Chesapeake Utilities (CPK) 10-Q 5 Aug 20 2020 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2020	Jul. 31, 2020
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2020
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	909 Silver Lake Boulevard
Entity Address, City or Town	Dover
Entity Address, State or Province	DE
Entity Address, Postal Zip Code	19904
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 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 Common Stock, Shares Outstanding		16,493,573
Entity Central Index Key	0000019745
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q2
Amendment Flag	false

Condensed Consolidated Statemen

Condensed Consolidated Statements of Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Operating Revenues
Regulated Energy	$ 73,518	$ 73,403	$ 176,473	$ 177,021
Unregulated Energy and other	23,533	21,139	73,268	77,984
Total Operating Revenues	97,051	94,542	249,741	255,005
Operating Expenses
Regulated Energy cost of sales	16,387	18,317	51,219	54,833
Unregulated Energy and other cost of sales	6,573	6,857	24,609	31,267
Operations	34,607	31,531	70,559	66,945
Operating Costs and Expenses	4,143	3,600	7,979	7,280
Settlement Gain	(130)	(130)	(130)	(130)
Depreciation and amortization			24,500	22,684
Depreciation and Amortization Costs	12,247	11,464	24,500	22,392
Other taxes	5,247	4,738	10,894	10,131
Total Operating Expenses	79,074	76,377	189,630	192,718
Operating Income	17,977	18,165	60,111	62,287
Other income (expense), net	(279)	(320)	3,039	(380)
Interest charges	5,054	5,552	10,868	11,180
Income from Continuing Operations Before Income Taxes	12,644	12,293	52,282	50,727
Income Taxes on Continuing Operations	1,983	3,379	12,580	13,002
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax	295	(610)	184	(757)
Net Income (Loss) Attributable to Parent	$ 10,956	$ 8,304	$ 39,886	$ 36,968
Weighted Average Common Shares Outstanding:
Basic (shares)	16,448,490	16,401,028	16,431,724	16,393,022
Diluted (shares)	16,503,603	16,445,743	16,487,807	16,439,333
Basic Earnings Per Share of Common Stock:
Income (Loss) from Continuing Operations, Per Basic Share	$ 0.65	$ 0.55	$ 2.42	$ 2.31
Discontinued Operation, Income (Loss) from Discontinued Operation, Net of Tax, Per Basic Share	0.02	(0.04)	0.01	(0.05)
Basic (in dollars per share)	0.67	0.51	2.43	2.26
Earnings Per Share, Diluted [Abstract]
Income (Loss) from Continuing Operations, Per Diluted Share	0.64	0.54	2.41	2.30
Discontinued Operation, Income (Loss) from Discontinued Operation, Net of Tax, Per Diluted Share	0.02	(0.04)	0.01	(0.05)
Diluted (in dollars per share)	$ 0.66	$ 0.50	$ 2.42	$ 2.25
Retained Earnings [Member]
Operating Expenses
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent	$ 10,661	$ 8,914	$ 39,702	$ 37,725
Net Income (Loss) Attributable to Parent	$ 10,956	$ 8,304	$ 39,886	$ 36,968

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Net Income	$ 10,956	$ 8,304	$ 39,886	$ 36,968
Other Comprehensive Income (Loss), net of tax:
Amortization of prior service cost, net of tax of $(5), $(5), $(10) and $(10), respectively	(14)	(14)	(28)	(29)
Net gain, net of tax of $28, $42, $55 and $86, respectively	80	121	160	242
Cash Flow Hedges, net of tax:
Unrealized gain (loss) on commodity contract cash flow hedges, net of tax of $651, $(850), $653 and $343, respectively	1,703	(2,115)	1,710	868
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), after Reclassification and Tax, Parent	(37)		(37)
Total Other Comprehensive Income (Loss), net of tax	1,732	(2,008)	1,805	1,081
Comprehensive Income	$ 12,688	$ 6,296	$ 41,691	$ 38,049

Condensed Consolidated Statem_3

Condensed Consolidated Statements of Comprehensive Income (Unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Statement of Comprehensive Income [Abstract]
Amortization of prior service cost, tax	$ (5)	$ (5)	$ (10)	$ (10)
Net gain, tax	28	42	55	86
Unrealized (loss)/gain on commodity contract cash flow hedges, tax	651	(850)	653	343
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Interest Rate Swaps During Period, Tax	$ (14)	$ 0	$ (14)	$ 0

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands		Jun. 30, 2020	Dec. 31, 2019
Property, Plant and Equipment
Regulated Energy		$ 1,499,389	$ 1,441,473
Unregulated Energy		277,209	265,209
Other businesses and eliminations		39,798	39,850
Total property, plant and equipment		1,816,396	1,746,532
Less: Accumulated depreciation and amortization		(357,303)	(336,876)
Plus: Construction work in progress		66,267	54,141
Net property, plant and equipment		1,525,360	1,463,797
Current Assets
Cash and cash equivalents		3,590	6,985
Trade and other receivables		46,695	49,562
Accounts Receivable, Allowance for Credit Loss, Current		(2,104)	(1,337)
Accounts Receivable, before Allowance for Credit Loss, Current		48,799	50,899
Accrued revenue		12,076	20,846
Propane inventory, at average cost		3,951	5,824
Other inventory, at average cost		5,397	6,067
Regulatory assets		3,625	5,144
Storage gas prepayments		1,943	3,541
Income taxes receivable		9,827	20,050
Prepaid expenses		9,167	13,928
Derivative assets, at fair value		1,270	0
Other current assets		1,017	2,879
Total current assets		98,558	134,826
Deferred Charges and Other Assets
Goodwill		32,684	32,668
Other intangible assets, net		7,520	8,129
Investments, at fair value		9,571	9,229
Operating Lease, Right-of-Use Asset		11,546	11,563
Regulatory assets		74,814	73,407
Receivables and other deferred charges		62,122	49,579
Total deferred charges and other assets		198,257	184,575
Total Assets		1,822,175	1,783,198
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)		8,013	7,984
Additional paid-in capital		263,272	259,253
Retained earnings		326,454	300,607
Accumulated other comprehensive loss		(4,462)	(6,267)
Deferred compensation obligation		5,659	4,543
Treasury stock		(5,659)	(4,543)
Total stockholders’ equity	[1]	593,277	561,577
Long-term debt, net of current maturities		430,106	440,168
Total capitalization		1,023,383	1,001,745
Current Liabilities
Less: current maturities		15,600	45,600
Short-term borrowing		286,405	247,371
Accounts payable		46,382	54,069
Customer deposits and refunds		30,707	30,939
Accrued interest		2,169	2,554
Dividends payable		7,244	6,644
Accrued compensation		9,260	16,236
Regulatory liabilities		10,328	5,991
Derivative liabilities, at fair value		802	1,844
Other accrued liabilities		20,926	12,076
Total current liabilities		429,823	423,324
Deferred Credits and Other Liabilities
Deferred income taxes		193,595	180,656
Regulatory liabilities		130,180	127,744
Environmental liabilities		4,520	6,468
Other pension and benefit costs		28,185	30,569
Operating Lease, Liability, Noncurrent		10,055	9,896
Deferred investment tax credits and other liabilities		2,434	2,796
Total deferred credits and other liabilities		368,969	358,129
Environmental and other commitments and contingencies (Notes 5 and 6)
Total Capitalization and Liabilities		$ 1,822,175	$ 1,783,198
[1]	2,000,000 shares of preferred stock at $0.01 par value have been authorized. No shares have been issued or are outstanding; accordingly, no information has been included in the statements of stockholders’ equity.

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Statement of Financial Position [Abstract]
Allowance for uncollectible accounts	$ 2,104	$ 1,337
Common stock, par value (in dollars per share)	$ 0.4867	$ 0.4867
Common stock, shares authorized (shares)	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
Preferred Stock, Shares Issued	0	0

Condensed Consolidated Statem_4

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Operating Activities
Net Income	$ 39,886	$ 36,968
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	24,500	22,684
Depreciation and accretion included in other costs	4,807	4,322
Deferred income taxes	12,232	7,746
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax	(200)
Realized gain on commodity contracts and sale of assets	(3,496)	(572)
Unrealized loss (gain) on investments/commodity contracts	130	(1,089)
Employee benefits and compensation	21	764
Share-based compensation	2,322	1,095
Changes in assets and liabilities:
Accounts receivable and accrued revenue	11,455	51,362
Propane inventory, storage gas and other inventory	4,140	6,458
Regulatory assets/liabilities, net	4,133	(1,610)
Prepaid expenses and other current assets	6,016	9,660
Accounts payable and other accrued liabilities	(1,604)	(56,902)
Income taxes (payable) receivable	(1,480)	4,316
Customer deposits and refunds	(232)	(4,316)
Accrued compensation	(7,086)	(5,365)
Other assets and liabilities, net	(3,866)	(946)
Net cash provided by operating activities	91,678	74,575
Investing Activities
Property, plant and equipment expenditures	(82,779)	(90,443)
Proceeds from sale of assets	4,273	207
Proceeds from the sale of discontinued operations	200
Environmental expenditures	1,948	644
Net cash used in investing activities	(80,254)	(90,880)
Financing Activities
Common stock dividends	(12,976)	(11,759)
Issuance (repurchase) of stock under the Dividend Reinvestment Plan	359	(368)
Tax Withholding payments related to net settled stock compensation	(977)	(692)
Change in cash overdrafts due to outstanding checks	(3,431)	548
Net borrowings under line of credit agreements	42,319	6,220
Proceeds from long-term debt and long-term borrowing under the Revolver	(13)	29,956
Repayment of long-term debt and capital lease obligation	(40,100)	(6,435)
Net cash (used) provided by financing activities	(14,819)	17,470
Net (Decrease) Increase in Cash and Cash Equivalents	(3,395)	1,165
Cash and Cash Equivalents—Beginning of Period	6,985	6,089
Cash and Cash Equivalents—End of Period	$ 3,590	$ 7,254

Condensed Consolidated Statem_5

Condensed Consolidated Statements of Stockholders' Equity (Unaudited) - USD ($) $ in Thousands		Total		Common Stock [Member]		Additional Paid-In Capital [Member]		Retained Earnings [Member]	Accumulated Other Comprehensive Loss [Member]	Deferred Compensation [Member]	Treasury Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares Held In Trust For Deferred Compensation Plan		97,053
Common Stock, Dividends, Per Share, Declared		$ 0.3700
Beginning Balances (shares) at Dec. 31, 2018	[1],[2]			16,378,545
Beginning Balances at Dec. 31, 2018		$ 518,439		$ 7,971	[1]	$ 255,651		$ 261,530	$ (6,713)	$ 3,854	$ (3,854)
Ending Balances (shares) at Mar. 31, 2019	[1],[2]			16,397,017
Ending Balances at Mar. 31, 2019		$ 543,659	[1]	$ 7,980	[1]	255,307		284,111	(3,739)	4,376	(4,376)
Common Stock, Dividends, Per Share, Declared		$ 0.7750
Beginning Balances (shares) at Dec. 31, 2018	[1],[2]			16,378,545
Beginning Balances at Dec. 31, 2018		$ 518,439		$ 7,971	[1]	255,651		261,530	(6,713)	3,854	(3,854)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		36,968						36,968
New Accounting Pronouncement or Change in Accounting Principle, Effect of Adoption, Quantification		0						115	(115)
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect									(115)
Other comprehensive income (loss)		1,081							1,081
Other Comprehensive Income (Loss), Net of Tax		1,081
Dividend declared		(12,851)						(12,851)
Retirement savings plan and dividend reinvestment plan (shares)				0
Dividend reinvestment plan		(2)		$ 0		(2)
Share-based compensation (shares)				25,231
Share-based compensation and tax benefit		749	[3],[4]	$ 13		736	[3],[4]
Treasury stock activities		0								840	(840)
Ending Balances (shares) at Jun. 30, 2019	[1],[2]			16,403,776
Ending Balances at Jun. 30, 2019		$ 544,384	[1]	$ 7,984	[1]	256,385		285,762	(5,747)	4,694	(4,694)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation		7,635
Common Stock, Dividends, Per Share, Declared		$ 0.4050
Beginning Balances (shares) at Mar. 31, 2019	[1],[2]			16,397,017
Beginning Balances at Mar. 31, 2019		$ 543,659	[1]	$ 7,980	[1]	255,307		284,111	(3,739)	4,376	(4,376)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		8,304						8,304
Other comprehensive income (loss)		(2,008)							(2,008)
Other Comprehensive Income (Loss), Net of Tax		(2,008)
Dividend declared		(6,653)						6,653
Dividend reinvestment plan		(1)				(1)
Share-based compensation (shares)	[3],[4]			6,759
Share-based compensation and tax benefit		1,083	[3],[4]	$ 4	[3],[4]	1,079
Treasury stock activities										318	(318)
Ending Balances (shares) at Jun. 30, 2019	[1],[2]			16,403,776
Ending Balances at Jun. 30, 2019		$ 544,384	[1]	$ 7,984	[1]	256,385		285,762	(5,747)	4,694	(4,694)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares Held In Trust For Deferred Compensation Plan		105,409
Preferred Stock, Shares Authorized		2,000,000
Preferred Stock, Par or Stated Value Per Share		$ 0.01
Shares Held In Trust For Deferred Compensation Plan		95,329
Common Stock, Dividends, Per Share, Declared		$ 0.4050
Beginning Balances (shares) at Dec. 31, 2019	[1]			16,403,776
Beginning Balances at Dec. 31, 2019		$ 561,577	[1]	$ 7,984	[1]	259,253		300,607	(6,267)	4,543	(4,543)
Ending Balances (shares) at Mar. 31, 2020	[1]			16,433,105
Ending Balances at Mar. 31, 2020		$ 584,129	[1]	$ 7,998	[1]	259,521		322,804	(6,194)	5,468	(5,468)
Common Stock, Dividends, Per Share, Declared		$ 0.8450
Beginning Balances (shares) at Dec. 31, 2019	[1]			16,403,776
Beginning Balances at Dec. 31, 2019		$ 561,577	[1]	$ 7,984	[1]	259,253		300,607	(6,267)	4,543	(4,543)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		39,886						39,886
New Accounting Pronouncement or Change in Accounting Principle, Effect of Adoption, Quantification								(30)
Other comprehensive income (loss)		1,805							1,805
Other Comprehensive Income (Loss), Net of Tax		1,805
Dividend declared		(14,009)						14,009
Retirement savings plan and dividend reinvestment plan (shares)				25,576
Dividend reinvestment plan		2,286		$ 13		2,273
Share-based compensation (shares)				34,456
Share-based compensation and tax benefit	[3],[4]	1,762		$ 16		1,746
Treasury stock activities		0								1,116	(1,116)
Ending Balances (shares) at Jun. 30, 2020	[1]			16,463,808
Ending Balances at Jun. 30, 2020		$ 593,277	[1]	$ 8,013	[1]	263,272		326,454	(4,462)	5,659	(5,659)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation		10,319
Common Stock, Dividends, Per Share, Declared		$ 0.4400
Beginning Balances (shares) at Mar. 31, 2020	[1]			16,433,105
Beginning Balances at Mar. 31, 2020		$ 584,129	[1]	$ 7,998	[1]	259,521		322,804	(6,194)	5,468	(5,468)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		10,956						10,956
Other comprehensive income (loss)		1,732							1,732
Other Comprehensive Income (Loss), Net of Tax		1,732
Dividend declared		(7,306)						7,306
Retirement savings plan and dividend reinvestment plan (shares)				21,833
Dividend reinvestment plan		1,932		$ 11		1,921
Share-based compensation (shares)				8,870
Share-based compensation and tax benefit		1,834	[3],[4]	$ 4		1,830	[3],[4]
Treasury stock activities		0								191	(191)
Ending Balances (shares) at Jun. 30, 2020	[1]			16,463,808
Ending Balances at Jun. 30, 2020		$ 593,277	[1]	$ 8,013	[1]	$ 263,272		$ 326,454	$ (4,462)	$ 5,659	$ (5,659)
Preferred Stock, Shares Authorized		2,000,000
Preferred Stock, Par or Stated Value Per Share		$ 0.01
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares Held In Trust For Deferred Compensation Plan		107,141
[1]	2,000,000 shares of preferred stock at $0.01 par value have been authorized. No shares have been issued or are outstanding; accordingly, no information has been included in the statements of stockholders’ equity.
[2]	Includes 107,141 shares at June 30, 2020 , 95,329 shares at December 31, 2019, 105,409 shares at June 30, 2019 and 97,053 shares at December 31, 2018, respectively, held in a Rabbi Trust related to our Non-Qualified Deferred Compensation Plan.
[3]	The shares issued under the SICP are net of shares withheld for employee taxes. For the six months ended June 30, 2020 and 2019 , we withheld 10,319 and 7,635 shares, respectively, for employee taxes.
[4]	Includes amounts for shares issued for directors’ compensation.

Condensed Consolidated Statem_6

Condensed Consolidated Statements of Stockholders' Equity (Parenthetical) (Unaudited) - $ / shares	3 Months Ended				6 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019	Dec. 31, 2018
Statement of Stockholders' Equity [Abstract]
Dividend declared (in dollars per share)	$ 0.4400	$ 0.4050	$ 0.4050	$ 0.3700	$ 0.8450	$ 0.7750
Deferred compensation plan held Rabbi Trust (shares)	107,141		105,409		107,141	105,409	95,329	97,053
Preferred Stock, Shares Authorized	2,000,000				2,000,000		2,000,000
Preferred Stock, Par or Stated Value Per Share	$ 0.01				$ 0.01		$ 0.01
Shares issued under the performance incentive plan withheld for employee taxes (shares)					10,319	7,635

Summary of Accounting Policies

Summary of Accounting Policies	6 Months Ended
	Jun. 30, 2020
Accounting Policies [Abstract]
Summary of Accounting Policies	Summary of Accounting Policies Basis of Presentation References in this document to the “Company,” “Chesapeake Utilities,” “we,” “us” and “our” are intended to mean Chesapeake Utilities Corporation, its divisions and/or its subsidiaries, as appropriate in the context of the disclosure. The accompanying unaudited condensed consolidated financial statements have been prepared in compliance with the rules and regulations of the SEC and GAAP. In accordance with these rules and regulations, certain information and disclosures normally required for audited financial statements have been condensed or omitted. These financial statements should be read in conjunction with the consolidated financial statements and notes thereto, included in our latest Annual Report on Form 10-K for the year ended December 31, 2019 . In the opinion of management, these financial statements reflect all adjustments that are necessary for a fair presentation of our results of operations, financial position and cash flows for the interim periods presented. Where necessary to improve comparability, prior period amounts have been changed to conform to current period presentation. Due to the seasonality of our business, results for interim periods are not necessarily indicative of results for the entire fiscal year. Revenue and earnings are typically greater during the first and fourth quarters, when consumption of energy is highest due to colder temperatures. Beginning in the third quarter of 2019 , our management began executing a strategy to sell the operating assets of PESCO. In the fourth quarter of 2019, we closed on four separate transactions to sell PESCO's assets and contracts. As a result of these sales, we have fully exited the natural gas marketing business, which provided natural gas management and supply services to commercial and industrial customers in Florida, Delaware, Maryland, Pennsylvania, Ohio and other states. Accordingly, PESCO’s historical financial results are reflected in our condensed consolidated financial statements as discontinued operations, which required retrospective application to financial information for all periods presented. Refer to Note 3, Acquisitions and Divestitures, for further information Effects of COVID-19 On March 13, 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 have continued to significantly impact economic conditions in the United States. We are considered an “essential business,” which allows us to continue our operational activities and construction projects while the social distancing restrictions remain in place. In response to the COVID-19 pandemic and related restrictions, we implemented our pandemic response plan, which includes having all employees who can work remotely do so in order to promote social distancing and providing personal protective equipment to field employees to reduce the spread of COVID-19. Impacts from the restrictions imposed in our service territories and the implementation of our pandemic response plan, included reduced energy consumption primarily in the commercial and industrial sectors, incremental expenses associated with COVID-19 including protective personal equipment, premium pay for field employees and higher bad debt expense. The additional operating expenses we incurred support the ongoing delivery of our essential services during these unprecedented times. The negative impact was partially offset by reduced federal income tax expense recognized in connection with implementation of the CARES Act and lower short-term borrowing costs resulting from a decrease in interest rates. As the COVID-19 pandemic is still ongoing, to date we have not established regulatory assets associated with the incremental expense impacts, as currently authorized by the Delaware and Maryland PSCs. In Florida, the PSC requires utility companies seeking regulatory asset treatment for COVID-19 related expenses to individually file a formal petition for consideration. We are committed to communicating timely updates and will continue to monitor developments affecting our employees, customers, suppliers, stockholders and take additional precautions as warranted to operate safely and to comply with the CDC, Occupational Safety and Health Administration, state and local requirements in order to protect our employees, customers and the communities we serve, and update and communicate the ongoing financial impact on our results once determined. Refer to Note 5, Rates and Other Regulatory Activities, for further information on the potential deferral of incremental expenses associated with COVID-19. FASB Statements and Other Authoritative Pronouncements Recently Adopted Accounting Standards Financial Instruments - Credit Losses (ASC 326) - In June 2016, the FASB issued ASU 2016-13, Measurement of Credit Losses on Financial Instruments , which changes how entities account for credit losses for most financial assets and certain other instruments, and subsequent guidance which served to clarify or amend the original standard. ASU 2016-13 and the related amendments require entities to estimate lifetime expected credit losses for trade receivables and to provide additional disclosure related to credit losses. We adopted ASU 2016-13 on January 1, 2020 and recorded an immaterial cumulative effect in retained earnings as of that date. As a result, prior period financial information has not been recast and continues to be reported under the accounting guidance that was effective during those periods. 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 analyzed the balance of our trade receivables based on the underlying service line they pertain to. This resulted in an examination of trade receivables from our energy distribution, energy transmission, energy delivery services and propane operations service lines. Our energy distribution service line consists of all our regulated distribution utility operations on the Delmarva Peninsula and throughout 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 as a component of their 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 compressed natural gas ("CNG") delivery operations. The majority of the customer base these business units serve 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 they present. 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 amounts of revenues earned. 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. During the first quarter of 2020, COVID-19 began to rapidly spread within the United States. Federal, state and local governments throughout the country imposed restrictions to promote social distancing to slow the spread of the virus, which has also had the effect of limiting commercial activity. These measures have resulted in significant job losses and a slowing of economic activity across the United States and in the areas that we serve. We have been identified as an “essential business,” which allowed us to continue operational activity and construction projects with social distancing restrictions in place. We have considered the impact of COVID-19 for the six months ended June 30, 2020, monitored developments that impact our customers’ ability to pay and have revised our estimates of expected credit losses. Our prior estimates for expected credit losses had not included an evaluation of current conditions or forward-looking economic indicators as we were not required to consider those factors under the previous incurred loss accounting guidance. The below table provides a reconciliation of our allowance for credit losses at June 30, 2020 : (in thousands) Balance at December 31, 2019 $ 1,337 Additions: Provision for credit losses 794 Recoveries 450 Deductions: Write offs (477 ) Balance at June 30, 2020 $ 2,104 Fair Value Measurement (ASC 820) - In August 2018, the FASB issued ASU 2018-13, Disclosure Framework - Changes to the Disclosure Requirements for Fair Value Measurement , which removes, modifies and adds certain disclosure requirements on fair value measurements in ASC 820. We adopted ASU 2018-13 beginning January 1, 2020 and, since the changes only impacted disclosures, its adoption did not have a material impact on our financial position or results of operations. Intangibles - Goodwill (ASC 350) - In January 2017, the FASB issued ASU 2017-04, Simplifying the Test for Goodwill Impairment , which simplifies how an entity is required to test goodwill for impairment by eliminating Step 2 from the goodwill impairment test. ASU 2017-04 was effective beginning January 1, 2020. The amendments included in this ASU are to be applied prospectively, and are not expected to have a material impact on our financial position or results of operations.

