continuing Operations 89,796 83,467 70,642 Income (loss) from Discontinued Operations, Net of Tax — (1) 686 Gain on sale of Discontinued Operations, Net of tax — — 170 Net Income $ 89,796 $ 83,466 $ 71,498 Depreciation and Amortization Regulated Energy $ 52,707 $ 48,748 $ 46,079 Unregulated Energy 16,257 13,869 11,988 Other businesses and eliminations 9 44 50 Total depreciation and amortization $ 68,973 $ 62,661 $ 58,117 Capital Expenditures Regulated Energy $ 97,554 $ 139,733 $ 147,100 Unregulated Energy 40,773 81,651 46,295 Other businesses 2,355 6,425 2,480 Total capital expenditures $ 140,682 $ 227,809 $ 195,875 (1) All significant intersegment revenues are billed at market rates and have been eliminated from consolidated revenues. As of December 31, 2022 2021 Identifiable Assets Regulated Energy segment $ 1,716,255 $ 1,629,191 Unregulated Energy segment 463,239 439,114 Other businesses and eliminations 35,543 46,564 Total identifiable assets $ 2,215,037 $ 2,114,869

Supplemental Cash Flow Disclosu

Supplemental Cash Flow Disclosures	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Supplemental Cash Flow Disclosures	S UPPLEMENTAL C ASH F LOW D ISCLOSURES Cash paid for interest and income taxes during the years ended December 31, 2022, 2021 and 2020 were as follows: For the Year Ended December 31, 2022 2021 2020 (in thousands) Cash paid for interest $ 24,267 $ 20,809 $ 22,884 Cash (received) paid for income taxes, net of refunds $ (4,963) $ 8,395 $ (8,135) Non-cash investing and financing activities during the years ended December 31, 2022, 2021, and 2020 were as follows: For the Year Ended December 31, 2022 2021 2020 (in thousands) Capital property and equipment acquired on account, but not paid for as of December 31 $ 13,211 $ 16,164 $ 23,625 Common stock issued for the Retirement Savings Plan $ — $ 1,712 $ 1,605 Common stock issued under the SICP $ 2,868 $ 2,834 $ 1,971

Derivative Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Derivative Instruments	8. D ERIVATIVE I NSTRUMENTS We use derivative and non-derivative contracts to manage risks related to obtaining adequate supplies and the price fluctuations of natural gas, electricity and propane and to mitigate interest rate risk. Our natural gas, electric and propane distribution operations have entered into agreements with suppliers to purchase natural gas, electricity and propane for resale to our customers. Our natural gas gathering and transmission company has entered into contracts with producers to secure natural gas to meet its obligations. Purchases under these contracts typically either do not meet the definition of derivatives or are considered “normal purchases and normal sales” and are accounted for on an accrual basis. Our propane distribution operations may also enter into fair value hedges of their inventory or cash flow hedges of their future purchase commitments in order to mitigate the impact of wholesale price fluctuations. Occasionally, we may enter into interest rate swap agreements to mitigate risk associated with changes in short-term borrowing rates. As of December 31, 2022 and 2021, our natural gas and electric distribution operations did not have any outstanding derivative contracts. Volume of Derivative Activity As of December 31, 2022, the volume of our open commodity derivative contracts were as follows: Business unit Commodity Contract Type Quantity hedged (in millions) Designation Longest expiration date of hedge Sharp Propane (gallons) Purchases 20.0 Cash flow hedges August, 2025 Sharp Propane (gallons) Sales 5.0 Cash flow hedges December, 2023 Sharp entered into futures and swap agreements to mitigate the risk of fluctuations in wholesale propane index prices associated with the propane volumes expected to be purchased and/or sold during the heating season. Under the futures and swap agreements, Sharp will receive or pay the difference between (i) the index prices (Mont Belvieu prices in December 2022 through August 2025) and (ii) the per gallon propane contracted prices, to the extent the index prices deviate from the contracted prices. We designated and accounted for the propane swaps as cash flows hedges. The change in the fair value of the swap agreements is recorded as unrealized gain (loss) in other comprehensive income (loss) and later recognized in the statement of income in the same period and in the same line item as the hedged transaction. We expect to reclassify approximately $0.8 million of unrealized gain from accumulated other comprehensive income to earnings during the next 12-month period ending December 31, 2023. Interest Rate Swap Activities We manage interest rate risk by entering into derivative contracts to hedge the variability in cash flows attributable to changes in the short-term borrowing rates. In the second quarter of 2020, we entered into interest rate swaps with notional amounts totaling $100.0 million associated with three of our short-term lines of credit which expired in October 2020. Pricing on the interest rate swaps ranged between 0.2615 and 0.3875 percent for the period. In the fourth quarter of 2020, we entered into additional interest rate swaps with notional amounts totaling $60.0 million through December 2021 with pricing of 0.20 percent and 0.205 percent for the period associated with our outstanding borrowing under the Revolver. In February 2021, we entered into an additional interest rate swap with a notional amount of $40.0 million through December 2021 with pricing of 0.17 percent. In September 2022, we entered into an interest rate swap with a notional amount of $50.0 million through September 2025, with pricing of 3.98 percent. Prior to August 2022, our short-term borrowing interest rate was based on the 30-day LIBOR rate. In August 2022, we amended and restated the Revolver and transitioned the benchmark interest rate to the 30-day SOFR as a result of the impending expiration of LIBOR. Our pre-2022 interest rate swaps were cash settled monthly as the counter-party paid us the 30-day LIBOR rate less the fixed rate. Our current interest rate swap is cash settled monthly as the counter-party pays us the 30-day SOFR rate less the fixed rate. We designate and account for interest rate swaps as cash flows hedges. Accordingly, unrealized gains and losses associated with the interest rate swaps are recorded as a component of accumulated other comprehensive income (loss). When the interest rate swaps settle, the realized gain or loss is recorded in the income statement and is recognized as a component of interest charges. Broker Margin Futures exchanges have contract specific margin requirements that require the posting of cash or cash equivalents relating to traded contracts. Margin requirements consist of initial margin that is posted upon the initiation of a position, maintenance margin that is usually expressed as a percent of initial margin, and variation margin that fluctuates based on the daily mark-to-market relative to maintenance margin requirements. We currently maintain a broker margin account for Sharp included within our Other Current Liabilities on the consolidated balance sheet, the balance as of December 31, 2022 and 2021 was $0.1 million and $4.1 million, respectively. Financial Statements Presentation The following tables present information about the fair value and related gains and losses of our derivative contracts. We did not have any derivative contracts with a credit-risk-related contingency. Fair values of the derivative contracts recorded in the consolidated balance sheets as of December 31, 2022 and 2021 are as follows: Derivative Assets Fair Value as of (in thousands) Balance Sheet Location December 31, 2022 December 31, 2021 Derivatives not designated as hedging instruments Propane swap agreements Derivative assets, at fair value $ — $ 16 Derivatives designated as cash flow hedges Propane swap agreements Derivative assets, at fair value (1) 3,317 7,060 Interest rate swap agreements Derivative assets, at fair value (1) 452 — Total Derivative Assets $ 3,769 $ 7,076 (1) Derivative assets, at fair value include $2.8 million and $4.3 million in current assets in the consolidated balance sheet at December 31, 2022 and 2021, respectively, with the remainder of the balance classified as long-term. Derivative Liabilities Fair Value as of (in thousands) Balance Sheet Location December 31, 2022 December 31, 2021 Derivatives designated as cash flow hedges Propane swap agreements Derivative liabilities, at fair value (1) $ 1,810 $ 743 Interest rate swap agreements Derivative liabilities, at fair value (1) 405 — Total Derivative Liabilities $ 2,215 $ 743 (1) Derivative liabilities, at fair value include $0.6 million and $0.7 million in current liabilities in the consolidated balance sheet at December 31, 2022 and 2021, respectively, with the remainder of the balance classified as long-term. The effects of gains and losses from derivative instruments are as follows: Amount of Gain (Loss) on Derivatives: Location of Gain For the Year Ended December 31, (in thousands) 2022 2021 2020 Derivatives not designated as hedging instruments Propane swap agreements Propane and natural gas costs $ 56 $ (1) $ — Derivatives designated as fair value hedges Put/Call option Propane and natural gas costs — (24) (12) Put/Call option Propane inventory — — 34 Derivatives designated as cash flow hedges Propane swap agreements Revenues (373) (536) — Propane swap agreements Propane and natural gas costs 3,881 7,187 2,428 Propane swap agreements Other comprehensive income (loss) (1,303) 9,777 7,463 Interest rate swap agreements Interest expense (47) (40) 60 Interest rate swap agreements Other comprehensive income (loss) — — 20 Total $ 2,214 $ 16,363 $ 9,993

Fair Value of Financial Instrum

Fair Value of Financial Instruments	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Fair Value of Financial Instruments	F AIR V ALUE OF F INANCIAL I NSTRUMENTS GAAP establishes a fair value hierarchy that prioritizes the inputs to valuation methods used to measure fair value. The three levels of the fair value hierarchy are the following: Fair Value Hierarchy Description of Fair Value Level Fair Value Technique Utilized Level 1 Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities Investments - equity securities - The fair values of these trading securities are recorded at fair value based on unadjusted quoted prices in active markets for identical securities. Investments - mutual funds and other - The fair values of these investments, comprised of money market and mutual funds, are recorded at fair value based on quoted net asset values of the shares. Level 2 Quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability Derivative assets and liabilities - The fair value of the propane put/call options, propane and interest rate swap agreements are measured using market transactions for similar assets and liabilities in either the listed or over-the-counter markets. Level 3 Prices or valuation techniques requiring inputs that are both significant to the fair value measurement and unobservable (i.e. supported by little or no market activity) Investments - guaranteed income fund - The fair values of these investments are recorded at the contract value, which approximates their fair value. Financial Assets and Liabilities Measured at Fair Value The following tables summarize our 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 of December 31, 2022 and 2021, respectively: Fair Value Measurements Using: As of December 31, 2022 Fair Value Quoted Prices in Significant Other Significant (in thousands) Assets: Investments—equity securities $ 24 $ 24 $ — $ — Investments—guaranteed income fund 1,853 — — 1,853 Investments—mutual funds and other 8,699 8,699 — — Total investments 10,576 8,723 — 1,853 Derivative assets 3,769 — 3,769 — Total assets $ 14,345 $ 8,723 $ 3,769 $ 1,853 Liabilities: Derivative liabilities $ 2,215 $ — $ 2,215 $ — Fair Value Measurements Using: As of December 31, 2021 Fair Value Quoted Prices in Active Markets (Level 1) Significant Other Significant (in thousands) Assets: Investments—equity securities $ 26 $ 26 $ — $ — Investments—guaranteed income fund 2,036 — — 2,036 Investments—mutual funds and other 10,033 10,033 — — Total investments 12,095 10,059 — 2,036 Derivative assets 7,076 — 7,076 — Total assets $ 19,171 $ 10,059 $ 7,076 $ 2,036 Liabilities: Derivative liabilities $ 743 $ — $ 743 $ — The following table sets forth the summary of the changes in the fair value of Level 3 investments for the years ended December 31, 2022 and 2021: For the Year Ended December 31, 2022 2021 (in thousands) Beginning Balance $ 2,036 $ 2,156 Purchases and adjustments 132 88 Transfers/disbursements (347) (241) Investment income 32 33 Ending Balance $ 1,853 $ 2,036 Investment income from the Level 3 investments is reflected in other income (expense), net in the consolidated statements of income. At December 31, 2022 and 2021, there were no non-financial assets or liabilities required to be reported at fair value. We review our non-financial assets for impairment at least on an annual basis, as required. Other Financial Assets and Liabilities Financial assets with carrying values approximating fair value include cash and cash equivalents and accounts receivable. Financial liabilities with carrying values approximating fair value include accounts payable, other accrued liabilities and short-term debt. The fair value of cash and cash equivalents is measured using the comparable value in the active market and approximates its carrying value (Level 1 measurement). The fair value of short-term debt approximates the carrying value due to its near-term maturities and because interest rates approximate current market rates (Level 2 measurement). At December 31, 2022, long-term debt, which includes the current maturities but excludes debt issuance cost, had a carrying value of $600.8 million, compared to the estimated fair value of $505.0 million. At December 31, 2021, long-term debt, which includes the current maturities and excludes debt issuance costs, had a carrying value of $568.8 million, compared to a fair value of $597.2 million. The fair value was calculated using a discounted cash flow methodology that incorporates a market interest rate based on published corporate borrowing rates for debt instruments with similar terms and average maturities, and with adjustments for duration, optionality, and risk profile. The valuation technique used to estimate the fair value of long-term debt would be considered a Level 2 measurement. See Note 16, Employee Benefit Plans, for fair value measurement information related to our pension plan assets.

Goodwill and Other Intangible A

Goodwill and Other Intangible Assets	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Goodwill and Other Intangible Assets	G OODWILL AND O THER I NTANGIBLE A SSETS The carrying value of goodwill as of December 31, 2022 and 2021 was as follows: (in thousands) Regulated Energy Unregulated Energy Total Goodwill Balance at December 31, 2021 $ 7,689 $ 37,019 $ 44,708 Additions (1) — 1,505 1,505 Balance at December 31, 2022 $ 7,689 $ 38,524 $ 46,213 (1) Includes goodwill from the purchase of operating assets of Planet Found in the fourth quarter of 2022. The annual impairment testing for the years 2022 and 2021 indicated no impairment of goodwill. The carrying value and accumulated amortization of intangible assets subject to amortization as of December 31, 2022 and 2021 are as follows: As of December 31, 2022 2021 (in thousands) Gross Accumulated Gross Accumulated Customer relationships (1) $ 16,965 $ 6,131 $ 16,814 $ 5,125 Non-Compete agreements 3,105 1,411 2,431 1,078 Patents (2)(3) 5,819 533 452 354 Other 270 225 270 218 Total $ 26,159 $ 8,300 $ 19,967 $ 6,775 (1) The customer relationship amounts include $6.1 million as a result of the purchase of Diversified Energy in December 2021. (2) The patents amount include $3.7 million as a result of the purchase of the operating assets of Planet Found in October 2022. (3) Includes amounts related to patented technology developed by Marlin Gas Services and the acquisition of Planet Found. The customer relationships, non-compete agreements, patents and other intangible assets acquired in the purchases of the operating assets of several companies are being amortized over a weighted average o f 14 years. Amortization expense of intangible assets for the year ended December 31, 2022, 2021 and 2020 was $1.5 million , $1.3 million and $1.2 million, respectively.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Income Taxes	I NCOME T AXES We file a consolidated federal income tax return. Income tax expense allocated to our subsidiaries is based upon their respective taxable incomes and tax credits. State income tax returns are filed on a separate company basis in most states where we have operations and/or are required to file. Our state returns for tax years after 2016 are subject to examination. At December 31, 2022, the 2015 through 2019 federal income tax returns are under examination, and no report has been issued at this time. During 2022, the Company settled its Internal Revenue Service examination relating to the 2015-2019 tax years. As a result, we had federal NOLs totaling $6.3 million and $12.2 million in 2019 and 2018, respectively. Under the CARES Act, discussed below, we elected to carry the losses back to 2015 and 2013. The company recovered $12.8 million of tax and received interest income of $0.8 million as a result of carrying back the NOLs referred to above. For state income tax purposes, we had NOL in various states of $67.7 million and $14.6 million as of December 31, 2022 and 2021, respectively, almost all of which will expire in 2040. Excluding NOLs from discontinued operations, we have recorded deferred tax assets of $1.5 million related to state NOL carry-forwards at both December 31, 2022 and 2021, respectively. We have not recorded a valuation allowance to reduce the future benefit of the tax NOL because we believe they will be fully utilized. Tax Law Changes In March 2020, the CARES Act was signed into law and included several significant changes to the Internal Revenue Code. The CARES Act includes certain tax relief provisions including the ability to carryback five years net operating losses arising in a tax year beginning in 2018, 2019, or 2020. This provision allows a taxpayer to recover taxes previously paid at a 35 percent federal income tax rate during tax years prior to 2018. In addition, the CARES Act removed the taxable income limitation to allow a tax NOL to fully offset taxable income for tax years beginning before January 1, 2021. Tax benefits associated with this legislation were not available for the year ended December 31, 2022. As a result, our income tax expense for the years ended December 31, 2021 included a tax benefit $0.9 million, attributable to the tax NOL carryback provided under the CARES Act for losses generated in 2018 and 2019. This NOL carryback was applied to our 2013 and 2015 tax years in which we paid federal income taxes at a 35 percent tax rate. On December 22, 2017, President Trump signed into law the TCJA. Substantially all of the provisions of the TCJA were effective for taxable years beginning on or after January 1, 2018. The provisions that significantly impacted us include the reduction of the corporate federal income tax rate from 35 percent to 21 percent. Our federal income tax expense for periods beginning on January 1, 2018 and thereafter are based on the new federal corporate income tax rate. The TCJA included changes to the Internal Revenue Code, which materially impacted our 2017 financial statements. ASC 740, Income Taxes, requires recognition of the effects of changes in tax laws in the period in which the law is enacted. ASC 740 requires deferred tax assets and liabilities to be measured at the enacted tax rate expected to apply when temporary differences are to be realized or settled. During 2018, we completed the assessment of the impact of accounting for certain effects of the TCJA. At the date of enactment in 2017, we re-measured deferred income taxes based upon the new corporate tax rate. See Note 18, Rates and Other Regulatory Activities, for further discussion of the TCJA's impact on our regulated businesses. The following tables provide: (a) the components of income tax expense in 2022, 2021, and 2020; (b) the reconciliation between the statutory federal income tax rate and the effective income tax rate for 2022, 2021, and 2020 from continuing operations; and (c) the components of accumulated deferred income tax assets and liabilities at December 31, 2022 and 2021. For the Year Ended December 31, 2022 2021 2020 (in thousands) Current Income Tax Expense Federal $ 8,284 $ 2,775 $ (2,777) State 1,948 (96) 2,162 Other (47) (47) (47) Total current income tax expense (benefit) 10,185 2,632 (662) Deferred Income Tax Expense (1) Property, plant and equipment 14,968 24,074 23,224 Deferred gas costs 8,923 1,857 (714) Pensions and other employee benefits 1,109 (655) (75) FPU merger-related premium cost and deferred gain (351) (351) 156 Net operating loss carryforwards 2 97 5,107 Other (1,004) 1,577 (3,498) Total deferred income tax expense 23,647 26,599 24,200 Income Tax Expense from Continuing Operations 33,832 29,231 23,538 Income Tax Expense from Discontinued Operations — — 153 Total Income Tax $ 33,832 $ 29,231 $ 23,691 (1) Includes $7.8 million, $8.2 million, and $4.9 million of deferred state income taxes for the years 2022, 2021 and 2020, respectively. For the Year Ended December 31, 2022 2021 2020 (in thousands) Reconciliation of Effective Income Tax Rates from Continuing Operations Federal income tax expense (1) $ 25,982 $ 23,666 $ 19,778 State income taxes, net of federal benefit 7,714 6,371 5,051 ESOP dividend deduction (177) (180) (218) CARES Act Tax Benefit — (919) (1,841) Other 313 293 768 Total Income Tax Expense from Continuing Operations $ 33,832 $ 29,231 $ 23,538 Effective Income Tax Rate from Continuing Operations 27.34 % 25.94 % 24.99 % (1) Federal income taxes were calculated at 21 percent for 2022, 2021, and 2020. As of December 31, 2022 2021 (in thousands) Deferred Income Taxes Deferred income tax liabilities: Property, plant and equipment $ 238,687 $ 224,034 Acquisition adjustment 5,915 6,266 Loss on reacquired debt 164 183 Deferred gas costs 11,288 2,366 Natural gas conversion costs 5,026 5,529 Storm reserve liability 5,791 5,783 Other 8,236 6,301 Total deferred income tax liabilities $ 275,107 $ 250,462 Deferred income tax assets: Pension and other employee benefits $ 3,985 $ 5,354 Environmental costs 1,052 996 Net operating loss carryforwards 1,488 1,490 Storm reserve liability 453 448 Accrued expenses 9,007 4,843 Other 2,955 3,781 Total deferred income tax assets $ 18,940 $ 16,912 Deferred Income Taxes Per Consolidated Balance Sheets $ 256,167 $ 233,550

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Long-Term Debt	L ONG - TERM D EBT Our outstanding long-term debt is shown below: As of December 31, (in thousands) 2022 2021 Uncollateralized Senior Notes: 5.93% note, due October 31, 2023 $ 3,000 $ 6,000 5.68% note, due June 30, 2026 11,600 14,500 6.43% note, due May 2, 2028 4,200 4,900 3.73% note, due December 16, 2028 12,000 14,000 3.88% note, due May 15, 2029 35,000 40,000 3.25% note, due April 30, 2032 66,500 70,000 3.48% note, due May 31, 2038 50,000 50,000 3.58% note, due November 30, 2038 50,000 50,000 3.98% note, due August 20, 2039 100,000 100,000 2.98% note, due December 20, 2034 70,000 70,000 3.00% note, due July 15, 2035 50,000 50,000 2.96% note, due August 15, 2035 40,000 40,000 2.49% notes Due January 25, 2037 50,000 50,000 2.95% notes Due March 15, 2042 50,000 — Equipment security note 2.46% note, due September 24, 2031 8,517 9,378 Less: debt issuance costs (946) (913) Total long-term debt 599,871 567,865 Less: current maturities (21,483) (17,962) Total long-term debt, net of current maturities $ 578,388 $ 549,903 Notes Purchase Agreement On March 15, 2022, we issued 2.95 percent Senior Notes due March 15, 2042 to MetLife in the aggregate principal amount of $50.0 million. We used the proceeds received from the issuances of the Senior Notes to reduce short-term borrowings under the Revolver and to fund capital expenditures. These Senior Notes have similar covenants and default provisions as our other Senior Notes, and have an annual principal payment beginning in the eleventh year after the issuance. On September 28, 2022, we agreed to issue and Prudential agreed to purchase 5.43 percent Senior Notes due March 14, 2038 in the aggregate principal amount of $80.0 million. We expect to issue the Notes on or before March 14, 2023. We anticipate using the proceeds received from the issuance of the Notes to reduce short-term borrowings under our revolving credit facility and to fund capital expenditures. These Senior Notes have similar covenants and default provisions as our other Senior Notes, and have an annual principal payment beginning in the sixth year after the issuance. Equipment Security Note On September 24, 2021, we entered into an Equipment Financing Agreement with Banc of America Leasing & Capital, LLC to issue $9.6 million in sustainable financing associated with the purchase of qualifying equipment by our subsidiary, Marlin Gas Services. The equipment security note bears a 2.46 percent interest rate and has a term of 10 years. Under the terms of the agreement, we granted a security interest in the equipment to the lender, to serve as collateral. Annual maturities Annual maturities and principal repayments of long-term debt are as follows: Year 2023 2024 2025 2026 2027 Thereafter Total (in thousands) Payments $ 21,483 $ 18,505 $ 25,528 $ 34,551 $ 31,674 $ 469,076 $ 600,817 Shelf Agreements We have entered into Shelf Agreements with Prudential and MetLife, whom are under no obligation to purchase any unsecured debt. The following table summarizes our shelf agreements at December 31, 2022: (in thousands) Total Borrowing Capacity Less Amount of Debt Issued Less Unfunded Commitments Remaining Borrowing Capacity Shelf Agreements (1) Prudential Shelf Agreement (2) $ 370,000 $ (220,000) $ (80,000) $ 70,000 MetLife Shelf Agreement 150,000 (50,000) — 100,000 Total $ 520,000 $ (270,000) $ (80,000) $ 170,000 (1) The amended Prudential and MetLife Shelf Agreements both expire in February 2026. (2) Unfunded commitments of $80.0 million reflects Senior Notes expected to be issued on or before March 14, 2023. In February 2023, we amended our Shelf Agreements with Prudential and MetLife. The amended agreements now provide for total borrowing capacity of up to $405.0 million under the Prudential Shelf Agreement and $200.0 million under the MetLife Shelf Agreement. Additionally, the amendments extend the term of the agreements for an additional three years from the effective dates. The Uncollateralized Senior Notes, Shelf Agreements or Shelf Notes set forth certain business covenants to which we are subject when any note is outstanding, including covenants that limit or restrict our ability, and the ability of our subsidiaries, to incur indebtedness, or place or permit liens and encumbrances on any of our property or the property of our subsidiaries. Uncollateralized Senior Notes All of our Uncollateralized Senior Notes require periodic principal and interest payments as specified in each note. They also contain various restrictions. The most stringent restrictions state that we must maintain equity of at least 40.0 percent of total capitalization (including short-term borrowings), and the fixed charge coverage ratio must be at least 1.2 times. The most recent Senior Notes issued since September 2013 also contain a restriction that we must maintain an aggregate net book value in our regulated business assets of at least 50.0 percent of our consolidated total assets. Failure to comply with those covenants could result in accelerated due dates and/or termination of the Senior Note agreements. Certain Uncollateralized Senior Notes contain a “restricted payments” covenant as defined in the respective note agreements. The most restrictive covenants of this type are included within the 5.93 percent Senior Note, due October 31, 2023. The covenant provides that we cannot pay or declare any dividends or make any other restricted payments in excess of the sum of $10.0 million, plus our consolidated net income accrued on and after January 1, 2003. As of December 31, 2022, the cumulative consolidated net income base was $754.2 million, offset by restricted payments of $326.4 million, leaving $427.8 million of cumulative net income free of restrictions. As of December 31, 2022, we were in compliance with all of our debt covenants.

Short-Term Borrowing

Short-Term Borrowing	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Short-Term Borrowing	S HORT - TERM B ORROWINGS We are authorized by our Board of Directors to borrow up to $400.0 million of short-term debt, as required. At December 31, 2022 and 2021, we had $202.2 million and $221.6 million, respectively, of short-term borrowings outstanding at a weighted average interest rate of 5.04 percent and 0.83 percent, respectively. In August 2021, we amended and restated our Revolver into a multi-tranche facility totaling $400.0 million with multiple participating lenders. The two tranches of the facility consist of a $200.0 million 364-day short-term debt tranche and a $200.0 million five-year tranche, both of which have three (3) one-year extension options, which can be authorized by our Chief Financial Officer. We are eligible to establish the repayment term for individual borrowings under the five year tranche of the Revolver and to the extent that an individual loan under the Revolver exceeded 12 months, the outstanding balance would be classified as a component of long-term debt. In August 2022, we amended both tranches of the Revolver, which now bear interest using SOFR as the benchmark interest rate, plus a 10-basis point SOFR adjustment, in lieu of LIBOR which is being retired by financial institutions. In addition, the 364-day tranche was extended for the upcoming year, expiring in August 2023. As part of these amendments, the parties agreed to eliminate the previous covenant capping the aggregate investments limit at $150.0 million where we maintain an ownership interest less than 50 percent. Additionally, the 364-day tranche of the facility now offers a reduced interest margin similar to the five-year tranche for amounts borrowed in connection with new sustainable investments. All other terms and conditions remained unchanged. Borrowings outstanding under the sustainable investment sublimit of the 364-day tranche amounted to $9.4 million at December 31, 2022. The availability of funds under the Revolver is subject to conditions specified in the credit agreement, all of which we currently satisfy. These conditions include our compliance with financial covenants and the continued accuracy of representations and warranties contained in the Revolver's loan documents. We are required by the financial covenants in the Revolver to maintain, at the end of each fiscal year, a funded indebtedness ratio of no greater than 65 percent. As of December 31, 2022, we are in compliance with this covenant. The 364-day tranche of the Revolver expires in August 2023 and the five-year tranche expires in August 2026, both of which are available to fund our short-term cash needs to meet seasonal working capital requirements and to temporarily fund portions of our capital expenditures. Borrowings under both tranches of the Revolver are subject to a pricing grid, including the commitment fee and the interest rate charged based upon our total indebtedness to total capitalization ratio for the prior quarter. As of December 31, 2022, the pricing under the 364-day tranche of the Revolver does not include an unused commitment fee and maintains an interest rate of 70 basis points over SOFR plus a 10 basis point SOFR adjustment. As of December 31, 2022, the pricing under the five-year tranche of the Revolver included an unused commitment fee of 9 basis points and an interest rate of 95 basis points over SOFR plus a 10 basis point SOFR adjustment. Our total available credit under the Revolver at December 31, 2022 was $192.0 million. As of December 31, 2022, we had issued $5.8 million in letters of credit to various counterparties under the Revolver. These letters of credit are not included in the outstanding short-term borrowings and we do not anticipate that they will be drawn upon by the counterparties. The letters of credit reduce the available borrowings under the Revolver. For additional information on interest rate swaps related to our short-term borrowings, see Note 8 , Derivative Instruments .