Calculation of Earnings Per Sha

Calculation of Earnings Per Share	6 Months Ended
	Jun. 30, 2020
Earnings Per Share [Abstract]
Calculation of Earnings Per Share	Calculation of Earnings Per Share Three Months Ended Six Months Ended June 30, June 30, 2020 2019 2020 2019 (in thousands, except shares and per share data) Calculation of Basic Earnings Per Share: Income from Continuing Operations $ 10,661 $ 8,914 $ 39,702 $ 37,725 Income (Loss) from Discontinued Operations 295 (610 ) 184 (757 ) Net Income $ 10,956 $ 8,304 $ 39,886 $ 36,968 Weighted average shares outstanding 16,448,490 16,401,028 16,431,724 16,393,022 Basic Earnings Per Share from Continuing Operations $ 0.65 $ 0.55 $ 2.42 $ 2.31 Basic Earnings (Loss) Per Share from Discontinued Operations 0.02 (0.04 ) 0.01 (0.05 ) Basic Earnings Per Share $ 0.67 $ 0.51 $ 2.43 $ 2.26 Calculation of Diluted Earnings Per Share: Reconciliation of Denominator: Weighted shares outstanding—Basic 16,448,490 16,401,028 16,431,724 16,393,022 Effect of dilutive securities—Share-based compensation 55,113 44,715 56,083 46,311 Adjusted denominator—Diluted 16,503,603 16,445,743 16,487,807 16,439,333 Diluted Earnings Per Share from Continuing Operations $ 0.64 $ 0.54 $ 2.41 $ 2.30 Diluted Earnings (Loss) Per Share from Discontinued Operations 0.02 (0.04 ) 0.01 (0.05 ) Diluted Earnings Per Share $ 0.66 $ 0.50 $ 2.42 $ 2.25

Acquisitions and Divestitures (

Acquisitions and Divestitures (Notes)	6 Months Ended
	Jun. 30, 2020
Discontinued Operations and Disposal Groups [Abstract]
Business Combination Disclosure [Text Block]	Acquisitions and Divestitures Pending Acquisition of Elkton Gas In July 2020, we closed on the acquisition of Elkton Gas, which provides natural gas distribution service to approximately 7,000 residential and commercial customers within a franchised area of Cecil County, Maryland. The purchase price is approximately $15.0 million . Elkton Gas’ territory is contiguous to our franchised service territory in Cecil County, Maryland. Elkton Gas will continue to operate out of its existing office with the same local personnel who are also expected to serve our existing franchised service territory in Cecil County. Acquisition of Boulden In December 2019, Sharp acquired certain propane operating assets of Boulden, which provides propane distribution service to approximately 5,200 customers in Delaware, Maryland and Pennsylvania, for approximately $24.6 million , net of cash acquired. Additionally, the purchase price included $0.2 million of working capital. We recorded contingent consideration of $0.6 million related to the seller's adherence to various provisions contained in the contract through the first anniversary of the transaction closing. We accounted for the purchase of the operating assets of Boulden as a business combination and integrated the business into our Sharp operation. There are multiple strategic benefits to this acquisition including it: (i) overlays with the pending Elkton Gas acquisition to establish an integrated energy delivery platform in Cecil County, Maryland; (ii) includes an established customer base with opportunities for future growth; (iii) enables operational synergies, including supply, for the northern Delmarva Peninsula; and (iv) provides opportunities to market additional services and pricing programs to these customers. In connection with this acquisition, we recorded $8.3 million in property, plant and equipment, $5.1 million in intangible assets associated with customer relationships and non-compete agreements and $11.2 million in goodwill, all of which is deductible for income tax purposes. The amounts recorded in conjunction with the acquisition are preliminary, and subject to adjustment based on contractual provisions and will be finalized in the fourth quarter of 2020. For the three months ended June 30, 2020 , Boulden generated operating revenue and income of $0.8 million and $0.1 million , respectively. For the six months ended June 30, 2020 , Boulden generated operating revenue and income of $3.6 million and $1.4 million , respectively. Divestiture of PESCO During the fourth quarter of 2019, we sold PESCO's assets and contracts in four separate transactions and exited the natural gas marketing business. As a result of the sales agreements, we began to report PESCO as discontinued operations during the third quarter of 2019, excluded PESCO's performance from continuing operations for all periods presented and classified its assets and liabilities as held for sale where applicable. We received a total of $23.1 million in cash consideration from the buyers, inclusive of working capital of $8.0 million and recognized total pre-tax gain of $7.5 million ( $5.5 million after tax) in connection with these transactions, $7.3 million of this gain was recognized in the fourth quarter of 2019. Operating revenues and costs of sales from the previous reporting periods, which were previously eliminated in consolidation, have been grossed up and are now reflected as a component of operating revenues and costs of sales for the three and six months ended June 30, 2019 . We recast these amounts because, upon completion of the sales transactions, we continued to provide and receive services from the buyers through the remainder of the contractual terms. A summary of discontinued operations presented in the condensed consolidated statements of income includes the following: Three Months Six Months June 30, June 30, (in thousands) 2020 2019 2020 2019 Operating revenues (1) $ 3 $ 41,280 $ 23 $ 118,302 Cost of sales (1) 10 40,539 1 115,701 Other operating expenses 39 1,470 197 3,460 Operating loss (46 ) (729 ) (175 ) (859 ) Interest and other expense (6 ) (101 ) (29 ) (166 ) Loss from Discontinued Operations before income taxes (52 ) (830 ) (204 ) (1,025 ) Gain on sale of Discontinued Operations 200 — 200 Income tax benefit (147 ) (220 ) (188 ) (268 ) Gain (Loss) from Discontinued Operations, Net of Tax $ 295 $ (610 ) $ 184 $ (757 ) (1) Included in operating revenues and cost of sales for the three and six months ended June 30, 2019 , is $4.9 million and $14.8 million , respectively, representing amounts which had been previously eliminated in consolidation related to intercompany activity that continued with the buyers after the disposition of the assets of PESCO. Since the disposition of the assets and contracts of PESCO was completed in the fourth quarter of 2019, there were no assets or liabilities classified as held for sale at June 30, 2020 and December 31, 2019. We have elected not to separately disclose discontinued operations on the condensed consolidated statements of cash flows. The following table summarizes significant statements of cash flows data related to the discontinued operations of PESCO: (in thousands) Three Months Ended June 30, 2019 Six Months Ended June 30, 2019 Depreciation and amortization $ 146 $ 291 Deferred income taxes $ (1,021 ) $ 375 Realized loss on commodity contracts $ (97 ) $ (681 )
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]	Divestiture of PESCO During the fourth quarter of 2019, we sold PESCO's assets and contracts in four separate transactions and exited the natural gas marketing business. As a result of the sales agreements, we began to report PESCO as discontinued operations during the third quarter of 2019, excluded PESCO's performance from continuing operations for all periods presented and classified its assets and liabilities as held for sale where applicable. We received a total of $23.1 million in cash consideration from the buyers, inclusive of working capital of $8.0 million and recognized total pre-tax gain of $7.5 million ( $5.5 million after tax) in connection with these transactions, $7.3 million of this gain was recognized in the fourth quarter of 2019. Operating revenues and costs of sales from the previous reporting periods, which were previously eliminated in consolidation, have been grossed up and are now reflected as a component of operating revenues and costs of sales for the three and six months ended June 30, 2019 . We recast these amounts because, upon completion of the sales transactions, we continued to provide and receive services from the buyers through the remainder of the contractual terms. A summary of discontinued operations presented in the condensed consolidated statements of income includes the following: Three Months Six Months June 30, June 30, (in thousands) 2020 2019 2020 2019 Operating revenues (1) $ 3 $ 41,280 $ 23 $ 118,302 Cost of sales (1) 10 40,539 1 115,701 Other operating expenses 39 1,470 197 3,460 Operating loss (46 ) (729 ) (175 ) (859 ) Interest and other expense (6 ) (101 ) (29 ) (166 ) Loss from Discontinued Operations before income taxes (52 ) (830 ) (204 ) (1,025 ) Gain on sale of Discontinued Operations 200 — 200 Income tax benefit (147 ) (220 ) (188 ) (268 ) Gain (Loss) from Discontinued Operations, Net of Tax $ 295 $ (610 ) $ 184 $ (757 ) (1) Included in operating revenues and cost of sales for the three and six months ended June 30, 2019 , is $4.9 million and $14.8 million , respectively, representing amounts which had been previously eliminated in consolidation related to intercompany activity that continued with the buyers after the disposition of the assets of PESCO. Since the disposition of the assets and contracts of PESCO was completed in the fourth quarter of 2019, there were no assets or liabilities classified as held for sale at June 30, 2020 and December 31, 2019. We have elected not to separately disclose discontinued operations on the condensed consolidated statements of cash flows. The following table summarizes significant statements of cash flows data related to the discontinued operations of PESCO: (in thousands) Three Months Ended June 30, 2019 Six Months Ended June 30, 2019 Depreciation and amortization $ 146 $ 291 Deferred income taxes $ (1,021 ) $ 375 Realized loss on commodity contracts $ (97 ) $ (681 )

Revenue Recognition (Notes)

Revenue Recognition (Notes)	6 Months Ended
	Jun. 30, 2020
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customer [Text Block]	Revenue Recognition We recognize revenue when our performance obligations under contracts with customers have been satisfied, which generally occurs when our businesses have delivered or transported natural gas, electricity or propane to customers. We exclude sales taxes and other similar taxes from the transaction price. Typically, our customers pay for the goods and/or services we provide in the month following the satisfaction of our performance obligation. The revenues in the following tables exclude operating revenues from PESCO that are reflected as discontinued operations. The following table displays our revenue from continuing operations by major source based on product and service type for the three months ended June 30, 2020 and 2019 : Three months ended June 30, 2020 Three Months Ended June 30, 2019 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Regulated Energy Unregulated Energy Other and Eliminations Total Energy distribution Delaware natural gas division $ 11,758 $ — $ — $ 11,758 $ 8,256 $ — $ — $ 8,256 Florida natural gas division 7,231 — — 7,231 7,015 — — 7,015 FPU electric distribution 15,701 — — 15,701 20,464 — — 20,464 FPU natural gas distribution 19,498 — — 19,498 18,663 — — 18,663 Maryland natural gas division 3,979 — — 3,979 3,186 — — 3,186 Sandpiper natural gas/propane operations 2,858 — — 2,858 3,482 — — 3,482 Total energy distribution 61,025 — — 61,025 61,066 — — 61,066 Energy transmission Aspire Energy — 4,555 — 4,555 — 5,422 — 5,422 Eastern Shore 18,277 — — 18,277 17,740 — — 17,740 Peninsula Pipeline 5,361 — — 5,361 3,565 — — 3,565 Total energy transmission 23,638 4,555 — 28,193 21,305 5,422 — 26,727 Energy generation Eight Flags — 3,694 — 3,694 — 4,235 — 4,235 Propane operations Propane delivery operations — 17,260 — 17,260 — 17,488 — 17,488 Energy delivery services Marlin Gas Services — 2,248 — 2,248 — 1,108 — 1,108 Other and eliminations Eliminations (11,145 ) (16 ) (4,340 ) (15,501 ) (8,968 ) (2,628 ) (4,618 ) (16,214 ) Other — — 132 132 — — 132 132 Total other and eliminations (11,145 ) (16 ) (4,208 ) (15,369 ) (8,968 ) (2,628 ) (4,486 ) (16,082 ) Total operating revenues (1) $ 73,518 $ 27,741 $ (4,208 ) $ 97,051 $ 73,403 $ 25,625 $ (4,486 ) $ 94,542 (1) Total operating revenues for the three months ended June 30, 2020 , include other revenue (revenues from sources other than contracts with customers) of $0.1 million and $0.04 million for our Regulated and Unregulated Energy segments, respectively, and $(0.3) million and $0.1 million for our Regulated and Unregulated Energy segments, respectively, for the three months ended June 30, 2019 . The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the Maryland division and Sandpiper and late fees. The following table displays our revenue from continuing operations by major source based on product and service type for the six months ended June 30, 2020 and 2019 : Six months ended June 30, 2020 Six months ended June 30, 2019 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Regulated Energy Unregulated Energy Other and Eliminations Total Energy distribution Delaware natural gas division $ 38,325 $ — $ — $ 38,325 $ 35,805 $ — $ — $ 35,805 Florida natural gas division 15,708 — — 15,708 14,915 — — 14,915 FPU electric distribution 29,920 — — 29,920 34,842 — — 34,842 FPU natural gas distribution 44,942 — — 44,942 42,449 — — 42,449 Maryland natural gas division 13,117 — — 13,117 13,233 — — 13,233 Sandpiper natural gas/propane operations 9,150 — — 9,150 10,564 — — 10,564 Total energy distribution 151,162 — — 151,162 151,808 — — 151,808 Energy transmission Aspire Energy — 14,336 — 14,336 — 18,892 — 18,892 Eastern Shore 37,556 — — 37,556 36,796 — — 36,796 Peninsula Pipeline 10,185 — — 10,185 7,131 — — 7,131 Total energy transmission 47,741 14,336 — 62,077 43,927 18,892 — 62,819 Energy generation Eight Flags — 8,017 — 8,017 — 8,377 — 8,377 Propane operations Propane delivery operations — 55,883 — 55,883 — 64,017 — 64,017 Energy delivery services Marlin Gas Services — 3,557 — 3,557 — 3,541 — 3,541 Other and eliminations Eliminations (22,430 ) (40 ) (8,749 ) (31,219 ) (18,714 ) (8,123 ) (8,984 ) (35,821 ) Other — — 264 264 — — 264 264 Total other and eliminations (22,430 ) (40 ) (8,485 ) (30,955 ) (18,714 ) (8,123 ) (8,720 ) (35,557 ) Total operating revenues (1) $ 176,473 $ 81,753 $ (8,485 ) $ 249,741 $ 177,021 $ 86,704 $ (8,720 ) $ 255,005 (1) Total operating revenues for the six months ended June 30, 2020 , include other revenue (revenues from sources other than contracts with customers) of $0.8 million and $0.1 million for our Regulated and Unregulated Energy segments, respectively, and $(0.2) million and $0.2 million for our Regulated and Unregulated Energy segments, respectively, for the six months ended June 30, 2019 . The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the Maryland division and Sandpiper and late 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 condensed consolidated balance sheets. The balances of our trade receivables, contract assets, and contract liabilities as of June 30, 2020 and December 31, 2019 were as follows: Trade Receivables Contract Assets (Current) Contract Assets (Non-current) Contract Liabilities (Current) (in thousands) Balance at 12/31/2019 $ 47,430 $ 18 $ 3,465 $ 589 Balance at 6/30/2020 35,764 18 4,338 347 Increase (decrease) $ (11,666 ) $ — $ 873 $ (242 ) Our trade receivables are included in trade and other receivables in the condensed consolidated balance sheets. Our current contract assets are included in other current assets in the condensed consolidated balance sheet. Our non-current contract assets are included in other assets in the condensed consolidated balance sheet and primarily 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 condensed consolidated balance sheets and relate to non-refundable prepaid fixed fees for our Mid-Atlantic propane delivery operation's retail offerings. Our performance obligation is satisfied over the term of the respective retail offering plan on a ratable basis. For each of the three months ended June 30, 2020 and 2019, we recognized revenue of $0.2 million . For the six months ended June 30, 2020 and 2019, we recognized revenue of $0.6 million and $0.5 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 June 30, 2020 , are expected to be recognized as follows: (in thousands) 2020 2021 2022 2023 2024 2025 2026 and thereafter Eastern Shore and Peninsula Pipeline $ 19,059 $ 35,720 $ 28,513 $ 22,930 $ 20,641 $ 19,283 $ 175,743 Natural gas distribution operations 1,950 4,124 5,167 4,936 4,699 4,166 32,996 FPU electric distribution 283 566 566 566 566 275 825 Total revenue contracts with remaining performance obligations $ 21,292 $ 40,410 $ 34,246 $ 28,432 $ 25,906 $ 23,724 $ 209,564

Rates and Other Regulatory Acti

Rates and Other Regulatory Activities	6 Months Ended
	Jun. 30, 2020
Regulated Operations [Abstract]
Public Utilities Disclosure [Text Block]	Rates and Other Regulatory Activities 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, our intrastate pipeline subsidiary, is subject to regulation (excluding cost of service) by the Florida PSC. Delaware CGS: In August 2019, we filed with the Delaware PSC an application seeking an order that will establish the regulatory accounting treatment and valuation methodology for the acquisition of propane CGS owned by our affiliate, Sharp and the conversion of the CGS to natural gas service. We proposed to acquire each CGS one at a time and to pay replacement cost for each CGS system. In addition, we requested authorization to pay for and capitalize the CGS residents’ behind- the-meter conversion costs. Our existing natural gas customers will be protected against subsidizing the acquisitions and conversions of the CGS systems because we will complete only those systems that meet our economic test. In September 2019, the Delaware PSC issued an order to open a docket for the purpose of reviewing our application and to conduct evidentiary hearings on the matter. A final order was approved by the Delaware PSC in June 2020. Maryland Approval of the Elkton Gas Acquisition: In December 2019, we entered into an agreement with SJI to acquire its subsidiary, Elkton Gas, which provides natural gas distribution service to approximately 7,000 residential and commercial customers within a franchised area of Cecil County, Maryland. Upon completion of the transaction, Elkton Gas will become our wholly-owned subsidiary. Elkton Gas territory is contiguous to our franchised service territory in Cecil County, Maryland. In May 2020, we, the Maryland Office of People’s Counsel and the Maryland PSC staff reached a settlement agreement with regard to our acquisition of Elkton Gas. The parties participated in an evidentiary hearing before the Maryland Public Law Judge, providing testimony in support of the proposed settlement agreement. On June 29, 2020, the Maryland PSC issued a final order approving the settlement agreement. The acquisition was closed in July 2020. We expect Elkton Gas will continue to operate out of its existing office with the same local personnel. Application for Authority to Exercise a Franchise: In March 2020, we filed with the Maryland PSC an application seeking approval to exercise a franchise granted to us by the Board of County Commissioners of Somerset County, Maryland in December 2019. The application was approved in June 2020. Florida Electric Limited Proceeding-Storm Recovery (Pre-Hurricane Michael ): In February 2018, FPU filed a petition with the Florida PSC, requesting recovery of incremental storm restoration costs related to several hurricanes and tropical storms, along with the replenishment of the storm reserve to its pre-storm level of $1.5 million . As a result of these hurricanes and tropical storms, FPU’s storm reserve was depleted and, at the time of filing the petition, had a deficit of $0.8 million . This matter went to hearing in December 2018 and was subsequently approved at the March 2019 Agenda with the Final Order issued on March 25, 2019. FPU received approval to begin a surcharge on customer bills for two years beginning in April 2019, to recover storm-related costs and replenish the storm reserve. Hurricane Michael: In October 2018, Hurricane Michael passed through FPU's electric distribution operation's service territory in Northwest Florida. The hurricane caused widespread and severe damage to FPU's infrastructure resulting in the loss of electric service to 100 percent of its customers in the Northwest Florida service territory. FPU, after exerting extraordinary hurricane restoration efforts, restored service to those customers who were able to accept it. FPU expended more than $65.0 million to restore service, which was recorded as new plant and equipment, charged against FPU’s accumulated depreciation or charged against FPU’s storm reserve. Additionally, amounts currently being reviewed by the Florida PSC for regulatory asset treatment have been recorded as receivables and other deferred charges. In August 2019, FPU filed a limited proceeding requesting recovery of storm-related costs associated with Hurricane Michael (capital and expenses) through a change in base rates. FPU also requested treatment and recovery of certain storm-related costs as regulatory assets for items currently not allowed to be recovered through the storm reserve as well as the recovery of capital replaced as a result of the storm. Recovery of these costs includes a component of an overall return on capital additions and regulatory assets. In the fourth quarter of 2019, FPU along with the Office of Public Counsel in Florida, filed a joint motion with the Florida PSC to approve an interim rate increase, subject to refund, pending the final ruling on the recovery of the restoration costs incurred. The petition was approved by the Florida PSC in November 2019 and temporary rate increases were implemented effective January 2020. We have fully reserved these interim rates, pending a final resolution and settlement of the limited proceeding. In March 2020, we filed an update to our original filing to account for actual charges incurred through December 2019, revised the amortization period of the storm-related costs from 30 years as originally requested to 10 years, and included costs related to Hurricane Dorian of approximately $1.2 million in this filing. We continue to work with the Florida PSC and the petition is currently on the schedule for approval at the Florida PSC Agenda in September 2020. Electric Depreciation Study: In September 2019, FPU filed a petition, with the Florida PSC, for approval of its consolidated electric depreciation rates. Once approved, we expect the new rates to be retroactively effective to January 1, 2020. The petition, was joined to the open docket regarding Hurricane Michael, and is currently on the schedule for hearing at the Florida PSC agenda in September 2020. West Palm Beach Expansion Project: In June 2019, Peninsula Pipeline filed with the Florida PSC for approval of its Transportation Service Agreement with FPU. Peninsula Pipeline will construct several new interconnection points and pipeline expansions in Palm Beach County, Florida, which will enable FPU to serve an industrial research park and several new residential developments. Peninsula Pipeline will provide transportation service to FPU, increasing reliability, system pressure as well as introducing diversity in fuel source for natural gas to serve the increased demand in these areas. The petition was approved by the Florida PSC at the August 6, 2019 Agenda. Interim services began in the fourth quarter of 2019. We expect to complete the remainder of the project in phases through the second quarter of 2021. Callahan Pipeline, Nassau County: Peninsula Pipeline and Seacoast Gas Transmission are constructing a jointly owned 26 -mile, 16 -inch steel pipeline that interconnects to the Cypress Pipeline interstate system in western Nassau County in order to serve growing demand in both Nassau and Duval counties, Florida. The Callahan pipeline will terminate into the existing Peninsula Pipeline-Peoples Gas jointly owned pipeline, which serves Amelia Island and the Peoples Gas distribution system. The Callahan Pipeline enhances FPU’s ability to expand service into Nassau County and enables Peoples Gas to enhance its system pressure and the reliability of its service in Duval County. This project was placed in-service in the second quarter of 2020. Eastern Shore Del-Mar Energy Pathway Project: In December 2019, the FERC issued an order approving the construction of the Del-Mar Energy Pathway project. The order, which was applied for in September 2018 by Eastern Shore, approved the construction and operation of new facilities that will provide an additional 14,300 Dts/d of firm service to four customers. Facilities to be constructed include six miles of pipeline looping in Delaware; 13 miles of new mainline extension in Sussex County, Delaware and Wicomico and Somerset Counties in Maryland; and new pressure control and delivery stations in these counties. The benefits of this project include: (i) additional natural gas transmission pipeline infrastructure in eastern Sussex County, Delaware, and (ii) extension of Eastern Shore’s pipeline system, for the first time, into Somerset County, Maryland. Construction on the project began in January 2020, and Eastern Shore anticipates that this project will be fully in-service by the beginning of the fourth quarter of 2021. Capital Cost Surcharge: In December 2019, the FERC approved Eastern Shore’s proposed capital cost surcharge to become effective January 1, 2020. The surcharge, an approved item in the settlement of Eastern Shore’s last general rate case, allows Eastern Shore to recover capital costs associated with mandated highway or railroad relocation projects that required the replacement of existing Eastern Shore facilities. Eastern Shore expects to recover $0.5 million in capital cost surcharges on an annual basis. As Eastern Shore continues to relocate its pipeline and incur capital expenditures, we will continue to utilize the surcharge to seek recovery of its costs. Renewable Natural Gas Tariff: In October 2019, Eastern Shore filed an application with the FERC to include renewable natural gas (biogas) utilization and standards in its tariff. Eastern Shore had proposed changes to its gas quality specifications that would enable it to accommodate renewable natural gas at various receipt points on its system. Changes to the gas quality specifications would ensure interchangeability of renewable natural gas with the natural gas currently delivered to Eastern Shore. The tariffs became effective in November 2019. COVID-19 Impact We are monitoring the global outbreak of COVID-19 and taking steps to mitigate the potential risks posed by its spread. We provide an “essential service” to our customers, which means that it is paramount that we keep our employees who operate our business safe and informed. We have taken and are continuously monitoring and updating precautions and protocols to ensure the safety of our employees and customers. As an “essential business” we are allowed to continue operational activity and construction projects with appropriate safety precautions, personal protective equipment and social distancing restrictions in place. We have taken steps to assure our customers that disconnections for non-payment will be temporarily suspended. We are also working with our suppliers to understand the potential impacts to our supply chain; if material negative impacts are identified, we will work to mitigate them. This is a rapidly evolving situation, and could lead to extended disruption of economic activity in our markets. We will continue to monitor developments affecting our employees, customers, suppliers and shareholders, and will take additional precautions as warranted to comply with the CDC, state and local requirements and recommendations to protect our employees, customers and the communities we serve. As a result of these measures, we are incurring costs associated with crisis management and the pandemic response including restrictions put in place by the state PSCs on utility disconnects for non-payment, technology costs incurred to expand work from home capabilities, additional sanitation and cleaning costs and costs of acquiring personal protective equipment as well as other expenses. We are tracking and analyzing whether these costs qualify for cost recovery and could be classified as regulatory assets. In April 2020, the Maryland PSC issued an order that authorized utilities to establish a regulatory asset to record prudently incurred incremental costs related to COVID-19, beginning on March 16, 2020. The Maryland PSC found that the creation of a regulatory asset for COVID-19 related expenses will facilitate the recovery of those costs prudently incurred to serve customers during this period, and that the deferral of such costs is appropriate because the current catastrophic health emergency is outside the control of the utility and is a non-recurring event. In May 2020, the Delaware PSC issued an order authorizing Delaware utilities to establish a regulatory asset to record COVID-19 related incremental costs incurred to ensure customers have essential utility services, for the period beginning on March 24, 2020 and ending 30 days after the state of emergency ends. The creation of the regulatory asset for COVID-19 related costs offers utilities the ability to seek recovery of those costs. The Florida PSC has not issued a regulatory order authorizing utilities to defer incremental costs related to COVID-19 as a regulatory asset. As such, utilities have to petition the Florida PSC for approval to establish a regulatory asset for these costs. As of June 30, 2020, we have not deferred any COVID-19 related incremental costs as regulatory assets as we continue to assess these costs. We will continue to monitor similar orders issued by the FERC or the respective PSCs in our service territories to identify additional relief which could be available to our regulated businesses. Summary TCJA Table The following table summarizes the TCJA impact on our regulated businesses: Regulatory Liabilities related to Accumulated Deferred Income Taxes ("ADIT") Operation and Regulatory Jurisdiction Amount (in thousands) Status Status of Customer Rate impact related to lower federal corporate income tax rate Eastern Shore (FERC) $34,190 Will be addressed in Eastern Shore's next rate case filing. Implemented one-time bill credit (totaling $0.9 million) in April 2018. Customer rates were adjusted in April 2018. Delaware Division (Delaware PSC) $12,788 PSC approved amortization of ADIT in January 2019. Implemented one-time bill credit (totaling $1.5 million) in April 2019. Customer rates were adjusted in March 2019. Maryland Division (Maryland PSC) $4,029 PSC approved amortization of ADIT in May 2018. Implemented one-time bill credit (totaling $0.4 million) in July 2018. Customer rates were adjusted in May 2018. Sandpiper Energy (Maryland PSC) $3,739 PSC approved amortization of ADIT in May 2018. Implemented one-time bill credit (totaling $0.6 million) in July 2018. Customer rates were adjusted in May 2018. Chesapeake Florida Gas Division/Central Florida Gas (Florida PSC) $8,244 PSC issued order authorizing amortization and retention of net ADIT liability by the Company in February 2019. Florida PSC's final order was issued in February 2019. Excluding GRIP, tax savings arising from the TCJA rate reduction will be retained by the Company. GRIP: Tax savings for 2018 will be refunded to customers in 2020 through the annual GRIP cost recovery mechanism. Future customer GRIP surcharges will be adjusted to reflect tax savings associated with TCJA. FPU Natural Gas (excludes Fort Meade and Indiantown) (Florida PSC) $19,201 Same treatment on a net basis as Chesapeake Florida Gas Division (above). Same treatment on a net basis as Chesapeake Florida Gas Division (above). FPU Fort Meade and Indiantown Divisions $312 Same treatment on a net basis as Chesapeake Florida Gas Division (above). Tax rate reduction: The impact was immaterial for the divisions. GRIP (Applicable to Fort Meade division only): Same treatment as Chesapeake Florida Gas Division (above). FPU Electric (Florida PSC) $6,823 In January 2019, PSC issued order approving amortization of ADIT through purchased power cost recovery, storm reserve and rates. TCJA benefit is provided to customers through a combination of reductions to the fuel cost recovery rate, base rates, as well as application to the storm reserve over the next several years.

Environmental Commitments and C

Environmental Commitments and Contingencies	6 Months Ended
	Jun. 30, 2020
Environmental Remediation Obligations [Abstract]
Environmental Commitments and Contingencies	Environmental Commitments and Contingencies 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 June 30, 2020 and December 31, 2019 , we had approximately $6.1 million and $8.0 million , respectively, in environmental liabilities related to FPU’s MGP sites in Key West, Pensacola, Sanford and West Palm Beach. FPU has approval to recover, from insurance and through customer rates, up to $14.0 million of its environmental costs related to its MGP sites. As of June 30, 2020 and December 31, 2019 , we had recovered approximately $12.2 million and $11.9 million , respectively, leaving approximately $1.8 million and $2.1 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. The following is a summary of our remediation status and estimated costs to implement clean-up of our key MGP sites: MGP Site (Jurisdiction) Status Estimated Cost to Clean up (Expect to Recover through Rates with Customers) West Palm Beach (Florida) Remedial actions approved by the Florida Department of Environmental Protection have been implemented on the east parcel of the site. We expect to implement similar remedial actions on the site's west parcel in 2020. Between $3.3 million to $14.2 million, including costs associated with the relocation of FPU’s operations at this site, and any potential costs associated with future redevelopment of the properties. Sanford (Florida) In March 2018, the United States Environmental Protection Agency ("EPA") approved a "site-wide ready for anticipated use" status, which is the final step before delisting a site. Construction has been completed and restrictive covenants are in place to ensure protection of human health. The only remaining activity is long-term groundwater monitoring. FPU's remaining remediation expenses, including attorneys' fees and costs, are anticipated to be immaterial. Winter Haven (Florida) Remediation is ongoing. Not expected to exceed $0.4 million. Seaford (Delaware) Conducted investigations of on-site and off-site impacts in the vicinity of the site, from 2014 through 2018, and submitted the findings to Delaware Department of Natural Resources and Environmental Control ("DNREC") in a March 2019 report. An interim action involving air-sparging/vapor extraction is being implemented, in accordance with the DNREC-approved Work Plan. Between $0.2 million and $0.5 million.

Other Commitments and Contingen

Other Commitments and Contingencies	6 Months Ended
	Jun. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
Other Commitments and Contingencies	Other Commitments and Contingencies Natural Gas and Electric 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 are effective as of April 1, 2020 and expire on March 31, 2023. Previously, our Delmarva Peninsula natural gas distribution operations had asset management agreements with PESCO to manage their natural gas transportation and storage capacity. See Note 3, Acquisitions and Divestitures, for additional details regarding the sale of PESCO's assets and contracts. In May 2019, FPU natural gas distribution operations and Eight Flags entered into separate asset management agreements with Emera Energy Services, Inc. to manage their natural gas transportation capacity. The parties entered into short-term agreements for a one year term beginning July 2019 through July 2020. The parties also entered into long-term agreements for a 10 -year term that will commence in July 2020. Chesapeake Utilities' Florida Division has firm transportation service contracts with Florida Gas Transmission Company ("FGT") and Gulfstream Natural Gas System, LLC ("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 two 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 June 30, 2020 , FPU was in compliance with all of the requirements of its fuel 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. 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 June 30, 2020 was $37.0 million . The aggregate amount guaranteed at June 30, 2020 was approximately $11.2 million with the guarantees expiring on various dates through March 2, 2021 . At June 30, 2020 , the corporate guarantees related to PESCO were less than $0.1 million and are expected to be terminated in the third quarter of 2020. See Note 3, Acquisitions and Divestitures , for additional details on the sale of assets and contracts for PESCO. Chesapeake Utilities also guarantees the payment of FPU’s first mortgage bonds. The maximum exposure under this guarantee is the outstanding principal plus accrued interest balances. The outstanding principal balances of FPU’s first mortgage bonds approximate their carrying values. See Note 15 , Long-Term Debt , for further details. As of June 30, 2020 , we have issued letters of credit totaling approximately $4.4 million related to the electric transmission services for FPU's electric division, the firm transportation service agreement between TETLP and our Delaware and Maryland divisions and our current and previous primary insurance carriers. These letters of credit have various expiration dates through October 22, 2020 . There have been no draws on these letters of credit as of June 30, 2020 . We do not anticipate that the counterparties will draw upon these letters of credit, and we expect that they will be renewed to the extent necessary in the future. At June 30, 2020

Segment Information

Segment Information	6 Months Ended
	Jun. 30, 2020
Segment Reporting [Abstract]
Segment Information	Segment Information We use the management approach to identify operating segments. We organize our business around differences in regulatory environment and the operating results of each segment are regularly reviewed by the chief operating decision maker (our Chief Executive Officer) 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 operations, and the new mobile compressed natural gas distribution and pipeline solutions subsidiary. 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. Effective in the third quarter of 2019, the natural gas marketing and related services subsidiary (PESCO), previously reported in the Unregulated Energy segment, are reflected in discontinued operations. See Note 3, Acquisitions and Divestitures for additional details of the sale of PESCO. 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 financial information about our reportable segments: Three Months Ended Six Months Ended June 30, June 30, 2020 2019 2020 2019 (in thousands) Operating Revenues, Unaffiliated Customers Regulated Energy $ 73,043 $ 72,880 $ 175,536 $ 175,951 Unregulated Energy 24,008 21,662 74,205 79,054 Total operating revenues, unaffiliated customers $ 97,051 $ 94,542 $ 249,741 $ 255,005 Intersegment Revenues (1) Regulated Energy $ 475 $ 523 $ 937 $ 1,070 Unregulated Energy 3,733 3,963 7,548 7,650 Other businesses 132 132 264 264 Total intersegment revenues $ 4,340 $ 4,618 $ 8,749 $ 8,984 Operating Income Regulated Energy $ 18,006 $ 18,028 $ 45,894 $ 47,769 Unregulated Energy 281 (771 ) 14,142 14,486 Other businesses and eliminations (310 ) 908 75 32 Operating income 17,977 18,165 60,111 62,287 Other income (expense), net (279 ) (320 ) 3,039 (380 ) Interest charges 5,054 5,552 10,868 11,180 Income from Continuing Operations before Income Taxes 12,644 12,293 52,282 50,727 Income Taxes on Continuing Operations 1,983 3,379 12,580 13,002 Income from Continuing Operations 10,661 8,914 39,702 37,725 Income (loss) from Discontinued Operations, Net of Tax 295 (610 ) 184 (757 ) Net Income $ 10,956 $ 8,304 $ 39,886 $ 36,968 (1) All significant intersegment revenues are billed at market rates and have been eliminated from consolidated operating revenues. (in thousands) June 30, 2020 December 31, 2019 Identifiable Assets Regulated Energy segment $ 1,477,616 $ 1,434,066 Unregulated Energy segment 296,140 296,810 Other businesses and eliminations 48,419 52,322 Total identifiable assets $ 1,822,175 $ 1,783,198

Stockholder's Equity - Accumula

Stockholder's Equity - Accumulated Other Comprehensive Income (Loss)	6 Months Ended
	Jun. 30, 2020
Equity [Abstract]
Accumulated Other Comprehensive Income (Loss)	Stockholder's Equity Accumulated Other Comprehensive 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 tables present the changes in the balance of accumulated other comprehensive (loss)/income as of June 30, 2020 and 2019 . All amounts except the stranded tax reclassification are presented net of tax. Defined Benefit Commodity Interest Rate Pension and Contracts Swap Postretirement Cash Flow Cash Flow Plan Items Hedges Hedges Total (in thousands) As of December 31, 2019 $ (4,933 ) $ (1,334 ) $ — $ (6,267 ) Other comprehensive income (loss) before reclassifications — 2,770 (29 ) 2,741 Amounts reclassified from accumulated other comprehensive income (loss) 132 (1,060 ) (8 ) (936 ) Net current-period other comprehensive income 132 1,710 (37 ) 1,805 As of June 30, 2020 $ (4,801 ) $ 376 $ (37 ) $ (4,462 ) (in thousands) As of December 31, 2018 $ (5,928 ) $ (785 ) $ — $ (6,713 ) Other comprehensive income before reclassifications — 1,000 — 1,000 Amounts reclassified from accumulated other comprehensive income/(loss) 213 (132 ) — 81 Net prior-period other comprehensive income 213 868 — 1,081 Prior-year reclassification — (115 ) — (115 ) As of June 30, 2019 $ (5,715 ) $ (32 ) $ — $ (5,747 ) The following table presents amounts reclassified out of accumulated other comprehensive loss for the three and six months ended June 30, 2020 and 2019 . Deferred gains or losses for our commodity contracts and interest rate swap cash flow hedges are recognized in earnings upon settlement. Three Months Ended Six Months Ended June 30, June 30, 2020 2019 2020 2019 (in thousands) Amortization of defined benefit pension and postretirement plan items: Prior service credit (1) $ 19 $ 19 $ 38 $ 39 Net loss (1) (108 ) (163 ) (215 ) (328 ) Total before income taxes (89 ) (144 ) (177 ) (289 ) Income tax benefit 23 37 45 76 Net of tax (66 ) (107 ) (132 ) (213 ) Gains and losses on commodity contracts cash flow hedges: Propane swap agreements (2) 238 252 1,465 858 Natural gas swaps (2)(3) — — — 11 Natural gas futures (2)(3) — (125 ) — (698 ) Total before income taxes 238 127 1,465 171 Income tax expense (66 ) (34 ) (405 ) (39 ) Net of tax 172 93 1,060 132 Gains on interest rate swap cash flow hedges: Interest rate swap agreements 11 — 11 — Total before income taxes 11 — 11 — Income tax expense (3 ) — (3 ) — Net of tax 8 — 8 — Total reclassifications for the period $ 114 $ (14 ) $ 936 $ (81 ) (1) These amounts are included in the computation of net periodic costs (benefits). See Note 10 , Employee Benefit Plans , for additional details. (2) These amounts are included in the effects of gains and losses from derivative instruments. See Note 13, Derivative Instruments , for additional details. (3) PESCO's results are reflected as discontinued operations in our condensed consolidated statements of income. Amortization of defined benefit pension and postretirement plan items is included in other expense, net gains and losses on propane swap agreements, call options and natural gas futures contracts are included in cost of sales, the realized gain or loss on interest rate swap agreements is recognized as a component of interest charges in the accompanying condensed consolidated statements of income. The income tax benefit is included in income tax expense in the accompanying condensed consolidated statements of income.

Employee Benefit Plans

Employee Benefit Plans	6 Months Ended
	Jun. 30, 2020
Retirement Benefits [Abstract]
Employee Benefit Plans	Employee Benefit Plans Net periodic benefit costs for our pension and post-retirement benefits plans for the three and six months ended June 30, 2020 and 2019 are set forth in the following tables: Chesapeake FPU Chesapeake SERP Chesapeake FPU For the Three Months Ended June 30, 2020 2019 2020 2019 2020 2019 2020 2019 2020 2019 (in thousands) Interest cost $ 46 $ 104 $ 518 $ 615 $ 16 $ 21 $ 8 $ 9 $ 10 $ 12 Expected return on plan assets (42 ) (127 ) (745 ) (693 ) — — — — — — Amortization of prior service credit — — — — — — (19 ) (19 ) — — Amortization of net loss 65 101 135 129 5 26 12 12 — — Net periodic cost (benefit) 69 78 (92 ) 51 21 47 1 2 10 12 Amortization of pre-merger regulatory asset — — — 191 — — — — 2 2 Total periodic cost $ 69 $ 78 $ (92 ) $ 242 $ 21 $ 47 $ 1 $ 2 $ 12 $ 14 Chesapeake Pension Plan FPU Pension Plan Chesapeake SERP Chesapeake Postretirement Plan FPU Medical Plan For the Six Months Ended June 30, 2020 2019 2020 2019 2020 2019 2020 2019 2020 2019 (in thousands) Interest cost $ 92 $ 209 $ 1,036 $ 1,230 $ 32 $ 42 $ 16 $ 19 $ 20 $ 24 Expected return on plan assets (84 ) (254 ) (1,490 ) (1,386 ) — — — — — — Amortization of prior service credit — — — — — — (38 ) (39 ) — — Amortization of net loss 130 203 270 258 10 52 24 24 — — Net periodic cost (benefit) 138 158 (184 ) 102 42 94 2 4 20 24 Amortization of pre-merger regulatory asset — — — 381 — — — — 4 4 Total periodic cost $ 138 $ 158 $ (184 ) $ 483 $ 42 $ 94 $ 2 $ 4 $ 24 $ 28 We expect to record immaterial pension and post-retirement benefit costs for 2020. The components of our net periodic costs have been recorded or reclassified to other expense, net in the condensed consolidated statements of income. Pursuant to a Florida PSC order, FPU continues to record, as a regulatory asset, a portion of the unrecognized postretirement benefit costs related to its regulated operations after the FPU merger. The portion of the unrecognized pension and postretirement benefit costs related to FPU’s unregulated operations and Chesapeake Utilities' operations is recorded to accumulated other comprehensive loss. The following tables present the amounts included in the regulatory asset and accumulated other comprehensive loss that were recognized as components of net periodic benefit cost during the three and six months ended June 30, 2020 and 2019 : For the Three Months Ended June 30, 2020 Chesapeake FPU Chesapeake SERP Chesapeake FPU Total (in thousands) Prior service credit $ — $ — $ — $ (19 ) $ — $ (19 ) Net loss 65 135 5 12 — 217 Total recognized in net periodic benefit cost 65 135 5 (7 ) — 198 Recognized from accumulated other comprehensive loss/(gain) (1) 65 26 5 (7 ) — 89 Recognized from regulatory asset — 109 — — — 109 Total $ 65 $ 135 $ 5 $ (7 ) $ — $ 198 For the Three Months Ended June 30, 2019 Chesapeake FPU Chesapeake SERP Chesapeake FPU Total (in thousands) Prior service credit $ — $ — $ — $ (19 ) $ — $ (19 ) Net loss 101 129 26 12 — 268 Total recognized in net periodic benefit cost 101 129 26 (7 ) — 249 Recognized from accumulated other comprehensive loss/(gain) (1) 101 24 26 (7 ) — 144 Recognized from regulatory asset — 105 — — — 105 Total $ 101 $ 129 $ 26 $ (7 ) $ — $ 249 For the Six Months Ended June 30, 2020 Chesapeake Pension Plan FPU Pension Plan Chesapeake SERP Chesapeake Postretirement Plan FPU Medical Plan Total (in thousands) Prior service credit $ — $ — $ — $ (38 ) $ — $ (38 ) Net loss 130 270 10 24 — 434 Total recognized in net periodic benefit cost 130 270 10 (14 ) — 396 Recognized from accumulated other comprehensive loss/(gain) (1) 130 52 10 (14 ) — 178 Recognized from regulatory asset — 218 — — — 218 Total $ 130 $ 270 $ 10 $ (14 ) $ — $ 396 For the Six Months Ended June 30, 2019 Chesapeake Pension Plan FPU Pension Plan Chesapeake SERP Chesapeake Postretirement Plan FPU Medical Plan Total (in thousands) Prior service credit $ — $ — $ — $ (39 ) $ — $ (39 ) Net loss 203 258 52 24 — 537 Total recognized in net periodic benefit cost 203 258 52 (15 ) — 498 Recognized from accumulated other comprehensive loss/(gain) (1) 203 49 52 (15 ) — 289 Recognized from regulatory asset — 209 — — — 209 Total $ 203 $ 258 $ 52 $ (15 ) $ — $ 498 (1) See Note 9 , Stockholder's Equity . During the three and six months ended June 30, 2020 , we contributed approximately $0.2 million to the Chesapeake Pension Plan and approximately $1.8 million and $2.1 million , respectively, to the FPU Pension Plan. We expect to contribute approximately $0.3 million and $3.2 million , respectively, to the Chesapeake Pension Plan and FPU Pension Plans during 2020 , which represents the minimum annual contribution payments required. A provision in the CARES Act, which was passed by Congress and signed into law by President Trump in March 2020, authorized the deferral of 2020 pension contributions to January 1, 2021. Despite this authorization, we have not deferred, and do not expect to defer, any of our 2020 pension plan contributions to 2021. The Chesapeake SERP, the Chesapeake Postretirement Plan and the FPU Medical Plan are unfunded and are expected to be paid out of our general funds. Cash benefits paid under the Chesapeake SERP for the three and six months ended June 30, 2020 were immaterial and $0.1 million , respectively. We expect to pay total cash benefits of approximately $0.2 million under the Chesapeake SERP in 2020 . Cash benefits paid under the Chesapeake Postretirement Plan, primarily for medical claims for the three and six months ended June 30, 2020 were immaterial. We estimate that approximately $0.1 million will be paid for such benefits under the Chesapeake Postretirement Plan in 2020 . Cash benefits paid under the FPU Medical Plan, primarily for medical claims for the three and six months ended June 30, 2020 , were immaterial. We estimate that approximately $0.1 million will be paid for such benefits under the FPU Medical Plan in 2020 .