Leases

Leases	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Leases	LEASES We have entered into lease arrangements for office space, land, equipment, pipeline facilities and warehouses. These lease arrangements enable us to better conduct business operations in the regions in which we operate. Office space is leased to provide adequate workspace for our employees in several locations throughout our service territories. We lease land at various locations throughout our service territories to enable us to inject natural gas into underground storage and distribution systems, for bulk storage capacity, for our propane operations and for storage of equipment used in repairs and maintenance of our infrastructure. We lease natural gas compressors to ensure timely and reliable transportation of natural gas to our customers. Additionally, we lease a pipeline to deliver natural gas to an industrial customer in Polk County, Florida. We also lease warehouses to store equipment and materials used in repairs and maintenance for our businesses. Some of our leases are subject to annual changes in the Consumer Price Index (“CPI”). While lease liabilities are not re-measured as a result of changes to the CPI, changes to the CPI are treated as variable lease payments and recognized in the period in which the obligation for those payments was incurred. A 100-basis-point increase in CPI would not have resulted in material additional annual lease costs during 2022. Most of our leases include options to renew, with renewal terms that can extend the lease term from one to 25 years or more. The exercise of lease renewal options is at our sole discretion. The amounts disclosed in our consolidated balance sheet at December 31, 2022, pertaining to the right-of-use assets and lease liabilities, are measured based on our current expectations of exercising our available renewal options. Our existing leases are not subject to any restrictions or covenants that would preclude our ability to pay dividends, obtain financing or enter into additional leases. As of December 31, 2022, we have not entered into any leases, which have not yet commenced, that would entitle us to significant rights or create additional obligations. The following table presents information related to our total lease cost included in our consolidated statements of income: Year Ended December 31, (in thousands) Classification 2022 2021 Operating lease cost (1) Operations expense $ 2,883 $ 2,064 (1) Includes short-term leases and variable lease costs, which are immaterial. The following table presents the balance and classifications of our right-of-use assets and lease liabilities included in our consolidated balance sheet at December 31, 2022 and 2021: (in thousands) Balance sheet classification December 31, 2022 December 31, 2021 Assets Operating lease assets Operating lease right-of-use assets $ 14,421 $ 10,139 Liabilities Current Operating lease liabilities Other accrued liabilities $ 2,552 $ 1,996 Noncurrent Operating lease liabilities Operating lease - liabilities 12,392 8,571 Total lease liabilities $ 14,944 $ 10,567 The following table presents our weighted-average remaining lease term and weighted-average discount rate for our operating leases at December 31, 2022 and 2021: December 31, 2022 December 31, 2021 Weighted-average remaining lease term ( in years ) Operating leases 8.54 8.10 Weighted-average discount rate Operating leases 3.4 % 3.6 % The following table presents additional information related to cash paid for amounts included in the measurement of lease liabilities included in our consolidated statements of cash flows at December 31, 2022 and 2021: Year Ended December 31, (in thousands) 2022 2021 Operating cash flows from operating leases $ 2,931 $ 1,996 The following table presents the future undiscounted maturities of our operating leases at December 31, 2022 and for each of the next five years and thereafter: (in thousands) Operating Leases (1) 2023 $ 2,871 2024 2,546 2025 2,161 2026 1,684 2027 1,529 Thereafter 6,192 Total lease payments 16,983 Less: Interest (2,039) Present value of lease liabilities $ 14,944 (1) Operating lease payments include $2.1 million related to options to extend lease terms that are reasonably certain of being exercised.

Stockholders' Equity

Stockholders' Equity	12 Months Ended
	Dec. 31, 2022
Equity [Abstract]
Accumulated Other Comprehensive Income (Loss)	S TOCKHOLDERS' E QUITY Common Stock Issuances In June 2020, we filed a shelf registration statement with the SEC to facilitate the issuance of our common stock. In August 2020, we filed a prospectus supplement under the shelf registration statement for an ATM equity program under which we may issue and sell shares of our common stock up to an aggregate offering price of $75.0 million through June of 2023. We maintain an effective shelf registration statement with the SEC for the issuance of shares under our DRIP. Depending on our capital needs and subject to market conditions, in addition to other possible debt and equity offerings, we may issue additional shares under the direct stock purchase component of the DRIP. In 2021, we issued approximately 0.1 million shares at an average price per share of $125.71 and received net proceeds of $15.2 million under the DRIP. In 2022, we issued less than 0.1 million shares at an average price per share of $136.26 and received net proceeds of $4.5 million under the DRIP. We used the net proceeds from our share issuances, after fees, for general corporate purposes, including, but not limited to, financing of capital expenditures, repayment of short-term debt, financing acquisitions, investing in subsidiaries, and general working capital purposes. Accumulated Other Comprehensive Income (Loss) Defined benefit pension and postretirement plan items, unrealized gains (losses) of our propane swap agreements and natural gas swaps and futures contracts, designated as commodity contracts cash flow hedges, and the unrealized gains (losses) of our interest rate swap agreements, designated as cash flow hedges, are the components of our accumulated other comprehensive loss. The following table presents the changes in the balance of accumulated other comprehensive income (loss) for the years ended December 31, 2022 and 2021. All amounts in the following tables are presented net of tax. Defined Benefit Pension and Postretirement Plan Items Commodity Contract Cash Flow Hedges Interest Rate Swap Cash Flow Hedges Total (in thousands) As of December 31, 2020 $ (5,146) $ 2,309 $ (28) $ (2,865) Other comprehensive income before reclassifications 262 7,075 — 7,337 Amounts reclassified from accumulated other comprehensive income (loss) 1,616 (4,813) 28 (3,169) Net current-period other comprehensive income 1,878 2,262 28 4,168 As of December 31, 2021 (3,268) 4,571 — 1,303 Other comprehensive income (loss) before reclassifications 705 (934) — (229) Amounts reclassified from accumulated other comprehensive income (loss) 57 (2,545) 35 (2,453) Net current-period other comprehensive income 762 (3,479) 35 (2,682) As of December 31, 2022 $ (2,506) $ 1,092 $ 35 $ (1,379) The following table presents amounts reclassified out of accumulated other comprehensive income (loss) for the years ended December 31, 2022, 2021 and 2020. Deferred gains and losses of our commodity contracts cash flow hedges are recognized in earnings upon settlement. For the Year Ended December 31, (in thousands) 2022 2021 2020 Amortization of defined benefit pension and postretirement plan items: Prior service credit (1) $ 77 $ 77 $ 77 Net actuarial loss (1) (152) (2,243) (592) Total before income taxes (75) (2,166) (515) Income tax benefit (3) 18 550 150 Net of tax $ (57) $ (1,616) $ (365) Gains on commodity contracts cash flow hedges Propane swap agreements (2) $ 3,508 $ 6,651 $ 2,428 Total before income taxes 3,508 6,651 2,428 Income tax expense (3) (963) (1,838) (671) Net of tax $ 2,545 $ 4,813 $ 1,757 Gains and (losses) on interest rate swap cash flow hedges: Interest rate swap agreements $ (47) $ (40) $ 60 Total before income taxes (47) (40) 60 Income tax expense (3) 12 12 (16) Net of tax $ (35) $ (28) $ 44 Total reclassifications for the period $ 2,453 $ 3,169 $ 1,436 (1) These amounts are included in the computation of net periodic benefits. See Note 16 , Employee Benefit Plans , for additional details. (2) These amounts are included in the effects of gains and losses from derivative instruments. See Note 8, Derivative Instruments , for additional details. (3) The income tax benefit is included in income tax expense in the accompanying consolidated statements of income.

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Employee Benefit Plans	E MPLOYEE B ENEFIT P LANS We measure the assets and obligations of the defined benefit pension plans and other postretirement benefits plans to determine the plans’ funded status as of the end of the year. We record as a component of other comprehensive income/loss or a regulatory asset the changes in funded status that occurred during the year that are not recognized as part of net periodic benefit costs. Defined Benefit Pension Plans At December 31, 2022 we sponsored two defined benefit pension plans: the FPU Pension Plan and the Chesapeake SERP. During the fourth quarter of 2021, we formally terminated the Chesapeake Pension Plan. Accordingly, a portion of the pension settlement expense associated with the termination was allocated to our Regulated Energy operations and was recorded as regulatory assets, previously approved in all of the impacted jurisdictions. The remaining portion of the pension settlement expense totaling $0.6 million was recorded in other expense in our consolidated statement of income which reflected the amount allocated to our Unregulated Energy operations or was deemed not recoverable through the regulatory process. The FPU Pension Plan, a qualified plan, covers eligible FPU non-union employees hired before January 1, 2005 and union employees hired before the respective union contract expiration dates in 2005 and 2006. Prior to the FPU merger, the FPU Pension Plan was frozen with respect to additional years of service and compensation, effective December 31, 2009. The Chesapeake SERP, a nonqualified plan, is comprised of two sub-plans. The first sub-plan was frozen with respect to additional years of service and additional compensation as of December 31, 2004. The second sub-plan provides fixed payments for several executives who joined the Company as a result of an acquisition and whose agreements with the Company provided for this benefit. The unfunded liability for all plans at both December 31, 2022 and 2021, is included in the other pension and benefit costs liability in our consolidated balance sheets. The following schedules set forth the funded status at December 31, 2022 and 2021 and the net periodic cost for the years ended December 31, 2022, 2021 and 2020 for the Chesapeake and FPU Pension Plans as well as the Chesapeake SERP: Chesapeake FPU Chesapeake At December 31, 2022 2021 2022 2021 2022 2021 (in thousands) Change in benefit obligation: Benefit obligation — beginning of year $ — $ 6,146 $ 67,030 $ 70,366 $ 2,096 $ 2,212 Interest cost — 141 1,781 1,714 50 48 Actuarial (gain) loss — (371) (15,713) (1,953) (335) (12) Effect of settlement — (5,884) — — — — Benefits paid — (32) (3,157) (3,097) (152) (152) Benefit obligation — end of year — — 49,941 67,030 1,659 2,096 Change in plan assets: Fair value of plan assets — beginning of year — 4,609 58,712 55,966 — — Actual return on plan assets — (237) (9,552) 4,246 — — Employer contributions — 1,544 200 1,597 152 152 Effect of settlement — (5,884) — — — — Benefits paid — (32) (3,157) (3,097) (152) (152) Fair value of plan assets — end of year — — 46,203 58,712 — — Accrued pension cost / funded status $ — $ — $ (3,738) $ (8,318) $ (1,659) $ (2,096) Assumptions: Discount rate — % 2.50 % 5.25 % 2.75 % 5.00 % 2.50 % Expected return on plan assets — % 3.50 % 6.00 % 6.00 % — % — % Chesapeake FPU Chesapeake For the Years Ended December 31, 2022 2021 2020 2022 2021 2020 2022 2021 2020 (in thousands) Components of net periodic pension cost: Interest cost $ — $ 141 $ 176 $ 1,781 $ 1,714 $ 2,085 $ 50 $ 48 $ 63 Expected return on assets — (166) (157) (3,430) (3,306) (2,967) — — — Amortization of actuarial loss — 257 243 466 612 552 28 28 20 Settlement expense — 1,810 203 — — — — — — Net periodic pension cost — 2,042 465 (1,183) (980) (330) 78 76 83 Amortization of pre-merger regulatory asset — — — — — — — — — Total periodic cost $ — $ 2,042 $ 465 $(1,183) $ (980) $ (330) $ 78 $ 76 $ 83 Assumptions: Discount rate — % 2.25 % 3.00 % 2.75 % 2.50 % 3.25 % 2.50 % 2.25 % 3.00 % Expected return on plan assets — % 3.50 % 3.50 % 6.00 % 6.00 % 6.00 % — % — % — % Our funding policy provides that payments to the trust of each qualified plan shall be equal to at least the minimum funding requirements of the Employee Retirement Income Security Act of 1974. The following schedule summarizes the assets of the FPU Pension Plan, by investment type, at December 31, 2022, 2021 and 2020: FPU Pension Plan At December 31, 2022 2021 2020 Asset Category Equity securities 53 % 52 % 54 % Debt securities 38 % 38 % 37 % Other 9 % 10 % 9 % Total 100 % 100 % 100 % The investment policy of the FPU Pension Plan is designed to provide the capital assets necessary to meet the financial obligations of the plan. The investment goals and objectives are to achieve investment returns that, together with contributions, will provide funds adequate to pay promised benefits to present and future beneficiaries of the plan, earn a competitive return to increasingly fund a large portion of the plan’s retirement liabilities, minimize pension expense and cumulative contributions resulting from liability measurement and asset performance, and maintain the appropriate mix of investments to reduce the risk of large losses over the expected remaining life of the plan. The following allocation range of asset classes is intended to produce a rate of return sufficient to meet the FPU Pension Plan’s goals and objectives: Asset Allocation Strategy Asset Class Minimum Allocation Percentage Maximum Allocation Percentage Domestic Equities (Large Cap, Mid Cap and Small Cap) 14 % 32 % Foreign Equities (Developed and Emerging Markets) 13 % 25 % Fixed Income (Inflation Bond and Taxable Fixed) 29 % 47 % Alternative Strategies (Long/Short Equity and Hedge Fund of Funds) 4 % 10 % Diversifying Assets (High Yield Fixed Income, Commodities, and Real Estate) 2 % 6 % Cash 0 % 5 % Due to periodic contributions and different asset classes producing varying returns, the actual asset values may temporarily move outside of the intended ranges. The investments are monitored on a quarterly basis, at a minimum, for asset allocation and performance. At December 31, 2022 and 2021, the assets of the FPU Pension Plan were comprised of the following investments: Fair Value Measurement Hierarchy For the Years Ended December 31, 2022 2021 Asset Category Total Total (in thousands) Mutual Funds - Equity securities U.S. Large Cap (1) $ 3,413 $ 4,302 U.S. Mid Cap (1) 1,425 1,835 U.S. Small Cap (1) 692 954 International (2) 9,352 10,863 Alternative Strategies (3) 4,824 5,888 19,706 23,842 Mutual Funds - Debt securities Fixed income (4) 15,343 19,551 High Yield (4) 2,269 3,014 17,612 22,565 Mutual Funds - Other Commodities (5) 1,832 2,297 Real Estate (6) 1,709 2,729 Guaranteed deposit (7) 398 497 3,939 5,523 Total Pension Plan Assets in fair value hierarchy (8) 41,257 51,930 Investments measured at net asset value (9) 4,946 6,782 Total Pension Plan Assets $ 46,203 $ 58,712 (1) Includes funds that invest primarily in United States common stocks. (2) Includes funds that invest primarily in foreign equities and emerging markets equities. (3) Includes funds that actively invest in both equity and debt securities, funds that sell short securities and funds that provide long-term capital appreciation. The funds may invest in debt securities below investment grade. (4) Includes funds that invest in investment grade and fixed income securities. (5) Includes funds that invest primarily in commodity-linked derivative instruments and fixed income securities. (6) Includes funds that invest primarily in real estate. (7) Includes investment in a group annuity product issued by an insurance company. (8) All investments in the FPU Pension Plan are classified as Level 1 within the Fair Value hierarchy exclusive of the Guaranteed Deposit Account which is classified as Level 3. (9) Certain investments that were measured at net asset value per share have not been classified in the fair value hierarchy. These amounts are presented to reconcile to total pension plan assets. At December 31, 2022 and 2021, our pension plan investments were classified under the same fair value measurement hierarchy (Level 1 through Level 3) described under Note 9, Fair Value of Financial Instruments. The Level 3 investments were recorded at fair value based on the contract value of annuity products underlying guaranteed deposit accounts, which was calculated using discounted cash flow models. The contract value of these products represented deposits made to the contract, plus earnings at guaranteed crediting rates, less withdrawals and fees. Certain investments that were measured at net asset value per share have not been classified in the fair value hierarchy and are presented in the table above to reconcile to total pension plan assets. The following table sets forth the summary of the changes in the fair value of Level 3 investments for the years ended December 31, 2022 and 2021: For the Year Ended December 31, 2022 2021 (in thousands) Balance, beginning of year $ 497 $ 1,019 Purchases 208 3,160 Transfers in 3,270 5,914 Disbursements (3,541) (9,587) Investment income (loss) (36) (9) Balance, end of year $ 398 $ 497 Other Postretirement Benefits Plans We sponsor two defined benefit postretirement health plans: the Chesapeake Utilities Postretirement Plan ("Chesapeake Postretirement Plan") and the FPU Medical Plan. At December 31, 2022 and 2021, the funded status of the Chesapeake Postretirement Plan was $0.6 million and $0.9 million, respectively. The funded status of the FPU Medical Plan was $0.7 million and $1.0 million as of December 31, 2022 and 2021, respectively. Net periodic postretirement benefit costs for the Chesapeake Postretirement Plan and the FPU Medical Plan were not material for the years ended December 31, 2022, 2021, and 2020. The following table presents the amounts not yet reflected in net periodic benefit cost and included in accumulated other comprehensive loss or as a regulatory asset as of December 31, 2022: (in thousands) FPU Chesapeake Chesapeake FPU Total Prior service credit $ — $ — $ (216) $ — $ (216) Net loss (gain) 14,540 295 597 (401) 15,031 Total $ 14,540 $ 295 $ 381 $ (401) $ 14,815 Accumulated other comprehensive loss (gain) pre-tax (1) $ 2,763 $ 295 $ 381 $ (76) $ 3,363 Post-merger regulatory asset 11,777 — — (325) 11,452 Total unrecognized cost $ 14,540 $ 295 $ 381 $ (401) $ 14,815 (1) The total amount of accumulated other comprehensive loss recorded on our consolidated balance sheet as of December 31, 2022 is net of income tax benefits of $0.9 million. Pursuant to a Florida PSC order, FPU continues to record as a regulatory asset a portion of the unrecognized pension and postretirement benefit costs after the merger with Chesapeake Utilities related to its regulated operations, which is included in the above table as a post-merger regulatory asset. As of December 31, 2022, the pre-merger regulatory asset related to the FPU Pension and FPU Medical Plan was fully amortized. Assumptions The assumptions used for the discount rate to calculate the benefit obligations were based on the interest rates of high-quality bonds in 2022, considering the expected lives of each of the plans. In determining the average expected return on plan assets for the FPU Pension Plan, various factors, such as historical long-term return experience, investment policy and current and expected allocation, were considered. Since the FPU Pension Plan is frozen with respect to additional years of service and compensation, the rate of assumed compensation increases is not applicable. The health care inflation rate for 2022 used to calculate the benefit obligation is 5 percent for medical and 6 percent for prescription drugs for the Chesapeake Postretirement Plan; and 5 percent for both medical and prescription drugs for the FPU Medical Plan. Estimated Future Benefit Payments In 2023, we do not anticipate contributing to the FPU Pension Plan and expect to contribute $0.2 million to the Chesapeake SERP. We also expect to contribute less than $0.1 million to both the Chesapeake Postretirement Plan and FPU Medical Plan, in 2023. The schedule below shows the estimated future benefit payments for each of the plans previously described: FPU Pension Plan (1) Chesapeake SERP (2) Chesapeake Postretirement Plan (2) FPU Medical Plan (2) (in thousands) 2023 $ 3,432 $ 151 $ 60 $ 57 2024 $ 3,503 $ 149 $ 58 $ 59 2025 $ 3,648 $ 162 $ 55 $ 59 2026 $ 3,680 $ 159 $ 50 $ 58 2027 $ 3,675 $ 156 $ 48 $ 59 Years 2028 through 2032 $ 18,368 $ 707 $ 200 $ 227 (1) The pension plan is funded; therefore, benefit payments are expected to be paid out of the plan assets. (2) Benefit payments are expected to be paid out of our general funds. Retirement Savings Plan We sponsor a 401(k) Retirement Savings Plan which is offered to all eligible employees who have completed three months of service. We match 100 percent of eligible participants’ pre-tax contributions to the Retirement Savings Plan up to a maximum of six percent of eligible compensation. The employer matching contribution is made in cash and is invested based on a participant’s investment directions. In addition, we may make a discretionary supplemental contribution to participants in the plan, without regard to whether or not they make pre-tax contributions. Any supplemental employer contribution is generally made in our common stock. With respect to the employer match and supplemental employer contribution, employees are 100 percent vested after two years of service or upon reaching 55 years of age while still employed by us. New employees who do not make an election to contribute and do not opt out of the Retirement Savings Plan will be automatically enrolled at a deferral rate of three percent, and the automatic deferral rate will increase by one percent per year up to a maximum of ten percent. All contributions and matched funds can be invested among the mutual funds available for investment. Employer contributions to our Retirement Savings Plan totaled $6.2 million, $5.9 million, and $5.9 million for the years ended December 31, 2022, 2021 and 2020, respectively. As of December 31, 2022, there were 798,586 shares of our common stock reserved to fund future contributions to the Retirement Savings Plan. Non-Qualified Deferred Compensation Plan Members of our Board of Directors and officers of the Company are eligible to participate in the Non-Qualified Deferred Compensation Plan. Directors can elect to defer any portion of their cash or stock compensation and officers can defer up to 80 percent of their base compensation, cash bonuses or any amount of their stock bonuses (net of required withholdings). Officers may receive a matching contribution on their cash compensation deferrals up to six percent of their compensation, provided it does not duplicate a match they receive in the Retirement Savings Plan. Stock bonuses are not eligible for matching contributions. Participants are able to elect the payment of deferred compensation to begin on a specified future date or upon separation from service. Additionally, participants can elect to receive payments upon the earlier or later of a fixed date or separation from service. The payments can be made in one lump sum or annual installments for up to 15 years. All obligations arising under the Non-Qualified Deferred Compensation Plan are payable from our general assets, although we have established a Rabbi Trust to informally fund the plan. Deferrals of cash compensation may be invested by the participants in various mutual funds (the same options that are available in the Retirement Savings Plan). The participants are credited with gains or losses on those investments. Deferred stock compensation may not be diversified. The participants are credited with dividends on our common stock in the same amount that is received by all other stockholders. Such dividends are reinvested into our common stock. Assets held in the Rabbi Trust, recorded as Investments on the consolidated balance sheet, had a fair value of $10.6 million and $12.1 million at December 31, 2022 and 2021, respectively. The assets of the Rabbi Trust are at all times subject to the claims of our general creditors.

Share-Based Compensation Plans

Share-Based Compensation Plans	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Share-Based Compensation Plans	S HARE -B ASED C OMPENSATION P LANS Our non-employee directors and key employees have been granted share-based awards through our SICP. We record these share-based awards as compensation costs over the respective service period for which services are received in exchange for an award of equity or equity-based compensation. The compensation cost is based primarily on the fair value of the shares awarded, using the estimated fair value of each share on the date it was granted, and the number of shares to be issued at the end of the service period. We have 322,509 shares of common stock reserved for issuance under the SICP. The table below presents the amounts included in net income related to share-based compensation expense for the awards granted under the SICP for the years ended December 31, 2022, 2021 and 2020: For the Year Ended December 31, 2022 2021 2020 (in thousands) Awards to non-employee directors $ 959 $ 782 $ 733 Awards to key employees 5,479 5,163 4,096 Total compensation expense 6,438 5,945 4,829 Less: tax benefit (1,663) (1,535) (1,254) Share-based compensation amounts included in net income $ 4,775 $ 4,410 $ 3,575 Non-employee Directors Shares granted to non-employee directors are issued in advance of the directors’ service periods and are fully vested as of the grant date. We record a deferred expense equal to the fair value of the shares issued and amortize the expense equally over a service period of one year or less. Our directors receive an annual retainer of shares of common stock under the SICP for services rendered through the subsequent Annual Meeting of Shareholders. Accordingly, our directors that served on the Board as of May 2022 and 2021 each received 652 and 683 shares of common stock, respectively, with a weighted average fair value of $130.36 and $117.11 per share, respectively. In July 2022, we announced the appointment of two new non-employee directors to our Board. These newly appointed directors were each granted a pro-rated share-based award of 526 shares through the SICP in accordance with the beginning of their service period. The associated expense is being recognized consistent with the methodology described above. At December 31, 2022, there was $0.3 million of unrecognized compensation expense related to shares granted to non-employee directors. This expense will be recognized over the remaining service period ending in May 2023. Officers and Key Employees Our Compensation Committee is authorized to grant our key employees the right to receive awards of shares of our common stock, contingent upon the achievement of established performance goals and subject to SEC transfer restrictions once awarded. Our President and CEO has the right to issue awards of shares of our common stock, to other officers of the Company, contingent upon various performance goals and subject to SEC transfer restrictions. We currently have several outstanding multi-year performance plans, which are based upon the successful achievement of long-term goals, growth and financial results and comprise both market-based and performance-based conditions and targets. The fair value per share, tied to a performance-based condition or target, is equal to the market price per share on the grant date. For the market-based conditions, we used the Monte Carlo valuation to estimate the fair value of each share granted. The table below presents the summary of the stock activity for awards to all officers: Number of Weighted Average Outstanding — December 31, 2020 186,878 $ 87.06 Granted 69,903 100.76 Vested (53,147) 76.31 Expired (852) 74.85 Forfeited (1) (5,384) 93.39 Outstanding — December 31, 2021 197,398 94.15 Granted 69,620 117.61 Vested (60,850) 90.60 Expired (2,678) 91.42 Outstanding — December 31, 2022 203,490 $ 103.06 (1) In conjunction with the retirement of one key employee during 2020, these shares were forfeited for the remainder of the service periods associated with awards granted during their employment with the Company. For the year ended December 31, 2022, we granted awards of 69,620 shares of common stock to officers under the SICP, including awards granted in February 2022 and to key employees thereafter appointed to officer positions. The shares granted are multi-year awards that will vest no later than the three-year service period ending December 31, 2024. The intrinsic value of these awards was $24.0 million, $28.8 million, and $20.2 million at December 31, 2022, 2021 and 2020, respectively. At December 31, 2022, there was $4.7 million of unrecognized compensation cost related to these awards, which is expected to be recognized through 2024. In 2022, 2021 and 2020, we withheld shares with a value at least equivalent to the employees’ minimum statutory obligation for the applicable income and other employment taxes, and remitted the cash to the appropriate taxing authorities with the executives electing to receive the net shares. The below table presents the number of shares withheld /and amounts remitted to taxing authorities: For the Year Ended December 31, 2022 2021 2020 (amounts except shares, in thousands) Shares withheld to satisfy tax obligations 21,832 14,020 10,319 Amounts remitted to tax authorities to satisfy obligations $ 2,838 $ 1,478 $ 977