Investments

Investments	6 Months Ended
	Jun. 30, 2020
Investments, Debt and Equity Securities [Abstract]
Investments	Investments The investment balances at June 30, 2020 and December 31, 2019 , consisted of the following: (in thousands) June 30, December 31, Rabbi trust (associated with the Non-Qualified Deferred Compensation Plan) $ 9,551 $ 9,202 Investments in equity securities 20 27 Total $ 9,571 $ 9,229 We classify these investments as trading securities and report them at their fair value. For the three months ended June 30, 2020 and 2019 , we recorded a net unrealized gain of approximately $1.4 million and $0.4 million , respectively, in other expense, net in the condensed consolidated statements of income related to these investments. For the six months ended June 30, 2020 and 2019 , we recorded a net unrealized loss of approximately $0.1 million and a net unrealized gain of approximately $1.1 million , respectively, in other expense, net in the condensed consolidated statements of income related to these investments. For the investment in the Rabbi Trust, we also have recorded an associated liability, which is included in other pension and benefit costs in the condensed consolidated balance sheets and is adjusted each period for the gains and losses incurred by the investments in the Rabbi Trust.

Share-Based Compensation

Share-Based Compensation	6 Months Ended
	Jun. 30, 2020
Share-based Payment Arrangement [Abstract]
Share-Based Compensation	Share-Based Compensation Our non-employee directors and key employees are 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. The table below presents the amounts included in net income related to share-based compensation expense for the three and six months ended June 30, 2020 and 2019 : Three Months Ended Six Months Ended June 30, June 30, 2020 2019 2020 2019 (in thousands) Awards to non-employee directors $ 181 $ 157 $ 357 $ 305 Awards to key employees 1,085 452 1,965 790 Total compensation expense 1,266 609 2,322 1,095 Less: tax benefit (331 ) (158 ) (607 ) (285 ) Share-based compensation amounts included in net income $ 935 $ 451 $ 1,715 $ 810 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 date of the grant. 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. In May 2020, after the most recent election of directors, each of our continuing non-employee directors received an annual retainer of 887 shares of common stock under the SICP for service as a director through the 2021 Annual Meeting of Stockholders; accordingly, 8,870 shares, with a weighted average fair value of $84.47 per share, were issued and vested in 2020. In January 2020, a newly appointed member of the Board of Directors received a pro-rated retainer of 254 shares of common stock under the SICP to serve as a non-employee director through the 2020 Annual Meeting of Stockholders. The shares awarded to the non-employee director immediately vested upon issuance in January 2020, had a weighted average fair value of $95.83 per share, and the expense was recognized over the remaining service period ending on the date of the 2020 Annual Meeting of Stockholders. At June 30, 2020 , there was approximately $0.6 million of unrecognized compensation expense related to shares granted to non-employee directors. This expense will be recognized over the remaining service period ending on the date of the 2021 Annual Meeting of Stockholders. Key Employees The table below presents the summary of the stock activity for awards to key employees for the six months ended June 30, 2020 : Number of Shares Weighted Average Fair Value Outstanding—December 31, 2019 157,817 $ 80.28 Granted 66,857 $ 92.78 Vested (35,651 ) $ 66.48 Expired (5,302 ) $ 65.32 Outstanding—June 30, 2020 183,721 $ 86.98 In February 2020 , our Board of Directors granted awards of 66,857 shares of common stock to key employees under the SICP. The shares granted are multi-year awards that will vest at the end of the three-year service period ending December 31, 2022. All of these stock awards are earned based upon the successful achievement of long-term financial results, which comprise market-based and performance-based conditions or targets. The fair value of each performance-based condition or target is equal to the market price of our common stock on the grant date of each award. For the market-based conditions, we used the Monte Carlo valuation to estimate the fair value of each market-based award granted. In March 2020, upon the appointment of certain of our executive officers, we withheld shares with a value at least equivalent to each such executive officer’s minimum statutory obligation for applicable income and other employment taxes related to shares that we awarded in February 2020 for the performance period ended December 31, 2019 , remitted the cash to the appropriate taxing authorities, and paid the balance of such awarded shares to each such executive officer. We withheld 10,319 shares, based on the value of the shares on their award date. Total combined payments for the employees’ tax obligations to the taxing authorities were approximately $1.0 million . At June 30, 2020 , the aggregate intrinsic value of the SICP awards granted to key employees was approximately $15.4 million . At June 30, 2020 , there was approximately $5.8 million of unrecognized compensation cost related to these awards, which is expected to be recognized as expense from the remainder of 2020 through 2022. Stock Options There were no stock options outstanding or issued during the six months ended June 30, 2020 and 2019 .

Derivative Instruments

Derivative Instruments	6 Months Ended
	Jun. 30, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	Derivative Instruments 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. Aspire Energy 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 June 30, 2020 , our natural gas and electric distribution operations did not have any outstanding derivative contracts. PESCO's Derivative Instruments As discussed in Note 3, Acquisitions and Divestitures , during the fourth quarter of 2019, we sold PESCO's assets and contracts and, therefore, no longer have natural gas futures and contracts recorded in our condensed consolidated financial statements. Commodity Derivative Activities As of June 30, 2020 , the volume of our commodity derivative contracts were as follows: Business unit Commodity Quantity hedged (in millions) Designation Longest Expiration date of hedge Sharp Propane (gallons) 22.5 Cash flows hedges May 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 during the heating season. Under the futures and swap agreements, Sharp will receive the difference between: (i) the index prices (Mont Belvieu prices for June 2020 through May 2023), and (ii) the per gallon propane swap prices, to the extent the index prices exceed the contracted prices. If the index prices are lower than the swap prices, Sharp will pay the difference. We designated and accounted for 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 $0.3 million from accumulated other comprehensive income (loss) to earnings during the next 12 -month period ended June 30, 2021. 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 through October 2020 . The interest rate swaps were entered to hedge the variability in cash flows attributable to changes in the short-term borrowing rates during this period. Pricing on the interest rate swaps range between 0.2615 and 0.3875 percent for the period. Our short-term borrowing will be based on the 30-day LIBOR rate. The interest rate swaps will be cash settled monthly as the counter-party will pay us the 30-day LIBOR rate less the fixed rate. We designated and accounted 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 will be recorded in the income statement and recognized as a component of interest charges. We expect to reclassify less than $0.1 million from accumulated other comprehensive income (loss) to earnings during the next 12 -month period ended June 30, 2021. 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, with the balance related to the account is as follows: (in thousands) Balance Sheet Location June 30, 2020 December 31, 2019 Sharp Other Current Assets $ 595 $ 2,317 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. As of June 30, 2020 and December 31, 2019 , we did not have material fair value hedges. The fair values of the derivative contracts recorded in the condensed consolidated balance sheets as of June 30, 2020 and December 31, 2019 , are as follows: Derivative Assets Fair Value As Of (in thousands) Balance Sheet Location June 30, 2020 December 31, 2019 Derivatives designated as cash flow hedges Propane swap agreements Derivative assets, at fair value $ 1,270 $ — Total asset derivatives $ 1,270 $ — Derivative Liabilities Fair Value As Of (in thousands) Balance Sheet Location June 30, 2020 December 31, 2019 Derivatives designated as cash flow hedges Propane swap agreements Derivative liabilities, at fair value $ 751 $ 1,844 Interest rate swap agreements Derivative liabilities, at fair value 51 — Total liability derivatives $ 802 $ 1,844 The effects of gains and losses from derivative instruments on the condensed consolidated financial statements are as follows: Amount of Gain (Loss) on Derivatives: Location of Gain For the Three Months Ended June 30, For the Six Months Ended June 30, (in thousands) (Loss) on Derivatives 2020 2019 2020 2019 Derivatives designated as cash flow hedges Propane swap agreements Cost of sales $ 238 $ 252 $ 1,465 $ 858 Propane swap agreements Other comprehensive income (loss) 2,354 (494 ) 2,363 515 Interest rate swap agreements Interest expense 11 — 11 — Interest rate swap agreements Other comprehensive loss (51 ) — (51 ) — Natural gas swap contracts Other comprehensive loss — (8 ) — (67 ) Natural gas futures contracts Other comprehensive income (loss) — (2,463 ) — 763 Total $ 2,552 $ (2,713 ) $ 3,788 $ 2,069

Fair Value of Financial Instrum

Fair Value of Financial Instruments	6 Months Ended
	Jun. 30, 2020
Fair Value Disclosures [Abstract]
Fair Value of Financial Instruments	Fair Value of Financial Instruments 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 and 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 June 30, 2020 and December 31, 2019 : Fair Value Measurements Using: As of June 30, 2020 Fair Value Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) (in thousands) Assets: Investments—equity securities $ 20 $ 20 $ — $ — Investments—guaranteed income fund 2,334 — — 2,334 Investments—mutual funds and other 7,217 7,217 — — Total investments 9,571 7,237 — 2,334 Derivative assets 1,270 — 1,270 — Total assets $ 10,841 $ 7,237 $ 1,270 $ 2,334 Liabilities: Derivative liabilities $ 802 $ — $ 802 $ — Fair Value Measurements Using: As of December 31, 2019 Fair Value Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) (in thousands) Assets: Investments—equity securities $ 27 $ 27 $ — $ — Investments—guaranteed income fund 803 — — 803 Investments—mutual funds and other 8,399 8,399 — — Total investments 9,229 8,426 — 803 Derivative assets — — — — Total assets $ 9,229 $ 8,426 $ — $ 803 Liabilities: Derivative liabilities $ 1,844 $ — $ 1,844 $ — The following table sets forth the summary of the changes in the fair value of Level 3 investments for the six months ended June 30, 2020 and 2019 : Six Months Ended 2020 2019 (in thousands) Beginning Balance $ 803 $ 686 Purchases and adjustments 226 110 Transfers 1,345 — Distribution (50 ) (12 ) Investment income 10 7 Ending Balance $ 2,334 $ 791 Investment income from the Level 3 investments is reflected in other expense, (net) in the condensed consolidated statements of income. At June 30, 2020 , 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 and 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 3 measurement). At June 30, 2020 , long-term debt which includes current maturities but excludes debt issuance costs, had a carrying value of approximately $446.5 million , compared to the estimated fair value of $481.7 million . At December 31, 2019 , long-term debt, which includes the current maturities but excludes debt issuance costs, had a carrying value of approximately $486.6 million , compared to a fair value of approximately $505.0 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 3 measurement.

Long-Term Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2020
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Our outstanding long-term debt is shown below: June 30, December 31, (in thousands) 2020 2019 FPU secured first mortgage bonds (1) : 9.08% bond, due June 1, 2022 $ 7,992 $ 7,990 Uncollateralized senior notes: 5.50% note, due October 12, 2020 2,000 2,000 5.93% note, due October 31, 2023 10,500 12,000 5.68% note, due June 30, 2026 17,400 20,300 6.43% note, due May 2, 2028 5,600 6,300 3.73% note, due December 16, 2028 18,000 18,000 3.88% note, due May 15, 2029 45,000 50,000 3.25% note, due April 30, 2032 70,000 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 Term Note due February 28, 2020 — 30,000 Less: debt issuance costs (786 ) (822 ) Total long-term debt 445,706 485,768 Less: current maturities (15,600 ) (45,600 ) Total long-term debt, net of current maturities $ 430,106 $ 440,168 (1) FPU secured first mortgage bonds are guaranteed by Chesapeake Utilities. Term Notes In January 2019 , we issued a $30 million unsecured term note through Branch Banking and Trust Company, with a maturity date of February 28, 2020 . This note was paid in full in February 2020 utilizing our short-term borrowing facilities. Shelf Agreements We have entered into Shelf Agreements with Prudential, MetLife and NYL, whom are under no obligation to purchase any unsecured debt. The following table summarizes our Shelf Agreements at June 30, 2020 : (in thousands) Total Borrowing Capacity Less: Amount of Debt Issued Less: Unfunded Commitments Remaining Borrowing Capacity Shelf Agreement Prudential Shelf Agreement (1) (2) $ 370,000 $ (170,000 ) $ (50,000 ) $ 150,000 MetLife Shelf Agreement (3) 150,000 — — 150,000 NYL Shelf Agreement (4) 150,000 (100,000 ) (40,000 ) 10,000 Total Shelf Agreements as of June 30, 2020 $ 670,000 $ (270,000 ) $ (90,000 ) $ 310,000 (1) In January 2020, we requested and Prudential accepted our request to purchase $50.0 million of our unsecured debt. We issued the Shelf Notes in July 2020 at the rate of 3.00 percent per annum. (2) In April 2020, the Prudential Shelf Agreement was amended to increase the available borrowing capacity to $150.0 million . (3) In May 2020, we reached into an agreement with MetLife to provide a new $150.0 million MetLife Shelf Agreement for a three-year term ending in March 31, 2023. (4) In February 2020 , we requested and NYL accepted our request to purchase $40.0 million of our unsecured debt. We expect to issue the Shelf Notes in August 2020 at the rate of 2.96 percent per annum. 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.

Short-Term Borrowings (Notes)

Short-Term Borrowings (Notes)	6 Months Ended
	Jun. 30, 2020
Short-Term Borrowing [Abstract]
Short-term Debt [Text Block]	16. Short-Term Borrowings At June 30, 2020 and December 31, 2019 , we had $286.4 million and $247.4 million , respectively, of short-term borrowings outstanding at the weighted average interest rates of 1.05 percent and 2.62 percent , respectively. Included in the June 30, 2020 balance, is $100.0 million in short-term debt for which we have entered into interest rate swap agreements as discussed below. We have an aggregate of $370.0 million in credit lines comprised of four unsecured bank credit facilities with four financial institutions, with $220.0 million in total available credit, and a Revolver with five participating Lenders totaling $150.0 million . As a result of the uncertainty regarding the length of and depth of the impacts of the COVID-19 pandemic, in the second quarter of 2020, we received commitments for an additional $95.0 million of short-term debt capacity through four credit facilities that mature on October 31, 2020 . These facilities have a commitment fee of 0.35 percent with an interest rate of 1.75 percent over LIBOR, to the extent we borrow under these facilities. All of these facilities expire in October 2020. The following table summarizes our short-term borrowing facilities information at June 30, 2020 and December 31, 2019 : Outstanding borrowings at (in thousands) Total Facility LIBOR Based Interest Rate June 30, 2020 December 31, 2019 Available at June 30, 2020 Bank Credit Facility Existing Bilateral Facilities Committed revolving credit facility A $ 55,000 plus 0.75 percent $ 55,000 $ 55,000 $ — Committed revolving credit facility B 80,000 plus 0.75 percent 77,501 57,150 2,499 Committed revolving credit facility C 45,000 plus 0.75 percent 32,412 42,040 12,588 Committed revolving credit facility D 40,000 plus 0.85 percent 40,000 40,000 — Committed revolving credit facility E (2) 150,000 plus 1.125 percent 80,000 50,000 70,000 Total existing bilateral facilities 370,000 284,913 244,190 85,087 Incremental Facilities Committed revolving credit facility F 35,000 plus 1.75 percent — — 35,000 Committed revolving credit facility G 15,000 plus 1.75 percent — — 15,000 Committed revolving credit facility H 25,000 plus 1.75 percent — — 25,000 Committed revolving credit facility I 20,000 plus 1.75 percent — — 20,000 Total incremental facilities 95,000 — — 95,000 Total short term credit facilities $ 465,000 284,913 244,190 $ 180,087 Book overdrafts (1) 1,492 3,181 Total short-term borrowing $ 286,405 $ 247,371 (1) If presented, these book overdrafts would be funded through the bank revolving credit facilities. (2) This committed revolving credit facility includes a restriction that our short-term borrowings, excluding any borrowings under the committed revolving credit facility, cannot exceed $350.0 million . The availability of funds under our credit facilities is subject to conditions specified in the respective credit agreements, all of which we currently satisfy. These conditions include our compliance with financial covenants and the continued accuracy of representations and warranties contained in these agreements. We are required by the financial covenants in our revolving credit facilities to maintain, at the end of each fiscal year, a funded indebtedness ratio of no greater than 65 percent . As of June 30, 2020 , we are in compliance with all of our debt covenants. 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 through October 2020 . The interest rate swaps were entered to hedge the variability in cash flows attributable to changes in the short-term borrowing rates during this period. The fixed swap rates will range between 0.2615 and 0.3875 percent for the period. Our short-term borrowing will be based on the 30-day LIBOR rate. The interest swap will be cash settled monthly as the counter-party will pay us the 30-day LIBOR rate less the fixed rate.

Leases Leases

Leases Leases	6 Months Ended
	Jun. 30, 2020
Lease Disclosure [Abstract]
Lessee, Operating Leases [Text Block]	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 all our employees in several locations throughout the Mid-Atlantic, Mid-West and in Florida. 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 have resulted in immaterial additional annual lease costs. 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 condensed consolidated balance sheet at June 30, 2020 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 which preclude our ability to pay dividends, obtain financing or enter into additional leases. As of June 30, 2020 , 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 condensed consolidated statements of income: Three Months Ended Six Months Ended June 30, June 30, ( in thousands) Classification 2020 2019 2020 2019 Operating lease cost (1) Operations expense $ 629 $ 654 $ 1,255 $ 1,288 Finance lease cost: Amortization of lease assets Depreciation and amortization — 249 — 650 Interest on lease liabilities Interest expense — 1 — 5 Net lease cost $ 629 $ 904 $ 1,255 $ 1,943 (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 condensed consolidated balance sheet at June 30, 2020 and December 31, 2019 : (in thousands) Balance sheet classification June 30, 2020 December 31, 2019 Assets Operating lease assets Operating lease right-of-use assets $ 11,546 $ 11,563 Total lease assets $ 11,546 $ 11,563 Liabilities Current Operating lease liabilities Other accrued liabilities $ 1,647 $ 1,705 Noncurrent Operating lease liabilities Operating lease - liabilities 10,055 9,896 Total lease liabilities $ 11,702 $ 11,601 The following table presents our weighted-average remaining lease terms and weighted-average discount rates for our operating and financing leases at June 30, 2020 and December 31, 2019 : June 30, 2020 December 31, 2019 Weighted-average remaining lease term ( in years ) Operating leases 8.6 8.88 Weighted-average discount rate Operating leases 3.8 % 3.8 % The following table presents additional information related to cash paid for amounts included in the measurement of lease liabilities included in our condensed consolidated statements of cash flows as of June 30, 2020 and 2019 : Six Months Ended June 30, (in thousands) 2020 2019 Operating cash flows from operating leases $ 1,034 $ 1,100 Operating cash flows from finance leases $ — $ 5 Financing cash flows from finance leases $ — $ 650 The following table presents the future undiscounted maturities of our operating and financing leases at June 30, 2020 and for each of the next five years and thereafter: (in thousands) Operating Leases (1) Remainder of 2020 $ 1,089 2021 2,031 2022 1,937 2023 1,874 2024 1,619 2025 1,383 Thereafter 3,876 Total lease payments $ 13,809 Less: Interest 2,107 Present value of lease liabilities $ 11,702 (1) Operating lease payments include $4.0 million related to options to extend lease terms that are reasonably certain of being exercised.

Summary of Accounting Policies

Summary of Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2020
Accounting Policies [Abstract]
COVID-19 Effect [Policy Text Block]	Effects of COVID-19 On March 13, 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 have continued to significantly impact economic conditions in the United States. We are considered an “essential business,” which allows us to continue our operational activities and construction projects while the social distancing restrictions remain in place. In response to the COVID-19 pandemic and related restrictions, we implemented our pandemic response plan, which includes having all employees who can work remotely do so in order to promote social distancing and providing personal protective equipment to field employees to reduce the spread of COVID-19. Impacts from the restrictions imposed in our service territories and the implementation of our pandemic response plan, included reduced energy consumption primarily in the commercial and industrial sectors, incremental expenses associated with COVID-19 including protective personal equipment, premium pay for field employees and higher bad debt expense. The additional operating expenses we incurred support the ongoing delivery of our essential services during these unprecedented times. The negative impact was partially offset by reduced federal income tax expense recognized in connection with implementation of the CARES Act and lower short-term borrowing costs resulting from a decrease in interest rates. As the COVID-19 pandemic is still ongoing, to date we have not established regulatory assets associated with the incremental expense impacts, as currently authorized by the Delaware and Maryland PSCs. In Florida, the PSC requires utility companies seeking regulatory asset treatment for COVID-19 related expenses to individually file a formal petition for consideration. We are committed to communicating timely updates and will continue to monitor developments affecting our employees, customers, suppliers, stockholders and take additional precautions as warranted to operate safely and to comply with the CDC, Occupational Safety and Health Administration, state and local requirements in order to protect our employees, customers and the communities we serve, and update and communicate the ongoing financial impact on our results once determined. Refer to Note 5, Rates and Other Regulatory Activities, for further information on the potential deferral of incremental expenses associated with COVID-19.
Basis of Presentation	Basis of Presentation References in this document to the “Company,” “Chesapeake Utilities,” “we,” “us” and “our” are intended to mean Chesapeake Utilities Corporation, its divisions and/or its subsidiaries, as appropriate in the context of the disclosure. The accompanying unaudited condensed consolidated financial statements have been prepared in compliance with the rules and regulations of the SEC and GAAP. In accordance with these rules and regulations, certain information and disclosures normally required for audited financial statements have been condensed or omitted. These financial statements should be read in conjunction with the consolidated financial statements and notes thereto, included in our latest Annual Report on Form 10-K for the year ended December 31, 2019 . In the opinion of management, these financial statements reflect all adjustments that are necessary for a fair presentation of our results of operations, financial position and cash flows for the interim periods presented. Where necessary to improve comparability, prior period amounts have been changed to conform to current period presentation. Due to the seasonality of our business, results for interim periods are not necessarily indicative of results for the entire fiscal year. Revenue and earnings are typically greater during the first and fourth quarters, when consumption of energy is highest due to colder temperatures. Beginning in the third quarter of 2019 , our management began executing a strategy to sell the operating assets of PESCO. In the fourth quarter of 2019, we closed on four separate transactions to sell PESCO's assets and contracts. As a result of these sales, we have fully exited the natural gas marketing business, which provided natural gas management and supply services to commercial and industrial customers in Florida, Delaware, Maryland, Pennsylvania, Ohio and other states. Accordingly, PESCO’s historical financial results are reflected in our condensed consolidated financial statements as discontinued operations, which required retrospective application to financial information for all periods presented. Refer to Note 3, Acquisitions and Divestitures, for further information
FASB Statements and Other Authoritative Pronouncements	FASB Statements and Other Authoritative Pronouncements Recently Adopted Accounting Standards Financial Instruments - Credit Losses (ASC 326) - In June 2016, the FASB issued ASU 2016-13, Measurement of Credit Losses on Financial Instruments , which changes how entities account for credit losses for most financial assets and certain other instruments, and subsequent guidance which served to clarify or amend the original standard. ASU 2016-13 and the related amendments require entities to estimate lifetime expected credit losses for trade receivables and to provide additional disclosure related to credit losses. We adopted ASU 2016-13 on January 1, 2020 and recorded an immaterial cumulative effect in retained earnings as of that date. As a result, prior period financial information has not been recast and continues to be reported under the accounting guidance that was effective during those periods. 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 analyzed the balance of our trade receivables based on the underlying service line they pertain to. This resulted in an examination of trade receivables from our energy distribution, energy transmission, energy delivery services and propane operations service lines. Our energy distribution service line consists of all our regulated distribution utility operations on the Delmarva Peninsula and throughout 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 as a component of their 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 compressed natural gas ("CNG") delivery operations. The majority of the customer base these business units serve 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 they present. 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 amounts of revenues earned. 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. During the first quarter of 2020, COVID-19 began to rapidly spread within the United States. Federal, state and local governments throughout the country imposed restrictions to promote social distancing to slow the spread of the virus, which has also had the effect of limiting commercial activity. These measures have resulted in significant job losses and a slowing of economic activity across the United States and in the areas that we serve. We have been identified as an “essential business,” which allowed us to continue operational activity and construction projects with social distancing restrictions in place. We have considered the impact of COVID-19 for the six months ended June 30, 2020, monitored developments that impact our customers’ ability to pay and have revised our estimates of expected credit losses. Our prior estimates for expected credit losses had not included an evaluation of current conditions or forward-looking economic indicators as we were not required to consider those factors under the previous incurred loss accounting guidance. The below table provides a reconciliation of our allowance for credit losses at June 30, 2020 : (in thousands) Balance at December 31, 2019 $ 1,337 Additions: Provision for credit losses 794 Recoveries 450 Deductions: Write offs (477 ) Balance at June 30, 2020 $ 2,104 Fair Value Measurement (ASC 820) - In August 2018, the FASB issued ASU 2018-13, Disclosure Framework - Changes to the Disclosure Requirements for Fair Value Measurement , which removes, modifies and adds certain disclosure requirements on fair value measurements in ASC 820. We adopted ASU 2018-13 beginning January 1, 2020 and, since the changes only impacted disclosures, its adoption did not have a material impact on our financial position or results of operations. Intangibles - Goodwill (ASC 350) - In January 2017, the FASB issued ASU 2017-04, Simplifying the Test for Goodwill Impairment , which simplifies how an entity is required to test goodwill for impairment by eliminating Step 2 from the goodwill impairment test. ASU 2017-04 was effective beginning January 1, 2020. The amendments included in this ASU are to be applied prospectively, and are not expected to have a material impact on our financial position or results of operations.

Summary of Accounting Policie_2

Summary of Accounting Policies Summary of Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2020
Accounting Policies [Abstract]
Financing Receivable, Allowance for Credit Loss [Table Text Block]	The below table provides a reconciliation of our allowance for credit losses at June 30, 2020 : (in thousands) Balance at December 31, 2019 $ 1,337 Additions: Provision for credit losses 794 Recoveries 450 Deductions: Write offs (477 ) Balance at June 30, 2020 $ 2,104

Calculation of Earnings Per S_2

Calculation of Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2020
Earnings Per Share [Abstract]
Calculation of Basic and Diluted Earnings Per Share	Three Months Ended Six Months Ended June 30, June 30, 2020 2019 2020 2019 (in thousands, except shares and per share data) Calculation of Basic Earnings Per Share: Income from Continuing Operations $ 10,661 $ 8,914 $ 39,702 $ 37,725 Income (Loss) from Discontinued Operations 295 (610 ) 184 (757 ) Net Income $ 10,956 $ 8,304 $ 39,886 $ 36,968 Weighted average shares outstanding 16,448,490 16,401,028 16,431,724 16,393,022 Basic Earnings Per Share from Continuing Operations $ 0.65 $ 0.55 $ 2.42 $ 2.31 Basic Earnings (Loss) Per Share from Discontinued Operations 0.02 (0.04 ) 0.01 (0.05 ) Basic Earnings Per Share $ 0.67 $ 0.51 $ 2.43 $ 2.26 Calculation of Diluted Earnings Per Share: Reconciliation of Denominator: Weighted shares outstanding—Basic 16,448,490 16,401,028 16,431,724 16,393,022 Effect of dilutive securities—Share-based compensation 55,113 44,715 56,083 46,311 Adjusted denominator—Diluted 16,503,603 16,445,743 16,487,807 16,439,333 Diluted Earnings Per Share from Continuing Operations $ 0.64 $ 0.54 $ 2.41 $ 2.30 Diluted Earnings (Loss) Per Share from Discontinued Operations 0.02 (0.04 ) 0.01 (0.05 ) Diluted Earnings Per Share $ 0.66 $ 0.50 $ 2.42 $ 2.25

Acquisitions and Divestitures_2

Acquisitions and Divestitures (Tables)	6 Months Ended
	Jun. 30, 2020
Discontinued Operations and Disposal Groups [Abstract]
Disposal Groups, Including Discontinued Operations [Table Text Block]	A summary of discontinued operations presented in the condensed consolidated statements of income includes the following: Three Months Six Months June 30, June 30, (in thousands) 2020 2019 2020 2019 Operating revenues (1) $ 3 $ 41,280 $ 23 $ 118,302 Cost of sales (1) 10 40,539 1 115,701 Other operating expenses 39 1,470 197 3,460 Operating loss (46 ) (729 ) (175 ) (859 ) Interest and other expense (6 ) (101 ) (29 ) (166 ) Loss from Discontinued Operations before income taxes (52 ) (830 ) (204 ) (1,025 ) Gain on sale of Discontinued Operations 200 — 200 Income tax benefit (147 ) (220 ) (188 ) (268 ) Gain (Loss) from Discontinued Operations, Net of Tax $ 295 $ (610 ) $ 184 $ (757 ) (1) Included in operating revenues and cost of sales for the three and six months ended June 30, 2019 , is $4.9 million and $14.8 million , respectively, representing amounts which had been previously eliminated in consolidation related to intercompany activity that continued with the buyers after the disposition of the assets of PESCO.
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]	The following table summarizes significant statements of cash flows data related to the discontinued operations of PESCO: (in thousands) Three Months Ended June 30, 2019 Six Months Ended June 30, 2019 Depreciation and amortization $ 146 $ 291 Deferred income taxes $ (1,021 ) $ 375 Realized loss on commodity contracts $ (97 ) $ (681 )

Revenue Recognition (Tables)

Revenue Recognition (Tables)	6 Months Ended
	Jun. 30, 2020
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue [Table Text Block]	The following table displays our revenue from continuing operations by major source based on product and service type for the three months ended June 30, 2020 and 2019 : Three months ended June 30, 2020 Three Months Ended June 30, 2019 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Regulated Energy Unregulated Energy Other and Eliminations Total Energy distribution Delaware natural gas division $ 11,758 $ — $ — $ 11,758 $ 8,256 $ — $ — $ 8,256 Florida natural gas division 7,231 — — 7,231 7,015 — — 7,015 FPU electric distribution 15,701 — — 15,701 20,464 — — 20,464 FPU natural gas distribution 19,498 — — 19,498 18,663 — — 18,663 Maryland natural gas division 3,979 — — 3,979 3,186 — — 3,186 Sandpiper natural gas/propane operations 2,858 — — 2,858 3,482 — — 3,482 Total energy distribution 61,025 — — 61,025 61,066 — — 61,066 Energy transmission Aspire Energy — 4,555 — 4,555 — 5,422 — 5,422 Eastern Shore 18,277 — — 18,277 17,740 — — 17,740 Peninsula Pipeline 5,361 — — 5,361 3,565 — — 3,565 Total energy transmission 23,638 4,555 — 28,193 21,305 5,422 — 26,727 Energy generation Eight Flags — 3,694 — 3,694 — 4,235 — 4,235 Propane operations Propane delivery operations — 17,260 — 17,260 — 17,488 — 17,488 Energy delivery services Marlin Gas Services — 2,248 — 2,248 — 1,108 — 1,108 Other and eliminations Eliminations (11,145 ) (16 ) (4,340 ) (15,501 ) (8,968 ) (2,628 ) (4,618 ) (16,214 ) Other — — 132 132 — — 132 132 Total other and eliminations (11,145 ) (16 ) (4,208 ) (15,369 ) (8,968 ) (2,628 ) (4,486 ) (16,082 ) Total operating revenues (1) $ 73,518 $ 27,741 $ (4,208 ) $ 97,051 $ 73,403 $ 25,625 $ (4,486 ) $ 94,542 (1) Total operating revenues for the three months ended June 30, 2020 , include other revenue (revenues from sources other than contracts with customers) of $0.1 million and $0.04 million for our Regulated and Unregulated Energy segments, respectively, and $(0.3) million and $0.1 million for our Regulated and Unregulated Energy segments, respectively, for the three months ended June 30, 2019 . The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the Maryland division and Sandpiper and late fees. The following table displays our revenue from continuing operations by major source based on product and service type for the six months ended June 30, 2020 and 2019 : Six months ended June 30, 2020 Six months ended June 30, 2019 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Regulated Energy Unregulated Energy Other and Eliminations Total Energy distribution Delaware natural gas division $ 38,325 $ — $ — $ 38,325 $ 35,805 $ — $ — $ 35,805 Florida natural gas division 15,708 — — 15,708 14,915 — — 14,915 FPU electric distribution 29,920 — — 29,920 34,842 — — 34,842 FPU natural gas distribution 44,942 — — 44,942 42,449 — — 42,449 Maryland natural gas division 13,117 — — 13,117 13,233 — — 13,233 Sandpiper natural gas/propane operations 9,150 — — 9,150 10,564 — — 10,564 Total energy distribution 151,162 — — 151,162 151,808 — — 151,808 Energy transmission Aspire Energy — 14,336 — 14,336 — 18,892 — 18,892 Eastern Shore 37,556 — — 37,556 36,796 — — 36,796 Peninsula Pipeline 10,185 — — 10,185 7,131 — — 7,131 Total energy transmission 47,741 14,336 — 62,077 43,927 18,892 — 62,819 Energy generation Eight Flags — 8,017 — 8,017 — 8,377 — 8,377 Propane operations Propane delivery operations — 55,883 — 55,883 — 64,017 — 64,017 Energy delivery services Marlin Gas Services — 3,557 — 3,557 — 3,541 — 3,541 Other and eliminations Eliminations (22,430 ) (40 ) (8,749 ) (31,219 ) (18,714 ) (8,123 ) (8,984 ) (35,821 ) Other — — 264 264 — — 264 264 Total other and eliminations (22,430 ) (40 ) (8,485 ) (30,955 ) (18,714 ) (8,123 ) (8,720 ) (35,557 ) Total operating revenues (1) $ 176,473 $ 81,753 $ (8,485 ) $ 249,741 $ 177,021 $ 86,704 $ (8,720 ) $ 255,005 (1) Total operating revenues for the six months ended June 30, 2020 , include other revenue (revenues from sources other than contracts with customers) of $0.8 million and $0.1 million for our Regulated and Unregulated Energy segments, respectively, and $(0.2) million and $0.2 million for our Regulated and Unregulated Energy segments, respectively, for the six months ended June 30, 2019 . The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the 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 June 30, 2020 and December 31, 2019 were as follows: Trade Receivables Contract Assets (Current) Contract Assets (Non-current) Contract Liabilities (Current) (in thousands) Balance at 12/31/2019 $ 47,430 $ 18 $ 3,465 $ 589 Balance at 6/30/2020 35,764 18 4,338 347 Increase (decrease) $ (11,666 ) $ — $ 873 $ (242 )
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block]	Revenue for these businesses for the remaining performance obligations, at June 30, 2020 , are expected to be recognized as follows: (in thousands) 2020 2021 2022 2023 2024 2025 2026 and thereafter Eastern Shore and Peninsula Pipeline $ 19,059 $ 35,720 $ 28,513 $ 22,930 $ 20,641 $ 19,283 $ 175,743 Natural gas distribution operations 1,950 4,124 5,167 4,936 4,699 4,166 32,996 FPU electric distribution 283 566 566 566 566 275 825 Total revenue contracts with remaining performance obligations $ 21,292 $ 40,410 $ 34,246 $ 28,432 $ 25,906 $ 23,724 $ 209,564

Rates and Other Regulatory Ac_2

Rates and Other Regulatory Activities Rates and Regulatory Activities (Tables)	6 Months Ended
	Jun. 30, 2020
Rates and Regulatory Activities [Abstract]
Summary of Effects of Federal Tax Reform on Regulated Businesses [Table Text Block]	The following table summarizes the TCJA impact on our regulated businesses: Regulatory Liabilities related to Accumulated Deferred Income Taxes ("ADIT") Operation and Regulatory Jurisdiction Amount (in thousands) Status Status of Customer Rate impact related to lower federal corporate income tax rate Eastern Shore (FERC) $34,190 Will be addressed in Eastern Shore's next rate case filing. Implemented one-time bill credit (totaling $0.9 million) in April 2018. Customer rates were adjusted in April 2018. Delaware Division (Delaware PSC) $12,788 PSC approved amortization of ADIT in January 2019. Implemented one-time bill credit (totaling $1.5 million) in April 2019. Customer rates were adjusted in March 2019. Maryland Division (Maryland PSC) $4,029 PSC approved amortization of ADIT in May 2018. Implemented one-time bill credit (totaling $0.4 million) in July 2018. Customer rates were adjusted in May 2018. Sandpiper Energy (Maryland PSC) $3,739 PSC approved amortization of ADIT in May 2018. Implemented one-time bill credit (totaling $0.6 million) in July 2018. Customer rates were adjusted in May 2018. Chesapeake Florida Gas Division/Central Florida Gas (Florida PSC) $8,244 PSC issued order authorizing amortization and retention of net ADIT liability by the Company in February 2019. Florida PSC's final order was issued in February 2019. Excluding GRIP, tax savings arising from the TCJA rate reduction will be retained by the Company. GRIP: Tax savings for 2018 will be refunded to customers in 2020 through the annual GRIP cost recovery mechanism. Future customer GRIP surcharges will be adjusted to reflect tax savings associated with TCJA. FPU Natural Gas (excludes Fort Meade and Indiantown) (Florida PSC) $19,201 Same treatment on a net basis as Chesapeake Florida Gas Division (above). Same treatment on a net basis as Chesapeake Florida Gas Division (above). FPU Fort Meade and Indiantown Divisions $312 Same treatment on a net basis as Chesapeake Florida Gas Division (above). Tax rate reduction: The impact was immaterial for the divisions. GRIP (Applicable to Fort Meade division only): Same treatment as Chesapeake Florida Gas Division (above). FPU Electric (Florida PSC) $6,823 In January 2019, PSC issued order approving amortization of ADIT through purchased power cost recovery, storm reserve and rates. TCJA benefit is provided to customers through a combination of reductions to the fuel cost recovery rate, base rates, as well as application to the storm reserve over the next several years.

Environmental Commitments and_2

Environmental Commitments and Contingencies Summary of Environmental Liabilities (Tables)	6 Months Ended
	Jun. 30, 2020
Environmental Commitments and Contingencies [Abstract]
Environmental Remedies [Table Text Block]	MGP Site (Jurisdiction) Status Estimated Cost to Clean up (Expect to Recover through Rates with Customers) West Palm Beach (Florida) Remedial actions approved by the Florida Department of Environmental Protection have been implemented on the east parcel of the site. We expect to implement similar remedial actions on the site's west parcel in 2020. Between $3.3 million to $14.2 million, including costs associated with the relocation of FPU’s operations at this site, and any potential costs associated with future redevelopment of the properties. Sanford (Florida) In March 2018, the United States Environmental Protection Agency ("EPA") approved a "site-wide ready for anticipated use" status, which is the final step before delisting a site. Construction has been completed and restrictive covenants are in place to ensure protection of human health. The only remaining activity is long-term groundwater monitoring. FPU's remaining remediation expenses, including attorneys' fees and costs, are anticipated to be immaterial. Winter Haven (Florida) Remediation is ongoing. Not expected to exceed $0.4 million. Seaford (Delaware) Conducted investigations of on-site and off-site impacts in the vicinity of the site, from 2014 through 2018, and submitted the findings to Delaware Department of Natural Resources and Environmental Control ("DNREC") in a March 2019 report. An interim action involving air-sparging/vapor extraction is being implemented, in accordance with the DNREC-approved Work Plan. Between $0.2 million and $0.5 million.

Segment Information (Tables)

Segment Information (Tables)	6 Months Ended
	Jun. 30, 2020
Segment Reporting [Abstract]
Schedule of Segment Reporting Information by Segment	The following table presents financial information about our reportable segments: Three Months Ended Six Months Ended June 30, June 30, 2020 2019 2020 2019 (in thousands) Operating Revenues, Unaffiliated Customers Regulated Energy $ 73,043 $ 72,880 $ 175,536 $ 175,951 Unregulated Energy 24,008 21,662 74,205 79,054 Total operating revenues, unaffiliated customers $ 97,051 $ 94,542 $ 249,741 $ 255,005 Intersegment Revenues (1) Regulated Energy $ 475 $ 523 $ 937 $ 1,070 Unregulated Energy 3,733 3,963 7,548 7,650 Other businesses 132 132 264 264 Total intersegment revenues $ 4,340 $ 4,618 $ 8,749 $ 8,984 Operating Income Regulated Energy $ 18,006 $ 18,028 $ 45,894 $ 47,769 Unregulated Energy 281 (771 ) 14,142 14,486 Other businesses and eliminations (310 ) 908 75 32 Operating income 17,977 18,165 60,111 62,287 Other income (expense), net (279 ) (320 ) 3,039 (380 ) Interest charges 5,054 5,552 10,868 11,180 Income from Continuing Operations before Income Taxes 12,644 12,293 52,282 50,727 Income Taxes on Continuing Operations 1,983 3,379 12,580 13,002 Income from Continuing Operations 10,661 8,914 39,702 37,725 Income (loss) from Discontinued Operations, Net of Tax 295 (610 ) 184 (757 ) Net Income $ 10,956 $ 8,304 $ 39,886 $ 36,968 (1) All significant intersegment revenues are billed at market rates and have been eliminated from consolidated operating revenues. (in thousands) June 30, 2020 December 31, 2019 Identifiable Assets Regulated Energy segment $ 1,477,616 $ 1,434,066 Unregulated Energy segment 296,140 296,810 Other businesses and eliminations 48,419 52,322 Total identifiable assets $ 1,822,175 $ 1,783,198

Stockholder's Equity - Accumul

Stockholder's Equity - Accumulated Other Comprehensive Income (Loss) (Tables)	6 Months Ended
	Jun. 30, 2020
Equity [Abstract]
Changes in Accumulated Other Comprehensive Loss	Defined Benefit Commodity Interest Rate Pension and Contracts Swap Postretirement Cash Flow Cash Flow Plan Items Hedges Hedges Total (in thousands) As of December 31, 2019 $ (4,933 ) $ (1,334 ) $ — $ (6,267 ) Other comprehensive income (loss) before reclassifications — 2,770 (29 ) 2,741 Amounts reclassified from accumulated other comprehensive income (loss) 132 (1,060 ) (8 ) (936 ) Net current-period other comprehensive income 132 1,710 (37 ) 1,805 As of June 30, 2020 $ (4,801 ) $ 376 $ (37 ) $ (4,462 ) (in thousands) As of December 31, 2018 $ (5,928 ) $ (785 ) $ — $ (6,713 ) Other comprehensive income before reclassifications — 1,000 — 1,000 Amounts reclassified from accumulated other comprehensive income/(loss) 213 (132 ) — 81 Net prior-period other comprehensive income 213 868 — 1,081 Prior-year reclassification — (115 ) — (115 ) As of June 30, 2019 $ (5,715 ) $ (32 ) $ — $ (5,747 )
Reclassifications out of Accumulated Other Comprehensive Income (Loss)	The following table presents amounts reclassified out of accumulated other comprehensive loss for the three and six months ended June 30, 2020 and 2019 . Deferred gains or losses for our commodity contracts and interest rate swap cash flow hedges are recognized in earnings upon settlement. Three Months Ended Six Months Ended June 30, June 30, 2020 2019 2020 2019 (in thousands) Amortization of defined benefit pension and postretirement plan items: Prior service credit (1) $ 19 $ 19 $ 38 $ 39 Net loss (1) (108 ) (163 ) (215 ) (328 ) Total before income taxes (89 ) (144 ) (177 ) (289 ) Income tax benefit 23 37 45 76 Net of tax (66 ) (107 ) (132 ) (213 ) Gains and losses on commodity contracts cash flow hedges: Propane swap agreements (2) 238 252 1,465 858 Natural gas swaps (2)(3) — — — 11 Natural gas futures (2)(3) — (125 ) — (698 ) Total before income taxes 238 127 1,465 171 Income tax expense (66 ) (34 ) (405 ) (39 ) Net of tax 172 93 1,060 132 Gains on interest rate swap cash flow hedges: Interest rate swap agreements 11 — 11 — Total before income taxes 11 — 11 — Income tax expense (3 ) — (3 ) — Net of tax 8 — 8 — Total reclassifications for the period $ 114 $ (14 ) $ 936 $ (81 ) (1) These amounts are included in the computation of net periodic costs (benefits). See Note 10 , Employee Benefit Plans , for additional details. (2) These amounts are included in the effects of gains and losses from derivative instruments. See Note 13, Derivative Instruments , for additional details. (3) PESCO's results are reflected as discontinued operations in our condensed consolidated statements of income.