Rates and Other Regulatory Acti

Rates and Other Regulatory Activities	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Rates and Other Regulatory Activities	R ATES AND O THER R EGULATORY A CTIVITIES Our natural gas and electric distribution operations in Delaware, Maryland and Florida are subject to regulation by their respective PSC; Eastern Shore, our natural gas transmission subsidiary, is subject to regulation by the FERC; and Peninsula Pipeline and Aspire Energy Express, our intrastate pipeline subsidiaries, are subject to regulation (excluding cost of service) by the Florida PSC and Public Utilities Commission of Ohio, respectively. Delaware See the discussion below under COVID-19 impact . Maryland Customer Information System Regulatory Asset Petition: In July 2022, we filed a joint petition for our natural gas divisions in Maryland (Maryland Division, Sandpiper, and Elkton Gas) for the approval to establish a regulatory asset for non-capitalizable expenses related to the set-up and implementation of the Company’s new Customer Information System ("CIS"). The petition was approved by the Maryland PSC in August 2022. A similar petition for our Florida Regulated Energy business units was filed during the same time frame and has not yet been scheduled on the Florida PSC Agenda. The Delaware Division has previously received approval for this accounting treatment. We have evaluated and selected the CIS with implementation anticipated to begin during the first quarter of 2023. The conversion is expected to be complete in the first quarter of 2025. Ocean City Maryland Reinforcement: In March 2022, we filed a Section 7(f) - Request for Service Area Determination with the FERC regarding plans to extend our natural gas facilities across the Delaware/Maryland state line from Sussex County, Delaware, to Worcester County, Maryland, to provide a secondary feed to Sandpiper Energy. The FERC approved the Section 7(f) request on August 29, 2022. The project will increase the reliability of the existing distribution system in those areas while also expanding infrastructure to serve new customers. Construction has been initiated with estimated completion in early 2023. Florida Wildlight Expansion: In August 2022, Peninsula Pipeline and FPU filed a joint petition with the Florida PSC for approval of the Transportation Service Agreement between the parties associated with the Wildlight Expansion project. The Wildlight Expansion project will enable us to meet the significant growing demand for service in Yulee, Florida. The agreement and project have been structured to allow us to build the project alongside the construction and build-out of the development, and charge the reservation rate as each phase of the project goes into service. The agreement reflects the construction of pipeline facilities in two separate phases. Phase one will consist of three extensions with associated facilities, and a gas injection interconnect with associated facilities. Phase two will consist of two additional pipeline extensions. The various phases of the project are anticipated to be placed in service beginning in the first quarter of 2023, with construction on the overall project continuing through 2025. The petition was approved by the Florida PSC in November 2022. Natural Gas Rate Case: In May 2022, our natural gas distribution businesses in Florida (FPU, FPU-Indiantown division, FPU-Fort Meade division and Chesapeake Utilities CFG division, collectively, “Florida natural gas distribution businesses”) filed a consolidated natural gas rate case with the Florida PSC. The application included a request for the following: (i) permanent rate relief of approximately $24.1 million, effective January 1, 2023, (ii) a depreciation study also submitted with the filing; (iii) authorization to make certain changes to tariffs to include the consolidation of rates and rate structure across the businesses and to unify the Florida natural gas distribution businesses under FPU; (iv) authorization to retain the acquisition adjustment recorded at the time of the FPU merger in our revenue requirement; and (v) authorization to establish an environmental remediation surcharge for the purposes of addressing future expected remediation costs for FPU MGP sites. In August 2022, interim rates were approved by the Florida PSC in the amount of approximately $7.7 million on an annualized basis, effective for all meter readings in September 2022. The discovery process and subsequent hearings were concluded during the fourth quarter of 2022 and briefs were submitted during the same quarter of 2022. In January 2023, the Florida PSC approved the application for consolidation and permanent rate relief of approximately $17.2 million on an annual basis. Actual rates in connection with the rate relief were approved by the Florida PSC in February 2023 with an effective date of March 1, 2023. Winter Haven Expansion Project: In May 2021, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with CFG for an incremental 6,800 Dts/d of firm service in the Winter Haven, Florida area. As part of this agreement, Peninsula Pipeline constructed a new interconnect with FGT and a new regulator station for CFG. This additional firm service is supporting new incremental load due to growth, including providing service to a new can manufacturing facility, as well as providing reliability and operational benefits to CFG’s existing distribution system in the area. In connection with Peninsula Pipeline’s new regulator station, CFG also extended its distribution system to connect to the new station. The Transportation Service Agreement was approved by the Florida PSC in September 2021 and the project was placed in service during the third quarter of 2022. Beachside Pipeline Extension: In June 2021, Peninsula Pipeline and Florida City Gas entered into a Transportation Service Agreement for an incremental 10,176 Dts/d of firm service in Indian River County, Florida, to support Florida City Gas’ growth along the Indian River's barrier island. As part of this agreement, Peninsula Pipeline will construct 11.3 miles of pipeline from its existing pipeline in the Sebastian, Florida area, which will travel east under the Intercoastal Waterway ("ICW") and southward on the barrier island. As required by Peninsula Pipeline’s tariff and Florida Statutes, Peninsula Pipeline filed the required company and customer affidavits with the Florida PSC in June 2021 and the expected in-service date is during the first quarter of 2023. St.Cloud / Twin Lakes Expansion: In July 2022, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with our Florida natural gas division, FPU, for an additional 2,400 Dt/d of firm service in the St. Cloud, Florida area. As part of this agreement, Peninsula Pipeline will construct a pipeline extension and regulator station for FPU. The extension will be used to support new incremental load due to growth in the area, including providing service, most immediately, to the residential development, Twin Lakes. The expansion will also improve reliability and provide operational benefits to FPU's existing distribution system in the area, supporting future growth. The petition was approved by the Florida PSC on October 4, 2022. We expect this expansion to be in service by the second quarter of 2023. Storm Protection Plan: In 2020, the Florida PSC implemented the Storm Protection Plan ("SPP") and Storm Protection Plan Cost Recovery Clause ("SPPCRC") rules, which require electric utilities to petition the Florida PSC for approval of a Transmission and Distribution Storm Protection Plan that covers the utility’s immediate 10-year planning period with updates to the plan at least every 3 years. The SPPCR rules allow the utility to file for recovery of associated costs related to its SPP. Our Florida electric distribution operations' SPP and SPPCRC were filed d uring the first quarter of 2022 and approved in the fourth quarter of 2022 with modifications, by the Florida PSC. Rates associated with this initiative were effective in January 2023. Eastern Shore Southern Expansion Project: In January 2022, Eastern Shore submitted a prior notice filing with the FERC pursuant to blanket certificate procedures, regarding its proposal to install an additional compressor unit and related facilities at Eastern Shore's existing compressor station in Bridgeville, Sussex County, Delaware. The project will enable Eastern Shore to provide additional firm natural gas transportation service to an existing shipper on Eastern Shore's pipeline system. The project obtained FERC approval in January 2023 and is currently estimated to go into service in the fourth quarter of 2023. Capital Cost Surcharge: In December 2022, Eastern Shore submitted a filing with the FERC regarding a capital cost surcharge to recover capital costs associated with mandated highway relocate projects that required the replacement of existing Eastern Shore facilities and a Pipeline and Hazardous Materials Safety Administration ("PHMSA") compliance project. The capital cost surcharge is an approved item in the settlement of Eastern Shore’s last rate case. In conjunction with the filing of this surcharge, pursuant to the settlement agreement, a cumulative adjustment to the existing surcharge to reflect additional depreciation was included in this filing. The FERC issued an order approving the surcharge as filed on December 19, 2022. The combined revised surcharge became effective January 1, 2023. COVID-19 Impact In March 2020, the CDC declared a national emergency due to the rapidly growing outbreak of COVID-19. In response to this declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the country imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to slow the spread of the illness. These restrictions significantly impacted economic conditions in the United States in 2020 and continued to impact economic conditions, to a lesser extent, through 2021 and 2022. Chesapeake Utilities is considered an “essential business,” which allowed us to continue operational activities and construction projects with appropriate safety precautions and personal protective equipment, while being mindful of the social distancing restrictions that were in place. In response to the COVID-19 pandemic and related restrictions, we experienced reduced consumption of energy largely in the commercial and industrial sectors, higher bad debt expenses and incremental expenses associated with COVID-19, including expenditures associated with personal protective equipment and premium pay for field personnel. The additional operating expenses we incurred support the ongoing delivery of our essential services during these unprecedented times. In April and May 2020, we were authorized by the Maryland and Delaware PSCs, respectively, to record regulatory assets for COVID-19 related costs which offered us the ability to seek recovery of those costs. In July 2021, the Florida PSC issued an order that approved incremental expenses we incurred due to COVID-19. The order allowed us to establish a regulatory asset in a total amount of $2.1 million as of June 30, 2021 for natural gas and electric distribution operations. The regulatory asset is being amortized over two years and is recovered through the Purchased Gas Adjustment and Swing Service mechanisms for our natural gas distribution businesses and through the Fuel Purchased Power Cost Recovery clause for our electric division. As of December 31, 2022 and 2021, our total COVID-19 regulatory asset balance was $1.2 million and $2.3 million, respectively. In 2021 and 2022, restrictions were gradually lifted as vaccines became widely available in the United States. The various state of emergencies associated with the COVID-19 pandemic that were previously declared in our service territories have been terminated and we have adjusted our operating practices accordingly to ensure the safety of our operations and will take the necessary actions to comply with the CDC, and the Occupational Safety and Health Administration, as new developments occur. Summary TCJA Table Customer rates for our regulated business were adjusted as approved by the regulators, prior to 2020 except for Elkton Gas, which implemented a one-time bill credit in May 2020. The following table summarized the regulatory liabilities related to accumulated deferred taxes ("ADIT") associated with TCJA for our regulated businesses as of December 31, 2022 and 2021: Amount (in thousands) Operation and Regulatory Jurisdiction December 31, 2022 December 31, 2021 Status Eastern Shore (FERC) $34,190 $34,190 Will be addressed in Eastern Shore's next rate case filing. Chesapeake Delaware natural gas division (Delaware PSC) $12,230 $12,591 PSC approved amortization of ADIT in January 2019. Chesapeake Maryland natural gas division (Maryland PSC) $3,703 $3,840 PSC approved amortization of ADIT in May 2018. Sandpiper Energy (Maryland PSC) $3,597 $3,656 PSC approved amortization of ADIT in May 2018. Chesapeake Florida natural gas division/CFG (Florida PSC) $7,846 $8,032 PSC issued order authorizing amortization and retention of net ADIT liability by the Company in February 2019. FPU Natural Gas (excludes Fort Meade and Indiantown) (Florida PSC) $19,074 $19,189 Same treatment on a net basis as Chesapeake Florida Gas Division (above). FPU Fort Meade and Indiantown natural gas divisions (Florida PSC) $259 $271 Same treatment on a net basis as Chesapeake Florida Gas Division (above). FPU electric division (Florida PSC) $4,993 $5,237 In January 2019, PSC issued order approving amortization of ADIT through purchased power cost recovery, storm reserve and rates. Elkton Gas (Maryland PSC) $1,059 $1,091 PSC approved amortization of ADIT in March 2018. Regulatory Assets and Liabilities At December 31, 2022 and 2021, our regulated utility operations recorded the following regulatory assets and liabilities included in our consolidated balance sheets. These assets and liabilities will be recognized as revenues and expenses in future periods as they are reflected in customers’ rates. As of December 31, 2022 2021 (in thousands) Regulatory Assets Under-recovered purchased fuel, gas and conservation cost recovery (1)(2) $ 43,583 $ 9,199 Under-recovered GRIP revenue (3) 1,705 2,101 Deferred postretirement benefits (4) 13,927 16,749 Deferred conversion and development costs (1) 23,653 23,383 Acquisition adjustment (5) 25,609 27,182 Deferred costs associated with COVID-19 (6) 1,233 2,289 Deferred storm costs (7) 27,687 36,004 Other 12,257 7,060 Total Regulatory Assets $ 149,654 $ 123,967 Regulatory Liabilities Self-insurance (8) $ 339 $ 563 Over-recovered purchased fuel and conservation cost recovery (1) 3,827 1,073 Storm reserve (8) 2,845 2,829 Accrued asset removal cost (9) 50,261 47,887 Deferred income taxes due to rate change (10) 87,690 88,804 Interest related to storm recovery (7) 1,207 2,146 Other 1,851 1,498 Total Regulatory Liabilities $ 148,020 $ 144,800 (1) We are allowed to recover the asset or are required to pay the liability in rates. We do not earn an overall rate of return on these assets. (2) At December 31, 2022, includes $21.2 million being recovered over a three year period primarily concentrated in our electric division. Per Florida PSC approval, our electric division was allowed to recover these amounts over an extended period of time in an effort to reduce the impact of increased commodity prices to our customers. Recovery of these costs began in January 2023. (3) The Florida PSC allowed us to recover through a surcharge, capital and other program-related-costs, inclusive of an appropriate return on investment, associated with accelerating the replacement of qualifying distribution mains and services (defined as any material other than coated steel or plastic) in FPU’s natural gas distribution, Fort Meade division and Chesapeake Utilities’ CFG division. We are allowed to recover the asset or are required to pay the liability in rates related to GRIP. (4) The Florida PSC allowed FPU to treat as a regulatory asset the portion of the unrecognized costs pursuant to ASC Topic 715 , Compensation - Retirement Benefits , related to its regulated operations. This balance also includes the portion of pension settlement expense associated with the termination of the Chesapeake Pension Plan pursuant to an order from the FERC and the respective PSCs that allowed us to defer Eastern Shore, Delaware and Maryland Divisions' portion. See Note 16 , Employee Benefit Plans, for additional information. (5) We are allowed to include the premiums paid in various natural gas utility acquisitions in Florida in our rate bases and recover them over a specific time period pursuant to the Florida PSC approvals. We paid $34.2 million of the premium in 2009, including a gross up for income tax, because it is not tax deductible, and $0.7 million of the premium paid by FPU in 2010. (6) We deferred as regulatory assets the net incremental expense impact associated with the net expense impact of COVID-19 as authorized by the stated PSCs. (7) The Florida PSC authorized us to recover regulatory assets (including interest) associated with the recovery of Hurricanes Michael and Dorian storm costs which will be amortized between 6 and 10 years. Recovery of these costs includes a component of an overall return on capital additions and regulatory assets. (8) We have storm reserves in our Florida regulated energy operations and self-insurance for our regulated energy operations that allow us to collect through rates amounts to be used against general claims, storm restoration costs and other losses as they are incurred. (9) See Note 1 , Summary of Significant Accounting Policies, for additional information on our asset removal cost policies. (10) We recorded a regulatory liability for our regulated businesses related to the revaluation of accumulated deferred tax assets/liabilities as a result of the TCJA. The liability will be amortized over a period between 5 to 80 years based on the remaining life of the associated property. Based upon the regulatory proceedings, we will pass back the respective portion of the excess accumulated deferred taxes to rate payers. See Note 11, Income Taxes , for additional information.

Environmental Commitments and C

Environmental Commitments and Contingencies	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Environmental Commitments and Contingencies	E NVIRONMENTAL C OMMITMENTS AND C ONTINGENCIES We are subject to federal, state and local laws and regulations governing environmental quality and pollution control. These laws and regulations require us to remove or remediate, at current and former operating sites, the effect on the environment of the disposal or release of specified substances. MGP Sites We have participated in the investigation, assessment or remediation of, and have exposures at, seven former MGP sites. We have received approval for recovery of clean-up costs in rates for sites located in Salisbury, Maryland; Seaford, Delaware; and Winter Haven, Key West, Pensacola, Sanford and West Palm Beach, Florida. As of December 31, 2022 and 2021, we had approximately $4.3 million and $5.2 million, respectively, in environmental liabilities, related to the former MGP sites. As of December 31, 2022 and 2021, we have cumulative regulatory assets of $0.8 million and $1.3 million, respectively, for future recovery of environmental costs for customers. Specific to FPU's four MGP sites in Key West, Pensacola, Sanford and West Palm Beach, FPU has approval to recover, from insurance and from customers through rates, up to $14.0 million of its environmental costs related to its MGP sites. As of December 31, 2022 and 2021, we have recovered approximately $13.3 million and $12.9 million, respectively, leaving approximately $0.7 million and $1.1 million, respectively, in regulatory assets for future recovery of environmental costs from FPU’s customers. Environmental liabilities for our MGP sites are recorded on an undiscounted basis based on the estimate of future costs provided by independent consultants. We continue to expect that all costs related to environmental remediation and related activities, including any potential future remediation costs for which we do not currently have approval for regulatory recovery, will be recoverable from customers through rates. Remediation is ongoing for the MGP's in Winter Haven and Key West in Florida and in Seaford, Delaware and the remaining clean-up costs are estimated to be between $0.3 million to $0.9 million for these three sites. The Environmental Protection Agency has approved a "site-wide ready for anticipated use" status for the Sanford, Florida MGP site, which is the final step before delisting a site. The remaining remediation expenses for the Sanford MGP site are immaterial. The remedial actions approved by the Florida Department of Environmental Protection have been implemented on the east parcel of our West Palm Beach Florida site. Similar remedial actions have been initiated on the site's west parcel, and construction of active remedial systems are expected to be completed in 2023. We expect the costs to clean-up the site to be between $3.3 million to $14.2 million, including any potential costs associated with future redevelopment of the properties.

Other Commitments and Contingen

Other Commitments and Contingencies	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Other Commitments and Contingencies	O THER C OMMITMENTS AND C ONTINGENCIES Natural Gas, Electric and Propane Supply In March 2020, our Delmarva Peninsula natural gas distribution operations entered into asset management agreements with a third party to manage their natural gas transportation and storage capacity. The agreements were effective as of April 1, 2020 and expire in March 2023. FPU natural gas distribution operations and Eight Flags have separate asset management agreements with Emera Energy Services, Inc. to manage their natural gas transportation capacity. These agreements commenced in November 2020 and expire in March 2029. Chesapeake Utilities' Florida Division has firm transportation service contracts with FGT and Gulfstream. Pursuant to a capacity release program approved by the Florida PSC, all of the capacity under these agreements has been released to various third parties. Under the terms of these capacity release agreements, Chesapeake Utilities is contingently liable to FGT and Gulfstream should any party, that acquired the capacity through release, fail to pay the capacity charge. To date, Chesapeake Utilities has not been required to make a payment resulting from this contingency. FPU’s electric supply contracts require FPU to maintain an acceptable standard of creditworthiness based on specific financial ratios. FPU’s agreement with Florida Power & Light Company requires FPU to meet or exceed a debt service coverage ratio of 1.25 times based on the results of the prior 12 months. If FPU fails to meet this ratio, it must provide an irrevocable letter of credit or pay all amounts outstanding under the agreement within five business days. FPU’s electric supply agreement with Gulf Power requires FPU to meet the following ratios based on the average of the prior six quarters: (a) funds from operations interest coverage ratio (minimum of 2 times), and (b) total debt to total capital (maximum of 65 percent). If FPU fails to meet the requirements, it has to provide the supplier a written explanation of actions taken, or proposed to be taken, to become compliant. Failure to comply with the ratios specified in the Gulf Power agreement could also result in FPU having to provide an irrevocable letter of credit. As of December 31, 2022, FPU was in compliance with all of the requirements of its supply contracts. Eight Flags provides electricity and steam generation services through its CHP plant located on Amelia Island, Florida. In June 2016, Eight Flags began selling power generated from the CHP plant to FPU pursuant to a 20-year power purchase agreement for distribution to our electric customers. In July 2016, Eight Flags also started selling steam pursuant to a separate 20-year contract, to the landowner on which the CHP plant is located. The CHP plant is powered by natural gas transported by FPU through its distribution system and Peninsula Pipeline through its intrastate pipeline. The total purchase obligations for natural gas, electric and propane supplies are as follows: Year 2023 2024-2025 2026-2027 Beyond 2027 Total (in thousands) Purchase Obligations $ 83,521 $ 82,815 $ 71,327 $ 144,768 $ 382,431 Corporate Guarantees The Board of Directors has authorized us to issue corporate guarantees securing obligations of our subsidiaries and to obtain letters of credit securing our subsidiaries' obligations. The maximum authorized liability under such guarantees and letters of credit as of December 31, 2022 was $20.0 million. The aggregate amount guaranteed at December 31, 2022 was approximately $13.5 million with the guarantees expiring on various dates through November 30, 2023. In addition, the Board has authorized us to issue specific purpose corporate guarantees. The amount of specific purpose guarantees outstanding at December 31, 2022 was $11.1 million, including a guarantee issued in July 2022 in the amount of $7.1 million associated with the Florida natural gas rate case.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2022
Accounting Policies [Abstract]
Use of Estimates	Use of EstimatesThe preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates in measuring assets and liabilities and related revenues and expenses. These estimates involve judgments about various future economic factors that are difficult to predict and are beyond our control; therefore, actual results could differ from these estimates. As additional information becomes available, or actual amounts are determined, recorded estimates are revised. Consequently, operating results can be affected by revisions to prior accounting estimates.
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment are stated at original cost less accumulated depreciation or fair value, if impaired. Costs include direct labor, materials and third-party construction contractor costs, allowance for funds used during construction ("AFUDC"), and certain indirect costs related to equipment and employees engaged in construction. The costs of repairs and minor replacements are charged to expense as incurred, and the costs of major renewals and betterments are capitalized. Upon retirement or disposition of property within the regulated businesses, the gain or loss, net of salvage value, is charged to accumulated depreciation. Upon retirement or disposition of property owned by the unregulated businesses, the gain or loss, net of salvage value, is charged to income. A summary of property, plant and equipment by classification as of December 31, 2022 and 2021 is provided in the following table: As of December 31, (in thousands) 2022 2021 Property, plant and equipment Regulated Energy Natural gas distribution - Delmarva Peninsula and Florida $ 925,501 $ 859,627 Natural gas transmission - Delmarva Peninsula, Pennsylvania, Ohio and Florida 741,865 727,277 Electric distribution 135,633 133,383 Unregulated Energy Propane operations – Mid-Atlantic, North Carolina, South Carolina and Florida 185,090 176,095 Natural gas transmission and supply – Ohio 128,620 112,050 Electricity and steam generation 36,886 36,740 Mobile CNG and pipeline solutions 38,543 32,374 Renewable energy investments 4,076 — Other 29,890 35,418 Total property, plant and equipment 2,226,104 2,112,964 Less: Accumulated depreciation and amortization (462,926) (417,479) Plus: Construction work in progress 47,295 49,393 Net property, plant and equipment $ 1,810,473 $ 1,744,878 Contributions or Advances in Aid of Construction Customer contributions or advances in aid of construction reduce property, plant and equipment, unless the amounts are refundable to customers. Contributions or advances may be refundable to customers after a number of years based on the amount of revenues generated from the customers or the duration of the service provided to the customers. Refundable contributions or advances are recorded initially as liabilities. Non-refundable contributions reduce property, plant and equipment at the time of such determination. As of December 31, 2022 and 2021, the non-refundable contributions totaled $7.6 million and $6.3 million, respectively. AFUDC Some of the additions to our regulated property, plant and equipment include AFUDC, which represents the estimated cost of funds, from both debt and equity sources, used to finance the construction of major projects. AFUDC is capitalized in the applicable rate base for ratemaking purposes when the completed projects are placed in service. During the years ended December 31, 2022, 2021 and 2020, AFUDC totaled $0.1 million, $0.4 million and $0.7 million, respectively, which was reflected as a reduction of interest charges. Leases We have entered into lease arrangements for office space, land, equipment, pipeline facilities and warehouses. These leases enable us to conduct our business operations in the regions in which we operate. Our operating leases are included in operating lease right-of-use assets, other accrued liabilities, and operating lease - liabilities in our consolidated balance sheets. Right-of-use assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. Operating lease right-of-use assets and liabilities are recognized at commencement date based on the present value of lease payments over the lease term. Leases with an initial term of 12 months or less are not recorded on our balance sheet; we recognize lease expense for these leases on a straight-line basis over the lease term. Our leases do not provide an implicit lease rate, therefore, we utilize our incremental borrowing rate, as the basis to calculate the present value of future lease payments, at lease commencement. Our incremental borrowing rate represents the rate that we would have to pay to borrow funds on a collateralized basis over a similar term and in a similar economic environment. We have lease agreements with lease and non-lease components. At the adoption of ASC 842, we elected not to separate non-lease components from all classes of our existing leases. The non-lease components have been accounted for as part of the single lease component to which they are related. See Note 14, Leases, for additional information. Jointly-owned Pipelines Property, plant and equipment for our Florida natural gas transmission operation included $28.3 million of jointly owned assets at December 31, 2022, primarily comprised of the 26-mile Callahan intrastate transmission pipeline in Nassau County, Florida jointly-owned with Seacoast Gas Transmission. Peninsula Pipeline's ownership is 50 percent. Direct expenses for the jointly-owned pipeline are included in operating expenses of our consolidated statements of income. Accumulated depreciation for this pipeline totaled $1.5 million and $0.9 million at December 31, 2022 and 2021, respectively. Impairment of Long-lived Assets
Depreciation and Accretion Included in Operations Expenses	Depreciation and Accretion Included in Operations Expenses We compute depreciation expense for our regulated operations by applying composite, annual rates, as approved by the respective regulatory bodies. The following table shows the average depreciation rates used for regulated operations during the years ended December 31, 2022, 2021 and 2020: 2022 2021 2020 Natural gas distribution – Delmarva Peninsula 2.5% 2.5% 2.5% Natural gas distribution – Florida 2.5% 2.5% 2.5% Natural gas transmission – Delmarva Peninsula 2.7% 2.7% 2.7% Natural gas transmission – Florida 2.4% 2.3% 2.3% Natural gas transmission – Ohio 5.0% N/A N/A Electric distribution 2.8% 2.8% 2.9% For our unregulated operations, we compute depreciation expense on a straight-line basis over the following estimated useful lives of the assets: Asset Description Useful Life Propane distribution mains 10-37 years Propane bulk plants and tanks 10-40 years Propane equipment, meters and meter installations 5-33 years Measuring and regulating station equipment 5-37 years Natural gas pipelines 45 years Natural gas right of ways Perpetual CHP plant 30 years Natural gas processing equipment 20-25 years Office furniture and equipment 3-10 years Transportation equipment 4-20 years Structures and improvements 5-45 years Other Various We report certain depreciation and accretion in operations expense, rather than as a depreciation and amortization expense, in the accompanying consolidated statements of income in accordance with industry practice and regulatory requirements. Depreciation and accretion included in operations expense consists of the accretion of the costs of removal for future retirements of utility assets, vehicle depreciation, computer software and hardware depreciation, and other minor amounts of depreciation expense. For the years ended December 31, 2022, 2021 and 2020, we reported $11.0 million, $10.2 million and $9.6 million, respectively, of depreciation and accretion in operations expenses.
Regulated Operations	Regulated Operations We account for our regulated operations in accordance with ASC Topic 980, Regulated Operations, which includes accounting principles for companies whose rates are determined by independent third-party regulators. When setting rates, regulators often make decisions, the economics of which require companies to defer costs or revenues in different periods than may be appropriate for unregulated enterprises. When this situation occurs, a regulated company defers the associated costs as regulatory assets on the balance sheet and records them as expense on the income statement as it collects revenues. Further, regulators can also impose liabilities upon a regulated company, for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future, as regulatory liabilities. If we were required to terminate the application of these regulatory provisions to our regulated operations, all such deferred amounts would be recognized in the statement of income at that time, which could have a material impact on our financial position, results of operations and cash flows. We monitor our regulatory and competitive environments to determine whether the recovery of our regulatory assets continues to be probable. If we determined that recovery of these assets is no longer probable, we would write off the assets against earnings. We believe that the provisions of ASC Topic 980, Regulated Operations, continue to apply to our regulated operations and that the recovery of our regulatory assets is probable.
Operating Revenues	Revenue Recognition Revenues for our natural gas and electric distribution operations are based on rates approved by the PSC in each state in which they operate. Customers’ base rates may not be changed without formal approval by these commissions. The PSCs, however, have authorized our regulated operations to negotiate rates, based on approved methodologies, with customers that have competitive alternatives. Eastern Shore’s revenues are based on rates approved by the FERC. The FERC has also authorized Eastern Shore to negotiate rates above or below the FERC-approved maximum rates, which customers can elect as an alternative to FERC-approved maximum rates. For regulated deliveries of natural gas and electricity, we read meters and bill customers on monthly cycles that do not coincide with the accounting periods used for financial reporting purposes. We accrue unbilled revenues for natural gas and electricity delivered, but not yet billed, at the end of an accounting period to the extent that they do not coincide. We estimate the amount of the unbilled revenue by jurisdiction and customer class. All of our regulated natural gas and electric distribution operations have fuel cost recovery mechanisms, except for two utilities that provide only unbundled delivery service (Chesapeake Utilities' CFG division and FPU's Indiantown division). These mechanisms allow us to adjust billing rates, without further regulatory approvals, to reflect changes in the cost of purchased fuel. Differences between the cost of fuel purchased and delivered are deferred and accounted for as either unrecovered fuel cost or amounts payable to customers. Generally, these deferred amounts are recovered or refunded within one year. We charge flexible rates to our natural gas distribution industrial interruptible customers who can use alternative fuels. Interruptible service imposes no contractual obligation to deliver or receive natural gas on a firm service basis. Our unregulated propane distribution businesses record revenue in the period the products are delivered and/or services are rendered for their bulk delivery customers. For propane customers with meters whose billing cycles do not coincide with our accounting periods, we accrue unbilled revenue for product delivered but not yet billed and bill customers at the end of an accounting period, as we do in our regulated energy businesses. Our Ohio natural gas transmission/supply operation recognizes revenues based on actual volumes of natural gas shipped using contractual rates based upon index prices that are published monthly. Eight Flags records revenues based on the amount of electricity and steam generated and sold to its customers. Our mobile compressed natural gas operation recognizes revenue for CNG services at the end of each calendar month for services provided during the month based on agreed upon rates for labor, equipment utilized, costs incurred for natural gas compression, miles driven, mobilization and demobilization fees. We report revenue taxes, such as gross receipts taxes, franchise taxes, and sales taxes, on a net basis. For our businesses with agreements that contain variable consideration, we use the invoice practical expedient method. We determined that the amounts invoiced to customers correspond directly with the value to our customers and our performance to date.
Cost of Sales	Natural gas, electric and propane costs include the direct costs attributable to the products sold or services provided to our customers. These costs include primarily the variable commodity cost of natural gas, electricity and propane, costs of pipeline capacity needed to transport and store natural gas, transmission costs for electricity, costs to gather and process natural gas, costs to transport propane to/from our storage facilities or our mobile CNG equipment to customer locations, and steam and electricity generation costs. Depreciation expense is not included in natural gas, electric and propane costs.
Operations and Maintenance Expenses	Operations and Maintenance Expenses Operations and maintenance expenses include operations and maintenance salaries and benefits, materials and supplies, usage of vehicles, tools and equipment, payments to contractors, utility plant maintenance, customer service, professional fees and other outside services, insurance expense, minor amounts of depreciation, accretion of removal costs for future retirements of utility assets and other administrative expenses.
Cash and Cash Equivalents	Cash and Cash Equivalents Our policy is to invest cash in excess of operating requirements in overnight income-producing accounts. Such amounts are stated at cost, which approximates fair value. Investments with an original maturity of three months or less when purchased are considered cash equivalents.
Accounts Receivable and Allowance for Doubtful Accounts	Accounts Receivable and Allowance for Credit Losses Accounts receivable consist primarily of amounts due for sales of natural gas, electricity and propane and transportation and distribution services to customers. An allowance for doubtful accounts is recorded against amounts due based upon our collections experiences and an assessment of our customers’ inability or reluctance to pay. If circumstances change, our estimates of recoverable accounts receivable may also change. Circumstances which could affect such estimates include, but are not limited to, customer credit issues, natural gas, electricity and propane prices and impacts from general economic conditions. Accounts receivable are written off when they are deemed to be uncollectible. Our estimate for expected credit losses has been developed by analyzing our portfolio of financial assets that present potential credit exposure risk. These assets consist solely of our trade receivables from customers and contract assets. The estimate is based on five years of historical collections experience, a review of current economic and operating conditions in our service territories, and an examination of economic indicators which provide a reasonable and supportable basis of potential future activity. Those indicators include metrics which we believe provide insight into the future collectability of our trade receivables such as unemployment rates and economic growth statistics in our service territories. When determining estimated credit losses, we analyze the balance of our trade receivables based on the underlying line of business. This includes an examination of trade receivables from our energy distribution, energy transmission, energy delivery services and propane operations businesses. Our energy distribution business consists of all our regulated distribution utility (natural gas and electric) operations on the Delmarva Peninsula and in Florida. These business units have the ability to recover their costs through the rate-making process, which can include consideration for amounts historically written off to be included in rate base. Therefore, they possess a mechanism to recover credit losses which we believe reduces their exposure to credit risk. Our energy transmission and energy delivery services business units consist of our natural gas pipelines and our mobile CNG delivery operations. The majority of customers served by these business units are regulated distribution utilities who also have the ability to recover their costs. We believe this cost recovery mechanism significantly reduces the amount of credit risk. Our propane operations are unregulated and do not have the same ability to recover their costs as our regulated operations. However, historically our propane operations have not had material write offs relative to the amount of revenues generated. Our estimate of expected credit losses reflects our anticipated losses associated with our trade receivables as a result of non-payment from our customers beginning the day the trade receivable is established. We believe the risk of loss associated with trade receivables classified as current presents the least amount of credit exposure risk and therefore, we assign a lower estimate to our current trade receivables. As our trade receivables age outside of their expected due date, our estimate increases. Our allowance for credit losses relative to the balance of our trade receivables has historically been immaterial as a result of on time payment activity from our customers. The table below illustrates the changes in the balance of our allowance for expected credit losses for the year ended December 31, 2022: (in thousands) Balance at December 31, 2021 $ 3,141 Additions: Provision for credit losses 1,550 Recoveries 172 Deductions: Write offs (1,986) Balance at December 31, 2022 $ 2,877
Inventories	Inventories We use the average cost method to value propane, materials and supplies, and other merchandise inventory. If market prices drop below cost, inventory balances that are subject to price risk are adjusted to their net realizable value. There were no lower-of-cost-or-net realizable value adjustment for the years ended December 31, 2022, 2021 or 2020.
Goodwill and Other Intangible Assets	Goodwill and Other Intangible AssetsGoodwill is not amortized but is tested for impairment at least annually, or more frequently if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value. We use a present value technique based on discounted cash flows to estimate the fair value of our reporting units. An impairment charge is recognized if the carrying value of a reporting unit’s goodwill exceeds its fair value. The testing of goodwill for the years ended December 31, 2022, 2021 and 2020 indicated no goodwill impairment. Other intangible assets are amortized on a straight-line basis over their estimated economic useful lives.
Other Deferred Charges	Other Deferred ChargesOther deferred charges include issuance costs associated with short-term borrowings. These charges are amortized over the life of the related short-term debt borrowings.
Asset Retirement Obligation [Policy Text Block]	Asset Removal CostAs authorized by the appropriate regulatory body (state PSC or FERC), we accrue future asset removal costs associated with utility property, plant and equipment even if a legal obligation does not exist. Such accruals are provided for through depreciation expense and are recorded with corresponding credits to regulatory liabilities or assets. When we retire depreciable utility plant and equipment, we charge the associated original costs to accumulated depreciation and amortization, and any related removal costs incurred are charged to regulatory liabilities or assets. The difference between removal costs recognized in depreciation rates and the accretion and depreciation expense recognized for financial reporting purposes is a timing difference between recovery of these costs in rates and their recognition for financial reporting purposes. Accordingly, these differences are deferred as regulatory liabilities or assets. In the rate setting process, the regulatory liability or asset is excluded from the rate base upon which those utilities have the opportunity to earn their allowed rates of return. The costs associated with our asset retirement obligations are either currently being recovered in rates or are probable of recovery in future rates
Pension and Other Postretirement Plans	Pension and Other Postretirement Plans Pension and other postretirement plan costs and liabilities are determined on an actuarial basis and are affected by numerous assumptions and estimates, including the fair value of plan assets, estimates of the expected returns on plan assets, assumed discount rates, the level of contributions made to the plans, and current demographic and actuarial mortality data. We review annually the estimates and assumptions underlying our pension and other postretirement plan costs and liabilities with the assistance of third-party actuarial firms. The assumed discount rates, expected returns on plan assets and the mortality assumption are the factors that generally have the most significant impact on our pension costs and liabilities. The assumed discount rates, health care cost trend rates and rates of retirement generally have the most significant impact on our postretirement plan costs and liabilities. The discount rates are utilized principally in calculating the actuarial present value of our pension and postretirement obligations and net pension and postretirement costs. When estimating our discount rates, we consider high-quality corporate bond rates, such as the Empower curve index and the FTSE Index, changes in those rates from the prior year and other pertinent factors, including the expected life of each of our plans and their respective payment options. The expected long-term rates of return on assets are utilized in calculating the expected returns on the plan assets component of our annual pension plan costs. We estimate the expected returns on plan assets by evaluating expected bond returns, asset allocations, the effects of active plan management, the impact of periodic plan asset rebalancing and historical performance. We also consider the guidance from our investment advisors in making a final determination of our expected rates of return on plan assets.
Income Taxes and Investment Tax Credit Adjustments	Income Taxes, Investment Tax Credit Adjustments and Tax-Related Contingency Deferred tax assets and liabilities are recorded for the income tax effect of temporary differences between the financial statement basis and tax basis of assets and liabilities and are measured using the enacted income tax rates in effect in the years in which the differences are expected to reverse. Deferred tax assets are recorded net of any valuation allowance when it is more likely than not that such income tax benefits will be realized. Investment tax credits on utility property have been deferred and are allocated to income ratably over the lives of the subject property. We account for uncertainty in income taxes in our consolidated financial statements only if it is more likely than not that an uncertain tax position is sustainable based on technical merits. Recognizable tax positions are then measured to determine the amount of benefit recognized in the consolidated financial statements. We recognize penalties and interest related to unrecognized tax benefits as a component of other income. We account for contingencies associated with taxes other than income when the likelihood of a loss is both probable and estimable. In assessing the likelihood of a loss, we do not consider the existence of current inquiries, or the likelihood of future inquiries, by tax authorities as a factor. Our assessment is based solely on our application of the appropriate statutes and the likelihood of a loss, assuming the proper inquiries are made by tax authorities.
Financial Instruments	Financial Instruments We utilize financial instruments to mitigate commodity price risk associated with fluctuations of natural gas, electricity and propane and to mitigate interest rate risk. Our propane operations enter into derivative transactions, such as swaps, put options and call options in order to mitigate the impact of wholesale price fluctuations on inventory valuation and future purchase commitments. These transactions may be designated as fair value hedges or cash flow hedges, if they meet all of the accounting requirements pursuant to ASC Topic 815, Derivatives and Hedging, and we elect to designate the instruments as hedges. If designated as a fair value hedge, the value of the hedging instrument, such as a swap, future, or put option, is recorded at fair value, with the effective portion of the gain or loss of the hedging instrument effectively reducing or increasing the value of the hedged item. If designated as a cash flow hedge, the value of the hedging instrument, such as a swap or call option, is recorded at fair value with the effective portion of the gain or loss of the hedging instrument being recorded in comprehensive income. The ineffective portion of the gain or loss of a hedge is recorded in earnings. If the instrument is not designated as a fair value or cash flow hedge, or it does not meet the accounting requirements of a hedge under ASC Topic 815, Derivatives and Hedging , it is recorded at fair value with all gains or losses being recorded directly in earnings. Our natural gas, electric and propane operations enter into agreements with suppliers to purchase natural gas, electricity, and propane for resale to our respective customers. Purchases under these contracts, as well as distribution and sales agreements with counterparties or customers, either do not meet the definition of a derivative, or qualify for “normal purchases and normal sales” treatment under ASC Topic 815 Derivatives and Hedging , and are accounted for on an accrual basis.
Recently Adopted Accounting Standards
Schedule of Prospective Adoption of New Accounting Pronouncements [Table Text Block]	Recent Accounting Standards There are no pending or recently effective accounting standards which have had, or are expected to have, a material impact to our consolidated financial statements or disclosures.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2022
Accounting Policies [Abstract]
Property, Plant and Equipment [Table Text Block]	A summary of property, plant and equipment by classification as of December 31, 2022 and 2021 is provided in the following table: As of December 31, (in thousands) 2022 2021 Property, plant and equipment Regulated Energy Natural gas distribution - Delmarva Peninsula and Florida $ 925,501 $ 859,627 Natural gas transmission - Delmarva Peninsula, Pennsylvania, Ohio and Florida 741,865 727,277 Electric distribution 135,633 133,383 Unregulated Energy Propane operations – Mid-Atlantic, North Carolina, South Carolina and Florida 185,090 176,095 Natural gas transmission and supply – Ohio 128,620 112,050 Electricity and steam generation 36,886 36,740 Mobile CNG and pipeline solutions 38,543 32,374 Renewable energy investments 4,076 — Other 29,890 35,418 Total property, plant and equipment 2,226,104 2,112,964 Less: Accumulated depreciation and amortization (462,926) (417,479) Plus: Construction work in progress 47,295 49,393 Net property, plant and equipment $ 1,810,473 $ 1,744,878
Annual Depreciation Rates Table [Table Text Block]	Depreciation and Accretion Included in Operations Expenses We compute depreciation expense for our regulated operations by applying composite, annual rates, as approved by the respective regulatory bodies. The following table shows the average depreciation rates used for regulated operations during the years ended December 31, 2022, 2021 and 2020: 2022 2021 2020 Natural gas distribution – Delmarva Peninsula 2.5% 2.5% 2.5% Natural gas distribution – Florida 2.5% 2.5% 2.5% Natural gas transmission – Delmarva Peninsula 2.7% 2.7% 2.7% Natural gas transmission – Florida 2.4% 2.3% 2.3% Natural gas transmission – Ohio 5.0% N/A N/A Electric distribution 2.8% 2.8% 2.9%
Estimated Useful Life Of Assets Table [Table Text Block]	For our unregulated operations, we compute depreciation expense on a straight-line basis over the following estimated useful lives of the assets: Asset Description Useful Life Propane distribution mains 10-37 years Propane bulk plants and tanks 10-40 years Propane equipment, meters and meter installations 5-33 years Measuring and regulating station equipment 5-37 years Natural gas pipelines 45 years Natural gas right of ways Perpetual CHP plant 30 years Natural gas processing equipment 20-25 years Office furniture and equipment 3-10 years Transportation equipment 4-20 years Structures and improvements 5-45 years Other Various