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	6 Months Ended
	Jun. 30, 2020
Retirement Benefits [Abstract]
Schedule of Net Benefit Costs [Table Text Block]	Net periodic benefit costs for our pension and post-retirement benefits plans for the three and six months ended June 30, 2020 and 2019 are set forth in the following tables: Chesapeake FPU Chesapeake SERP Chesapeake FPU For the Three Months Ended June 30, 2020 2019 2020 2019 2020 2019 2020 2019 2020 2019 (in thousands) Interest cost $ 46 $ 104 $ 518 $ 615 $ 16 $ 21 $ 8 $ 9 $ 10 $ 12 Expected return on plan assets (42 ) (127 ) (745 ) (693 ) — — — — — — Amortization of prior service credit — — — — — — (19 ) (19 ) — — Amortization of net loss 65 101 135 129 5 26 12 12 — — Net periodic cost (benefit) 69 78 (92 ) 51 21 47 1 2 10 12 Amortization of pre-merger regulatory asset — — — 191 — — — — 2 2 Total periodic cost $ 69 $ 78 $ (92 ) $ 242 $ 21 $ 47 $ 1 $ 2 $ 12 $ 14 Chesapeake Pension Plan FPU Pension Plan Chesapeake SERP Chesapeake Postretirement Plan FPU Medical Plan For the Six Months Ended June 30, 2020 2019 2020 2019 2020 2019 2020 2019 2020 2019 (in thousands) Interest cost $ 92 $ 209 $ 1,036 $ 1,230 $ 32 $ 42 $ 16 $ 19 $ 20 $ 24 Expected return on plan assets (84 ) (254 ) (1,490 ) (1,386 ) — — — — — — Amortization of prior service credit — — — — — — (38 ) (39 ) — — Amortization of net loss 130 203 270 258 10 52 24 24 — — Net periodic cost (benefit) 138 158 (184 ) 102 42 94 2 4 20 24 Amortization of pre-merger regulatory asset — — — 381 — — — — 4 4 Total periodic cost $ 138 $ 158 $ (184 ) $ 483 $ 42 $ 94 $ 2 $ 4 $ 24 $ 28
Amounts Included in Regulatory asset and AOCI [Table Text Block]	The following tables present the amounts included in the regulatory asset and accumulated other comprehensive loss that were recognized as components of net periodic benefit cost during the three and six months ended June 30, 2020 and 2019 : For the Three Months Ended June 30, 2020 Chesapeake FPU Chesapeake SERP Chesapeake FPU Total (in thousands) Prior service credit $ — $ — $ — $ (19 ) $ — $ (19 ) Net loss 65 135 5 12 — 217 Total recognized in net periodic benefit cost 65 135 5 (7 ) — 198 Recognized from accumulated other comprehensive loss/(gain) (1) 65 26 5 (7 ) — 89 Recognized from regulatory asset — 109 — — — 109 Total $ 65 $ 135 $ 5 $ (7 ) $ — $ 198 For the Three Months Ended June 30, 2019 Chesapeake FPU Chesapeake SERP Chesapeake FPU Total (in thousands) Prior service credit $ — $ — $ — $ (19 ) $ — $ (19 ) Net loss 101 129 26 12 — 268 Total recognized in net periodic benefit cost 101 129 26 (7 ) — 249 Recognized from accumulated other comprehensive loss/(gain) (1) 101 24 26 (7 ) — 144 Recognized from regulatory asset — 105 — — — 105 Total $ 101 $ 129 $ 26 $ (7 ) $ — $ 249 For the Six Months Ended June 30, 2020 Chesapeake Pension Plan FPU Pension Plan Chesapeake SERP Chesapeake Postretirement Plan FPU Medical Plan Total (in thousands) Prior service credit $ — $ — $ — $ (38 ) $ — $ (38 ) Net loss 130 270 10 24 — 434 Total recognized in net periodic benefit cost 130 270 10 (14 ) — 396 Recognized from accumulated other comprehensive loss/(gain) (1) 130 52 10 (14 ) — 178 Recognized from regulatory asset — 218 — — — 218 Total $ 130 $ 270 $ 10 $ (14 ) $ — $ 396 For the Six Months Ended June 30, 2019 Chesapeake Pension Plan FPU Pension Plan Chesapeake SERP Chesapeake Postretirement Plan FPU Medical Plan Total (in thousands) Prior service credit $ — $ — $ — $ (39 ) $ — $ (39 ) Net loss 203 258 52 24 — 537 Total recognized in net periodic benefit cost 203 258 52 (15 ) — 498 Recognized from accumulated other comprehensive loss/(gain) (1) 203 49 52 (15 ) — 289 Recognized from regulatory asset — 209 — — — 209 Total $ 203 $ 258 $ 52 $ (15 ) $ — $ 498 (1) See Note 9 , Stockholder's Equity

Investments (Tables)

Investments (Tables)	6 Months Ended
	Jun. 30, 2020
Investments, Debt and Equity Securities [Abstract]
Investments schedule [Table Text Block]	The investment balances at June 30, 2020 and December 31, 2019 , consisted of the following: (in thousands) June 30, December 31, Rabbi trust (associated with the Non-Qualified Deferred Compensation Plan) $ 9,551 $ 9,202 Investments in equity securities 20 27 Total $ 9,571 $ 9,229

Share-Based Compensation (Table

Share-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2020
Shares awarded to non-employee directors [Line Items]
Schedule of Compensation Cost for Share-based Payment Arrangements, Allocation of Share-based Compensation Costs by Plan	The table below presents the amounts included in net income related to share-based compensation expense for the three and six months ended June 30, 2020 and 2019 : Three Months Ended Six Months Ended June 30, June 30, 2020 2019 2020 2019 (in thousands) Awards to non-employee directors $ 181 $ 157 $ 357 $ 305 Awards to key employees 1,085 452 1,965 790 Total compensation expense 1,266 609 2,322 1,095 Less: tax benefit (331 ) (158 ) (607 ) (285 ) Share-based compensation amounts included in net income $ 935 $ 451 $ 1,715 $ 810
Award to key employees [Member]
Shares awarded to non-employee directors [Line Items]
Schedule of Share-based Compensation, Activity	The table below presents the summary of the stock activity for awards to key employees for the six months ended June 30, 2020 : Number of Shares Weighted Average Fair Value Outstanding—December 31, 2019 157,817 $ 80.28 Granted 66,857 $ 92.78 Vested (35,651 ) $ 66.48 Expired (5,302 ) $ 65.32 Outstanding—June 30, 2020 183,721 $ 86.98

Derivative Instruments (Tables)

Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments [Table Text Block]	As of June 30, 2020 , the volume of our commodity derivative contracts were as follows: Business unit Commodity Quantity hedged (in millions) Designation Longest Expiration date of hedge Sharp Propane (gallons) 22.5 Cash flows hedges May 2023
Schedule of Due to (from) Broker-Dealers and Clearing Organizations [Table Text Block]	(in thousands) Balance Sheet Location June 30, 2020 December 31, 2019 Sharp Other Current Assets $ 595 $ 2,317
Fair Values of Derivative Contracts Recorded in Condensed Consolidated Balance Sheet	June 30, 2020 and December 31, 2019 , are as follows: Derivative Assets Fair Value As Of (in thousands) Balance Sheet Location June 30, 2020 December 31, 2019 Derivatives designated as cash flow hedges Propane swap agreements Derivative assets, at fair value $ 1,270 $ — Total asset derivatives $ 1,270 $ — Derivative Liabilities Fair Value As Of (in thousands) Balance Sheet Location June 30, 2020 December 31, 2019 Derivatives designated as cash flow hedges Propane swap agreements Derivative liabilities, at fair value $ 751 $ 1,844 Interest rate swap agreements Derivative liabilities, at fair value 51 — Total liability derivatives $ 802 $ 1,844
Effects of Gains and Losses from Derivative Instruments on Condensed Consolidated Financial Statements	The effects of gains and losses from derivative instruments on the condensed consolidated financial statements are as follows: Amount of Gain (Loss) on Derivatives: Location of Gain For the Three Months Ended June 30, For the Six Months Ended June 30, (in thousands) (Loss) on Derivatives 2020 2019 2020 2019 Derivatives designated as cash flow hedges Propane swap agreements Cost of sales $ 238 $ 252 $ 1,465 $ 858 Propane swap agreements Other comprehensive income (loss) 2,354 (494 ) 2,363 515 Interest rate swap agreements Interest expense 11 — 11 — Interest rate swap agreements Other comprehensive loss (51 ) — (51 ) — Natural gas swap contracts Other comprehensive loss — (8 ) — (67 ) Natural gas futures contracts Other comprehensive income (loss) — (2,463 ) — 763 Total $ 2,552 $ (2,713 ) $ 3,788 $ 2,069

Fair Value of Financial Instr_2

Fair Value of Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2020
Fair Value Disclosures [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 June 30, 2020 and December 31, 2019 : Fair Value Measurements Using: As of June 30, 2020 Fair Value Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) (in thousands) Assets: Investments—equity securities $ 20 $ 20 $ — $ — Investments—guaranteed income fund 2,334 — — 2,334 Investments—mutual funds and other 7,217 7,217 — — Total investments 9,571 7,237 — 2,334 Derivative assets 1,270 — 1,270 — Total assets $ 10,841 $ 7,237 $ 1,270 $ 2,334 Liabilities: Derivative liabilities $ 802 $ — $ 802 $ — Fair Value Measurements Using: As of December 31, 2019 Fair Value Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) (in thousands) Assets: Investments—equity securities $ 27 $ 27 $ — $ — Investments—guaranteed income fund 803 — — 803 Investments—mutual funds and other 8,399 8,399 — — Total investments 9,229 8,426 — 803 Derivative assets — — — — Total assets $ 9,229 $ 8,426 $ — $ 803 Liabilities: Derivative liabilities $ 1,844 $ — $ 1,844 $ —
Summary of Changes in Fair Value of Investments	The following table sets forth the summary of the changes in the fair value of Level 3 investments for the six months ended June 30, 2020 and 2019 : Six Months Ended 2020 2019 (in thousands) Beginning Balance $ 803 $ 686 Purchases and adjustments 226 110 Transfers 1,345 — Distribution (50 ) (12 ) Investment income 10 7 Ending Balance $ 2,334 $ 791

Long-Term Debt (Tables)

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2020
Debt Disclosure [Abstract]
Outstanding Long-Term Debt	Our outstanding long-term debt is shown below: June 30, December 31, (in thousands) 2020 2019 FPU secured first mortgage bonds (1) : 9.08% bond, due June 1, 2022 $ 7,992 $ 7,990 Uncollateralized senior notes: 5.50% note, due October 12, 2020 2,000 2,000 5.93% note, due October 31, 2023 10,500 12,000 5.68% note, due June 30, 2026 17,400 20,300 6.43% note, due May 2, 2028 5,600 6,300 3.73% note, due December 16, 2028 18,000 18,000 3.88% note, due May 15, 2029 45,000 50,000 3.25% note, due April 30, 2032 70,000 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 Term Note due February 28, 2020 — 30,000 Less: debt issuance costs (786 ) (822 ) Total long-term debt 445,706 485,768 Less: current maturities (15,600 ) (45,600 ) Total long-term debt, net of current maturities $ 430,106 $ 440,168 (1) FPU secured first mortgage bonds are guaranteed by Chesapeake Utilities.
Schedule of Line of Credit Facilities [Line Items]
Schedule of Line of Credit Facilities [Table Text Block]	(in thousands) Total Borrowing Capacity Less: Amount of Debt Issued Less: Unfunded Commitments Remaining Borrowing Capacity Shelf Agreement Prudential Shelf Agreement (1) (2) $ 370,000 $ (170,000 ) $ (50,000 ) $ 150,000 MetLife Shelf Agreement (3) 150,000 — — 150,000 NYL Shelf Agreement (4) 150,000 (100,000 ) (40,000 ) 10,000 Total Shelf Agreements as of June 30, 2020 $ 670,000 $ (270,000 ) $ (90,000 ) $ 310,000

Short-Term Borrowings (Tables)

Short-Term Borrowings (Tables)	3 Months Ended
	Mar. 31, 2020
Short-term Debt [Line Items]
Schedule of Short-term Debt [Table Text Block]	The following table summarizes our short-term borrowing facilities information at June 30, 2020 and December 31, 2019 : Outstanding borrowings at (in thousands) Total Facility LIBOR Based Interest Rate June 30, 2020 December 31, 2019 Available at June 30, 2020 Bank Credit Facility Existing Bilateral Facilities Committed revolving credit facility A $ 55,000 plus 0.75 percent $ 55,000 $ 55,000 $ — Committed revolving credit facility B 80,000 plus 0.75 percent 77,501 57,150 2,499 Committed revolving credit facility C 45,000 plus 0.75 percent 32,412 42,040 12,588 Committed revolving credit facility D 40,000 plus 0.85 percent 40,000 40,000 — Committed revolving credit facility E (2) 150,000 plus 1.125 percent 80,000 50,000 70,000 Total existing bilateral facilities 370,000 284,913 244,190 85,087 Incremental Facilities Committed revolving credit facility F 35,000 plus 1.75 percent — — 35,000 Committed revolving credit facility G 15,000 plus 1.75 percent — — 15,000 Committed revolving credit facility H 25,000 plus 1.75 percent — — 25,000 Committed revolving credit facility I 20,000 plus 1.75 percent — — 20,000 Total incremental facilities 95,000 — — 95,000 Total short term credit facilities $ 465,000 284,913 244,190 $ 180,087 Book overdrafts (1) 1,492 3,181 Total short-term borrowing $ 286,405 $ 247,371 (1) If presented, these book overdrafts would be funded through the bank revolving credit facilities. (2) This committed revolving credit facility includes a restriction that our short-term borrowings, excluding any borrowings under the committed revolving credit facility, cannot exceed $350.0 million .

Leases Leases (Tables)

Leases Leases (Tables)	6 Months Ended
	Jun. 30, 2020
Lease Disclosure [Abstract]
Lease, Cost [Table Text Block]	The following table presents information related to our total lease cost included in our condensed consolidated statements of income: Three Months Ended Six Months Ended June 30, June 30, ( in thousands) Classification 2020 2019 2020 2019 Operating lease cost (1) Operations expense $ 629 $ 654 $ 1,255 $ 1,288 Finance lease cost: Amortization of lease assets Depreciation and amortization — 249 — 650 Interest on lease liabilities Interest expense — 1 — 5 Net lease cost $ 629 $ 904 $ 1,255 $ 1,943 (1)
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 condensed consolidated balance sheet at June 30, 2020 and December 31, 2019 : (in thousands) Balance sheet classification June 30, 2020 December 31, 2019 Assets Operating lease assets Operating lease right-of-use assets $ 11,546 $ 11,563 Total lease assets $ 11,546 $ 11,563 Liabilities Current Operating lease liabilities Other accrued liabilities $ 1,647 $ 1,705 Noncurrent Operating lease liabilities Operating lease - liabilities 10,055 9,896 Total lease liabilities $ 11,702 $ 11,601
Leases, Weighted Average Remaining Lease Term [Table Text Block]	The following table presents our weighted-average remaining lease terms and weighted-average discount rates for our operating and financing leases at June 30, 2020 and December 31, 2019 : June 30, 2020 December 31, 2019 Weighted-average remaining lease term ( in years ) Operating leases 8.6 8.88 Weighted-average discount rate Operating leases 3.8 % 3.8 %
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 condensed consolidated statements of cash flows as of June 30, 2020 and 2019 : Six Months Ended June 30, (in thousands) 2020 2019 Operating cash flows from operating leases $ 1,034 $ 1,100 Operating cash flows from finance leases $ — $ 5 Financing cash flows from finance leases $ — $ 650
Schedule of Maturities of Leases [Table Text Block]	The following table presents the future undiscounted maturities of our operating and financing leases at June 30, 2020 and for each of the next five years and thereafter: (in thousands) Operating Leases (1) Remainder of 2020 $ 1,089 2021 2,031 2022 1,937 2023 1,874 2024 1,619 2025 1,383 Thereafter 3,876 Total lease payments $ 13,809 Less: Interest 2,107 Present value of lease liabilities $ 11,702 (1) Operating lease payments include $4.0 million related to options to extend lease terms that are reasonably certain of being exercised.

Summary of Accounting policie_3

Summary of Accounting policies - Additional Information (Details) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2020USD ($)	Jun. 30, 2020USD ($)	Dec. 31, 2019USD ($)
Disposal Transactions Closing in October 2019 [Abstract]
Number of Disposal Transactions	4	4
Financing Receivable, Allowance for Credit Loss [Line Items]
Accounts Receivable, Allowance for Credit Losses, Current, Disclosure	$ 2,104	$ 2,104	$ 1,337
Provision for Other Credit Losses		794
Accounts Receivable, Allowance for Credit Loss, Recovery		450
Allowance for Loan and Lease Losses, Write-offs		$ (477)

Summary of Accounting Policie_4

Summary of Accounting Policies Acquisitions Additional information (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Business Acquisition [Line Items]
Revenues	$ 97,051	$ 94,542	$ 249,741	$ 255,005
Operating Income (Loss)	17,977	18,165	60,111	62,287
Unregulated Energy [Member]
Business Acquisition [Line Items]
Operating Income (Loss)	$ 281	$ (771)	$ 14,142	$ 14,486

Calculation of Earnings Per S_3

Calculation of Earnings Per Share - Calculation of Basic and Diluted Earnings Per Share (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Earnings Per Share [Abstract]
Income (Loss) from Continuing Operations, Per Basic Share	$ 0.65	$ 0.55	$ 2.42	$ 2.31
Discontinued Operation, Income (Loss) from Discontinued Operation, Net of Tax, Per Basic Share	$ 0.02	$ (0.04)	$ 0.01	$ (0.05)
Calculation of Basic Earnings Per Share:
Net Income	$ 10,956	$ 8,304	$ 39,886	$ 36,968
Weighted shares outstanding (shares)	16,448,490	16,401,028	16,431,724	16,393,022
Basic Earnings Per Share (in dollars per share)	$ 0.67	$ 0.51	$ 2.43	$ 2.26
Reconciliation of Numerator:
Net Income	$ 10,956	$ 8,304	$ 39,886	$ 36,968
Reconciliation of Denominator:
Weighted shares outstanding - Basic (shares)	16,448,490	16,401,028	16,431,724	16,393,022
Effect of dilutive securities:
Share-based compensation (shares)	55,113	44,715	56,083	46,311
Adjusted denominator-Diluted (shares)	16,503,603	16,445,743	16,487,807	16,439,333
Income (Loss) from Continuing Operations, Per Diluted Share	$ 0.64	$ 0.54	$ 2.41	$ 2.30
Discontinued Operation, Income (Loss) from Discontinued Operation, Net of Tax, Per Diluted Share	0.02	(0.04)	0.01	(0.05)
Diluted Earnings Per Share (in dollars per share)	$ 0.66	$ 0.50	$ 2.42	$ 2.25
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax	$ 295	$ (610)	$ 184	$ (757)

Acquisitions and Divestitures_3

Acquisitions and Divestitures (Details) $ in Thousands		3 Months Ended			6 Months Ended
		Jun. 30, 2020USD ($)	Mar. 31, 2020USD ($)	Jun. 30, 2019USD ($)	Jun. 30, 2020USD ($)	Jun. 30, 2019USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal Group, Including Discontinued Operation, Depreciation and Amortization				$ 146		$ 291
Deferred Income Tax Expense (Benefit)					$ 12,232	7,746
Disposal Group, Including Discontinued Operation, Revenue	[1]	$ 3		41,280	23	118,302
Disposal Group, Including Discontinued Operation, Costs of Goods Sold	[1]	10		40,539	1	115,701
Disposal Group, Including Discontinued Operation, Operating Expense		$ 39		1,470	$ 197	3,460
Number of Disposal Transactions		4			4
Proceeds from Divestiture of Businesses					$ 23,100
Disposal Group, Including Discontinued Operation, Operating Income (Loss)		$ (46)		(729)	(175)	(859)
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax					5,500
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax		(52)		(830)	(204)	(1,025)
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax, Incremental		200			200
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax		295		(610)	184	(757)
Settlement Gain		130		130	130	130
Disposal Group, Including Discontinued Operation, Interest Expense		(6)		(101)	(29)	(166)
Discontinued Operation, Tax Effect of Gain (Loss) from Disposal of Discontinued Operation		(147)		(220)	(188)	(268)
Revenues		97,051		94,542	249,741	255,005
Operating Income (Loss)		17,977		18,165	60,111	62,287
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax			$ 7,300		7,500
Regulated Energy [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Operating Income (Loss)		18,006		18,028	45,894	47,769
PESCO [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Discontinued Operation, Intra-Entity Amounts, Discontinued Operation after Disposal, Revenue		4,900			14,800
Discontinued Operations, Disposed of by Sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain Loss From Discontinued Operations		295		(610)	184	(757)
Discontinued Operations [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Deferred Income Tax Expense (Benefit)				(1,021)		375
Settlement Gain				(97)		(681)
Business Combination, Working Capital		8,000			8,000
Unregulated Energy [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Operating Income (Loss)		281		$ (771)	14,142	$ 14,486
Elkton Gas [Member] | Regulated Energy [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Business Acquisition, Purchase Price					$ 15,000
Number of customers acquired through acquisition					7,000
Boulden [Member] | Unregulated Energy [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment		8,300			$ 8,300
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Finite-Lived Intangibles		5,100			5,100
Goodwill, Acquired During Period					11,200
Revenues		800			3,600
Operating Income (Loss)		100			$ 1,400
Number of customers acquired through acquisition					5,200
Business Combination, Consideration Transferred					$ 24,600
Business Combination, Working Capital		200			200
Business Combination, Contingent Consideration, Liability		$ 600			$ 600
[1]	(1) Included in operating revenues and cost of sales for the three and six months ended June 30, 2019 , is $4.9 million and $14.8 million , respectively, representing amounts which had been previously eliminated in consolidation related to intercompany activity that continued with the buyers after the disposition of the assets of PESCO.