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Calculations of Basic and Diluted Earnings Per Share	The following table presents the calculation of our basic and diluted earnings per share: For the Year Ended December 31, 2022 2021 2020 (in thousands, except shares and per share data) Calculation of Basic Earnings Per Share: Income from Continuing Operations $ 89,796 $ 83,467 $ 70,642 Income/(Loss) from Discontinued Operations — (1) 856 Net Income $ 89,796 $ 83,466 $ 71,498 Weighted average shares outstanding 17,722,227 17,558,078 16,711,579 Earnings Per Share from Continuing Operations $ 5.07 $ 4.75 $ 4.23 Earnings Per Share from Discontinued Operations — — 0.05 Basic Earnings Per Share $ 5.07 $ 4.75 $ 4.28 Calculation of Diluted Earnings Per Share: Reconciliation of Denominator: Weighted average shares outstanding — Basic 17,722,227 17,558,078 16,711,579 Effect of dilutive securities — Share-based compensation 82,067 74,951 59,156 Adjusted denominator — Diluted 17,804,294 17,633,029 16,770,735 Earnings Per Share from Continuing Operations $ 5.04 $ 4.73 $ 4.21 Earnings Per Share from Discontinued Operations — — 0.05 Diluted Earnings Per Share $ 5.04 $ 4.73 $ 4.26

Revenue Recognition Revenue R_2

Revenue Recognition Revenue Recognition (Tables)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue [Table Text Block]	for the years ended December 31, 2022, 2021 and 2020: For the year ended December 31, 2022 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Energy distribution Delaware natural gas division $ 82,176 $ — $ — $ 82,176 Florida natural gas division 40,036 — — 40,036 FPU electric distribution 81,714 — — 81,714 FPU natural gas distribution 115,834 — — 115,834 Maryland natural gas division 26,607 — — 26,607 Sandpiper natural gas/propane operations 21,278 — — 21,278 Elkton Gas 9,198 — — 9,198 Total energy distribution 376,843 — — 376,843 Energy transmission Aspire Energy — 56,225 — 56,225 Aspire Energy Express 1,377 — — 1,377 Eastern Shore 78,624 — — 78,624 Peninsula Pipeline 27,263 — — 27,263 Total energy transmission 107,264 56,225 — 163,489 Energy generation Eight Flags — 25,318 — 25,318 Propane operations Propane distribution operations — 188,412 — 188,412 Compressed Natural Gas Services Marlin Gas Services — 11,159 — 11,159 Other and eliminations Eliminations (54,683) (364) (29,778) (84,825) Other — — 308 308 Total other and eliminations (54,683) (364) (29,470) (84,517) Total operating revenues (1) $ 429,424 $ 280,750 $ (29,470) $ 680,704 (1) Total operating revenues for the year ended December 31, 2022, include other revenue (revenues from sources other than contracts with customers) of $0.5 million and $0.4 million for our Regulated and Unregulated Energy segments, respectively. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for Maryland division and Sandpiper and late fees.	For the year ended December 31, 2021 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Energy distribution Delaware natural gas division $ 71,195 $ — $ — $ 71,195 Florida natural gas division 34,074 — — 34,074 FPU electric distribution 78,300 — — 78,300 FPU natural gas distribution 100,535 — — 100,535 Maryland natural gas division 22,449 — — 22,449 Sandpiper natural gas/propane operations 20,746 — — 20,746 Elkton Gas 7,105 — — 7,105 Total energy distribution 334,404 — — 334,404 Energy transmission Aspire Energy — 38,163 — 38,163 Aspire Energy Express 187 — — 187 Eastern Shore 76,911 — — 76,911 Peninsula Pipeline 26,630 — — 26,630 Total energy transmission 103,728 38,163 — 141,891 Energy generation Eight Flags — 18,652 — 18,652 Propane operations Propane distribution operations — 142,082 — 142,082 Compressed Natural Gas Services Marlin Gas Services — 8,315 — 8,315 Other and eliminations Eliminations (54,212) (343) (21,348) (75,903) Other — — 527 527 Total other and eliminations (54,212) (343) (20,821) (75,376) Total operating revenues (1) $ 383,920 $ 206,869 $ (20,821) $ 569,968	For the years ended December 31, 2020 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Energy distribution Delaware natural gas division $ 63,389 $ — $ — $ 63,389 Florida natural gas division 30,850 — — 30,850 FPU electric distribution 76,863 — — 76,863 FPU natural gas distribution 90,150 — — 90,150 Maryland natural gas division 21,853 — — 21,853 Sandpiper natural gas/propane operations 17,214 — — 17,214 Elkton Gas 2,399 — — 2,399 Total energy distribution 302,718 — — 302,718 Energy transmission Aspire Energy — 27,951 — 27,951 Aspire Energy Express 16 — — 16 Eastern Shore 75,117 — — 75,117 Peninsula Pipeline 23,080 — — 23,080 Total energy transmission 98,213 27,951 — 126,164 Energy generation Eight Flags — 16,147 — 16,147 Propane operations Propane distribution operations — 100,744 — 100,744 Compressed Natural Gas Services Marlin Gas Services — 7,818 — 7,818 Other and eliminations Eliminations (48,185) (134) (17,602) (65,921) Other — — 528 528 Total other and eliminations (48,185) (134) (17,074) (65,393) Total operating revenues (1) $ 352,746 $ 152,526 $ (17,074) $ 488,198 (1) Total operating revenues for the year ended December 31, 2020, include other revenue (revenues from sources other than contracts with customers) of $1.4 million and $0.2 million for our Regulated and Unregulated Energy segments, respectively. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for Maryland division and Sandpiper and late fees.
Contract with Customer, Asset and Liability [Table Text Block]	The balances of our trade receivables, contract assets, and contract liabilities as of December 31, 2022 and 2021 were as follows: Trade Receivables Contract Assets (Current) Contract Assets (Noncurrent) Contract Liabilities (Current) (in thousands) Balance at 12/31/2021 $ 56,277 $ 18 $ 4,806 $ 747 Balance at 12/31/2022 61,687 18 4,321 983 Increase (decrease) $ 5,410 $ — $ (485) $ 236
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block]	Revenue for these businesses for the remaining performance obligations at December 31, 2022 are expected to be recognized as follows: (in thousands) 2023 2024 2025 2026 2027 2028 and thereafter Eastern Shore and Peninsula Pipeline $ 36,472 $ 33,148 $ 26,890 $ 23,444 $ 20,536 $ 167,663 Natural gas distribution operations 6,287 6,106 5,748 5,518 5,101 33,113 FPU electric distribution 652 652 275 275 275 275 Total revenue contracts with remaining performance obligations $ 43,411 $ 39,906 $ 32,913 $ 29,237 $ 25,912 $ 201,051

Segment Information Segment Inf

Segment Information Segment Information (Tables)	12 Months Ended
	Dec. 31, 2022
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment [Table Text Block]	The following table presents information about our reportable segments. For the Year Ended December 31, 2022 2021 2020 (in thousands) Operating Revenues, Unaffiliated Customers Regulated Energy $ 422,894 $ 381,879 $ 350,853 Unregulated Energy 257,810 188,089 137,345 Total operating revenues, unaffiliated customers $ 680,704 $ 569,968 $ 488,198 Intersegment Revenues (1) Regulated Energy $ 6,530 $ 2,041 $ 1,893 Unregulated Energy 22,940 18,780 15,181 Other businesses 308 527 528 Total intersegment revenues $ 29,778 $ 21,348 $ 17,602 Operating Income Regulated Energy $ 115,317 $ 106,174 $ 92,124 Unregulated Energy 27,350 24,427 20,664 Other businesses and eliminations 266 511 (65) Operating Income 142,933 131,112 112,723 Other income, net 5,051 1,721 3,222 Interest charges 24,356 20,135 21,765 Income from Continuing Operations before Income Taxes 123,628 112,698 94,180 Income Taxes on Continuing Operations 33,832 29,231 23,538 Income from Continuing Operations 89,796 83,467 70,642 Income (loss) from Discontinued Operations, Net of Tax — (1) 686 Gain on sale of Discontinued Operations, Net of tax — — 170 Net Income $ 89,796 $ 83,466 $ 71,498 Depreciation and Amortization Regulated Energy $ 52,707 $ 48,748 $ 46,079 Unregulated Energy 16,257 13,869 11,988 Other businesses and eliminations 9 44 50 Total depreciation and amortization $ 68,973 $ 62,661 $ 58,117 Capital Expenditures Regulated Energy $ 97,554 $ 139,733 $ 147,100 Unregulated Energy 40,773 81,651 46,295 Other businesses 2,355 6,425 2,480 Total capital expenditures $ 140,682 $ 227,809 $ 195,875 (1) All significant intersegment revenues are billed at market rates and have been eliminated from consolidated revenues. As of December 31, 2022 2021 Identifiable Assets Regulated Energy segment $ 1,716,255 $ 1,629,191 Unregulated Energy segment 463,239 439,114 Other businesses and eliminations 35,543 46,564 Total identifiable assets $ 2,215,037 $ 2,114,869

Supplemental Cash Flow Disclo_2

Supplemental Cash Flow Disclosures (Tables)	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Cash Paid for Interest and Income Taxes	Cash paid for interest and income taxes during the years ended December 31, 2022, 2021 and 2020 were as follows: For the Year Ended December 31, 2022 2021 2020 (in thousands) Cash paid for interest $ 24,267 $ 20,809 $ 22,884 Cash (received) paid for income taxes, net of refunds $ (4,963) $ 8,395 $ (8,135)
Non-Cash Investing and Financing Activities	Non-cash investing and financing activities during the years ended December 31, 2022, 2021, and 2020 were as follows: For the Year Ended December 31, 2022 2021 2020 (in thousands) Capital property and equipment acquired on account, but not paid for as of December 31 $ 13,211 $ 16,164 $ 23,625 Common stock issued for the Retirement Savings Plan $ — $ 1,712 $ 1,605 Common stock issued under the SICP $ 2,868 $ 2,834 $ 1,971

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Schedule of Derivative Instruments [Table Text Block]	As of December 31, 2022, the volume of our open commodity derivative contracts were as follows: Business unit Commodity Contract Type Quantity hedged (in millions) Designation Longest expiration date of hedge Sharp Propane (gallons) Purchases 20.0 Cash flow hedges August, 2025 Sharp Propane (gallons) Sales 5.0 Cash flow hedges December, 2023
Fair Values of Derivative Contracts Recorded in Consolidated Balance Sheets	Fair values of the derivative contracts recorded in the consolidated balance sheets as of December 31, 2022 and 2021 are as follows: Derivative Assets Fair Value as of (in thousands) Balance Sheet Location December 31, 2022 December 31, 2021 Derivatives not designated as hedging instruments Propane swap agreements Derivative assets, at fair value $ — $ 16 Derivatives designated as cash flow hedges Propane swap agreements Derivative assets, at fair value (1) 3,317 7,060 Interest rate swap agreements Derivative assets, at fair value (1) 452 — Total Derivative Assets $ 3,769 $ 7,076 (1) Derivative assets, at fair value include $2.8 million and $4.3 million in current assets in the consolidated balance sheet at December 31, 2022 and 2021, respectively, with the remainder of the balance classified as long-term. Derivative Liabilities Fair Value as of (in thousands) Balance Sheet Location December 31, 2022 December 31, 2021 Derivatives designated as cash flow hedges Propane swap agreements Derivative liabilities, at fair value (1) $ 1,810 $ 743 Interest rate swap agreements Derivative liabilities, at fair value (1) 405 — Total Derivative Liabilities $ 2,215 $ 743
Derivative Instruments, Gain (Loss) [Table Text Block]	The effects of gains and losses from derivative instruments are as follows: Amount of Gain (Loss) on Derivatives: Location of Gain For the Year Ended December 31, (in thousands) 2022 2021 2020 Derivatives not designated as hedging instruments Propane swap agreements Propane and natural gas costs $ 56 $ (1) $ — Derivatives designated as fair value hedges Put/Call option Propane and natural gas costs — (24) (12) Put/Call option Propane inventory — — 34 Derivatives designated as cash flow hedges Propane swap agreements Revenues (373) (536) — Propane swap agreements Propane and natural gas costs 3,881 7,187 2,428 Propane swap agreements Other comprehensive income (loss) (1,303) 9,777 7,463 Interest rate swap agreements Interest expense (47) (40) 60 Interest rate swap agreements Other comprehensive income (loss) — — 20 Total $ 2,214 $ 16,363 $ 9,993

Fair Value of Financial Instr_2

Fair Value of Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Financial Assets and Liabilities Measured at Fair Value on Recurring Basis	The following tables summarize our 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 of December 31, 2022 and 2021, respectively: Fair Value Measurements Using: As of December 31, 2022 Fair Value Quoted Prices in Significant Other Significant (in thousands) Assets: Investments—equity securities $ 24 $ 24 $ — $ — Investments—guaranteed income fund 1,853 — — 1,853 Investments—mutual funds and other 8,699 8,699 — — Total investments 10,576 8,723 — 1,853 Derivative assets 3,769 — 3,769 — Total assets $ 14,345 $ 8,723 $ 3,769 $ 1,853 Liabilities: Derivative liabilities $ 2,215 $ — $ 2,215 $ — Fair Value Measurements Using: As of December 31, 2021 Fair Value Quoted Prices in Active Markets (Level 1) Significant Other Significant (in thousands) Assets: Investments—equity securities $ 26 $ 26 $ — $ — Investments—guaranteed income fund 2,036 — — 2,036 Investments—mutual funds and other 10,033 10,033 — — Total investments 12,095 10,059 — 2,036 Derivative assets 7,076 — 7,076 — Total assets $ 19,171 $ 10,059 $ 7,076 $ 2,036 Liabilities: Derivative liabilities $ 743 $ — $ 743 $ —
Schedule of Changes in Fair Value of Plan Assets	The following table sets forth the summary of the changes in the fair value of Level 3 investments for the years ended December 31, 2022 and 2021: For the Year Ended December 31, 2022 2021 (in thousands) Beginning Balance $ 2,036 $ 2,156 Purchases and adjustments 132 88 Transfers/disbursements (347) (241) Investment income 32 33 Ending Balance $ 1,853 $ 2,036

Goodwill and Other Intangible_2

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Schedule of Carrying Value of Goodwill	The carrying value of goodwill as of December 31, 2022 and 2021 was as follows: (in thousands) Regulated Energy Unregulated Energy Total Goodwill Balance at December 31, 2021 $ 7,689 $ 37,019 $ 44,708 Additions (1) — 1,505 1,505 Balance at December 31, 2022 $ 7,689 $ 38,524 $ 46,213 (1) Includes goodwill from the purchase of operating assets of Planet Found in the fourth quarter of 2022.
Schedule of Carrying Value and Accumulated Amortization of Intangible Assets	The carrying value and accumulated amortization of intangible assets subject to amortization as of December 31, 2022 and 2021 are as follows: As of December 31, 2022 2021 (in thousands) Gross Accumulated Gross Accumulated Customer relationships (1) $ 16,965 $ 6,131 $ 16,814 $ 5,125 Non-Compete agreements 3,105 1,411 2,431 1,078 Patents (2)(3) 5,819 533 452 354 Other 270 225 270 218 Total $ 26,159 $ 8,300 $ 19,967 $ 6,775

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Schedule of Income Tax Expense	The following tables provide: (a) the components of income tax expense in 2022, 2021, and 2020; (b) the reconciliation between the statutory federal income tax rate and the effective income tax rate for 2022, 2021, and 2020 from continuing operations; and (c) the components of accumulated deferred income tax assets and liabilities at December 31, 2022 and 2021. For the Year Ended December 31, 2022 2021 2020 (in thousands) Current Income Tax Expense Federal $ 8,284 $ 2,775 $ (2,777) State 1,948 (96) 2,162 Other (47) (47) (47) Total current income tax expense (benefit) 10,185 2,632 (662) Deferred Income Tax Expense (1) Property, plant and equipment 14,968 24,074 23,224 Deferred gas costs 8,923 1,857 (714) Pensions and other employee benefits 1,109 (655) (75) FPU merger-related premium cost and deferred gain (351) (351) 156 Net operating loss carryforwards 2 97 5,107 Other (1,004) 1,577 (3,498) Total deferred income tax expense 23,647 26,599 24,200 Income Tax Expense from Continuing Operations 33,832 29,231 23,538 Income Tax Expense from Discontinued Operations — — 153 Total Income Tax $ 33,832 $ 29,231 $ 23,691 (1) Includes $7.8 million, $8.2 million, and $4.9 million of deferred state income taxes for the years 2022, 2021 and 2020, respectively.
Summary of Reconciliation of Statutory Federal Tax and Effective Income Tax Rates	For the Year Ended December 31, 2022 2021 2020 (in thousands) Reconciliation of Effective Income Tax Rates from Continuing Operations Federal income tax expense (1) $ 25,982 $ 23,666 $ 19,778 State income taxes, net of federal benefit 7,714 6,371 5,051 ESOP dividend deduction (177) (180) (218) CARES Act Tax Benefit — (919) (1,841) Other 313 293 768 Total Income Tax Expense from Continuing Operations $ 33,832 $ 29,231 $ 23,538 Effective Income Tax Rate from Continuing Operations 27.34 % 25.94 % 24.99 % (1) Federal income taxes were calculated at 21 percent for 2022, 2021, and 2020.
Schedule of Accumulated Deferred Income Tax Assets and Liabilities	As of December 31, 2022 2021 (in thousands) Deferred Income Taxes Deferred income tax liabilities: Property, plant and equipment $ 238,687 $ 224,034 Acquisition adjustment 5,915 6,266 Loss on reacquired debt 164 183 Deferred gas costs 11,288 2,366 Natural gas conversion costs 5,026 5,529 Storm reserve liability 5,791 5,783 Other 8,236 6,301 Total deferred income tax liabilities $ 275,107 $ 250,462 Deferred income tax assets: Pension and other employee benefits $ 3,985 $ 5,354 Environmental costs 1,052 996 Net operating loss carryforwards 1,488 1,490 Storm reserve liability 453 448 Accrued expenses 9,007 4,843 Other 2,955 3,781 Total deferred income tax assets $ 18,940 $ 16,912 Deferred Income Taxes Per Consolidated Balance Sheets $ 256,167 $ 233,550

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2022
Text Block [Abstract]
Outstanding Long-Term Debt	Our outstanding long-term debt is shown below: As of December 31, (in thousands) 2022 2021 Uncollateralized Senior Notes: 5.93% note, due October 31, 2023 $ 3,000 $ 6,000 5.68% note, due June 30, 2026 11,600 14,500 6.43% note, due May 2, 2028 4,200 4,900 3.73% note, due December 16, 2028 12,000 14,000 3.88% note, due May 15, 2029 35,000 40,000 3.25% note, due April 30, 2032 66,500 70,000 3.48% note, due May 31, 2038 50,000 50,000 3.58% note, due November 30, 2038 50,000 50,000 3.98% note, due August 20, 2039 100,000 100,000 2.98% note, due December 20, 2034 70,000 70,000 3.00% note, due July 15, 2035 50,000 50,000 2.96% note, due August 15, 2035 40,000 40,000 2.49% notes Due January 25, 2037 50,000 50,000 2.95% notes Due March 15, 2042 50,000 — Equipment security note 2.46% note, due September 24, 2031 8,517 9,378 Less: debt issuance costs (946) (913) Total long-term debt 599,871 567,865 Less: current maturities (21,483) (17,962) Total long-term debt, net of current maturities $ 578,388 $ 549,903
Schedule of Maturities of Long-term Debt [Table Text Block]	Annual maturities and principal repayments of long-term debt are as follows: Year 2023 2024 2025 2026 2027 Thereafter Total (in thousands) Payments $ 21,483 $ 18,505 $ 25,528 $ 34,551 $ 31,674 $ 469,076 $ 600,817
Line of Credit Facility [Line Items]
Schedule of Line of Credit Facilities [Table Text Block]	The following table summarizes our shelf agreements at December 31, 2022: (in thousands) Total Borrowing Capacity Less Amount of Debt Issued Less Unfunded Commitments Remaining Borrowing Capacity Shelf Agreements (1) Prudential Shelf Agreement (2) $ 370,000 $ (220,000) $ (80,000) $ 70,000 MetLife Shelf Agreement 150,000 (50,000) — 100,000 Total $ 520,000 $ (270,000) $ (80,000) $ 170,000 (1) The amended Prudential and MetLife Shelf Agreements both expire in February 2026. (2) Unfunded commitments of $80.0 million reflects Senior Notes expected to be issued on or before March 14, 2023.

Leases Leases (Tables)

Leases Leases (Tables)	12 Months Ended
	Dec. 31, 2022
Leases [Abstract]
Lease, Cost [Table Text Block]	Year Ended December 31, (in thousands) Classification 2022 2021 Operating lease cost (1) Operations expense $ 2,883 $ 2,064 (1) Includes short-term leases and variable lease costs, which are immaterial.
Schedule of Leases Reported on Consolidated Statement of Financial Position [Table Text Block]	The following table presents the balance and classifications of our right-of-use assets and lease liabilities included in our consolidated balance sheet at December 31, 2022 and 2021: (in thousands) Balance sheet classification December 31, 2022 December 31, 2021 Assets Operating lease assets Operating lease right-of-use assets $ 14,421 $ 10,139 Liabilities Current Operating lease liabilities Other accrued liabilities $ 2,552 $ 1,996 Noncurrent Operating lease liabilities Operating lease - liabilities 12,392 8,571 Total lease liabilities $ 14,944 $ 10,567
Leases, Weighted Average Remaining Lease Term [Table Text Block]	The following table presents our weighted-average remaining lease term and weighted-average discount rate for our operating leases at December 31, 2022 and 2021: December 31, 2022 December 31, 2021 Weighted-average remaining lease term ( in years ) Operating leases 8.54 8.10 Weighted-average discount rate Operating leases 3.4 % 3.6 %
Lease, Cash Flow [Table Text Block]	The following table presents additional information related to cash paid for amounts included in the measurement of lease liabilities included in our consolidated statements of cash flows at December 31, 2022 and 2021: Year Ended December 31, (in thousands) 2022 2021 Operating cash flows from operating leases $ 2,931 $ 1,996
Schedule of Future Minimum Lease Payments for Capital Leases [Table Text Block]	The following table presents the future undiscounted maturities of our operating leases at December 31, 2022 and for each of the next five years and thereafter: (in thousands) Operating Leases (1) 2023 $ 2,871 2024 2,546 2025 2,161 2026 1,684 2027 1,529 Thereafter 6,192 Total lease payments 16,983 Less: Interest (2,039) Present value of lease liabilities $ 14,944 (1) Operating lease payments include $2.1 million related to options to extend lease terms that are reasonably certain of being exercised.

Stockholders' Equity (Tables)

Stockholders' Equity (Tables)	12 Months Ended
	Dec. 31, 2022
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents the changes in the balance of accumulated other comprehensive income (loss) for the years ended December 31, 2022 and 2021. All amounts in the following tables are presented net of tax. Defined Benefit Pension and Postretirement Plan Items Commodity Contract Cash Flow Hedges Interest Rate Swap Cash Flow Hedges Total (in thousands) As of December 31, 2020 $ (5,146) $ 2,309 $ (28) $ (2,865) Other comprehensive income before reclassifications 262 7,075 — 7,337 Amounts reclassified from accumulated other comprehensive income (loss) 1,616 (4,813) 28 (3,169) Net current-period other comprehensive income 1,878 2,262 28 4,168 As of December 31, 2021 (3,268) 4,571 — 1,303 Other comprehensive income (loss) before reclassifications 705 (934) — (229) Amounts reclassified from accumulated other comprehensive income (loss) 57 (2,545) 35 (2,453) Net current-period other comprehensive income 762 (3,479) 35 (2,682) As of December 31, 2022 $ (2,506) $ 1,092 $ 35 $ (1,379)
Reclassification out of Accumulated Other Comprehensive Income	The following table presents amounts reclassified out of accumulated other comprehensive income (loss) for the years ended December 31, 2022, 2021 and 2020. Deferred gains and losses of our commodity contracts cash flow hedges are recognized in earnings upon settlement. For the Year Ended December 31, (in thousands) 2022 2021 2020 Amortization of defined benefit pension and postretirement plan items: Prior service credit (1) $ 77 $ 77 $ 77 Net actuarial loss (1) (152) (2,243) (592) Total before income taxes (75) (2,166) (515) Income tax benefit (3) 18 550 150 Net of tax $ (57) $ (1,616) $ (365) Gains on commodity contracts cash flow hedges Propane swap agreements (2) $ 3,508 $ 6,651 $ 2,428 Total before income taxes 3,508 6,651 2,428 Income tax expense (3) (963) (1,838) (671) Net of tax $ 2,545 $ 4,813 $ 1,757 Gains and (losses) on interest rate swap cash flow hedges: Interest rate swap agreements $ (47) $ (40) $ 60 Total before income taxes (47) (40) 60 Income tax expense (3) 12 12 (16) Net of tax $ (35) $ (28) $ 44 Total reclassifications for the period $ 2,453 $ 3,169 $ 1,436 (1) These amounts are included in the computation of net periodic benefits. See Note 16 , Employee Benefit Plans , for additional details. (2) These amounts are included in the effects of gains and losses from derivative instruments. See Note 8, Derivative Instruments , for additional details. (3) The income tax benefit is included in income tax expense in the accompanying consolidated statements of income.

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2022
Schedule of Assets by Investment Type	The following schedule summarizes the assets of the FPU Pension Plan, by investment type, at December 31, 2022, 2021 and 2020: FPU Pension Plan At December 31, 2022 2021 2020 Asset Category Equity securities 53 % 52 % 54 % Debt securities 38 % 38 % 37 % Other 9 % 10 % 9 % Total 100 % 100 % 100 %
Schedule of Asset Allocation Strategy	The following allocation range of asset classes is intended to produce a rate of return sufficient to meet the FPU Pension Plan’s goals and objectives: Asset Allocation Strategy Asset Class Minimum Allocation Percentage Maximum Allocation Percentage Domestic Equities (Large Cap, Mid Cap and Small Cap) 14 % 32 % Foreign Equities (Developed and Emerging Markets) 13 % 25 % Fixed Income (Inflation Bond and Taxable Fixed) 29 % 47 % Alternative Strategies (Long/Short Equity and Hedge Fund of Funds) 4 % 10 % Diversifying Assets (High Yield Fixed Income, Commodities, and Real Estate) 2 % 6 % Cash 0 % 5 %
Summary of Pension Plan Assets	At December 31, 2022 and 2021, the assets of the FPU Pension Plan were comprised of the following investments: Fair Value Measurement Hierarchy For the Years Ended December 31, 2022 2021 Asset Category Total Total (in thousands) Mutual Funds - Equity securities U.S. Large Cap (1) $ 3,413 $ 4,302 U.S. Mid Cap (1) 1,425 1,835 U.S. Small Cap (1) 692 954 International (2) 9,352 10,863 Alternative Strategies (3) 4,824 5,888 19,706 23,842 Mutual Funds - Debt securities Fixed income (4) 15,343 19,551 High Yield (4) 2,269 3,014 17,612 22,565 Mutual Funds - Other Commodities (5) 1,832 2,297 Real Estate (6) 1,709 2,729 Guaranteed deposit (7) 398 497 3,939 5,523 Total Pension Plan Assets in fair value hierarchy (8) 41,257 51,930 Investments measured at net asset value (9) 4,946 6,782 Total Pension Plan Assets $ 46,203 $ 58,712
Schedule of Level Three Defined Benefit Plan Assets Roll Forward	The following table sets forth the summary of the changes in the fair value of Level 3 investments for the years ended December 31, 2022 and 2021: For the Year Ended December 31, 2022 2021 (in thousands) Balance, beginning of year $ 497 $ 1,019 Purchases 208 3,160 Transfers in 3,270 5,914 Disbursements (3,541) (9,587) Investment income (loss) (36) (9) Balance, end of year $ 398 $ 497
Schedule of Amounts Not Yet Reflected in Net Periodic Benefit Cost and Included in Accumulated Other Comprehensive Income Loss or Regulatory Assets	The following table presents the amounts not yet reflected in net periodic benefit cost and included in accumulated other comprehensive loss or as a regulatory asset as of December 31, 2022: (in thousands) FPU Chesapeake Chesapeake FPU Total Prior service credit $ — $ — $ (216) $ — $ (216) Net loss (gain) 14,540 295 597 (401) 15,031 Total $ 14,540 $ 295 $ 381 $ (401) $ 14,815 Accumulated other comprehensive loss (gain) pre-tax (1) $ 2,763 $ 295 $ 381 $ (76) $ 3,363 Post-merger regulatory asset 11,777 — — (325) 11,452 Total unrecognized cost $ 14,540 $ 295 $ 381 $ (401) $ 14,815 (1) The total amount of accumulated other comprehensive loss recorded on our consolidated balance sheet as of December 31, 2022 is net of income tax benefits of $0.9 million.
Schedule of Estimated Future Benefit Payments	The schedule below shows the estimated future benefit payments for each of the plans previously described: FPU Pension Plan (1) Chesapeake SERP (2) Chesapeake Postretirement Plan (2) FPU Medical Plan (2) (in thousands) 2023 $ 3,432 $ 151 $ 60 $ 57 2024 $ 3,503 $ 149 $ 58 $ 59 2025 $ 3,648 $ 162 $ 55 $ 59 2026 $ 3,680 $ 159 $ 50 $ 58 2027 $ 3,675 $ 156 $ 48 $ 59 Years 2028 through 2032 $ 18,368 $ 707 $ 200 $ 227 (1) The pension plan is funded; therefore, benefit payments are expected to be paid out of the plan assets. (2) Benefit payments are expected to be paid out of our general funds.
Pension benefit
Schedule of Funded Status of Benefit Obligation and Plan Assets	The following schedules set forth the funded status at December 31, 2022 and 2021 and the net periodic cost for the years ended December 31, 2022, 2021 and 2020 for the Chesapeake and FPU Pension Plans as well as the Chesapeake SERP: Chesapeake FPU Chesapeake At December 31, 2022 2021 2022 2021 2022 2021 (in thousands) Change in benefit obligation: Benefit obligation — beginning of year $ — $ 6,146 $ 67,030 $ 70,366 $ 2,096 $ 2,212 Interest cost — 141 1,781 1,714 50 48 Actuarial (gain) loss — (371) (15,713) (1,953) (335) (12) Effect of settlement — (5,884) — — — — Benefits paid — (32) (3,157) (3,097) (152) (152) Benefit obligation — end of year — — 49,941 67,030 1,659 2,096 Change in plan assets: Fair value of plan assets — beginning of year — 4,609 58,712 55,966 — — Actual return on plan assets — (237) (9,552) 4,246 — — Employer contributions — 1,544 200 1,597 152 152 Effect of settlement — (5,884) — — — — Benefits paid — (32) (3,157) (3,097) (152) (152) Fair value of plan assets — end of year — — 46,203 58,712 — — Accrued pension cost / funded status $ — $ — $ (3,738) $ (8,318) $ (1,659) $ (2,096) Assumptions: Discount rate — % 2.50 % 5.25 % 2.75 % 5.00 % 2.50 % Expected return on plan assets — % 3.50 % 6.00 % 6.00 % — % — %
Component of Net Periodic Pension Cost (Benefit)	Chesapeake FPU Chesapeake For the Years Ended December 31, 2022 2021 2020 2022 2021 2020 2022 2021 2020 (in thousands) Components of net periodic pension cost: Interest cost $ — $ 141 $ 176 $ 1,781 $ 1,714 $ 2,085 $ 50 $ 48 $ 63 Expected return on assets — (166) (157) (3,430) (3,306) (2,967) — — — Amortization of actuarial loss — 257 243 466 612 552 28 28 20 Settlement expense — 1,810 203 — — — — — — Net periodic pension cost — 2,042 465 (1,183) (980) (330) 78 76 83 Amortization of pre-merger regulatory asset — — — — — — — — — Total periodic cost $ — $ 2,042 $ 465 $(1,183) $ (980) $ (330) $ 78 $ 76 $ 83 Assumptions: Discount rate — % 2.25 % 3.00 % 2.75 % 2.50 % 3.25 % 2.50 % 2.25 % 3.00 % Expected return on plan assets — % 3.50 % 3.50 % 6.00 % 6.00 % 6.00 % — % — % — %
Other Postretirement Benefit Plans
Component of Net Periodic Pension Cost (Benefit)	Net periodic postretirement benefit costs for the Chesapeake Postretirement Plan and the FPU Medical Plan were not material for the years ended December 31, 2022, 2021, and 2020.

Share-Based Compensation Plans

Share-Based Compensation Plans (Tables)	12 Months Ended
	Dec. 31, 2022
Share-Based Compensation Amounts Included in Net Income	The table below presents the amounts included in net income related to share-based compensation expense for the awards granted under the SICP for the years ended December 31, 2022, 2021 and 2020: For the Year Ended December 31, 2022 2021 2020 (in thousands) Awards to non-employee directors $ 959 $ 782 $ 733 Awards to key employees 5,479 5,163 4,096 Total compensation expense 6,438 5,945 4,829 Less: tax benefit (1,663) (1,535) (1,254) Share-based compensation amounts included in net income $ 4,775 $ 4,410 $ 3,575
Cash Proceeds Received and Tax Benefit from Share-based Payment Awards [Table Text Block]	The below table presents the number of shares withheld /and amounts remitted to taxing authorities: For the Year Ended December 31, 2022 2021 2020 (amounts except shares, in thousands) Shares withheld to satisfy tax obligations 21,832 14,020 10,319 Amounts remitted to tax authorities to satisfy obligations $ 2,838 $ 1,478 $ 977
SICP Awards to Key Employees
Summary of Stock Activity Non-employee directors	The table below presents the summary of the stock activity for awards to all officers: Number of Weighted Average Outstanding — December 31, 2020 186,878 $ 87.06 Granted 69,903 100.76 Vested (53,147) 76.31 Expired (852) 74.85 Forfeited (1) (5,384) 93.39 Outstanding — December 31, 2021 197,398 94.15 Granted 69,620 117.61 Vested (60,850) 90.60 Expired (2,678) 91.42 Outstanding — December 31, 2022 203,490 $ 103.06

Rates and Other Regulatory Ac_2

Rates and Other Regulatory Activities Summary of Effects of Tax Reform Impact on Regulated Businesses (Tables)	12 Months Ended
	Dec. 31, 2022
Summary of Effects of Federal Tax Reform on Regulated Businesses [Abstract]
Summary of Effects of Federal Tax Reform on Regulated Businesses [Table Text Block]	Amount (in thousands) Operation and Regulatory Jurisdiction December 31, 2022 December 31, 2021 Status Eastern Shore (FERC) $34,190 $34,190 Will be addressed in Eastern Shore's next rate case filing. Chesapeake Delaware natural gas division (Delaware PSC) $12,230 $12,591 PSC approved amortization of ADIT in January 2019. Chesapeake Maryland natural gas division (Maryland PSC) $3,703 $3,840 PSC approved amortization of ADIT in May 2018. Sandpiper Energy (Maryland PSC) $3,597 $3,656 PSC approved amortization of ADIT in May 2018. Chesapeake Florida natural gas division/CFG (Florida PSC) $7,846 $8,032 PSC issued order authorizing amortization and retention of net ADIT liability by the Company in February 2019. FPU Natural Gas (excludes Fort Meade and Indiantown) (Florida PSC) $19,074 $19,189 Same treatment on a net basis as Chesapeake Florida Gas Division (above). FPU Fort Meade and Indiantown natural gas divisions (Florida PSC) $259 $271 Same treatment on a net basis as Chesapeake Florida Gas Division (above). FPU electric division (Florida PSC) $4,993 $5,237 In January 2019, PSC issued order approving amortization of ADIT through purchased power cost recovery, storm reserve and rates. Elkton Gas (Maryland PSC) $1,059 $1,091 PSC approved amortization of ADIT in March 2018.
Schedule of Regulatory Assets [Table Text Block]	At December 31, 2022 and 2021, our regulated utility operations recorded the following regulatory assets and liabilities included in our consolidated balance sheets. These assets and liabilities will be recognized as revenues and expenses in future periods as they are reflected in customers’ rates. As of December 31, 2022 2021 (in thousands) Regulatory Assets Under-recovered purchased fuel, gas and conservation cost recovery (1)(2) $ 43,583 $ 9,199 Under-recovered GRIP revenue (3) 1,705 2,101 Deferred postretirement benefits (4) 13,927 16,749 Deferred conversion and development costs (1) 23,653 23,383 Acquisition adjustment (5) 25,609 27,182 Deferred costs associated with COVID-19 (6) 1,233 2,289 Deferred storm costs (7) 27,687 36,004 Other 12,257 7,060 Total Regulatory Assets $ 149,654 $ 123,967 Regulatory Liabilities Self-insurance (8) $ 339 $ 563 Over-recovered purchased fuel and conservation cost recovery (1) 3,827 1,073 Storm reserve (8) 2,845 2,829 Accrued asset removal cost (9) 50,261 47,887 Deferred income taxes due to rate change (10) 87,690 88,804 Interest related to storm recovery (7) 1,207 2,146 Other 1,851 1,498 Total Regulatory Liabilities $ 148,020 $ 144,800 (1) We are allowed to recover the asset or are required to pay the liability in rates. We do not earn an overall rate of return on these assets. (2) At December 31, 2022, includes $21.2 million being recovered over a three year period primarily concentrated in our electric division. Per Florida PSC approval, our electric division was allowed to recover these amounts over an extended period of time in an effort to reduce the impact of increased commodity prices to our customers. Recovery of these costs began in January 2023. (3) The Florida PSC allowed us to recover through a surcharge, capital and other program-related-costs, inclusive of an appropriate return on investment, associated with accelerating the replacement of qualifying distribution mains and services (defined as any material other than coated steel or plastic) in FPU’s natural gas distribution, Fort Meade division and Chesapeake Utilities’ CFG division. We are allowed to recover the asset or are required to pay the liability in rates related to GRIP. (4) The Florida PSC allowed FPU to treat as a regulatory asset the portion of the unrecognized costs pursuant to ASC Topic 715 , Compensation - Retirement Benefits , related to its regulated operations. This balance also includes the portion of pension settlement expense associated with the termination of the Chesapeake Pension Plan pursuant to an order from the FERC and the respective PSCs that allowed us to defer Eastern Shore, Delaware and Maryland Divisions' portion. See Note 16 , Employee Benefit Plans, for additional information. (5) We are allowed to include the premiums paid in various natural gas utility acquisitions in Florida in our rate bases and recover them over a specific time period pursuant to the Florida PSC approvals. We paid $34.2 million of the premium in 2009, including a gross up for income tax, because it is not tax deductible, and $0.7 million of the premium paid by FPU in 2010. (6) We deferred as regulatory assets the net incremental expense impact associated with the net expense impact of COVID-19 as authorized by the stated PSCs. (7) The Florida PSC authorized us to recover regulatory assets (including interest) associated with the recovery of Hurricanes Michael and Dorian storm costs which will be amortized between 6 and 10 years. Recovery of these costs includes a component of an overall return on capital additions and regulatory assets. (8) We have storm reserves in our Florida regulated energy operations and self-insurance for our regulated energy operations that allow us to collect through rates amounts to be used against general claims, storm restoration costs and other losses as they are incurred. (9) See Note 1 , Summary of Significant Accounting Policies, for additional information on our asset removal cost policies. (10) We recorded a regulatory liability for our regulated businesses related to the revaluation of accumulated deferred tax assets/liabilities as a result of the TCJA. The liability will be amortized over a period between 5 to 80 years based on the remaining life of the associated property. Based upon the regulatory proceedings, we will pass back the respective portion of the excess accumulated deferred taxes to rate payers. See Note 11, Income Taxes , for additional information.

Environmental Commitments and_2

Environmental Commitments and Contingencies Environmental Remediation Status (Tables)	12 Months Ended
	Dec. 31, 2022
Environmental Remediation Obligations [Abstract]
Schedule of Environmental Loss Contingencies by Site [Table Text Block]	The remedial actions approved by the Florida Department of Environmental Protection have been implemented on the east parcel of our West Palm Beach Florida site. Similar remedial actions have been initiated on the site's west parcel, and construction of active remedial systems are expected to be completed in 2023. We expect the costs to clean-up the site to be between $3.3 million to $14.2 million, including any potential costs associated with future redevelopment of the properties.

Other Commitments and Conting_2

Other Commitments and Contingencies Other Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2022
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment [Table Text Block]	The total purchase obligations for natural gas, electric and propane supplies are as follows: Year 2023 2024-2025 2026-2027 Beyond 2027 Total (in thousands) Purchase Obligations $ 83,521 $ 82,815 $ 71,327 $ 144,768 $ 382,431

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Summary of Property, Plant and Equipment by Classification (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2022 USD ($) mi	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Property, Plant and Equipment [Line Items]
Contributions in Aid of Construction	$ 7,600	$ 6,300
Public Utilities, Allowance for Funds Used During Construction, Description	$ 100	400	$ 700
Number of Months to Establish ROU Asset and Liability	12 months
Property, plant and equipment
Total property, plant and equipment	$ 2,226,104	2,112,964
Less: Accumulated depreciation and amortization	(462,926)	(417,479)
Net property, plant and equipment	1,810,473	1,744,878
Construction Work in Progress	47,295	49,393
Jointly Owned Pipeline [Member]
Property, plant and equipment
Accumulated Depreciation, Depletion and Amortization, Sale or Disposal of Property, Plant and Equipment	1,500	900
Natural Gas Distribution [Member] | Delmarva and Florida [Member]
Property, plant and equipment
Total property, plant and equipment	925,501	859,627
Natural Gas Transmission [Member] | Delmarva Peninsula, Pennsylvania and Florida [Member]
Property, plant and equipment
Total property, plant and equipment	741,865	727,277
Natural Gas Transmission [Member] | OHIO
Property, plant and equipment
Total property, plant and equipment	128,620	112,050
Electric distribution | Florida
Property, plant and equipment
Total property, plant and equipment	135,633	133,383
Propane Operations [Member] | Mid-Atlantic and Florida [Member]
Property, plant and equipment
Total property, plant and equipment	185,090	176,095
Electricity and Steam Generation [Member] | Florida
Property, plant and equipment
Total property, plant and equipment	36,886	36,740
Mobile CNG Utility and Pipeline Solutions [Member] | Florida
Property, plant and equipment
Total property, plant and equipment	38,543	32,374
Other
Property, plant and equipment
Total property, plant and equipment	29,890	35,418
Other unregulated energy | Other [Member]
Property, plant and equipment
Total property, plant and equipment	$ 4,076	$ 0
Natural Gas Operations
Property, plant and equipment
Miles Of Natural Gas Pipeline | mi	26
Jointly Owned Pipeline [Member]
Property, plant and equipment
Net property, plant and equipment	$ 28,300

Summary of Significant Accoun_5

Summary of Significant Accounting Policies - Additional Information (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2022 USD ($) utility mi	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Summary Of Accounting Policies [Line Items]
Number of Months to Establish ROU Asset and Liability	12 months
Operating Lease, Liability	$ 14,944
Number of Utilities that do not have cost recovery mechanism	1
Delay of Revenue Recognition Due To Implementation of New Standard | utility	2
Maturity Period To Be Considered Cash Equivalents	3 months
Contributions or Advances in Aid of Construction	$ 7,600	$ 6,300
Net property, plant and equipment	1,810,473	1,744,878
Accumulated depreciation	462,926	417,479
Depreciation and accretion reported in operations expenses	11,000	10,200	$ 9,600
Operating Lease, Right-of-Use Asset	$ 14,421	$ 10,139
Natural Gas Operations
Summary Of Accounting Policies [Line Items]
Length of pipeline | mi	26
Minimum [Member]
Summary Of Accounting Policies [Line Items]
Operating Lease, Liability	$ 11,000
Maximum
Summary Of Accounting Policies [Line Items]
Operating Lease, Liability	$ 13,000

Summary of Significant Accoun_6

Summary of Significant Accounting Policies - Average Depreciation Rates (Detail)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Natural gas distribution | Delmarva
Property, Plant and Equipment [Line Items]
Average depreciation rates	2.50%	2.50%	2.50%
Natural gas distribution | Florida
Property, Plant and Equipment [Line Items]
Average depreciation rates	2.50%	2.50%	2.50%
Natural gas transmission | Delmarva
Property, Plant and Equipment [Line Items]
Average depreciation rates	2.70%	2.70%	2.70%
Natural gas transmission | Florida
Property, Plant and Equipment [Line Items]
Average depreciation rates	2.40%	2.30%	2.30%
Natural gas transmission | OHIO
Property, Plant and Equipment [Line Items]
Average depreciation rates	5%
Electric distribution | Florida
Property, Plant and Equipment [Line Items]
Average depreciation rates	2.80%	2.80%	2.90%

Summary of Significant Accoun_7

Summary of Significant Accounting Policies - Estimated Useful Lives of Assets (Detail)	12 Months Ended
	Dec. 31, 2022
Propane Distribution Mains [Member] | Minimum
Useful Life of Assets	10 years
Propane Distribution Mains [Member] | Maximum
Useful Life of Assets	37 years
Propane Bulk Plants And Tanks [Member] | Minimum
Useful Life of Assets	10 years
Propane Bulk Plants And Tanks [Member] | Maximum
Useful Life of Assets	40 years
Liquefied Petroleum Gas Equipment [Member] | Minimum
Useful Life of Assets	5 years
Liquefied Petroleum Gas Equipment [Member] | Maximum
Useful Life of Assets	33 years
Meters And Meter Installations [Member] | Minimum
Useful Life of Assets	5 years
Meters And Meter Installations [Member] | Maximum
Useful Life of Assets	33 years
Measuring And Regulating Station Equipment [Member] | Minimum
Useful Life of Assets	5 years
Measuring And Regulating Station Equipment [Member] | Maximum
Useful Life of Assets	37 years
Natural gas pipelines [Member] | Maximum
Useful Life of Assets	45 years
Natural gas processing equipment [Member] | Minimum
Useful Life of Assets	20 years
Natural gas processing equipment [Member] | Maximum
Useful Life of Assets	25 years
Office Furniture And Equipment [Member] | Minimum
Useful Life of Assets	3 years
Office Furniture And Equipment [Member] | Maximum
Useful Life of Assets	10 years
Transportation Equipment [Member] | Minimum
Useful Life of Assets	4 years
Transportation Equipment [Member] | Maximum
Useful Life of Assets	20 years
Structures And Improvements [Member] | Minimum
Useful Life of Assets	5 years
Structures And Improvements [Member] | Maximum
Useful Life of Assets	45 years
CHP plant | Maximum
Useful Life of Assets	30 years

Summary of Significant Accoun_8

Summary of Significant Accounting Policies Effects of New Accounting Pronouncements (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Accounting Policies [Abstract]
Additions, Charged to Income	$ 1,550
Additions, Other Accounts	172
SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction	(1,986)
Accounts Receivable, Allowance for Credit Losses, Current, Disclosure	$ 2,877	$ 3,141

Earnings Per Share - Calculatio

Earnings Per Share - Calculations of Basic and Diluted Earnings Per Share (Detail) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Disclosure Earnings Per Share Calculations Of Basic And Diluted Earnings Per Share [Abstract]
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent	$ 89,796	$ 83,467	$ 70,642
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax			$ 856
Income (Loss) from Continuing Operations, Per Basic Share	$ 5.07	$ 4.75	$ 4.23
Discontinued Operation, Income (Loss) from Discontinued Operation, Net of Tax, Per Basic Share	$ 0	$ 0	$ 0.05
Calculation of Basic Earnings Per Share:
Net Income	$ 89,796	$ 83,466	$ 71,498
Weighted shares outstanding - Basic (in shares)	17,722,227	17,558,078	16,711,579
Basic Earnings Per Share (in usd per share)	$ 5.07	$ 4.75	$ 4.28
Calculation of Diluted Earnings Per Share:
Net Income	$ 89,796	$ 83,466	$ 71,498
Reconciliation of Denominator:
Weighted shares outstanding - Basic (in shares)	17,722,227	17,558,078	16,711,579
Share-based Compensation	82,067	74,951	59,156
Adjusted denominator — Diluted	17,804,294	17,633,029	16,770,735
Income (Loss) from Continuing Operations, Per Diluted Share	$ 5.04	$ 4.73	$ 4.21
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax, Per Diluted Share	0	0	0.05
Diluted (in usd per share)	$ 5.04	$ 4.73	$ 4.26

Acquisitions - Additional Infor

Acquisitions - Additional Information (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($) Dekatherm	Dec. 31, 2020 USD ($)
Cash paid for acquisition	$ 11,766	$ 36,371	$ 22,231
Revenues	680,704	569,968	488,198
Operating Income (Loss)	142,933	131,112	112,723
Net Income	89,796	$ 83,466	71,498
Marlin Gas Services [Member]
Additional Compressed Natural Gas Deliverability | Dekatherm		7,000
Regulated Energy [Member]
Operating Income (Loss)	$ 115,317	$ 106,174	92,124
Regulated Energy [Member] | Elkton Gas [Member]
Number of customers acquired through acquisition	7,000
Unregulated Energy
Operating Income (Loss)	$ 27,350	24,427	$ 20,664
Unregulated Energy | Diversified Energy
Revenues	26,000	1,400
Operating Income (Loss)	$ 1,000	$ 300
Number of customers acquired through acquisition	19,000
Business Combination, Consideration Transferred	$ 37,500
Business Combination, Working Capital	1,700
Business Combination, Contingent Consideration, Liability	2,100
Property, Plant and Equipment, Acquired During Period	23,100
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net	5,900
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Indefinite-Lived Intangible Assets	6,200
Business Acquisition, Preacquisition Contingency, Amount of Settlement	$ 800
Gallons acquired through acquisition	10,000,000
Unregulated Energy | Davenport Energy
Number of customers acquired through acquisition	850
Business Combination, Consideration Transferred	$ 2,000
Property, Plant and Equipment, Acquired During Period	1,500
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net	$ 500
Gallons acquired through acquisition	400,000
Unregulated Energy | Planet Found
Business Combination, Consideration Transferred	$ 9,500
Business Combination, Working Capital	100
Business Combination, Contingent Consideration, Liability	900
Property, Plant and Equipment, Acquired During Period	4,000
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net	1,100
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Indefinite-Lived Intangible Assets	$ 4,400
Tons of Poultry Litter	1,200

Acquisitions Divestitures (Deta

Acquisitions Divestitures (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Accounts Receivable, before Allowance for Credit Loss, Current		$ 65,758	$ 61,623
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment		(462,926)	(417,479)
Discontinued Operation, Tax Effect of Discontinued Operation		0	0	$ (153)
Disposal Group, Including Discontinued Operation, Assets, Current		193,976	170,336
Deferred Income Tax Expense (Benefit)	[1]	23,647	26,599	24,200
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax		$ 0	$ 0	$ 170
[1] (1) Includes $7.8 million, $8.2 million, and $4.9 million of deferred state income taxes for the years 2022, 2021 and 2020, respectively.