Revenue Recognition Disegragati

Revenue Recognition Disegragation of Revenue (Details) - USD ($)	3 Months Ended				6 Months Ended
	Jun. 30, 2020		Jun. 30, 2019		Jun. 30, 2020		Jun. 30, 2019
Disaggregation of Revenue [Line Items]
Revenues	$ 97,051,000		$ 94,542,000		$ 249,741,000		$ 255,005,000
Revenue from Contract with Customer, Excluding Assessed Tax	97,051,000	[1]	94,542,000	[1]	249,741,000	[2]	255,005,000	[2]
Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	73,518,000	[1]	73,403,000	[1]	176,473,000	[2]	177,021,000	[2]
Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	27,741,000	[1]	25,625,000	[1]	81,753,000	[2]	86,704,000	[2]
Other Segments And Intersegments Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(4,208,000)		(4,486,000)		(8,485,000)		(8,720,000)
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(4,208,000)	[1]	(4,486,000)	[1]	(8,485,000)	[2]	(8,720,000)	[2]
Consolidation, Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(15,369,000)		(16,082,000)		(30,955,000)		(35,557,000)
Eliminations [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(11,145,000)		(8,968,000)		(22,430,000)		(18,714,000)
Other [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenues	100,000		(300,000)		800,000		(200,000)
Other [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenues	40,000		100,000		100,000		200,000
Revenue from Contract with Customer, Excluding Assessed Tax	(16,000)		(2,628,000)		(40,000)		(8,123,000)
Energy Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	61,025,000		61,066,000		151,162,000		151,808,000
Energy Distribution [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	61,025,000		61,066,000		151,162,000		151,808,000
Energy Distribution [Member] | Delaware natural gas division [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	11,758,000		8,256,000		38,325,000		35,805,000
Energy Distribution [Member] | Delaware natural gas division [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	11,758,000		8,256,000		38,325,000		35,805,000
Energy Distribution [Member] | Central Florida Gas Division [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	7,231,000		7,015,000		15,708,000		14,915,000
Energy Distribution [Member] | Central Florida Gas Division [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	7,231,000		7,015,000		15,708,000		14,915,000
Energy Distribution [Member] | FPU Electric Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	15,701,000		20,464,000		29,920,000		34,842,000
Energy Distribution [Member] | FPU Electric Distribution [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	15,701,000		20,464,000		29,920,000		34,842,000
Energy Distribution [Member] | Florida Public Utilities Company [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	19,498,000		18,663,000		44,942,000		42,449,000
Energy Distribution [Member] | Florida Public Utilities Company [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	19,498,000		18,663,000		44,942,000		42,449,000
Energy Distribution [Member] | Maryland Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	3,979,000		3,186,000		13,117,000		13,233,000
Energy Distribution [Member] | Maryland Natural Gas [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	3,979,000		3,186,000		13,117,000		13,233,000
Energy Distribution [Member] | Sandpiper [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,858,000		3,482,000		9,150,000		10,564,000
Energy Distribution [Member] | Sandpiper [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,858,000		3,482,000		9,150,000		10,564,000
Energy Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	28,193,000		26,727,000		62,077,000		62,819,000
Energy Transmission [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	23,638,000		21,305,000		47,741,000		43,927,000
Energy Transmission [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,555,000		5,422,000		14,336,000		18,892,000
Energy Transmission [Member] | Aspire [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,555,000		5,422,000		14,336,000		18,892,000
Energy Transmission [Member] | Aspire [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,555,000		5,422,000		14,336,000		18,892,000
Energy Transmission [Member] | Eastern Shore Gas Company [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	18,277,000		17,740,000		37,556,000		36,796,000
Energy Transmission [Member] | Eastern Shore Gas Company [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	18,277,000		17,740,000		37,556,000		36,796,000
Energy Transmission [Member] | Peninsula Pipeline [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5,361,000		3,565,000		10,185,000		7,131,000
Energy Transmission [Member] | Peninsula Pipeline [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5,361,000		3,565,000		10,185,000		7,131,000
Energy Generation [Member] | Eight Flags [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	3,694,000		4,235,000		8,017,000		8,377,000
Energy Generation [Member] | Eight Flags [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	3,694,000		4,235,000		8,017,000		8,377,000
Propane Delivery [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	17,260,000		17,488,000		55,883,000		64,017,000
Propane Delivery [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	17,260,000		17,488,000		55,883,000		64,017,000
Energy Services [Member] | Marlin Gas Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,248,000				3,557,000		3,541,000
Energy Services [Member] | Marlin Gas Services [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,248,000		1,108,000		3,557,000		3,541,000
Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(15,501,000)		(16,214,000)		(31,219,000)		(35,821,000)
Eliminations [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(11,145,000)		(8,968,000)		(22,430,000)		(18,714,000)
Eliminations [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(16,000)		(2,628,000)		(40,000)		(8,123,000)
Eliminations [Member] | Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(4,340,000)		(4,618,000)		(8,749,000)		(8,984,000)
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	132,000		132,000		264,000		264,000
Other [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0		0		0		0
Other [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 132,000		$ 132,000		$ 264,000		$ 264,000
[1]	(1) Total operating revenues for the three months ended June 30, 2020 , include other revenue (revenues from sources other than contracts with customers) of $0.1 million and $0.04 million for our Regulated and Unregulated Energy segments, respectively, and $(0.3) million and $0.1 million for our Regulated and Unregulated Energy segments, respectively, for the three months ended June 30, 2019 . The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the Maryland division and Sandpiper and late fees.
[2]	(1) Total operating revenues for the six months ended June 30, 2020 , include other revenue (revenues from sources other than contracts with customers) of $0.8 million and $0.1 million for our Regulated and Unregulated Energy segments, respectively, and $(0.2) million and $0.2 million for our Regulated and Unregulated Energy segments, respectively, for the six months ended June 30, 2019 . The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the Maryland division and Sandpiper and late fees.

Revenue Recognition Contract Ba

Revenue Recognition Contract Balances with Customers (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Revenue from Contract with Customer [Abstract]
Receivables from Customers	$ 35,764	$ 35,764		$ 47,430
Contract with Customer, Asset, Net, Current	18	18		18
Contract with Customer, Asset, Net, Noncurrent	4,338	4,338		3,465
Customer deposits and refunds	347	347		$ 589
Increase (Decrease) in Receivables		(11,666)
Increase (Decrease) in Other Current Assets		0
Increase (Decrease) in Other Noncurrent Assets		873
Increase (Decrease) in Other Current Liabilities		(242)
Contract with Customer, Liability, Revenue Recognized	$ 200	$ 600	$ 500

Revenue Recognition Remaining P

Revenue Recognition Remaining Performance Obligations (Details) $ in Thousands	Jun. 30, 2020USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue from Contract with Customer [Abstract]
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
Revenue from Contract with Customer [Abstract]
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
Revenue from Contract with Customer [Abstract]
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
Revenue from Contract with Customer [Abstract]
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
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 283
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	566
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	566
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	566
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	566
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	275
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	825
Natural gas distribution operations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	1,950
Natural gas distribution operations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	4,124
Natural gas distribution operations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	5,167
Natural gas distribution operations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	4,936
Natural gas distribution operations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	4,699
Natural gas distribution operations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	4,166
Natural gas distribution operations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	32,996
Eastern Shore and Peninsula Pipeline [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	19,059
Eastern Shore and Peninsula Pipeline [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	35,720
Eastern Shore and Peninsula Pipeline [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	28,513
Eastern Shore and Peninsula Pipeline [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	22,930
Eastern Shore and Peninsula Pipeline [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	20,641
Eastern Shore and Peninsula Pipeline [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	19,283
Eastern Shore and Peninsula Pipeline [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	175,743
Total for Segments [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	21,292
Total for Segments [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	40,410
Total for Segments [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	34,246
Total for Segments [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	28,432
Total for Segments [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	25,906
Total for Segments [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	23,724
Total for Segments [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 209,564

Rates and Other Regulatory Ac_3

Rates and Other Regulatory Activities - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2020USD ($)customerDekathermmi
Electric Limited Proceedings [Member]
Rates and Other Regulatory Activities [Line Items]
Extent of Customers Losing Service	100.00%
Asset Recovery Damaged Property Costs, Noncurrent	$ 1,500,000
Deferred Storm and Property Reserve Deficiency, Noncurrent	800,000
Amounts Spent to Restore Service	65,000,000
Hurricane Dorrian [Member]
Rates and Other Regulatory Activities [Line Items]
Asset Recovery Damaged Property Costs, Noncurrent	$ 1,200,000
Regulatory Liability, Amortization Period	30 years
Regulatory Liability, Amortization Period, Revised	10 years
Eastern Shore [Member]
Rates and Other Regulatory Activities [Line Items]
Cost Recovery, Capital	$ 500,000
Callahan Pipeline [Domain] | Peninsula Pipeline Company [Member]
Rates and Other Regulatory Activities [Line Items]
Number of Pipeline Miles | mi	26
Callahan Project [Member] | Peninsula Pipeline [Member]
Rates and Other Regulatory Activities [Line Items]
Diameter of Pipe | mi	16
Del-Mar Pathway Project [Member] | Eastern Shore [Member]
Rates and Other Regulatory Activities [Line Items]
Number of Mainline Pipeline Miles | mi	13
Additional Firm Natural Gas Transportation Deliverability | Dekatherm	14,300
number of customers | customer	4
Number of Pipeline Miles | mi	6
Fort Meade and Indiantown Divisions [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	$ 312,000
Delaware natural gas division [Member]
Rates and Other Regulatory Activities [Line Items]
One time bill credit related to TCJA	1,500,000
Regulatory Liabilities	12,788,000
Eastern Shore [Member]
Rates and Other Regulatory Activities [Line Items]
One time bill credit related to TCJA	900,000
Regulatory Liabilities	34,190,000
Florida Public Utilities Company [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	19,201,000
Central Florida Gas Division [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	8,244,000
Maryland Division [Member]
Rates and Other Regulatory Activities [Line Items]
One time bill credit related to TCJA	400,000
Regulatory Liabilities	4,029,000
Sandpiper [Member]
Rates and Other Regulatory Activities [Line Items]
One time bill credit related to TCJA	600,000
Regulatory Liabilities	3,739,000
FPU electric division [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	$ 6,823,000
Regulated Energy [Member] | Elkton Gas [Member]
Rates and Other Regulatory Activities [Line Items]
Number of customers acquired through acquisition	7,000

Environmental Commitments and_3

Environmental Commitments and Contingencies - Additional Information (Detail)	6 Months Ended	12 Months Ended
	Jun. 30, 2020USD ($)site	Dec. 31, 2019USD ($)
Environmental Commitments And Contingencies [Line Items]
Company's exposure in number of former Manufactured Gas Plant Sites | site	7
Environmental liabilities	$ 4,520,000	$ 6,468,000
West Palm Beach Florida [Member] | Minimum [Member]
Environmental Commitments And Contingencies [Line Items]
Estimated costs of remediation range, minimum	3,300,000
West Palm Beach Florida [Member] | Maximum [Member]
Environmental Commitments And Contingencies [Line Items]
Estimated costs of remediation range, minimum	14,200,000
Winter Haven Florida [Member] | Maximum [Member]
Environmental Commitments And Contingencies [Line Items]
Environmental remediation expense	400,000
Seaford [Member] | Minimum [Member]
Environmental Commitments And Contingencies [Line Items]
Estimated costs of remediation range, minimum	200,000
Seaford [Member] | Maximum [Member]
Environmental Commitments And Contingencies [Line Items]
Estimated costs of remediation range, minimum	500,000
FPU [Member]
Environmental Commitments And Contingencies [Line Items]
Environmental liabilities	6,100,000	8,000,000
Approval of recovery of environmental costs	14,000,000
Environmental costs recovered	12,200,000	11,900,000
FPU [Member] | Manufactured Gas Plant [Member]
Environmental Commitments And Contingencies [Line Items]
Regulatory Assets for future recovery of environmental costs	$ 1,800,000	$ 2,100,000

Other Commitments and Conting_2

Other Commitments and Contingencies - Additional Information (Detail) $ in Millions	6 Months Ended
	Jun. 30, 2020USD ($)
Other Commitments [Line Items]
Debt Service Coverage Ratio	1.25
Debt Service Coverage Ratio Measurement Period	12
Maximum Days To Make Default Good	5 days
Ratio based on average number of prior quarters	6
Ratios based on average of the prior quarters	1 year 6 months
Funds from operations interest coverage ratio minimum times	2
Total debt to capital maximum	0.65
Number Of Years For Power Purchase Agreement	20 years
Contract Duration	20 years
Aggregate guaranteed amount	$ 37
Guarantor Obligations, Current Carrying Value	11.2
Draws on letters of credit	$ 4.4
Florida Natural Gas Distribution and Eight Flags [Member]
Other Commitments [Line Items]
Number of Years for Asset Management Agreement	10 years
Delmarva [Member]
Other Commitments [Line Items]
Number of Years for Asset Management Agreement	3 years
Minimum [Member] | Florida Natural Gas Distribution and Eight Flags [Member]
Other Commitments [Line Items]
Number of Years for Asset Management Agreement	1 year

Segment Information - Schedule

Segment Information - Schedule of Segment Reporting Information by Segment (Detail) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2020USD ($)	Jun. 30, 2019USD ($)	Jun. 30, 2020USD ($)	Jun. 30, 2019USD ($)	Dec. 31, 2019USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments				2
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers		$ 97,051	$ 94,542	$ 249,741	$ 255,005
Operating Income
Total operating income		17,977	18,165	60,111	62,287
Other expense, net		(279)	(320)	3,039	(380)
Interest		5,054	5,552	10,868	11,180
Income Before Income Taxes		12,644	12,293	52,282	50,727
Income Taxes on Continuing Operations		1,983	3,379	12,580	13,002
Net Income		10,956	8,304	39,886	36,968
Identifiable Assets
Total identifiable assets		1,822,175		1,822,175		$ 1,783,198
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax		295	(610)	184	(757)
Regulated Energy [Member]
Operating Income
Total operating income		18,006	18,028	45,894	47,769
Identifiable Assets
Total identifiable assets		1,477,616		1,477,616		1,434,066
Unregulated Energy [Member]
Operating Income
Total operating income		281	(771)	14,142	14,486
Identifiable Assets
Total identifiable assets		296,140		296,140		296,810
Other [Member]
Identifiable Assets
Total identifiable assets		48,419		48,419		52,322
Other and eliminations [Member]
Operating Income
Total operating income		(310)	908	75	32
Continuing Operations [Member]
Identifiable Assets
Total identifiable assets		1,822,175		1,822,175		$ 1,783,198
Operating Revenues, Unaffiliated Customers [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers		97,051	94,542	249,741	255,005
Operating Revenues, Unaffiliated Customers [Member] | Regulated Energy [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers		73,043	72,880	175,536	175,951
Operating Revenues, Unaffiliated Customers [Member] | Unregulated Energy [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers		24,008	21,662	74,205	79,054
Intersegment Revenues [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	[1]	4,340	4,618	8,749	8,984
Intersegment Revenues [Member] | Regulated Energy [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	[1]	475	523	937	1,070
Intersegment Revenues [Member] | Unregulated Energy [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	[1]	3,733	3,963	7,548	7,650
Intersegment Revenues [Member] | Other [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	[1]	132	132	264	264
Retained Earnings [Member]
Operating Income
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent		10,661	8,914	39,702	37,725
Net Income		$ 10,956	$ 8,304	$ 39,886	$ 36,968
[1]	All significant intersegment revenues are billed at market rates and have been eliminated from consolidated operating revenues.

Stockholder's Equity - Accumu_2

Stockholder's Equity - Accumulated Other Comprehensive Income (Loss) - Changes in Accumulated Other Comprehensive Loss (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance			$ (6,267)	$ (6,713)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax			2,741	1,000
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax			(936)	81
Net current-period other comprehensive income (loss)	$ 1,732	$ (2,008)	1,805	1,081
Ending balance	(4,462)	(5,747)	(4,462)	(5,747)
UnrealizedGainsLossesFromDefinedBenefitPensionAndPostretirementPlanItems [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance			(4,933)	(5,928)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax			0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax			132	213
Net current-period other comprehensive income (loss)			132	213
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect				0
Ending balance	(4,801)	(5,715)	(4,801)	(5,715)
Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance			(1,334)	(785)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax			2,770	1,000
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax			(1,060)	(132)
Net current-period other comprehensive income (loss)			1,710	868
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect				(115)
Ending balance	376	$ (32)	376	(32)
AOCI Attributable to Parent [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect				$ (115)
Accumulated (Gain) Loss from Interest Rate Swap Cash Flows Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax			(29)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax			(8)
Net current-period other comprehensive income (loss)			(37)
Ending balance	$ (37)		$ (37)

Stockholder's Equity - Accum_2

Stockholder's Equity - Accumulated Other Comprehensive Income (Loss) - Reclassifications of Accumulated Other Comprehensive Loss (Detail) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Amortization of pension and postretirement items:
Tax benefit		$ (1,983)	$ (3,379)	$ (12,580)	$ (13,002)
Reclassification out of Accumulated Other Comprehensive Income [Member]
Amortization of pension and postretirement items:
Net of tax		114	(14)	936	(81)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment [Member]
Amortization of pension and postretirement items:
Prior service cost	[1]	19	19	38	39
Net loss	[1]	(108)	(163)	(215)	(328)
Total before tax		(89)	(144)	(177)	(289)
Tax benefit		23	37	45	76
Net of tax		(66)	(107)	(132)	(213)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Amortization of pension and postretirement items:
Total before tax		238	127	1,465	171
Tax benefit		(66)	(34)	(405)	(39)
Net of tax		172	93	1,060	132
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated (Gain) Loss from Interest Rate Swap Cash Flows Hedges [Member]
Amortization of pension and postretirement items:
Other Comprehensive Income Loss Adjustments AOCI Swap Agreements				11
Total before tax		11	0	11	0
Tax benefit		(3)	0	(3)	0
Net of tax		8	0	8	0
Propane Swap Agreement [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Amortization of pension and postretirement items:
Other Comprehensive Income Loss Adjustments AOCI Swap Agreements	[2]	238	252	1,465	858
Natural Gas Swaps [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Amortization of pension and postretirement items:
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, before Tax	[2],[3]				11
Natural Gas Futures [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Amortization of pension and postretirement items:
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, before Tax	[2],[3]	$ 0	$ (125)	$ 0	$ (698)
[1]	These amounts are included in the computation of net periodic costs (benefits). See Note 10 , Employee Benefit Plans , for additional details.
[2]	These amounts are included in the effects of gains and losses from derivative instruments. See Note 13, Derivative Instruments , for additional details.
[3]	PESCO's results are reflected as discontinued operations in our condensed consolidated statements of income.

Employee Benefit Plans (Detail)

Employee Benefit Plans (Detail) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost		$ (19)	$ (19)	$ (38)	$ (39)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		217	268	434	537
Defined Benefit Plan Amounts Recognized Gain (Loss)		198	249	396	498
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax	[1]	89	144	178	289
Defined Benefit Plan Amounts Recognized From Regulatory Asset		109	105	218	209
Chesapeake Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Contributions by Employer				200
Interest cost		46	104	92	209
Expected return on plan assets		(42)	(127)	(84)	(254)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		65	101	130	203
Net periodic cost (benefit)	[1]	69	78	138	158
Total periodic cost		69	78	138	158
Defined Benefit Plan Amounts Recognized Gain (Loss)		65	101	130	203
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax	[1]	65	101	130	203
Florida Public Utilities Company Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Contributions by Employer		1,800		2,100
Interest cost		518	615	1,036	1,230
Expected return on plan assets		(745)	(693)	(1,490)	(1,386)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		135	129	270	258
Net periodic cost (benefit)	[1]	(92)	51	(184)	102
Amortization of pre-merger regulatory asset		0	191	0	381
Total periodic cost		(92)	242	(184)	483
Defined Benefit Plan Amounts Recognized Gain (Loss)		135	129	270	258
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax	[1]	26	24	52	49
Defined Benefit Plan Amounts Recognized From Regulatory Asset		109	105	218	209
Chesapeake Pension SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Contributions by Employer				100
Interest cost		16	21	32	42
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		5	26	10	52
Net periodic cost (benefit)	[1]	21	47	42	94
Total periodic cost		21	47	42	94
Defined Benefit Plan Amounts Recognized Gain (Loss)		5	26	10	52
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax	[1]	5	26	10	52
Chesapeake Postretirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost		8	9	16	19
Amortization of prior service cost		(19)	(19)	(38)	(39)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		12	12	24	24
Net periodic cost (benefit)	[1]	1	2	2	4
Total periodic cost		1	2	2	4
Defined Benefit Plan Amounts Recognized Gain (Loss)		(7)	(7)	(14)	(15)
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax	[1]	(7)	(7)	(14)	(15)
Florida Public Utilities Company Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost		10	12	20	24
Net periodic cost (benefit)	[1]	10	12	20	24
Amortization of pre-merger regulatory asset		2	2	4	4
Total periodic cost		$ 12	$ 14	$ 24	$ 28
[1]	See Note 9 , Stockholder's Equity .

Employee Benefit Plans - Additi

Employee Benefit Plans - Additional Information (Detail) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2020USD ($)	Jun. 30, 2020USD ($)
Florida Public Utilities Company Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Contribution to pension plan	$ 1,800	$ 2,100
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	3,200	3,200
Chesapeake Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Contribution to pension plan		200
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	300	300
Chesapeake Pension SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Contribution to pension plan		100
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	200	200
Chesapeake Postretirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	100	100
Florida Public Utilities Company Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	$ 100	$ 100

Employee Benefit Plans - Amount

Employee Benefit Plans - Amounts Included in Regulatory Asset and Accumulated Other Comprehensive Income/Loss Recognized as Net Periodic Benefit Cost (Detail) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Prior service cost (credit)		$ (19)	$ (19)	$ (38)	$ (39)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		217	268	434	537
Recognized from accumulated other comprehensive loss	[1]	89	144	178	289
Recognized from regulatory asset		109	105	218	209
Total recognized in net periodic benefit cost		198	249	396	498
Chesapeake Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		65	101	130	203
Recognized from accumulated other comprehensive loss	[1]	65	101	130	203
Total recognized in net periodic benefit cost		65	101	130	203
Florida Public Utilities Company Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		135	129	270	258
Recognized from accumulated other comprehensive loss	[1]	26	24	52	49
Recognized from regulatory asset		109	105	218	209
Total recognized in net periodic benefit cost		135	129	270	258
Chesapeake Pension SERP [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		5	26	10	52
Recognized from accumulated other comprehensive loss	[1]	5	26	10	52
Total recognized in net periodic benefit cost		5	26	10	52
Chesapeake Postretirement Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Prior service cost (credit)		(19)	(19)	(38)	(39)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		12	12	24	24
Recognized from accumulated other comprehensive loss	[1]	(7)	(7)	(14)	(15)
Total recognized in net periodic benefit cost		$ (7)	$ (7)	$ (14)	$ (15)
[1]	See Note 9 , Stockholder's Equity .