Revenue Recognition Contract Ba

Revenue Recognition Contract Balances (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Receivables from Customers	$ 61,687	$ 56,277
Contract with Customer, Asset, Net, Noncurrent	4,321	4,806
Contract with Customer, Liability, Current	983	747
Increase (Decrease) in Receivables	5,410
Increase (Decrease) in Other Noncurrent Assets	(485)
Increase (Decrease) in Other Current Liabilities	236
Contract with Customer, Liability, Revenue Recognized	1,200	1,100
Contract with Customer, Asset, after Allowance for Credit Loss, Current	18	$ 18
Increase (Decrease) in Other Current Assets	$ 0

Revenue Recognition Disaggregat

Revenue Recognition Disaggregation of Revenue (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022		Dec. 31, 2021		Dec. 31, 2020
Disaggregation of Revenue [Line Items]
Revenues	$ 680,704		$ 569,968		$ 488,198
Revenue from Contract with Customer, Excluding Assessed Tax	680,704	[1]	569,968	[2]	488,198	[3]
Contract with Customer, Liability, Revenue Recognized	1,200		1,100
Other And Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(29,470)	[1]	(20,821)	[2]	(17,074)	[3]
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	308		527		528
Other [Member] | Corporate, Non-Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	308		527		528
Energy Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	163,489		141,891		126,164
Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(84,825)		(75,903)		(65,921)
Eliminations [Member] | Consolidation, Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(29,778)		(21,348)		(17,602)
Regulated Energy
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	429,424	[1]	383,920	[2]	352,746	[3]
Regulated Energy | Energy Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	376,843		334,404		302,718
Regulated Energy | Energy Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	107,264		103,728		98,213
Regulated Energy | Eliminations [Member] | Consolidation, Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(54,683)		(54,212)		(48,185)
Unregulated Energy
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	280,750	[1]	206,869	[2]	152,526	[3]
Unregulated Energy | Energy Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	56,225		38,163		27,951
Unregulated Energy | Eliminations [Member] | Consolidation, Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(364)		(343)		(134)
Other [Member] | Regulated Energy
Disaggregation of Revenue [Line Items]
Revenues	500		200		1,400
Other [Member] | Unregulated Energy
Disaggregation of Revenue [Line Items]
Revenues	400		400		200
Florida Natural Gas Distribution [Member] | Regulated Energy | Energy Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	40,036		34,074		30,850
Delaware natural gas division [Member] | Regulated Energy | Energy Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	82,176		71,195		63,389
FPU Electric Distribution [Member] | Regulated Energy | Energy Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	81,714		78,300		76,863
Florida Public Utilities Company [Member] | Regulated Energy | Energy Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	115,834		100,535		90,150
Maryland Natural Gas [Member] | Regulated Energy | Energy Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	26,607		22,449		21,853
Sandpiper [Member] | Regulated Energy | Energy Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	21,278		20,746		17,214
Aspire [Member] | Unregulated Energy | Energy Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	56,225		38,163		27,951
Eastern Shore Gas Company [Member] | Regulated Energy | Energy Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	78,624		76,911		75,117
Peninsula Pipeline [Member] | Regulated Energy | Energy Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	27,263		26,630		23,080
Eight Flags [Member] | Unregulated Energy | Energy Generation [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	25,318		18,652		16,147
Florida Propane [Member] | Unregulated Energy | Propane Delivery [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	188,412		142,082		100,744
Marlin Gas Services [Member] | Unregulated Energy | Energy Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	11,159		8,315		7,818
Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(84,517)		(75,376)		(65,393)
Eliminations [Member] | Other And Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(29,470)		(20,821)		(17,074)
Eliminations [Member] | Regulated Energy | Other And Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(54,683)		(54,212)		(48,185)
Eliminations [Member] | Unregulated Energy | Other And Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(364)		(343)		(134)
Aspire Energy Express | Regulated Energy | Energy Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,377		187		16
Elkton Gas [Member] | Regulated Energy | Energy Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 9,198		$ 7,105		$ 2,399
[1]1) Total operating revenues for the year ended December 31, 2022, include other revenue (revenues from sources other than contracts with customers) of $0.5 million and $0.4 million for our Regulated and Unregulated Energy segments, respectively. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for Maryland division and Sandpiper and late fees[2](1) Total operating revenues for the year ended December 31, 2021, include other revenue (revenues from sources other than contracts with customers of $0.2 million and $0.4 million for our Regulated and Unregulated Energy segments, respectively. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for Maryland division and Sandpiper and late fees[3](1) Total operating revenues for the year ended December 31, 2020, include other revenue (revenues from sources other than contracts with customers) of $1.4 million and $0.2 million for our Regulated and Unregulated Energy segments, respectively. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for Maryland division and Sandpiper and late fees

Revenue Recognition Remaining p

Revenue Recognition Remaining performance obligations (Details) $ in Thousands	Dec. 31, 2022 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Eastern Shore and Peninsula Pipeline [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Natural gas distribution operations [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | FPU Electric Distribution [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Total for Segments [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 43,411
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Eastern Shore and Peninsula Pipeline [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Natural gas distribution operations [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | FPU Electric Distribution [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Total for Segments [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 39,906
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Eastern Shore and Peninsula Pipeline [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Natural gas distribution operations [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | FPU Electric Distribution [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Total for Segments [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 32,913
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Eastern Shore and Peninsula Pipeline [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 36,472
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Natural gas distribution operations [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 6,287
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | FPU Electric Distribution [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 652
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Total for Segments [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 29,237
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Eastern Shore and Peninsula Pipeline [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 33,148
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Natural gas distribution operations [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 6,106
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | FPU Electric Distribution [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 652
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Total for Segments [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 25,912
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Eastern Shore and Peninsula Pipeline [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 26,890
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Natural gas distribution operations [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 5,748
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | FPU Electric Distribution [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 275
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | Eastern Shore and Peninsula Pipeline [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 23,444
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | Natural gas distribution operations [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	5,518
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | FPU Electric Distribution [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	275
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 | Eastern Shore and Peninsula Pipeline [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	20,536
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 | Natural gas distribution operations [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	5,101
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 | FPU Electric Distribution [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	275
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | Eastern Shore and Peninsula Pipeline [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	167,663
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | Natural gas distribution operations [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	33,113
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | FPU Electric Distribution [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	275
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | Total for Segments [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 201,051

Segment Information - Schedule

Segment Information - Schedule of Segment Reporting Information by Segment (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Operating Revenues, Unaffiliated Customers
Total intersegment revenues		$ 680,704	$ 569,968	$ 488,198
Intersegment Revenues (1)
Total intersegment revenues		680,704	569,968	488,198
Operating Income
Operating Income		142,933	131,112	112,723
Other income		5,051	1,721	3,222
Interest charges		24,356	20,135	21,765
Income Before Income taxes		123,628	112,698	94,180
Income Taxes on Continuing Operations		33,832	29,231	23,538
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent		89,796	83,467	70,642
Net Income		89,796	83,466	71,498
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent		0	(1)	686
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax		0	0	170
Depreciation and Amortization
Total depreciation and amortization		68,973	62,661	58,117
Identifiable Assets
Total identifiable assets		2,215,037	2,114,869
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax		0	(1)	686
Regulated Energy
Operating Income
Operating Income		115,317	106,174	92,124
Depreciation and Amortization
Total depreciation and amortization		52,707	48,748	46,079
Payments to Acquire Productive Assets		97,554	139,733	147,100
Unregulated Energy
Operating Income
Operating Income		27,350	24,427	20,664
Depreciation and Amortization
Total depreciation and amortization		16,257	13,869	11,988
Payments to Acquire Productive Assets		40,773	81,651	46,295
Other
Operating Income
Operating Income		266	511	(65)
Depreciation and Amortization
Payments to Acquire Productive Assets		2,355	6,425	2,480
Other and eliminations
Depreciation and Amortization
Total depreciation and amortization		9	44	50
Total for Segments [Member]
Depreciation and Amortization
Payments to Acquire Productive Assets		140,682	227,809	195,875
Operating Segments
Operating Revenues, Unaffiliated Customers
Total intersegment revenues		680,704	569,968	488,198
Intersegment Revenues (1)
Total intersegment revenues		680,704	569,968	488,198
Operating Segments | Regulated Energy
Operating Revenues, Unaffiliated Customers
Total intersegment revenues		422,894	381,879	350,853
Intersegment Revenues (1)
Total intersegment revenues		422,894	381,879	350,853
Identifiable Assets
Total identifiable assets		1,716,255	1,629,191
Operating Segments | Unregulated Energy
Operating Revenues, Unaffiliated Customers
Total intersegment revenues		257,810	188,089	137,345
Intersegment Revenues (1)
Total intersegment revenues		257,810	188,089	137,345
Identifiable Assets
Total identifiable assets		463,239	439,114
Intersegment Eliminations
Operating Revenues, Unaffiliated Customers
Total intersegment revenues	[1]	29,778	21,348	17,602
Intersegment Revenues (1)
Total intersegment revenues	[1]	29,778	21,348	17,602
Intersegment Eliminations | Regulated Energy
Operating Revenues, Unaffiliated Customers
Total intersegment revenues		6,530	2,041	1,893
Intersegment Revenues (1)
Total intersegment revenues		6,530	2,041	1,893
Intersegment Eliminations | Unregulated Energy
Operating Revenues, Unaffiliated Customers
Total intersegment revenues		22,940	18,780	15,181
Intersegment Revenues (1)
Total intersegment revenues		22,940	18,780	15,181
Intersegment Eliminations | Other
Operating Revenues, Unaffiliated Customers
Total intersegment revenues		308	527	528
Intersegment Revenues (1)
Total intersegment revenues		308	527	$ 528
Other And Intersegment Eliminations
Identifiable Assets
Total identifiable assets		$ 35,543	$ 46,564
[1]All significant intersegment revenues are billed at market rates and have been eliminated from consolidated revenues.

Supplemental Cash Flow Disclo_3

Supplemental Cash Flow Disclosures - Cash Paid for Interest and Income Taxes (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Disclosure Supplemental Cash Flow Disclosures Cash Paid For Interest And Income Taxes [Abstract]
Cash paid for interest	$ 24,267	$ 20,809	$ 22,884
Cash paid for income taxes	$ (4,963)	$ 8,395	$ (8,135)

Supplemental Cash Flow Disclo_4

Supplemental Cash Flow Disclosures - Non-Cash Investing and Financing Activities (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Disclosure Supplemental Cash Flow Disclosures Noncash Investing And Financing Activities [Abstract]
Capital property and equipment acquired on account, but not paid as of December 31	$ 13,211	$ 16,164	$ 23,625
Non Cash Performance Incentive Plan DRP	0	1,712	1,605
Performance Incentive Plan	$ 2,868	$ 2,834	$ 1,971

Derivative Instruments - Additi

Derivative Instruments - Additional Information (Detail) $ in Thousands		1 Months Ended	3 Months Ended	12 Months Ended
		Feb. 28, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Derivative [Line Items]
Energy Marketing Contract Liabilities, Current				$ 585	$ 704
Unrealized Gain (Loss) on Derivatives				2,214	16,363	$ 9,993
Notional Amount of Nonderivative Instruments			$ 60,000	$ 50,000		$ 100,000
Number of short-term lines of Credit, rate swap				3
Derivative assets, at fair value				$ 2,787	4,277
Subsequent Event
Derivative [Line Items]
Notional Amount of Nonderivative Instruments		$ 40,000
Fixed Swap Rate		0.17%
Interest Rate Swap Rate, Low Range [Member]
Derivative [Line Items]
Fixed Swap Rate			0.20%			0.2615%
Interest Rate Swap Rate, High Range [Member]
Derivative [Line Items]
Fixed Swap Rate			0.205%	3.98%		0.3875%
Derivatives designated as fair value hedges | Mark To Market Energy Assets | Put Option
Derivative [Line Items]
Derivative assets, at fair value				$ 0	16
Derivatives designated as fair value hedges | Mark To Market Energy Assets | Propane Swap Agreement
Derivative [Line Items]
Derivative assets, at fair value	[1]			3,317	7,060
Derivatives designated as fair value hedges | Mark To Market Energy Assets | Interest Rate Swap [Member]
Derivative [Line Items]
Derivative assets, at fair value	[1]			452	0
Derivatives designated as fair value hedges | Mark-to-market energy liabilities | Propane Swap Agreement
Derivative [Line Items]
Energy Marketing Contract Liabilities, Current	[2]			1,810	743
Derivatives designated as fair value hedges | Mark-to-market energy liabilities | Interest Rate Swap [Member]
Derivative [Line Items]
Energy Marketing Contract Liabilities, Current	[2]			405	0
Sharp Energy Inc [Member]
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months				800
Other Payables to Broker-Dealers and Clearing Organizations				100	4,100
Other Comprehensive Income (Loss) | Derivatives designated as fair value hedges | Propane Swap Agreement
Derivative [Line Items]
Unrealized Gain (Loss) on Derivatives				(1,303)	9,777	$ 7,463
Other Comprehensive Income (Loss) | Derivatives designated as fair value hedges | Interest Rate Swap [Member]
Derivative [Line Items]
Unrealized Gain (Loss) on Derivatives				0	0	20
Cost of Sales [Member] | Not Designated as Hedging Instrument [Member] | Propane Swap Agreement
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net				56	(1)	0
Cost of Sales [Member] | Derivatives designated as fair value hedges | Propane Swap Agreement
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net				3,881	7,187	2,428
Cost of Sales [Member] | Derivatives designated as fair value hedges | Put Or Call Option [Member]
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net				0	(24)	(12)
Inventories [Member] | Derivatives designated as fair value hedges | Put Or Call Option [Member]
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net				0	0	34
Interest Expense | Derivatives designated as fair value hedges | Interest Rate Swap [Member]
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net				$ (47)	$ (40)	$ 60
[1] (1)

Derivative Instruments Fair Val

Derivative Instruments Fair Value Hedges (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative liabilities, at fair value	$ 585	$ 704

Derivative Instruments - Fair V

Derivative Instruments - Fair Values of Derivative Contracts Recorded in Consolidated Balance Sheets (Detail) - USD ($) $ in Thousands		Dec. 31, 2022	Dec. 31, 2021
Derivatives, Fair Value [Line Items]
Energy Marketing Contracts Assets, Current		$ 2,787	$ 4,277
Energy Marketing Contracts Assets, Total		3,769	7,076
Energy Marketing Contract Liabilities, Current		585	704
Energy Marketing Contract Liabilities, Total		2,215	743
Designated as Hedging Instrument [Member] | Mark-to-market energy liabilities | Propane Swap Agreement
Derivatives, Fair Value [Line Items]
Energy Marketing Contract Liabilities, Current	[1]	1,810	743
Designated as Hedging Instrument [Member] | Mark-to-market energy liabilities | Interest Rate Swap [Member]
Derivatives, Fair Value [Line Items]
Energy Marketing Contract Liabilities, Current	[1]	405	0
Designated as Hedging Instrument [Member] | Mark To Market Energy Assets | Propane Swap Agreement
Derivatives, Fair Value [Line Items]
Energy Marketing Contracts Assets, Current	[2]	3,317	7,060
Designated as Hedging Instrument [Member] | Mark To Market Energy Assets | Put Option
Derivatives, Fair Value [Line Items]
Energy Marketing Contracts Assets, Current		0	16
Designated as Hedging Instrument [Member] | Mark To Market Energy Assets | Interest Rate Swap [Member]
Derivatives, Fair Value [Line Items]
Energy Marketing Contracts Assets, Current	[2]	$ 452	$ 0
[1](1) Derivative liabilities, at fair value include $0.6 million and $0.7 million in current liabilities in the consolidated balance sheet at December 31, 2022 and 2021, respectively, with the remainder of the balance classified as long-term.[2] (1)

Derivative Instruments - Effect

Derivative Instruments - Effects of Gains and Losses from Derivative Instruments (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Derivative Instruments, Gain (Loss) [Line Items]
Energy Marketing Contract Liabilities, Current		$ 585	$ 704
Gain (Loss) on derivatives		2,214	16,363	$ 9,993
Cost of Sales | Derivatives not designated as hedging instruments | Propane Swap Agreement
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		56	(1)	0
Cost of Sales | Derivatives designated as fair value hedges | Put Or Call Option [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		0	(24)	(12)
Cost of Sales | Derivatives designated as fair value hedges | Propane Swap Agreement
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		3,881	7,187	2,428
Other Comprehensive Income (Loss) | Derivatives designated as fair value hedges | Propane Swap Agreement
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivatives		(1,303)	9,777	7,463
Other Comprehensive Income (Loss) | Derivatives designated as fair value hedges | Interest Rate Swap [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on derivatives		0	0	20
Interest Expense | Derivatives designated as fair value hedges | Interest Rate Swap [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		(47)	(40)	60
Inventories [Member] | Derivatives designated as fair value hedges | Put Or Call Option [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		0	0	34
Revenues | Derivatives designated as fair value hedges | Propane Swap Agreement
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		(373)	(536)	$ 0
Mark To Market Energy Liabilities [Member] | Derivatives designated as fair value hedges | Propane Swap Agreement
Derivative Instruments, Gain (Loss) [Line Items]
Energy Marketing Contract Liabilities, Current	[1]	1,810	743
Mark To Market Energy Liabilities [Member] | Derivatives designated as fair value hedges | Interest Rate Swap [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Energy Marketing Contract Liabilities, Current	[1]	$ 405	$ 0
[1](1) Derivative liabilities, at fair value include $0.6 million and $0.7 million in current liabilities in the consolidated balance sheet at December 31, 2022 and 2021, respectively, with the remainder of the balance classified as long-term.

Derivative Instruments Volume o

Derivative Instruments Volume of Derivative Activity (Details) - Sharp Energy Inc [Member]	12 Months Ended
	Dec. 31, 2022 gal
Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	20,000,000
Swap Sales
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	5,000,000

Fair Value of Financial Instr_3

Fair Value of Financial Instruments - Additional Information (Detail) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Disclosure Fair Value Of Financial Instruments Additional Information [Abstract]
Long-term debt including current maturities	$ 600.8	$ 568.8
Fair value of long-term debt	$ 505	$ 597.2

Fair Value of Financial Instr_4

Fair Value of Financial Instruments - Financial Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Assets:
Investments	$ 10,576	$ 12,095
Fair Value, Inputs, Level 1 [Member]
Assets:
Assets, Fair Value Disclosure	8,723	10,059
Fair Value, Inputs, Level 1 [Member] | Mark-to-market energy liabilities
Liabilities:
Mark-to-market energy liabilities	0	0
Significant Other Observable Inputs (Level 2)
Assets:
Assets, Fair Value Disclosure	3,769	7,076
Significant Other Observable Inputs (Level 2) | Mark-to-market energy liabilities
Liabilities:
Mark-to-market energy liabilities	2,215	743
Significant Unobservable Inputs (Level 3)
Assets:
Assets, Fair Value Disclosure	1,853	2,036
Significant Unobservable Inputs (Level 3) | Mark-to-market energy liabilities
Liabilities:
Mark-to-market energy liabilities	0	0
Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Assets:
Investments	24	26
Equity Securities [Member] | Significant Other Observable Inputs (Level 2)
Assets:
Investments	0	0
Equity Securities [Member] | Significant Unobservable Inputs (Level 3)
Assets:
Investments	0	0
Guaranteed Income Fund [Member] | Fair Value, Inputs, Level 1 [Member]
Assets:
Investments	0	0
Guaranteed Income Fund [Member] | Significant Other Observable Inputs (Level 2)
Assets:
Investments	0	0
Guaranteed Income Fund [Member] | Significant Unobservable Inputs (Level 3)
Assets:
Investments	1,853	2,036
Other Investments [Member] | Fair Value, Inputs, Level 1 [Member]
Assets:
Investments	8,699	10,033
Other Investments [Member] | Significant Other Observable Inputs (Level 2)
Assets:
Investments	0	0
Other Investments [Member] | Significant Unobservable Inputs (Level 3)
Assets:
Investments	0	0
Investments [Member] | Fair Value, Inputs, Level 1 [Member]
Assets:
Investments	8,723	10,059
Investments [Member] | Significant Other Observable Inputs (Level 2)
Assets:
Investments	0	0
Investments [Member] | Significant Unobservable Inputs (Level 3)
Assets:
Investments	1,853	2,036
Mark-to-market energy assets, including put option | Fair Value, Inputs, Level 1 [Member]
Assets:
Mark-to-market energy assets, including put option	0	0
Mark-to-market energy assets, including put option | Significant Other Observable Inputs (Level 2)
Assets:
Mark-to-market energy assets, including put option	3,769	7,076
Mark-to-market energy assets, including put option | Significant Unobservable Inputs (Level 3)
Assets:
Mark-to-market energy assets, including put option	0	0
Fair Value
Assets:
Assets, Fair Value Disclosure	14,345	19,171
Fair Value | Mark-to-market energy liabilities
Liabilities:
Mark-to-market energy liabilities	2,215	743
Fair Value | Equity Securities [Member]
Assets:
Investments	24	26
Fair Value | Guaranteed Income Fund [Member]
Assets:
Investments	1,853	2,036
Fair Value | Other Investments [Member]
Assets:
Investments	8,699	10,033
Fair Value | Investments [Member]
Assets:
Investments	10,576	12,095
Fair Value | Mark-to-market energy assets, including put option
Assets:
Mark-to-market energy assets, including put option	$ 3,769	$ 7,076

Fair Value of Financial Instr_5

Fair Value of Financial Instruments Fair Value of Financial Instruments - Summary of Changes in Fair Value of Instruments (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	$ 2,036	$ 2,156
Purchases and adjustments	132	88
Transfers/disbursements	347	241
Investment income	32	33
Ending Balance	$ 1,853	$ 2,036

Goodwill and Other Intangible_3

Goodwill and Other Intangible Assets - Additional Information (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Goodwill [Line Items]
Finite-Lived Intangible Assets, Gross		$ 26,159	$ 19,967
Acquired finite-lived intangible assets, weighted average useful life		14 years
Goodwill		$ 46,213	44,708
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months		1,800
Amortization of intangible assets		1,500	1,300	$ 1,200
Finite-Lived Intangible Assets, Amortization Expense, Year Four		1,500
Amortization of intangible assets, 2022		1,400
Regulated Energy
Goodwill [Line Items]
Goodwill		7,689	7,689
Unregulated Energy
Goodwill [Line Items]
Goodwill		38,524	37,019
Customer list
Goodwill [Line Items]
Finite-Lived Intangible Assets, Gross	[1]	$ 16,965	16,814
Customer list | Minimum [Member]
Goodwill [Line Items]
Amortized period of acquired intangible assets		5 years
Noncompete Agreements [Member]
Goodwill [Line Items]
Finite-Lived Intangible Assets, Gross		$ 3,105	$ 2,431
[1]1) The customer relationship amounts include $6.1 million as a result of the purchase of Diversified Energy in December 2021.

Goodwill and Other Intangible_4

Goodwill and Other Intangible Assets - Schedule of Carrying Value of Goodwill (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021
Goodwill [Line Items]
Finite-Lived Intangible Assets, Gross		$ 26,159	$ 19,967
Finite-Lived Intangible Assets, Accumulated Amortization		8,300	6,775
Goodwill		46,213	44,708
Goodwill, Transfers	[1]	1,505
Regulated Energy
Goodwill [Line Items]
Goodwill		7,689	7,689
Goodwill, Transfers		0
Unregulated Energy
Goodwill [Line Items]
Goodwill		38,524	37,019
Goodwill, Transfers		1,505
Customer Lists [Member]
Goodwill [Line Items]
Finite-Lived Intangible Assets, Gross	[2]	16,965	16,814
Finite-Lived Intangible Assets, Accumulated Amortization	[2]	6,131	5,125
Customer Lists [Member] | Diversified Energy
Goodwill [Line Items]
Finite-Lived Intangible Assets, Gross		6,100
Noncompete Agreements [Member]
Goodwill [Line Items]
Finite-Lived Intangible Assets, Gross		3,105	2,431
Finite-Lived Intangible Assets, Accumulated Amortization		1,411	1,078
Patents [Member]
Goodwill [Line Items]
Finite-Lived Intangible Assets, Gross	[3],[4]	5,819	452
Finite-Lived Intangible Assets, Accumulated Amortization	[3],[4]	533	354
Other Intangible Assets [Member]
Goodwill [Line Items]
Finite-Lived Intangible Assets, Gross		270	270
Finite-Lived Intangible Assets, Accumulated Amortization		$ 225	$ 218
[1] (1) Includes goodwill from the purchase of operating assets of Planet Found in the fourth quarter of 2022. (2) The patents amount include $3.7 million as a result of the purchase of the operating assets of Planet Found in October 2022.

Goodwill and Other Intangible_5

Goodwill and Other Intangible Assets - Schedule of Carrying Value and Accumulated Amortization of Intangible Assets (Detail) - USD ($) $ in Thousands		Dec. 31, 2022	Dec. 31, 2021
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount		$ 26,159	$ 19,967
Accumulated Amortization		8,300	6,775
Customer Lists [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	[1]	16,965	16,814
Accumulated Amortization	[1]	6,131	5,125
Customer Lists [Member] | Diversified Energy
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount		6,100
Noncompete Agreements [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount		3,105	2,431
Accumulated Amortization		1,411	1,078
Patents [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	[2],[3]	5,819	452
Accumulated Amortization	[2],[3]	533	354
Patents [Member] | Planet Found
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount		3,700
Other Intangible Assets [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount		270	270
Accumulated Amortization		$ 225	$ 218
[1]1) The customer relationship amounts include $6.1 million as a result of the purchase of Diversified Energy in December 2021.[2](3) Includes amounts related to patented technology developed by Marlin Gas Services and the acquisition of Planet Found[3] (2) The patents amount include $3.7 million as a result of the purchase of the operating assets of Planet Found in October 2022.

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Operating Loss Carryforwards	$ 1,488	$ 1,490
Net Operating Losses and Tax Carryback	0	919	$ 1,841
Deferred State and Local Income Tax Expense (Benefit)	7,800	8,200	$ 4,900
Net Operating Losses and Tax Carryback, Total		(900)
Interest Income, Other	800
Deferred Tax Assets, Operating Loss Carryforwards	$ 1,488	1,490
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	21%		35%
State
Operating Loss Carryforwards [Line Items]
Federal net operating losses for income tax	$ 67,700	$ 14,600		$ (6,300)	$ (12,200)
Net Operating Losses and Tax Carryforwards, Recovered	$ 12,800

Income Taxes - Schedule of Inco

Income Taxes - Schedule of Income Tax Expense (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Current Income Tax Expense
Federal		$ 8,284	$ 2,775	$ (2,777)
State		1,948	(96)	2,162
Other		(47)	(47)	(47)
Total current income tax expense (benefit)		10,185	2,632	(662)
Deferred Income Tax Expense (1)
Total deferred income tax expense	[1]	23,647	26,599	24,200
Income Tax Expense from Continuing Operations		33,832	29,231	23,538
Discontinued Operation, Tax Effect of Gain (Loss) from Disposal of Discontinued Operation		0	0	153
Income Tax Expense (Benefit), Continuing Operations, Discontinued Operations		33,832	29,231	23,691
Deferred State and Local Income Tax Expense (Benefit)		7,800	8,200	4,900
Property, plant and equipment
Deferred Income Tax Expense (1)
Total deferred income tax expense		14,968	24,074	23,224
Deferred gas costs
Deferred Income Tax Expense (1)
Total deferred income tax expense		8,923	1,857	(714)
Pensions and other employee benefits
Deferred Income Tax Expense (1)
Total deferred income tax expense		1,109	(655)	(75)
FPU merger related premium cost and deferred gain
Deferred Income Tax Expense (1)
Total deferred income tax expense		(351)	(351)	156
Net operating loss carryforwards
Deferred Income Tax Expense (1)
Total deferred income tax expense		2	97	5,107
Other
Deferred Income Tax Expense (1)
Total deferred income tax expense		$ (1,004)	$ 1,577	$ (3,498)
[1] (1) Includes $7.8 million, $8.2 million, and $4.9 million of deferred state income taxes for the years 2022, 2021 and 2020, respectively.

Income Taxes - Summary of Recon

Income Taxes - Summary of Reconciliation of Statutory Federal Tax and Effective Income Tax Rates (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Disclosure Income Taxes Summary Of Reconciliation Of Statutory Federal Tax And Effective Income Tax Rates [Abstract]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent		21%		35%
Reconciliation of Effective Income Tax Rates Continuing Operations
Federal income tax expense (1)	[1]	$ 25,982	$ 23,666	$ 19,778
State income taxes, net of federal benefit		7,714	6,371	5,051
ESOP dividend deduction		(177)	(180)	(218)
Other		313	293	768
Income Tax Expense from Continuing Operations		$ 33,832	$ 29,231	$ 23,538
Effective Income Tax Rate from Continuing Operations		27.34%	25.94%	24.99%
Net Operating Losses and Tax Carryback		$ 0	$ (919)	$ (1,841)
[1]Federal income taxes were calculated at 21 percent for 2022, 2021, and 2020.

Income Taxes - Schedule of Accu

Income Taxes - Schedule of Accumulated Deferred Income Tax Assets and Liabilities (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Disclosure Income Taxes Schedule Of Accumulated Deferred Income Tax Assets And Liabilities [Abstract]
Deferred State and Local Income Tax Expense (Benefit)	$ 7,800	$ 8,200	$ 4,900
Deferred income tax liabilities:
Property, plant and equipment	238,687	224,034
Acquisition adjustment	5,915	6,266
Deferred Tax Liabilities Loss On Reacquired Debt	164	183
Deferred Income Tax Liability - Deferred Gas Costs	11,288	2,366
Deferred Income Tax Liability, Natural Gas Conversion Costs	5,026	5,529
Deferred Income Tax Liability, Storm Reserve	5,791	5,783
Other	8,236	6,301
Total deferred income tax liabilities	275,107	250,462
Deferred income tax assets:
Pension and other employee benefits	3,985	5,354
Environmental costs	1,052	996
Net operating loss carryforwards	1,488	1,490
Storm reserve liability	453	448
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals	9,007	4,843
Other	2,955	3,781
Total deferred income tax assets	18,940	16,912
Deferred income taxes	$ 256,167	$ 233,550

Income Taxes - Schedule of In_2

Income Taxes - Schedule of Income Tax Expense (Phantoms) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Disclosure Income Taxes Schedule Of Income Tax Expense [Abstract]
Deferred state income taxes	$ 7.8	$ 8.2	$ 4.9

Income Taxes - Summary of Rec_2

Income Taxes - Summary of Reconciliation of Statutory Federal Tax and Effective Income Tax Rates (Phantoms) (Detail)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2020
Disclosure Income Taxes Summary Of Reconciliation Of Statutory Federal Tax And Effective Income Tax Rates [Abstract]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	21%	35%

Income Taxes Federal Tax Reform

Income Taxes Federal Tax Reform (Details)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2020
Federal Tax Reform
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	21%	35%

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022		Feb. 01, 2023	Dec. 31, 2021
Debt Instrument [Line Items]
Debt Instrument, Unused Borrowing Capacity, Amount	[1]	$ 170,000
Percentage of equity of total capitalization		40%
Fixed charge coverage ratio		1.2
Required net book value of regulated business assets, minimum percentage of consolidated total assets		50%
Maximum limit on payment of dividends		$ 10,000
Cumulative consolidated net income base		754,200
Cumulative net income with restrictions		326,400
Long-term debt including current maturities		600,800			$ 568,800
Long-term Debt and Lease Obligation		599,871			567,865
Total long-term debt, net of current maturities		578,388			549,903
Unamortized Debt Issuance Expense		(946)			(913)
Long-term Debt and Lease Obligation, Current		(21,483)			(17,962)
MetLife [Member]
Debt Instrument [Line Items]
Face amount		150,000		$ 200,000
Debt Instrument, Unused Borrowing Capacity, Amount		100,000
Long-term debt including current maturities		50,000
Prudential [Member]
Debt Instrument [Line Items]
Debt Instrument, Unused Borrowing Capacity, Amount	[2]	70,000
Long-term debt including current maturities	[2]	220,000
Prudential [Member] | Maximum [Member]
Debt Instrument [Line Items]
Face amount		$ 370,000	[2]	$ 405,000
Uncollateralized Senior Note Due On Two Thousand Twenty Six [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage		5.68%
Long-term debt including current maturities		$ 11,600			14,500
Uncollateralized Senior Note Due December Two Thousand Thirty Four [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage		2.98%
Long-term debt including current maturities		$ 70,000
Uncollateralized Senior Note Due On May 2 Two Thousand Twenty Eight [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage		6.43%
Long-term debt including current maturities		$ 4,200			4,900
Uncollateralized Senior Note Two Due on December Two Thousand Twenty Eight [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage		3.73%
Long-term debt including current maturities		$ 12,000			14,000
Uncollateralized Senior Notes Due On Two Thousand Twenty Nine [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage		3.88%
Long-term debt including current maturities		$ 35,000			40,000
Uncollateralized Senior Note Due On Two Thousand Twenty Three [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage		5.93%
Long-term debt including current maturities		$ 3,000			6,000
Uncollateralized Senior Note Due April Two Thousand Thirty Two [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage		3.25%
Long-term debt including current maturities		$ 66,500			70,000
Uncollateralized Senior Note Due May Two Thousand Thirty Eight [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage		3.48%
Long-term debt including current maturities		$ 50,000			50,000
Uncollateralized Senior Note Due November Two Thousand Thirty Eight [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage		3.58%
Long-term debt including current maturities		$ 50,000			50,000
Uncollateralized Senior Note Due November Two Thousand Thirty Nine
Debt Instrument [Line Items]
Long-term debt including current maturities		$ 100,000			100,000
Uncollateralized Senior Note Due November Two Thousand Thirty Four
Debt Instrument [Line Items]
Long-term debt including current maturities					70,000
Uncollateralized Senior Note Due July Two Thousand Thirty Five
Debt Instrument [Line Items]
Long-term debt, interest percentage		3%
Long-term debt including current maturities		$ 50,000			50,000
Uncollateralized Senior Note Due August Two Thousand Thirty Five
Debt Instrument [Line Items]
Long-term debt, interest percentage		2.96%
Long-term debt including current maturities		$ 40,000			40,000
Uncollateralized Senior Note Due January Two Thousand Thirty Seven
Debt Instrument [Line Items]
Long-term debt, interest percentage		2.49%
Long-term debt including current maturities		$ 50,000			50,000
Equipment Security Note
Debt Instrument [Line Items]
Long-term debt, interest percentage		2.46%
Long-term debt including current maturities		$ 8,517			$ 9,378
Uncollateralized Senior Note Due March 15, 2042
Debt Instrument [Line Items]
Long-term debt, interest percentage		2.95%
Long-term debt including current maturities		$ 50,000
Uncollateralized Senior Note Due March 15, 2042 | MetLife [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities		$ 50,000
Uncollateralized Senior Note Due March 14, 2038
Debt Instrument [Line Items]
Long-term debt, interest percentage		5.43%
Long-term debt including current maturities		$ 80,000
Uncollateralized Senior Note Due March 14, 2038 | Prudential [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities		80,000
Marlin Gas Services [Member] | Equipment Security Note
Debt Instrument [Line Items]
Long-term debt including current maturities		$ 9,600
[1]1) The amended Prudential and MetLife Shelf Agreements both expire in February 2026.[2](2) Unfunded commitments of $80.0 million reflects Senior Notes expected to be issued on or before March 14, 2023

Long-Term Debt - Outstanding Lo

Long-Term Debt - Outstanding Long-Term Debt (Detail) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Restricted Payment	$ 326,400
Long-term Debt	600,800	$ 568,800
Less: debt issuance costs	(946)	(913)
Long-term Debt and Lease Obligation	599,871	567,865
Less: current maturities	(21,483)	(17,962)
Total long-term debt, net of current maturities	578,388	549,903
Unrestricted Payment	427,800
5.93% note, due October 31, 2023
Debt Instrument [Line Items]
Long-term Debt	$ 3,000	6,000
Debt Instrument, Interest Rate, Stated Percentage	5.93%
5.68% note, due June 30, 2026
Debt Instrument [Line Items]
Long-term Debt	$ 11,600	14,500
Debt Instrument, Interest Rate, Stated Percentage	5.68%
6.43% note, due May 2, 2028
Debt Instrument [Line Items]
Long-term Debt	$ 4,200	4,900
Debt Instrument, Interest Rate, Stated Percentage	6.43%
3.73% note, due December 16, 2028
Debt Instrument [Line Items]
Long-term Debt	$ 12,000	14,000
Debt Instrument, Interest Rate, Stated Percentage	3.73%
3.88% note, due May 15, 2029
Debt Instrument [Line Items]
Long-term Debt	$ 35,000	40,000
Debt Instrument, Interest Rate, Stated Percentage	3.88%
Uncollateralized Senior Note Due April Two Thousand Thirty Two [Member]
Debt Instrument [Line Items]
Long-term Debt	$ 66,500	70,000
Debt Instrument, Interest Rate, Stated Percentage	3.25%
Uncollateralized Senior Note Due May Two Thousand Thirty Eight [Member]
Debt Instrument [Line Items]
Long-term Debt	$ 50,000	50,000
Debt Instrument, Interest Rate, Stated Percentage	3.48%
Uncollateralized Senior Note Due November Two Thousand Thirty Eight [Member]
Debt Instrument [Line Items]
Long-term Debt	$ 50,000	$ 50,000
Debt Instrument, Interest Rate, Stated Percentage	3.58%
Uncollateralized Senior Note Due August Two Thousand Thirty Nine [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.98%
Uncollateralized Senior Note Due December Two Thousand Thirty Four [Member]
Debt Instrument [Line Items]
Long-term Debt	$ 70,000
Debt Instrument, Interest Rate, Stated Percentage	2.98%
Uncollateralized Senior Note Due March 15, 2042
Debt Instrument [Line Items]
Long-term Debt	$ 50,000
Debt Instrument, Interest Rate, Stated Percentage	2.95%

Long-Term Debt - Outstanding _2

Long-Term Debt - Outstanding Long-Term Debt (Phantoms) (Detail)	12 Months Ended
	Dec. 31, 2022
5.93% note, due October 31, 2023
Debt Instrument [Line Items]
Long-term debt, interest percentage	5.93%
Debt Instrument, Maturity Date	Oct. 31, 2023
5.68% note, due June 30, 2026
Debt Instrument [Line Items]
Long-term debt, interest percentage	5.68%
Debt Instrument, Maturity Date	Jun. 30, 2026
6.43% note, due May 2, 2028
Debt Instrument [Line Items]
Long-term debt, interest percentage	6.43%
Debt Instrument, Maturity Date	May 02, 2028
3.73% note, due December 16, 2028
Debt Instrument [Line Items]
Long-term debt, interest percentage	3.73%
Debt Instrument, Maturity Date	Dec. 16, 2028
3.88% note, due May 15, 2029
Debt Instrument [Line Items]
Long-term debt, interest percentage	3.88%
Debt Instrument, Maturity Date	May 15, 2029
Uncollateralized Senior Note Due on Two Thousand Thirty Two [Member]
Debt Instrument [Line Items]
Debt Instrument, Maturity Date	Apr. 30, 2032
Uncollateralized Senior Note Due May Two Thousand Thirty Eight [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage	3.48%
Debt Instrument, Maturity Date	May 31, 2038
Uncollateralized Senior Note Due November Two Thousand Thirty Eight [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage	3.58%
Debt Instrument, Maturity Date	Nov. 30, 2038
Uncollateralized Senior Note Due August Two Thousand Thirty Nine [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage	3.98%
Debt Instrument, Maturity Date	Aug. 20, 2039
Uncollateralized Senior Note Due December Two Thousand Thirty Four [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage	2.98%
Debt Instrument, Maturity Date	Dec. 20, 2034
Uncollateralized Senior Note Due July Two Thousand Thirty Five
Debt Instrument [Line Items]
Long-term debt, interest percentage	3%
Debt Instrument, Maturity Date	Jul. 15, 2035
Uncollateralized Senior Note Due August Two Thousand Thirty Five
Debt Instrument [Line Items]
Long-term debt, interest percentage	2.96%
Debt Instrument, Maturity Date	Aug. 15, 2035
Uncollateralized Senior Note Due April Two Thousand Thirty Two [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage	3.25%
Equipment Security Note
Debt Instrument [Line Items]
Long-term debt, interest percentage	2.46%
Debt Instrument, Maturity Date	Sep. 24, 2031
Uncollateralized Senior Note Due January Two Thousand Thirty Seven
Debt Instrument [Line Items]
Long-term debt, interest percentage	2.49%
Debt Instrument, Maturity Date	Jan. 25, 2037
Uncollateralized Senior Note Due March 15, 2042
Debt Instrument [Line Items]
Long-term debt, interest percentage	2.95%
Debt Instrument, Maturity Date	Mar. 15, 2042

Long-Term Debt Annual Maturitie

Long-Term Debt Annual Maturities (Details) $ in Thousands	Dec. 31, 2022 USD ($)
Long Term Debt Annual Maturities [Abstract]
Long-term Debt, Maturities, Repayments of Principal in Next Rolling Twelve Months	$ 21,483
Long-term Debt, Maturities, Repayments of Principal in Rolling Year Two	18,505
Long-term Debt, Maturities, Repayments of Principal in Rolling Year Three	25,528
Long-term Debt, Maturities, Repayments of Principal in Rolling Year Four	34,551
Long-term Debt, Maturities, Repayments of Principal in Rolling Year Five	31,674
Long-term Debt, Maturities, Repayments of Principal in Rolling after Year Five	469,076
Total Future Repayments	$ 600,817

Long-Term Debt Shelf Arrangemen

Long-Term Debt Shelf Arrangements (Details) - USD ($) $ in Thousands		Feb. 01, 2023	Dec. 31, 2022		Dec. 31, 2021
Line of Credit Facility [Line Items]
Long-term Debt			$ (600,800)		$ (568,800)
Debt Instrument, Unused Borrowing Capacity, Amount	[1]		170,000
Prudential [Member]
Line of Credit Facility [Line Items]
Long-term Debt	[2]		(220,000)
Debt Instrument, Unused Borrowing Capacity, Amount	[2]		70,000
MetLife [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Face Amount		$ 200,000	150,000
Long-term Debt			(50,000)
Debt Instrument, Unused Borrowing Capacity, Amount			100,000
Aggregate Shelf Agreements [Member]
Line of Credit Facility [Line Items]
Long-term Debt	[1]		(270,000)
Aggregated Unfunded Commitments [Member]
Line of Credit Facility [Line Items]
Long-term Debt	[1]		(80,000)
Aggregated Unfunded Commitments [Member] | Prudential [Member]
Line of Credit Facility [Line Items]
Long-term Debt	[2]		(80,000)
Uncollateralized Senior Note Due April Two Thousand Thirty Two [Member]
Line of Credit Facility [Line Items]
Long-term Debt			$ (66,500)		(70,000)
Debt Instrument, Interest Rate, Stated Percentage			3.25%
Uncollateralized Senior Note Due August Two Thousand Thirty Nine [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			3.98%
Uncollateralized Senior Note Due July Two Thousand Thirty Five
Line of Credit Facility [Line Items]
Long-term Debt			$ (50,000)		(50,000)
Debt Instrument, Interest Rate, Stated Percentage			3%
Uncollateralized Senior Note Due August Two Thousand Thirty Five
Line of Credit Facility [Line Items]
Long-term Debt			$ (40,000)		$ (40,000)
Debt Instrument, Interest Rate, Stated Percentage			2.96%
Uncollateralized Senior Note Due March 14, 2038
Line of Credit Facility [Line Items]
Long-term Debt			$ (80,000)
Debt Instrument, Interest Rate, Stated Percentage			5.43%
Uncollateralized Senior Note Due March 14, 2038 | Prudential [Member]
Line of Credit Facility [Line Items]
Long-term Debt			$ (80,000)
Maximum [Member] | Prudential [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Face Amount		$ 405,000	370,000	[2]
Maximum [Member] | Aggregate Shelf Agreements [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Face Amount	[1]		$ 520,000
[1]1) The amended Prudential and MetLife Shelf Agreements both expire in February 2026.[2](2) Unfunded commitments of $80.0 million reflects Senior Notes expected to be issued on or before March 14, 2023

Short-Term Borrowing - Addition

Short-Term Borrowing - Additional Information (Detail)	1 Months Ended	3 Months Ended	12 Months Ended
	Feb. 28, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2021 USD ($)
Short-term Debt [Line Items]
Short-term borrowings			$ 202,157,000		$ 221,634,000
Line of Credit Facility, Aggregate Borrowing Capacity			$ 200,000,000
Number Of Unsecured Bank Credit Facilities			3
Short-term Debt, Weighted Average Interest Rate, at Point in Time			5.04%		0.83%
Ratio of Indebtedness to Net Capital			0.65
Long-term debt including current maturities			$ 600,800,000		$ 568,800,000
Line of Credit Facility, Commitment Fee Percentage			9,500%
Line of Credit Facility, Remaining Borrowing Capacity			$ 192,000,000
Notional Amount of Nonderivative Instruments		$ 60,000,000	50,000,000	$ 100,000,000
Financing Receivable, Revolving			400,000,000
Amount of letter of credit to our current primary insurance company			5,800,000
Subsequent Event
Short-term Debt [Line Items]
Notional Amount of Nonderivative Instruments	$ 40,000,000
Fixed Swap Rate	0.17%
Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Line of Credit Facility, Aggregate Borrowing Capacity			$ 400,000,000
Interest Rate Swap Rate, Low Range [Member]
Short-term Debt [Line Items]
Fixed Swap Rate		0.20%		0.2615%
Interest Rate Swap Rate, High Range [Member]
Short-term Debt [Line Items]
Fixed Swap Rate		0.205%	3.98%	0.3875%
Revolving Line of Credit, Short-term
Short-term Debt [Line Items]
Financing Receivable, Revolving			$ 200,000,000
Debt Instrument, Interest Rate, Stated Percentage			7,000%
Aggregate Investment, Maximum			$ 150,000,000
Ownership Interest			0.50
Borrowings Outstanding, Sustainable Investing			$ 9,400,000
Interest Rate Credit Adjustment			10
Revolving Line of Credit, Long-term
Short-term Debt [Line Items]
Debt Instrument, Fee			9
Interest Rate Credit Adjustment			10

Short-Term Borrowing Short-Term

Short-Term Borrowing Short-Term Borrowing - Schedule of Short-Term Debt (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Short-term Debt [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 200,000
Line of Credit Facility, Remaining Borrowing Capacity	192,000
Short-term borrowing	$ 202,157	$ 221,634
Number Of Unsecured Bank Credit Facilities	3

Leases Schedule of Future Minim

Leases Schedule of Future Minimum Rental Payment for Operating Leases (Details) $ in Thousands	Dec. 31, 2022 USD ($)
Leases [Abstract]
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 2,871	[1]
Lessee Future Operating Lease Option Payments	2,100
Lessee, Operating Lease, Liability, Payments, Due Year Two	2,546	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Three	2,161	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Four	1,684	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Five	1,529	[1]
Lessee, Operating Lease, Liability, Payments, Due after Year Five	6,192	[1]
Lessee, Operating Lease, Liability, Payments, Due	16,983	[1]
Lessee, Operating Lease, Liability, Undiscounted Excess Amount	(2,039)
Operating Lease, Liability	$ 14,944
[1] (1)

Leases Lease Cost Additional (D

Leases Lease Cost Additional (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021
Leases [Abstract]
Operating Lease, Cost	[1]	$ 2,883	$ 2,064
[1]1) Includes short-term leases and variable lease costs, which are immaterial

Leases Leases - Right of Use As

Leases Leases - Right of Use Asset and Lease Liability Balance Sheet Classification (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Leases [Abstract]
Operating Lease, Right-of-Use Asset	$ 14,421	$ 10,139
Operating Lease, Liability, Current	2,552	1,996
Operating Lease, Liability, Noncurrent	12,392	8,571
Total Operating and Finance Lease Liabilities	$ 14,944	$ 10,567

Leases Weighted Average Remaini

Leases Weighted Average Remaining Lease Term Additional Information (Details)	Dec. 31, 2022	Dec. 31, 2021
Leases [Abstract]
Operating Lease, Weighted Average Remaining Lease Term	8 years 6 months 14 days	8 years 1 month 6 days
Operating Lease, Weighted Average Discount Rate, Percent	3.40%	3.60%

Leases Lease Cash Flows Additio

Leases Lease Cash Flows Additional Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Leases Cash Flows [Abstract]
Operating Lease, Payments	$ 2,931	$ 1,996

Stockholders' Equity Additional

Stockholders' Equity Additional Details (Details) - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Accumulated Other Comprehensive Income (Loss) [Line Items]
Preferred Stock, Shares Authorized	2,000,000	2,000,000
Preferred Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Proceeds from issuance of common stock, net of expenses	$ 0	$ 0	$ 60,980,000
Stock Issued During Period, Shares, Dividend Reinvestment Plan	100,000	100,000
Stock Issued During Period, Value, Dividend Reinvestment Plan	$ 136.26	$ 125.71
Proceeds from Issuance of Common Stock, Dividend Reinvestment Plan	4,500,000	$ 15,200,000
Maximum [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Proceeds from Stock Plans	$ 75,000,000

Stockholders' Equity Accumulate

Stockholders' Equity Accumulated Other comprehensive Income (Loss) - Changes in Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), after Tax [Roll Forward]
Accumulated other comprehensive loss at beginning of period	$ 1,303	$ (2,865)
Other Comprehensive Income (Loss), before Reclassifications, before Tax	(229)	7,337
Amounts reclassified from accumulated other comprehensive income/(loss)	(2,453)	(3,169)
Net current-period other comprehensive income/(loss)	(2,682)	4,168
Accumulated other comprehensive loss at end of period	(1,379)	1,303	$ (2,865)
AOCI Changes For Defined Benefit Pension And Postretirement Plans [Member]
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), after Tax [Roll Forward]
Accumulated other comprehensive loss at beginning of period	(3,268)	(5,146)
Other Comprehensive Income (Loss), before Reclassifications, before Tax	705	262
Amounts reclassified from accumulated other comprehensive income/(loss)	57	1,616
Net current-period other comprehensive income/(loss)	762	1,878
Accumulated other comprehensive loss at end of period	(2,506)	(3,268)	(5,146)
Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), after Tax [Roll Forward]
Accumulated other comprehensive loss at beginning of period	4,571	2,309
Other Comprehensive Income (Loss), before Reclassifications, before Tax	(934)	7,075
Amounts reclassified from accumulated other comprehensive income/(loss)	(2,545)	(4,813)	(1,757)
Net current-period other comprehensive income/(loss)	(3,479)	2,262
Accumulated other comprehensive loss at end of period	1,092	4,571	2,309
Accumulated (Gain) Loss from Interest Rate Swap Cash Flows Hedges
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), after Tax [Roll Forward]
Accumulated other comprehensive loss at beginning of period	0	(28)
Other Comprehensive Income (Loss), before Reclassifications, before Tax	0	0
Amounts reclassified from accumulated other comprehensive income/(loss)		28
Net current-period other comprehensive income/(loss)	35	28
Accumulated other comprehensive loss at end of period	$ 35	$ 0	$ (28)

Stockholders' Equity Accumula_2

Stockholders' Equity Accumulated Other Comprehensive Income (loss) - Reclassifications of Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Amortization of defined benefit pension and postretirement plan items:
Income tax benefit		$ (33,832)	$ (29,231)	$ (23,538)
Accumulated other comprehensive income (loss)		(1,379)	1,303	(2,865)
Other Comprehensive Income (Loss), before Reclassifications, before Tax		(229)	7,337
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		(2,453)	(3,169)
Other Comprehensive Income (Loss), Net of Tax		(2,682)	4,168
Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Amortization of defined benefit pension and postretirement plan items:
Accumulated other comprehensive income (loss)		1,092	4,571	2,309
Other Comprehensive Income (Loss), before Reclassifications, before Tax		(934)	7,075
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		(2,545)	(4,813)	(1,757)
Other Comprehensive Income (Loss), Net of Tax		(3,479)	2,262
Accumulated (Gain) Loss from Interest Rate Swap Cash Flows Hedges
Amortization of defined benefit pension and postretirement plan items:
Accumulated other comprehensive income (loss)		35	0	(28)
Other Comprehensive Income (Loss), before Reclassifications, before Tax		0	0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax			28
Other Comprehensive Income (Loss), Net of Tax		35	28
AOCI Changes For Defined Benefit Pension And Postretirement Plans [Member]
Amortization of defined benefit pension and postretirement plan items:
Accumulated other comprehensive income (loss)		(2,506)	(3,268)	(5,146)
Other Comprehensive Income (Loss), before Reclassifications, before Tax		705	262
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		57	1,616
Other Comprehensive Income (Loss), Net of Tax		762	1,878
Reclassification out of Accumulated Other Comprehensive Income [Member]
Amortization of defined benefit pension and postretirement plan items:
Net of tax		2,453	3,169	1,436
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment [Member]
Amortization of defined benefit pension and postretirement plan items:
Prior service cost	[1]	77	77	77
Net gain	[1]	(152)	(2,243)	(592)
Total before income taxes		(75)	(2,166)	(515)
Income tax benefit	[2]	18	550	150
Net of tax		(57)	(1,616)	(365)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Amortization of defined benefit pension and postretirement plan items:
Total before income taxes		3,508	6,651	2,428
Income tax benefit	[2]	(963)	(1,838)	(671)
Net of tax		2,545	4,813	1,757
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated (Gain) Loss from Interest Rate Swap Cash Flows Hedges
Amortization of defined benefit pension and postretirement plan items:
Total before income taxes		(47)	(40)	60
Income tax benefit	[2]	12	12	(16)
Net of tax		(35)	(28)	44
Other Comprehensive Income Loss Adjustments AOCI Swap Agreements		(47)	(40)	60
Propane Swap Agreement [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Amortization of defined benefit pension and postretirement plan items:
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, before Tax	[3]	$ 3,508	$ 6,651	$ 2,428
[1]1) These amounts are included in the computation of net periodic benefits. See Note 16 , Employee Benefit Plans , for additional details. (3) The income tax benefit is included in income tax expense in the accompanying consolidated statements of income. These amounts are included in the effects of gains and losses from derivative instruments. See Note 8, Derivative Instruments , for additional details.

Employee Benefit Plans - Additi

Employee Benefit Plans - Additional Information (Detail) $ in Thousands		12 Months Ended
		Dec. 31, 2022 USD ($) shares	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Income tax benefits		$ 900
Total unrecognized cost		$ 14,815
Required period of service for eligibility		3 months
Percentage of eligible participants contribution to the plan		100%
Employer matching contribution vested, percentage		100%
Deferred Compensation Arrangement with Individual, Requisite Service Period		2 years
Deferred Pension Settlement Expense		$ 600
Defined Benefit Plan, Benefit Obligation			2
Employee contribution age		55 years
Deferral rate		80%
Deferred Compensation Employer Matching Contribution Rate		6%
Number Of Years to Collect Benefits		20 years
Deferral rate increase, minimum		1%
Employer contributions to pension plan		$ 6,200	$ 5,900	$ 5,900
Shares reserved to fund future contributions | shares		798,586
Investments, Fair Value Disclosure		$ 10,576	12,095
Deferred compensation obligation		$ 7,060	7,240
Minimum
Defined Benefit Plan Disclosure [Line Items]
Maximum percentage of eligible compensation		3%
Maximum
Defined Benefit Plan Disclosure [Line Items]
Maximum percentage of eligible compensation		6%			10%
Number Of Years to Collect Benefits		15 years
FPU Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Total unrecognized cost		$ 14,540
Expected contribution	[1]	3,432
Chesapeake SERP
Defined Benefit Plan Disclosure [Line Items]
Total unrecognized cost		295
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year		200
Expected contribution	[2]	$ 151
Medical
Defined Benefit Plan Disclosure [Line Items]
Health care inflation rate		5%
Chesapeake Postretirement Plan
Defined Benefit Plan Disclosure [Line Items]
Total unrecognized cost		$ 381
Unfunded accumulated benefit obligation		$ (600)	(900)
Health care inflation rate		6%
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year		$ 100
Expected contribution	[2]	60
FPU Medical Plan
Defined Benefit Plan Disclosure [Line Items]
Total unrecognized cost		401
Unfunded accumulated benefit obligation		$ (700)	(1,000)
Health care inflation rate		5%
Expected contribution	[2]	$ 57
FPU Medical Plan and Chesapeake OPRB [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Number of Plans		2
Rabbi Trust Associated With Deferred Compensation Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Deferred compensation obligation		$ 10,600	12,100
Deferred Compensation Equity		$ 7,100	$ 7,200
[1]The pension plan is funded; therefore, benefit payments are expected to be paid out of the plan assets.[2]Benefit payments are expected to be paid out of our general funds.