Investments - Schedule of Inves

Investments - Schedule of Investments (Details) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Investments schedule [Line Items]
Investments, at fair value	$ 9,571	$ 9,229
Rabbi Trust Associated With Deferred Compensation Plan [Member]
Investments schedule [Line Items]
Investments, at fair value	9,551	9,202
Equity Securities [Member]
Investments schedule [Line Items]
Investments, at fair value	$ 20	$ 27

Investments - Additional Inform

Investments - Additional Information (Detail) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Investments, Debt and Equity Securities [Abstract]
Unrealized gain (loss), net of other expenses	$ 1,400,000	$ 400,000	$ (100,000)	$ 1,100,000

Share-Based Compensation - Shar

Share-Based Compensation - Share-Based Compensation Amounts Included in Net Income (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	$ 1,266	$ 609	$ 2,322	$ 1,095
Less: tax benefit	(331)	(158)	(607)	(285)
Share-Based Compensation amounts included in net income	935	451	$ 1,715	810
Awards to non-employee directors [Member]
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, Grants in Period			887
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value			$ 84.47
Total compensation expense	$ 181	157	$ 357	305
Award to key employees [Member]
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, Nonvested, Number	183,721		183,721		157,817
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period			66,857
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period			35,651
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Expired In Period			(5,302)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 86.98		$ 86.98		$ 80.28
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value			92.78
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value			66.48
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Expirations Weighted Average Grant Date Fair Value			$ 65.32
Total compensation expense	$ 1,085	$ 452	$ 1,965	$ 790

Share-Based Compensation - Summ

Share-Based Compensation - Summary of Stock Activity under the SICP (Detail)	6 Months Ended
	Jun. 30, 2020$ / sharesshares
Award to key employees [Member]
Number of Shares
Outstanding - December 31, 2017 (shares) | shares	157,817
Granted awards (shares) | shares	66,857
Vested (shares) | shares	(35,651)
Expired (shares) | shares	5,302
Outstanding - September 30, 2018 (shares) | shares	183,721
Weighted Average Fair Value
Outstanding - December 31, 2018 (in dollars per share) | $ / shares	$ 80.28
Granted (in dollars per share) | $ / shares	92.78
Vested (in dollars per share) | $ / shares	66.48
Expired (in dollars per share) | $ / shares	65.32
Outstanding - March 31, 2019 (in dollars per share) | $ / shares	$ 86.98
Awards to non-employee directors [Member]
Number of Shares
Granted awards (shares) | shares	887
Weighted Average Fair Value
Granted (in dollars per share) | $ / shares	$ 84.47

Share-Based Compensation - Addi

Share-Based Compensation - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Thousands	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation	10,319	7,635
Payment, Tax Withholding, Share-based Payment Arrangement	$ 977	$ 692
Unrecognized compensation cost	$ 5,800
Awards to non-employee directors [Member]
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, Grants in Period, Weighted Average Grant Date Fair Value	$ 84.47
Granted awards (shares)	887
Unrecognized compensation expense related to the awards to non-employee directors	$ 600
Total [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted awards (shares)	8,870
Awards to non-employee director [Member]
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, Grants in Period, Weighted Average Grant Date Fair Value	$ 95.83
Granted awards (shares)	254
Award to key employees [Member]
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 Expired In Period	(5,302)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 92.78
Granted awards (shares)	66,857
Vesting period	3 years
Payment, Tax Withholding, Share-based Payment Arrangement	$ 1,000
Intrinsic value of the SICP awards	$ 15,400
Accelerated Vested Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation	10,319

Derivative Instruments Volume o

Derivative Instruments Volume of Derivative Activity (Details) - Sharp Energy Inc [Member] gal in Millions, $ in Millions	6 Months Ended
	Jun. 30, 2020USD ($)gal
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months | $	$ 0.3
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimate of Time to Transfer	12 months
Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | gal	22.5

Derivative Instruments - Additi

Derivative Instruments - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2020USD ($)	Dec. 31, 2019USD ($)
Derivative [Line Items]
Energy Marketing Contracts Assets, Current	$ 1,270,000	$ 0
Energy Marketing Contract Liabilities, Current	(802,000)	(1,844,000)
Notional Amount of Nonderivative Instruments	$ 100,000,000
Number of short-term lines of Credit, rate swap	3
Interest Rate Swap [Member]
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ 100,000
Designated as Hedging Instrument [Member] | Mark To Market Energy Assets [Member] | Propane Swap Agreement [Member]
Derivative [Line Items]
Energy Marketing Contracts Assets, Current	1,270,000	0
Designated as Hedging Instrument [Member] | Mark-to-market energy liabilities [Member] | Interest Rate Swap [Member]
Derivative [Line Items]
Energy Marketing Contract Liabilities, Current	(51,000)	0
Designated as Hedging Instrument [Member] | Mark-to-market energy liabilities [Member] | Propane Swap Agreement [Member]
Derivative [Line Items]
Energy Marketing Contract Liabilities, Current	(751,000)	(1,844,000)
Sharp Energy Inc [Member]
Derivative [Line Items]
Receivables from Brokers-Dealers and Clearing Organizations	(595,000)	$ (2,317,000)
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ 300,000
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimate of Time to Transfer	12 months
Interest Rate Swap Rate, High Range [Member]
Derivative [Line Items]
Fixed Swap Rate	38.75%
Interest Rate Swap Rate, Low Range [Member]
Derivative [Line Items]
Fixed Swap Rate	26.15%

Derivative Instruments - Fair V

Derivative Instruments - Fair Values of Derivative Contracts Recorded in Condensed Consolidated Balance Sheet (Detail) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Derivatives, Fair Value [Line Items]
Energy Marketing Contracts Assets, Current	$ 1,270	$ 0
Energy Marketing Contract Liabilities, Current	802	1,844
Mark To Market Energy Assets [Member] | Propane Swap Agreement [Member] | Derivatives designated as hedging instrument [Member]
Derivatives, Fair Value [Line Items]
Energy Marketing Contracts Assets, Current	1,270	0
Mark-to-market energy liabilities [Member] | Propane Swap Agreement [Member] | Derivatives designated as hedging instrument [Member]
Derivatives, Fair Value [Line Items]
Energy Marketing Contract Liabilities, Current	751	1,844
Mark-to-market energy liabilities [Member] | Interest Rate Swap [Member] | Derivatives designated as hedging instrument [Member]
Derivatives, Fair Value [Line Items]
Energy Marketing Contract Liabilities, Current	$ 51	$ 0

Derivative Instruments - Effect

Derivative Instruments - Effects of Gains and Losses from Derivative Instruments on Condensed Consolidated Financial Statements (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 2,552	$ (2,713)	$ 3,788	$ 2,069
Cost of Sales [Member] | Derivatives designated as hedging instrument [Member] | Propane Swap Agreement [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	238	252	1,465	858
Other Comprehensive Income (Loss) [Member] | Derivatives designated as hedging instrument [Member] | Natural Gas Swaps [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, before Tax	0	(2,463)	0	763
Other Comprehensive Income (Loss) [Member] | Derivatives designated as hedging instrument [Member] | Propane Swap Agreement [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, before Tax	2,354	(494)	2,363	515
Other Comprehensive Income (Loss) [Member] | Derivatives designated as hedging instrument [Member] | Interest Rate Swap [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, before Tax	(51)	0	(51)	0
Other Comprehensive Income (Loss) [Member] | Derivatives designated as hedging instrument [Member] | Natural Gas Futures [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, before Tax	0	(8)	0	(67)
Interest Expense [Member] | Derivatives designated as hedging instrument [Member] | Interest Rate Swap [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 11	$ 0	$ 11	$ 0

Fair Value of Financial Instr_3

Fair Value of Financial Instruments - Financial Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Assets:
Investments	$ 9,571	$ 9,229
Energy Marketing Contracts Assets, Current	1,270	0
Liabilities:
Energy Marketing Contract Liabilities, Current	802	1,844
Equity Securities [Member]
Assets:
Investments	20	27
Quoted Prices in Active Markets (Level 1) [Member]
Assets:
Assets, Fair Value Disclosure	7,237	8,426
Quoted Prices in Active Markets (Level 1) [Member] | Equity Securities [Member]
Assets:
Investments	20	27
Quoted Prices in Active Markets (Level 1) [Member] | Investments - Mutual funds and other [Member]
Assets:
Investments	7,217	8,399
Quoted Prices in Active Markets (Level 1) [Member] | Total Investments [Member]
Assets:
Investments	7,237	8,426
Significant Other Observable Inputs (Level 2) [Member]
Assets:
Assets, Fair Value Disclosure	1,270	0
Significant Unobservable Inputs (Level 3) [Member]
Assets:
Assets, Fair Value Disclosure	2,334	803
Significant Unobservable Inputs (Level 3) [Member] | Investments in guaranteed income fund [Member]
Assets:
Investments	2,334	803
Significant Unobservable Inputs (Level 3) [Member] | Total Investments [Member]
Assets:
Investments	2,334	803
Recurring [Member]
Assets:
Assets, Fair Value Disclosure	10,841	9,229
Liabilities:
Energy Marketing Contract Liabilities, Current		1,844
Recurring [Member] | Equity Securities [Member]
Assets:
Investments	20	27
Recurring [Member] | Investments in guaranteed income fund [Member]
Assets:
Investments	2,334	803
Recurring [Member] | Investments - Mutual funds and other [Member]
Assets:
Investments		8,399
Recurring [Member] | Total Investments [Member]
Assets:
Investments	$ 9,571	9,229
Recurring [Member] | Mark To Market Energy Assets incl. natural gas and swap agreements[Member]
Assets:
Derivative assets		$ 0

Fair Value of Financial Instr_4

Fair Value of Financial Instruments - Summary of Changes in Fair Value of Investments (Detail) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	$ (50)	$ (12)
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	803	686
Purchases and adjustments	226	110
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers out of Level 3	(1,345)	0
Investment Income	10	7
Ending Balance	$ 2,334	$ 791

Fair Value of Financial Instr_5

Fair Value of Financial Instruments - Additional Information (Detail) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Fair Value Disclosures [Abstract]
Long-term debt including current maturities	$ 446.5	$ 486.6
Fair value of long-term debt	$ 481.7	$ 505

Long-Term Debt - Outstanding Lo

Long-Term Debt - Outstanding Long-Term Debt (Detail) - USD ($)		Jun. 30, 2020		Dec. 31, 2019
Debt Instrument [Line Items]
Total long-term debt		$ (446,500,000)		$ (486,600,000)
Debt Instrument, Unused Borrowing Capacity, Amount		310,000,000
Total Long-term debt		445,706,000		485,768,000
Less: current maturities		(15,600,000)		(45,600,000)
Less: debt issuance costs		786,000		822,000
Total long-term debt, net of current maturities		430,106,000		440,168,000
NYL Unsecured Debt [Member]
Debt Instrument [Line Items]
Total long-term debt	[1]	$ (40,000,000)
Debt Instrument, Interest Rate, Stated Percentage		2.96%
Aggregated Unfunded Commitments [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (90,000,000)
Prudential Unfunded Commitments [Member]
Debt Instrument [Line Items]
Total long-term debt	[2],[3]	$ (50,000,000)
Debt Instrument, Interest Rate, Stated Percentage	[2],[3]	3.00%
New York Life [Member]
Debt Instrument [Line Items]
Total long-term debt	[1]	$ (100,000,000)
9.08% bond, due June 1, 2022 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (7,992,000)	[4]	(7,990,000)
Debt Instrument, Interest Rate, Stated Percentage		9.08%
5.50% note, due October 12, 2020 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (2,000,000)		(2,000,000)
Debt Instrument, Interest Rate, Stated Percentage		5.50%
5.93% note, due October 31, 2023 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (10,500,000)		(12,000,000)
Debt Instrument, Interest Rate, Stated Percentage		5.93%
5.68% note, due June 30, 2026 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (17,400,000)		(20,300,000)
Debt Instrument, Interest Rate, Stated Percentage		5.68%
6.43% note, due May 2, 2028 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (5,600,000)		(6,300,000)
Debt Instrument, Interest Rate, Stated Percentage		6.43%
3.73% note, due December 16, 2028 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (18,000,000)		(18,000,000)
Debt Instrument, Interest Rate, Stated Percentage		3.73%
3.88% note, due May 15, 2029 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (45,000,000)		(50,000,000)
Debt Instrument, Interest Rate, Stated Percentage		3.88%
3.25% note, due April 30, 2032 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (70,000,000)		(70,000,000)
3.48% note, due May 31, 2038 [Member]
Debt Instrument [Line Items]
Total long-term debt		(50,000,000)		(50,000,000)
Uncollateralized Senior Note Due November Two Thousand Thirty Eight [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (50,000,000)		(50,000,000)
Debt Instrument, Interest Rate, Stated Percentage		3.58%
Uncollateralized Senior Note Due August Two Thousand Thirty Nine [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (100,000,000)		(100,000,000)
Debt Instrument, Interest Rate, Stated Percentage		3.98%
Term Note Due January Two Thousand Twenty [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (70,000,000)		(70,000,000)
Term Note Due February Two Thousand Twenty [Member]
Debt Instrument [Line Items]
Total long-term debt		0		$ (30,000,000)
Aggregate Shelf Agreements [Member]
Debt Instrument [Line Items]
Total long-term debt		(270,000,000)
Aggregate Shelf Agreements [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		670,000,000
Prudential [Member]
Debt Instrument [Line Items]
Total long-term debt	[2],[3]	(170,000,000)
Debt Instrument, Unused Borrowing Capacity, Amount	[2],[3]	150,000,000
Prudential [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	[2],[3]	370,000,000
MetLife [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	[5]	150,000,000
Debt Instrument, Unused Borrowing Capacity, Amount	[5]	$ 150,000,000
[1]	(4) In February 2020 , we requested and NYL accepted our request to purchase $40.0 million of our unsecured debt. We expect to issue the Shelf Notes in August 2020 at the rate of 2.96 percent per annum.
[2]	2) In April 2020, the Prudential Shelf Agreement was amended to increase the available borrowing capacity to $150.0 million .
[3]	(1) In January 2020, we requested and Prudential accepted our request to purchase $50.0 million of our unsecured debt. We issued the Shelf Notes in July 2020 at the rate of 3.00 percent per annum.
[4]	FPU secured first mortgage bonds are guaranteed by Chesapeake Utilities.
[5]	(3) In May 2020, we reached into an agreement with MetLife to provide a new $150.0 million MetLife Shelf Agreement for a three-year term ending in March 31, 2023.

Long-Term Debt - Outstanding _2

Long-Term Debt - Outstanding Long-Term Debt- Supplemental Information (Detail)	6 Months Ended
	Jun. 30, 2020
9.08% bond, due June 1, 2022 [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage	9.08%
Debt instrument, maturity date	Jun. 1, 2022
5.50% note, due October 12, 2020 [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage	5.50%
Debt instrument, maturity date	Oct. 12, 2020
5.93% note, due October 31, 2023 [Member]
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 [Member]
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 [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage	6.43%
Debt instrument, maturity date	May 2, 2028
3.73% note, due December 16, 2028 [Member]
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 [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage	3.88%
Debt instrument, maturity date	May 15, 2029
3.25% due April 30, 2032 [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage	3.25%
Debt instrument, maturity date	Apr. 30, 2032
3.48% note, due May 31, 2038 [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

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information (Detail) - USD ($)		6 Months Ended
		Jun. 30, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Document Period End Date		Jun. 30, 2020
Long-term debt including current maturities		$ 446,500,000	$ 486,600,000
Debt Instrument, Unused Borrowing Capacity, Amount		310,000,000
NYL Unsecured Debt [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities	[1]	$ 40,000,000
Debt Instrument, Interest Rate, Stated Percentage		2.96%
Prudential Unfunded Commitments [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities	[2],[3]	$ 50,000,000
Debt Instrument, Interest Rate, Stated Percentage	[2],[3]	3.00%
Uncollateralized Senior Note Due December Two Thousand Thirty Four [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		2.98%
Term Note Due January Two Thousand Twenty [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities		$ 70,000,000	70,000,000
Term Note Due February Two Thousand Twenty [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities		0	30,000,000
3.48% note, due May 31, 2038 [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities		50,000,000	50,000,000
3.25% note, due April 30, 2032 [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities		70,000,000	$ 70,000,000
New York Life [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities	[1]	100,000,000
Aggregated Unfunded Commitments [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities		90,000,000
Aggregate Shelf Agreements [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities		270,000,000
MetLife [Member]
Debt Instrument [Line Items]
Senior notes	[4]	150,000,000
Debt Instrument, Unused Borrowing Capacity, Amount	[4]	150,000,000
Prudential [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities	[2],[3]	170,000,000
Debt Instrument, Unused Borrowing Capacity, Amount	[2],[3]	150,000,000
New York Life [Member]
Debt Instrument [Line Items]
Debt Instrument, Unused Borrowing Capacity, Amount	[1]	10,000,000
Maximum [Member] | Aggregate Shelf Agreements [Member]
Debt Instrument [Line Items]
Senior notes		670,000,000
Maximum [Member] | Prudential [Member]
Debt Instrument [Line Items]
Senior notes	[2],[3]	370,000,000
Maximum [Member] | New York Life [Member]
Debt Instrument [Line Items]
Senior notes	[1]	$ 150,000,000
[1]	(4) In February 2020 , we requested and NYL accepted our request to purchase $40.0 million of our unsecured debt. We expect to issue the Shelf Notes in August 2020 at the rate of 2.96 percent per annum.
[2]	2) In April 2020, the Prudential Shelf Agreement was amended to increase the available borrowing capacity to $150.0 million .
[3]	(1) In January 2020, we requested and Prudential accepted our request to purchase $50.0 million of our unsecured debt. We issued the Shelf Notes in July 2020 at the rate of 3.00 percent per annum.
[4]	(3) In May 2020, we reached into an agreement with MetLife to provide a new $150.0 million MetLife Shelf Agreement for a three-year term ending in March 31, 2023.

Short-Term Borrowings (Details)

Short-Term Borrowings (Details)	6 Months Ended
	Jun. 30, 2020USD ($)	Dec. 31, 2019USD ($)
Short-term Debt [Line Items]
Line of Credit Facility, Commitment Fee Percentage	0.35%
Short-term Debt, Maximum Amount Outstanding During Period	$ 350,000,000
Ratio of Indebtedness to Net Capital	0.65
Notional Amount of Nonderivative Instruments	$ 100,000,000
Number of short-term lines of Credit, rate swap	3
Line of Credit Facility, Maximum Borrowing Capacity	$ 465,000,000
Line of Credit, Current	284,913,000	$ 244,190,000
Line of Credit Facility, Remaining Borrowing Capacity	180,087,000
Line of Credit Facility, Maximum Borrowing Capacity, Incremental	95,000,000
Line of Credit, Current, Incremental	0	0
Line of Credit Facility, Remaining Borrowing Capacity, Incremental	95,000,000
Line of Credit Facility, Maximum Borrowing Capacity, Existing	370,000,000
Line of Credit, Current, Existing	284,913,000	244,190,000
Line of Credit Facility, Remaining Borrowing Capacity, Existing	85,087,000
Bank Overdrafts	1,492,000	3,181,000
Short-term borrowing	$ 286,405,000	$ 247,371,000
Short-term Debt, Weighted Average Interest Rate, at Point in Time	1.05%	2.62%
Number Of Unsecured Bank Credit Facilities	4
Number Of Financial Institutions With Bank Credit Facilities	4
Line Of Credit Facility Maximum Borrowing Committed Capacity	$ 220,000,000
ParticipatingLendersInTheRevolver	5
Committed Line of Credit Facility Two [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis	LIBOR rate, plus 0.75 percent
Line of Credit Facility, Maximum Borrowing Capacity	$ 80,000,000
Line of Credit, Current	77,501,000	$ 57,150,000
Line of Credit Facility, Remaining Borrowing Capacity	$ 2,499,000
Committed Line of Credit Facility Three [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis	Lender's base rate, plus 0.75 percent
Line of Credit Facility, Maximum Borrowing Capacity	$ 45,000,000
Line of Credit, Current	32,412,000	42,040,000
Line of Credit Facility, Remaining Borrowing Capacity	$ 12,588,000
Committed Line of Credit Facility Five [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis	Lender's base rate, plus 0.85 percent
Line of Credit Facility, Maximum Borrowing Capacity	$ 40,000,000
Line of Credit, Current	40,000,000	40,000,000
Line of Credit Facility, Remaining Borrowing Capacity	$ 0
Committed Line of Credit Facility Four [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis	LIBOR rate, plus 1.125 percent
Line of Credit Facility, Maximum Borrowing Capacity	$ 150,000,000
Line of Credit, Current	80,000,000	50,000,000
Line of Credit Facility, Remaining Borrowing Capacity	$ 70,000,000
Committed Line of Credit Facility Six [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis	LIBOR rate, plus 1.75 percent
Line of Credit Facility, Maximum Borrowing Capacity	$ 35,000,000
Line of Credit Facility, Remaining Borrowing Capacity	$ 35,000,000
Committed Line of Credit Facility Seven [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis	LIBOR rate, plus 1.75 percent
Line of Credit Facility, Maximum Borrowing Capacity	$ 15,000,000
Line of Credit Facility, Remaining Borrowing Capacity	$ 15,000,000
Committed Line of Credit Facility Eight [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis	LIBOR rate, plus 1.75 percent
Line of Credit Facility, Maximum Borrowing Capacity	$ 25,000,000
Line of Credit Facility, Remaining Borrowing Capacity	$ 25,000,000
Committed Line of Credit Facility Nine [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis	LIBOR rate, plus 1.75 percent
Debt Instrument, Description of Variable Rate Basis	1.75%
Line of Credit Facility, Maximum Borrowing Capacity	$ 20,000,000
Line of Credit Facility, Remaining Borrowing Capacity	$ 20,000,000
Interest Rate Swap Rate, Low Range [Member]
Short-term Debt [Line Items]
Fixed Swap Rate	26.15%
Interest Rate Swap Rate, High Range [Member]
Short-term Debt [Line Items]
Fixed Swap Rate	38.75%
Committed Line of Credit Facility One [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis	LIBOR rate, plus 0.75 percent
Line of Credit Facility, Maximum Borrowing Capacity	$ 55,000,000
Line of Credit, Current	55,000,000	$ 55,000,000
Line of Credit Facility, Remaining Borrowing Capacity	$ 0

Leases (Details)

Leases (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2020USD ($)yr	Dec. 31, 2019USD ($)
Lease Disclosure [Abstract]
Operating Lease, Right-of-Use Asset	$ 11,546	$ 11,563
Effect of CPI Basis Point Change	100
Minimum Renewal Term Length in Years - Lessee | yr	1
Maximum Renewal Term Length in Years - Lessee | yr	25
Total Finance and Operating Lease Right-of-Use Asset	$ 11,546	11,563
Operating Lease, Liability, Current	1,647	1,705
Operating Lease, Liability, Noncurrent	10,055	9,896
Total Operating and Finance Lease Liabilities	$ 11,702	$ 11,601

Leases Leases - Lease Cost Addi

Leases Leases - Lease Cost Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended				6 Months Ended
	Jun. 30, 2020		Jun. 30, 2019		Jun. 30, 2020	Jun. 30, 2019
Lease, Cost [Abstract]
Operating Lease, Cost	$ 629	[1]	$ 654	[1]	$ 1,255	$ 1,288	[1]
Finance Lease, Right-of-Use Asset, Amortization	0		249		0
Finance Lease, Principal Payments					0	650
Finance Lease, Interest Expense	0		1		0	5
Lease, Cost	$ 629		$ 904		$ 1,255	$ 1,943
[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 Additional Information (Details) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Leases - Right of Use Asset and Lease Liability Balance Sheet Classification [Abstract]
Operating Lease, Right-of-Use Asset	$ 11,546	$ 11,563
Total Finance and Operating Lease Right-of-Use Asset	11,546	11,563
Operating Lease, Liability, Current	1,647	1,705
Operating Lease, Liability, Noncurrent	10,055	9,896
Total Operating and Finance Lease Liabilities	$ 11,702	$ 11,601

Leases Leases - Weighted Averag

Leases Leases - Weighted Average Remaining Lease Term Additional Information (Details)	Jun. 30, 2020	Dec. 31, 2019
Leases - Weighted Average Remaining Lease term Additional Information [Abstract]
Operating Lease, Weighted Average Discount Rate, Percent	3.80%	3.80%
Operating Lease, Weighted Average Remaining Lease Term	8 years 7 months 6 days	8 years 10 months 17 days

Leases Leases - Cash Flow Addit

Leases Leases - Cash Flow Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Leases - Cash Flow Additional Information [Abstract]
Operating Cash Flow from Operating Leases			$ 1,034	$ 1,100
Finance Lease, Interest Payment on Liability			0
Finance Lease, Interest Expense	$ 0	$ 1	0	5
Finance Lease, Principal Payments			$ 0	$ 650

Leases Leases - Schedule of Fut

Leases Leases - Schedule of Future Maturities Additional Information (Details) $ in Thousands	Jun. 30, 2020USD ($)
Leases - Schedule of Future Maturities Additional Information [Abstract]
Lessee, Operating Lease, Liability, Payments, Remainder of Fiscal Year	$ 1,089	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Two	2,031	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Three	1,937	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Four	1,874	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Five	1,619	[1]
Lessee, Operating Lease Liability, Payments, Due Year Six	1,383	[1]
Lessee, Operating Lease Liability, Payments, Due After Year Six	3,876	[1]
Lessee, Operating Lease, Liability, Payments, Due	13,809	[1]
Lessee, Operating Lease, Liability, Undiscounted Excess Amount	2,107	[1]
Operating Lease, Liability	11,702	[1]
Lessee Future Operating Lease Option Payments	$ 4,000
[1]	Operating lease payments include $4.0 million related to options to extend lease terms that are reasonably certain of being exercised.