Employee Benefit Plans - Schedu

Employee Benefit Plans - Schedule of Funded Status of Benefit Obligation and Plan Assets (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Change in benefit obligation:
Interest cost	$ 50	$ 48	$ 63
Assumptions:
Deferred Pension Settlement Expense	600
Chesapeake Pension Plan
Change in benefit obligation:
Benefit obligation - beginning of year	0	6,146
Interest cost	0	141	176
Actuarial loss	0	(371)
Defined Benefit Plan, Benefit Obligation, Payment for Settlement	0	(5,884)
Benefits paid	0	(32)
Benefit obligation - end of year	0	0	6,146
Change in plan assets:
Balance, beginning of year	0	4,609
Actual return on plan assets	0	(237)
Employer contributions	0	1,544
Defined Benefit Plan, Plan Assets, Payment for Settlement	0	(5,884)
Benefits paid	0	(32)
Balance, end of year	0	0	$ 4,609
Reconciliation:
Accrued pension cost	$ 0	$ 0
Assumptions:
Discount rate	0%	2.50%
Expected return on plan assets	0%	3.50%	3.50%
FPU Pension Plan
Change in benefit obligation:
Benefit obligation - beginning of year	$ 67,030	$ 70,366
Interest cost	1,781	1,714	$ 2,085
Actuarial loss	(15,713)	(1,953)
Benefits paid	(3,157)	(3,097)
Benefit obligation - end of year	49,941	67,030	70,366
Change in plan assets:
Balance, beginning of year	58,712	55,966
Actual return on plan assets	(9,552)	4,246
Employer contributions	200	1,597
Benefits paid	(3,157)	(3,097)
Balance, end of year	46,203	58,712	$ 55,966
Reconciliation:
Accrued pension cost	$ (3,738)	$ (8,318)
Assumptions:
Discount rate	5.25%	2.75%
Expected return on plan assets	6%	6%	6%
Chesapeake SERP
Change in benefit obligation:
Benefit obligation - beginning of year	$ 2,096	$ 2,212
Interest cost	50	48
Actuarial loss	(335)	(12)
Benefits paid	(152)	(152)
Benefit obligation - end of year	1,659	2,096	$ 2,212
Change in plan assets:
Employer contributions	152	152
Benefits paid	(152)	(152)
Reconciliation:
Accrued pension cost	$ (1,659)	$ (2,096)
Assumptions:
Discount rate	5%	2.50%
Chesapeake Postretirement Plan
Reconciliation:
Funded status	$ (600)	$ (900)
FPU Medical Plan
Reconciliation:
Funded status	$ (700)	$ (1,000)

Employee Benefit Plans - Sche_2

Employee Benefit Plans - Schedule of Amounts Not Yet Reflected in Net Periodic Benefit Cost and Included in Accumulated Other Comprehensive Income Loss or Regulatory Assets (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Interest cost		$ 50	$ 48	$ 63
Prior service cost (credit)		(216)
Net loss		15,031
Total		14,815
Accumulated other comprehensive loss pre-tax		3,363
Post-merger regulatory asset		(11,452)
Total unrecognized cost		(14,815)
Chesapeake Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Interest cost		0	141	176
Defined Benefit Plan, Expected Return (Loss) on Plan Assets		0	166	157
Defined Benefit Plan, Expected Amortization of Gain (Loss), Next Fiscal Year		0	(257)	(243)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement		0	(1,810)	(203)
Net Periodic Cost Benefit		0	2,042	465
Defined Benefit Plan, Net Periodic Benefit Cost (Credit)		0	2,042	465
Amortization Of Pre Merger Regulatory Asset		$ 0	$ 0	$ 0
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate		0%	2.25%	3%
Expected return on plan assets		0%	3.50%	3.50%
FPU Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Interest cost		$ 1,781	$ 1,714	$ 2,085
Prior service cost (credit)		0
Net loss		14,540
Total		14,540
Accumulated other comprehensive loss pre-tax	[1]	2,763
Post-merger regulatory asset		(11,777)
Total unrecognized cost		(14,540)
Defined Benefit Plan, Expected Return (Loss) on Plan Assets		3,430	3,306	2,967
Defined Benefit Plan, Expected Amortization of Gain (Loss), Next Fiscal Year		(466)	(612)	(552)
Net Periodic Cost Benefit		(1,183)	(980)	(330)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit)		(1,183)	(980)	(330)
Amortization Of Pre Merger Regulatory Asset		$ 0	$ 0	$ 0
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate		2.75%	2.50%	3.25%
Expected return on plan assets		6%	6%	6%
Chesapeake SERP
Defined Benefit Plan Disclosure [Line Items]
Interest cost		$ 50	$ 48
Prior service cost (credit)		0
Net loss		295
Total		295
Accumulated other comprehensive loss pre-tax	[1]	295
Post-merger regulatory asset		0
Total unrecognized cost		(295)
Defined Benefit Plan, Expected Amortization of Gain (Loss), Next Fiscal Year		(28)	(28)	$ (20)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement		0	0	0
Defined Benefit Plan, Net Periodic Benefit Cost (Credit)		$ 78	$ 76	$ 83
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate		2.50%	2.25%	3%
Chesapeake Postretirement Plan
Defined Benefit Plan Disclosure [Line Items]
Prior service cost (credit)		$ (216)
Net loss		597
Total		381
Accumulated other comprehensive loss pre-tax	[1]	381
Post-merger regulatory asset		0
Total unrecognized cost		(381)
FPU Medical Plan
Defined Benefit Plan Disclosure [Line Items]
Prior service cost (credit)		0
Net loss		(401)
Total		(401)
Accumulated other comprehensive loss pre-tax	[1]	(76)
Post-merger regulatory asset		(325)
Total unrecognized cost		$ (401)
[1]The total amount of accumulated other comprehensive loss recorded on our consolidated balance sheet as of December 31, 2022 is net of income tax benefits of $0.9 million.

Employee Benefit Plans - Sche_3

Employee Benefit Plans - Schedule of Amounts Not Yet Reflected in Net Periodic Benefit Cost and Included in Accumulated Other Comprehensive Income Loss or Regulatory Assets (Phantoms) (Detail) $ in Millions	Dec. 31, 2022 USD ($)
Disclosure Employee Benefit Plans Schedule Of Amounts Not Yet Reflected In Net Periodic Benefit Cost And Included In Accumulated Other Comprehensive Income Loss Or Regulatory Assets [Abstract]
Income tax benefits	$ 0.9

Employee Benefit Plans - Sche_4

Employee Benefit Plans - Schedule of Assets by Investment Type (Detail) - USD ($) $ in Thousands		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Fair Value, Inputs, Level 1, 2 and 3
Asset Category
Defined Benefit Plan, Fair Value of Plan Assets, Excluding Net Asset Value Investments	[1]	$ 41,257	$ 51,930
FPU Pension Plan
Asset Category
Percentage of assets by investment type		100%	100%	100%
FPU Pension Plan | Investments in equity securities
Asset Category
Percentage of assets by investment type		53%	52%	54%
FPU Pension Plan | Debt securities
Asset Category
Percentage of assets by investment type		38%	38%	37%
FPU Pension Plan | Other
Asset Category
Percentage of assets by investment type		9%	10%	9%
[1] (8) All investments in the FPU Pension Plan are classified as Level 1 within the Fair Value hierarchy exclusive of the Guaranteed Deposit Account which is classified as Level 3.

Employee Benefit Plans - Sche_5

Employee Benefit Plans - Schedule of Asset Allocation Strategy (Detail)	Dec. 31, 2022
Minimum | Domestic Equities
Debt and Equity Securities, FV-NI [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	14%
Minimum | Foreign Equities
Debt and Equity Securities, FV-NI [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	13%
Minimum | Fixed Income
Debt and Equity Securities, FV-NI [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	29%
Minimum | Alternative Strategies
Debt and Equity Securities, FV-NI [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	4%
Minimum | Diversifying Assets
Debt and Equity Securities, FV-NI [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	2%
Minimum | Cash
Debt and Equity Securities, FV-NI [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	0%
Maximum | Domestic Equities
Debt and Equity Securities, FV-NI [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	32%
Maximum | Foreign Equities
Debt and Equity Securities, FV-NI [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	25%
Maximum | Fixed Income
Debt and Equity Securities, FV-NI [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	47%
Maximum | Alternative Strategies
Debt and Equity Securities, FV-NI [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	10%
Maximum | Diversifying Assets
Debt and Equity Securities, FV-NI [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	6%
Maximum | Cash
Debt and Equity Securities, FV-NI [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	5%

Employee Benefit Plans - Summar

Employee Benefit Plans - Summary of Pension Plan Assets (Detail) - USD ($) $ in Thousands		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Debt and Equity Securities, FV-NI [Line Items]
Investments measured at net asset value	[1]	$ 4,946	$ 6,782
Investments in equity securities
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets		19,706	23,842
Investments in equity securities | Us Large Cap Equity Securities
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets	[2]	3,413	4,302
Investments in equity securities | Us Mid Cap Equity Securities
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets	[2]	1,425	1,835
Investments in equity securities | United States Equity Small Cap
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets	[2]	692	954
Investments in equity securities | International All Cap Equity
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets	[3]	9,352	10,863
Investments in equity securities | Alternative Strategies
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets	[4]	4,824	5,888
Debt securities
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets		17,612	22,565
Debt securities | Fixed Income
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets	[5]	15,343	19,551
Debt securities | High Yield Asset Backed Securities
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets	[5]	2,269	3,014
Other
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets		3,939	5,523
Other | Commodities
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets	[6]	1,832	2,297
Other | Real Estate
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets	[7]	1,709	2,729
Other | Guaranteed deposit
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets	[8]	398	497
Significant Unobservable Inputs (Level 3)
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets		398	497	$ 1,019
Fair Value, Inputs, Level 1, 2 and 3
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets, excluding investments measured at net asset value	[9]	41,257	51,930
Fair Value Measured at Net Asset Value Per Share
Debt and Equity Securities, FV-NI [Line Items]
Total Pension Plan Assets		$ 46,203	$ 58,712
[1]Certain investments that were measured at net asset value per share have not been classified in the fair value hierarchy. These amounts are presented to reconcile to total pension plan assets.[2]Includes funds that invest primarily in United States common stocks.[3]Includes funds that invest primarily in foreign equities and emerging markets equities.[4]Includes funds that actively invest in both equity and debt securities, funds that sell short securities and funds that provide long-term capital appreciation. The funds may invest in debt securities below investment grade.[5]Includes funds that invest in investment grade and fixed income securities.[6]Includes funds that invest primarily in commodity-linked derivative instruments and fixed income securities.[7]Includes funds that invest primarily in real estate.[8]7) Includes investment in a group annuity product issued by an insurance company.[9] (8) All investments in the FPU Pension Plan are classified as Level 1 within the Fair Value hierarchy exclusive of the Guaranteed Deposit Account which is classified as Level 3.

Employee Benefit Plans - Summ_2

Employee Benefit Plans - Summary of Changes in Fair Value of Level 3 Investments (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Alternative Investments, Fair Value of Plan Assets	[1]	$ 4,946	$ 6,782
Significant Unobservable Inputs (Level 3)
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Balance, beginning of year		497	1,019
Purchases		208	3,160
Transfers in		3,270	5,914
Disbursements		(3,541)	(9,587)
Investment Income		(36)	(9)
Balance, end of year		398	497
Fair Value, Inputs, Level 1, 2 and 3
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets, Excluding Net Asset Value Investments	[2]	41,257	51,930
Fair Value Measured at Net Asset Value Per Share
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Balance, beginning of year		58,712
Balance, end of year		46,203	58,712
Investments in equity securities
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Balance, beginning of year		23,842
Balance, end of year		19,706	23,842
Debt securities
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Balance, beginning of year		22,565
Balance, end of year		17,612	22,565
Other Investments [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Balance, beginning of year		5,523
Balance, end of year		3,939	5,523
Us Large Cap Equity Securities | Investments in equity securities
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Balance, beginning of year	[3]	4,302
Balance, end of year	[3]	3,413	4,302
Us Mid Cap Equity Securities | Investments in equity securities
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Balance, beginning of year	[3]	1,835
Balance, end of year	[3]	1,425	1,835
United States Equity Small Cap | Investments in equity securities
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Balance, beginning of year	[3]	954
Balance, end of year	[3]	692	954
International All Cap Equity | Investments in equity securities
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Balance, beginning of year	[4]	10,863
Balance, end of year	[4]	9,352	10,863
Alternative Strategies | Investments in equity securities
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Balance, beginning of year	[5]	5,888
Balance, end of year	[5]	4,824	5,888
Fixed Income Securities [Member] | Debt securities
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Balance, beginning of year	[6]	19,551
Balance, end of year	[6]	15,343	19,551
High Yield Asset Backed Securities | Debt securities
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Balance, beginning of year	[6]	3,014
Balance, end of year	[6]	2,269	3,014
Commodities | Other Investments [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Balance, beginning of year	[7]	2,297
Balance, end of year	[7]	1,832	2,297
Real Estate [Member] | Other Investments [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Balance, beginning of year	[8]	2,729
Balance, end of year	[8]	1,709	2,729
Guaranteed deposit | Other Investments [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Balance, beginning of year	[9]	497
Balance, end of year	[9]	$ 398	$ 497
[1]Certain investments that were measured at net asset value per share have not been classified in the fair value hierarchy. These amounts are presented to reconcile to total pension plan assets.[2] (8) All investments in the FPU Pension Plan are classified as Level 1 within the Fair Value hierarchy exclusive of the Guaranteed Deposit Account which is classified as Level 3.

Employee Benefit Plans - Compon

Employee Benefit Plans - Component of Net Periodic Pension Cost (Benefit) (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Components of net periodic cost:
Interest cost	$ 50	$ 48	$ 63
Chesapeake Postretirement Plan
Assumptions
Funded status	(600)	(900)
FPU Medical Plan
Assumptions
Funded status	(700)	(1,000)
Chesapeake SERP
Components of net periodic cost:
Interest cost	50	48
Actuarial (gain) loss	28	28	20
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	0	0	0
Net periodic postretirement cost	$ 78	$ 76	$ 83
Assumptions
Discount rate	2.50%	2.25%	3%
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	$ (335)	$ (12)
Defined Benefit Plan, Benefit Obligation, Benefits Paid	(152)	(152)
Defined Benefit Plan, Plan Assets, Contributions by Employer	152	152
Defined Benefit Plan, Plan Assets, Benefits Paid	(152)	(152)
Accrued pension cost	$ (1,659)	$ (2,096)
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	5%	2.50%
Chesapeake Pension Plan
Components of net periodic cost:
Interest cost	$ 0	$ 141	$ 176
Expected return on assets	0	(166)	(157)
Actuarial (gain) loss	0	257	243
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	0	1,810	203
Net periodic pension cost	0	2,042	465
Amortization of pre-merger regulatory asset	0	0	0
Net periodic postretirement cost	$ 0	$ 2,042	$ 465
Assumptions
Discount rate	0%	2.25%	3%
Expected return on plan assets	0%	3.50%	3.50%
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	$ 0	$ (371)
Defined Benefit Plan, Benefit Obligation, Benefits Paid	0	(32)
Defined Benefit Plan, Plan Assets, Amount	0	0	$ 4,609
Defined Benefit Plan, Plan Assets, Contributions by Employer	0	1,544
Defined Benefit Plan, Plan Assets, Benefits Paid	0	(32)
Accrued pension cost	$ 0	$ 0
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	0%	2.50%
FPU Pension Plan
Components of net periodic cost:
Interest cost	$ 1,781	$ 1,714	2,085
Expected return on assets	(3,430)	(3,306)	(2,967)
Actuarial (gain) loss	466	612	552
Net periodic pension cost	(1,183)	(980)	(330)
Amortization of pre-merger regulatory asset	0	0	0
Net periodic postretirement cost	$ (1,183)	$ (980)	$ (330)
Assumptions
Discount rate	2.75%	2.50%	3.25%
Expected return on plan assets	6%	6%	6%
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	$ (15,713)	$ (1,953)
Defined Benefit Plan, Benefit Obligation, Benefits Paid	(3,157)	(3,097)
Defined Benefit Plan, Plan Assets, Amount	46,203	58,712	$ 55,966
Defined Benefit Plan, Plan Assets, Contributions by Employer	200	1,597
Defined Benefit Plan, Plan Assets, Benefits Paid	(3,157)	(3,097)
Accrued pension cost	$ (3,738)	$ (8,318)
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	5.25%	2.75%

Employee Benefit Plans - Amount

Employee Benefit Plans - Amounts in Accumulated Other Comprehensive Income/Loss and Regulatory Asset (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Chesapeake Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Amortization of pre-merger regulatory asset	$ 0	$ 0	$ 0
FPU Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Amortization of pre-merger regulatory asset	$ 0	$ 0	$ 0

Employee Benefit Plans - Sche_6

Employee Benefit Plans - Schedule of Estimated Future Benefit Payments (Detail) $ in Thousands	Dec. 31, 2022 USD ($)
FPU Pension Plan
Defined Benefit Plan, Expected Future Benefit Payments, Maturity [Line Items]
2017	$ 3,432	[1]
2018	3,503	[1]
2019	3,648	[1]
2020	3,680	[1]
2021	3,675	[1]
Years 2022 through 2026	18,368	[1]
Chesapeake SERP
Defined Benefit Plan, Expected Future Benefit Payments, Maturity [Line Items]
2017	151	[2]
2018	149	[2]
2019	162	[2]
2020	159	[2]
2021	156	[2]
Years 2022 through 2026	707	[2]
Chesapeake Postretirement Plan
Defined Benefit Plan, Expected Future Benefit Payments, Maturity [Line Items]
2017	60	[2]
2018	58	[2]
2019	55	[2]
2020	50	[2]
2021	48	[2]
Years 2022 through 2026	200	[2]
FPU Medical Plan
Defined Benefit Plan, Expected Future Benefit Payments, Maturity [Line Items]
2017	57	[2]
2018	59	[2]
2019	59	[2]
2020	58	[2]
2021	59	[2]
Years 2022 through 2026	$ 227	[2]
[1]The pension plan is funded; therefore, benefit payments are expected to be paid out of the plan assets.[2]Benefit payments are expected to be paid out of our general funds.

Share-Based Compensation - Addi

Share-Based Compensation - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions	6 Months Ended	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares reserved for issuance	798,586	798,586
Number of Shares, Granted	526	652	683
Number of shares withheld		21,832	14,020	10,319
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount	$ 4.7	$ 4.7
SICP Awards to Non-employee directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation expense related to the awards to Non employee directors	0.3	$ 0.3
Weighted average grant-date fair value of awards granted		$ 130.36	$ 117.11
SICP Awards to Key Employees
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value		$ 90.60	$ 76.31
Number of Shares, Granted		69,620	69,903
Weighted average grant-date fair value of awards granted		$ 117.61	$ 100.76
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Nonvested	$ 24	$ 24	$ 28.8	$ 20.2
Stock and Incentive Compensation Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares reserved for issuance	322,509	322,509

Share-Based Compensation Plan_2

Share-Based Compensation Plans - Share-Based Compensation Amounts Included in Net Income (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	$ 6,438	$ 5,945	$ 4,829
Less: tax benefit	(1,663)	(1,535)	(1,254)
Share-Based Compensation amounts included in net income	4,775	4,410	3,575
SICP Awards to Non-employee directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	959	782	733
Share-based Payment Arrangement, Nonvested Award, Excluding Option, Cost Not yet Recognized, Amount	300
SICP Awards to Key Employees
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Nonvested	24,000	28,800	20,200
Total compensation expense	$ 5,479	$ 5,163	$ 4,096

Share-Based Compensation Plan_3

Share-Based Compensation Plans - Summary of Stock Activity Non-employee directors (Detail) - USD ($) $ / shares in Units, $ in Millions	6 Months Ended	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2022	Dec. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Number of Shares, Granted	526	652	683
SICP Awards to Non-employee directors
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Weighted Average Grant Date Fair Value, Granted		$ 130.36	$ 117.11
Share-based Payment Arrangement, Nonvested Award, Excluding Option, Cost Not yet Recognized, Amount	$ 0.3	$ 0.3

Share-Based Compensation Plan_4

Share-Based Compensation Plans - Summary of Stock Activity under SICP - Key employees (Detail) - $ / shares		6 Months Ended	12 Months Ended
		Dec. 31, 2022	Dec. 31, 2022	Dec. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Number of Shares, Granted		526	652	683
SICP Awards to Key Employees
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Number of Shares, Outstanding Beginning Balance			197,398	186,878
Number of Shares, Granted			69,620	69,903
Number of Shares, Vested			(60,850)	(53,147)
Number of Shares, Outstanding Ending Balance		203,490	203,490	197,398
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Weighted Average Grant Date Fair Value, Outstanding Beginning Balance			$ 94.15	$ 87.06
Weighted Average Grant Date Fair Value, Granted			117.61	100.76
Weighted Average Grant Date Fair Value, Vested			90.60	76.31
Weighted Average Grant Date Fair Value, Outstanding Ending Balance		$ 103.06	103.06	$ 94.15
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	[1]			(5,384)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	[1]			$ 93.39
Accelerated Vested Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Weighted Average Grant Date Fair Value, Vested			$ 91.42	$ 74.85
Share-based Compensation Arrangement by Share-based Payment Award, Accelerated Vesting, Number			2,678	852
[1]In conjunction with the retirement of one key employee during 2020, these shares were forfeited for the remainder of the service periods associated with awards granted during their employment with the Company.

Share-Based Compensation Plan_5

Share-Based Compensation Plans Shares Withheld and Tax Benefits Associated With Share-Based Payments (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Share-Based Payment Arrangement [Abstract]
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation	21,832	14,020	10,319
Payment, Tax Withholding, Share-based Payment Arrangement	$ 2,838	$ 1,478	$ 977

Rates and Other Regulatory Ac_3

Rates and Other Regulatory Activities - Additional Information (Detail) $ in Thousands		12 Months Ended
		Dec. 31, 2022 USD ($) Dekatherm mi	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Rates and Other Regulatory Activities [Line Items]
Restricted Payment		$ 326,400
Regulatory Assets		149,654	$ 123,967
Revenues		680,704	569,968	$ 488,198
Interim Rates		7,700
Permanent Rates		24,100
Annual Rate Case Recovery		17,200
COVID-19 Regulatory Asset		1,200	2,300
Underrecovered purchased fuel costs
Rates and Other Regulatory Activities [Line Items]
Regulatory Assets	[1]	43,583	$ 9,199
Florida Public Utilities Company [Member]
Rates and Other Regulatory Activities [Line Items]
COVID-19 Settlement Amount		$ 2,100
Winter Haven Expansion | Peninsula Pipeline Company
Rates and Other Regulatory Activities [Line Items]
Additional Firm Natural Gas Transportation Deliverability | Dekatherm		6,800
Beachside Expansion | Peninsula Pipeline Company
Rates and Other Regulatory Activities [Line Items]
Additional Firm Natural Gas Transportation Deliverability | Dekatherm		10,176
Number of Mainline Pipeline Miles | mi		11.3
Twin Lakes Expansion | Peninsula Pipeline Company
Rates and Other Regulatory Activities [Line Items]
Additional Firm Natural Gas Transportation Deliverability | Dekatherm		2,400
Elkton Gas [Member] | Regulated Energy [Member]
Rates and Other Regulatory Activities [Line Items]
Number of customers acquired through acquisition		7,000
[1]We are allowed to recover the asset or are required to pay the liability in rates. We do not earn an overall rate of return on these assets. (2) At December 31, 2022, includes $21.2 million being recovered over a three year period primarily concentrated in our electric division. Per Florida PSC approval, our electric division was allowed to recover these amounts over an extended period of time in an effort to reduce the impact of increased commodity prices to our customers. Recovery of these costs began in January 2023.

Rates and Other Regulatory Ac_4

Rates and Other Regulatory Activities Regulatory Assets and Liabilities (Details) - USD ($) $ in Thousands		Dec. 31, 2022	Dec. 31, 2021
Rates and Other Regulatory Activities [Line Items]
Regulatory Assets		$ 149,654	$ 123,967
Regulatory Liabilities		148,020	144,800
Underrecovered Gas & Fuel Costs		21,200
Self Insured Liabilities [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	[1]	339	563
Overrecovered Gas And Fuel Costs [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	[2]	3,827	1,073
Storm Reserve [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	[1]	2,845	2,829
Accrued asset removal cost
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	[3]	50,261	47,887
Deferred Income Tax Due to Rate Change [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	[4]	87,690	88,804
Other Regulatory Liability [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities		1,851	1,498
Storm Cost Recovery, Interest
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	[5]	1,207	2,146
Underrecovered Gas And Fuel Costs [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Assets	[2]	43,583	9,199
Deferred Post Retirement Benefits [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Assets	[6]	13,927	16,749
Deferred Conversion And Development Costs [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Assets	[2]	23,653	23,383
Acquisition Adjustment [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Assets	[7]	25,609	27,182
Other Regulatory Asset [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Assets		12,257	7,060
COVID-19 Deferred Costs
Rates and Other Regulatory Activities [Line Items]
Regulatory Assets	[8]	1,233	2,289
Deferred Storm Costs
Rates and Other Regulatory Activities [Line Items]
Regulatory Assets	[5]	27,687	36,004
Under-recovered GRIP Revenues
Rates and Other Regulatory Activities [Line Items]
Regulatory Assets	[9]	1,705	2,101
Florida Public Utilities Company [Member]
Rates and Other Regulatory Activities [Line Items]
Business Acquisition Premium Paid		34,200
Regulatory Liabilities		19,074	$ 19,189
Indiantown Gas Company
Rates and Other Regulatory Activities [Line Items]
Business Acquisition Premium Paid		$ 700
[1]We have storm reserves in our Florida regulated energy operations and self-insurance for our regulated energy operations that allow us to collect through rates amounts to be used against general claims, storm restoration costs and other losses as they are incurred.[2]We are allowed to recover the asset or are required to pay the liability in rates. We do not earn an overall rate of return on these assets. (2) At December 31, 2022, includes $21.2 million being recovered over a three year period primarily concentrated in our electric division. Per Florida PSC approval, our electric division was allowed to recover these amounts over an extended period of time in an effort to reduce the impact of increased commodity prices to our customers. Recovery of these costs began in January 2023. , Summary of Significant Accounting Policies, for additional information on our asset removal cost policies. We recorded a regulatory liability for our regulated businesses related to the revaluation of accumulated deferred tax assets/liabilities as a result of the TCJA. The liability will be amortized over a period between 5 to 80 years based on the remaining life of the associated property. Based upon the regulatory proceedings, we will pass back the respective portion of the excess accumulated deferred taxes to rate payers. See Note 11, Income Taxes , for additional information. , Compensation - Retirement Benefits , related to its regulated operations. This balance also includes the portion of pension settlement expense associated with the termination of the Chesapeake Pension Plan pursuant to an order from the FERC and the respective PSCs that allowed us to defer Eastern Shore, Delaware and Maryland Divisions' portion. See Note 16 , Employee Benefit Plans, for additional information.

Rates and Other Regulatory Ac_5

Rates and Other Regulatory Activities Federal Tax Reform Impact for Regulated Businesses (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Regulatory Liabilities Related to the Federal Tax Reform Impact [Line Items]
Regulatory Liabilities	$ 148,020	$ 144,800
Eastern Shore Gas Company [Member]
Regulatory Liabilities Related to the Federal Tax Reform Impact [Line Items]
Regulatory Liabilities	34,190	34,190
Delaware natural gas division [Member]
Regulatory Liabilities Related to the Federal Tax Reform Impact [Line Items]
Regulatory Liabilities	12,230	12,591
Maryland Division [Member]
Regulatory Liabilities Related to the Federal Tax Reform Impact [Line Items]
Regulatory Liabilities	3,703	3,840
Sandpiper [Member]
Regulatory Liabilities Related to the Federal Tax Reform Impact [Line Items]
Regulatory Liabilities	3,597	3,656
Central Florida Gas Division [Member]
Regulatory Liabilities Related to the Federal Tax Reform Impact [Line Items]
Regulatory Liabilities	7,846	8,032
Florida Public Utilities Company [Member]
Regulatory Liabilities Related to the Federal Tax Reform Impact [Line Items]
Regulatory Liabilities	19,074	19,189
Fort Meade and Indiantown Divisions [Member]
Regulatory Liabilities Related to the Federal Tax Reform Impact [Line Items]
Regulatory Liabilities	259	271
Elkton Gas [Member]
Regulatory Liabilities Related to the Federal Tax Reform Impact [Line Items]
Regulatory Liabilities	1,059	1,091
FPU electric division [Member]
Regulatory Liabilities Related to the Federal Tax Reform Impact [Line Items]
Regulatory Liabilities	$ 4,993	$ 5,237

Environmental Commitments and_3

Environmental Commitments and Contingencies - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2022 USD ($) site	Dec. 31, 2021 USD ($)
Environmental Commitments And Contingencies [Line Items]
Companys Exposure In Number Of Former Manufactured Gas Plant Sites | site	7
Environmental liabilities	$ 3,272,000	$ 3,538,000
Manufactured Gas Plant
Environmental Commitments And Contingencies [Line Items]
Regulatory assets for future recovery of environmental costs	800,000	1,300,000
Maximum
Environmental Commitments And Contingencies [Line Items]
Environmental Remediation Expense	900,000
Minimum
Environmental Commitments And Contingencies [Line Items]
Environmental Exit Costs, Reasonably Possible Additional Loss	300,000
West Palm Beach Florida | Maximum
Environmental Commitments And Contingencies [Line Items]
Environmental Exit Costs, Reasonably Possible Additional Loss	14,200,000
West Palm Beach Florida | Minimum
Environmental Commitments And Contingencies [Line Items]
Environmental Exit Costs, Reasonably Possible Additional Loss	3,300,000
FPU
Environmental Commitments And Contingencies [Line Items]
Environmental liabilities	4,300,000	5,200,000
Approval of recovery of environmental costs	14,000,000
Environmental costs recovered	13,300,000	12,900,000
FPU | Manufactured Gas Plant
Environmental Commitments And Contingencies [Line Items]
Regulatory assets for future recovery of environmental costs	$ 700,000	$ 1,100,000

Other Commitments and Conting_3

Other Commitments and Contingencies - Additional Information (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2022 USD ($)
Subsequent Event [Line Items]
Intercompany Agreements, Description	three years
Debt Service Coverage Ratio	1.25
Time to cure ratio	5 days
Ratio based on average number of prior quarters	6
Funds from operations interest coverage ratio minimum times	2
Total debt to capital maximum	65
Number Of Years to Collect Benefits	20 years
Total purchase obligations for 2018	$ 83,521
Total purchase obligations for 2019 - 2020	82,815
Total purchase obligations for 2021 - 2022	71,327
Total purchase obligations thereafter	144,768
Aggregate guaranteed amount	20,000
Guarantor Obligations, Current Carrying Value	13,500
Amount of letter of credit to our current primary insurance company	5,800
Specific Purpose
Subsequent Event [Line Items]
Guarantor Obligations, Current Carrying Value	11,100
Rate Case
Subsequent Event [Line Items]
Guarantor Obligations, Current Carrying Value	$ 7,100

Other Commitments and Conting_4

Other Commitments and Contingencies Purchase Obligations (Details) $ in Thousands	Dec. 31, 2022 USD ($)
Long-term Purchase Commitment [Line Items]
Purchase Obligation, Due in Next Twelve Months	$ 83,521
Purchase Obligation, Due in Second and Third Year	82,815
Purchase Obligation, Due in Fourth and Fifth Year	71,327
Purchase Obligation, Due after Fifth Year	144,768
Purchase Obligation	$ 382,431

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Year	$ 4,785	$ 1,337
Additions, Charged to Income	134	3,827
Additions, Other Accounts	(125)	613
Deductions	(1,653)	(992)
Balance at End of Year	$ 3,141	$ 4,785