Chesapeake Utilities (CPK) 10-Q 8 May 19 2019 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2019	Apr. 30, 2019
Document Document And Entity Information [Abstract]
Entity Registrant Name	CHESAPEAKE UTILITIES CORP
Trading Symbol	CPK
Entity Central Index Key	0000019745
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Mar. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q1
Amendment Flag	false
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		16,397,017

Condensed Consolidated Statemen

Condensed Consolidated Statements of Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Operating Revenues
Regulated Energy	$ 103,618	$ 109,393
Unregulated Energy and other	123,998	129,963
Total Operating Revenues	227,616	239,356
Operating Expenses
Regulated Energy cost of sales	36,516	48,231
Unregulated Energy and other cost of sales	89,703	99,826
Operations	37,144	32,702
Cost, Maintenance	3,681	3,593
Depreciation and amortization	11,074	9,704
Other taxes	5,505	4,894
Total Operating Expenses	183,623	198,950
Operating Income	43,993	40,406
Other income (expense), net	(45)	68
Interest charges	5,710	3,664
Income Before Income Taxes	38,238	36,810
Income taxes	9,574	9,955
Net Income	$ 28,664	$ 26,855
Weighted Average Common Shares Outstanding:
Basic (shares)	16,384,927	16,351,338
Diluted (shares)	16,432,852	16,402,985
Earnings Per Share of Common Stock:
Basic (in dollars per share)	$ 1.75	$ 1.64
Diluted (in dollars per share)	$ 1.74	$ 1.64

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Statement of Comprehensive Income [Abstract]
Net Income	$ 28,664	$ 26,855
Other Comprehensive Income (Loss), net of tax:
Amortization of prior service cost, net of tax of $(5) and $(5), respectively	(14)	(14)
Net gain, net of tax of $42 and $41, respectively	121	108
Cash Flow Hedges, net of tax:
Unrealized gain (loss) on commodity contract cash flow hedges, net of tax of $1,194 and $(756), respectively	2,982	(1,788)
Total Other Comprehensive Income (Loss), net of tax	3,089	(1,694)
Comprehensive Income	$ 31,753	$ 25,161

Condensed Consolidated Statem_3

Condensed Consolidated Statements of Comprehensive Income (Unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Statement of Comprehensive Income [Abstract]
Amortization of prior service cost, tax	$ (5)	$ (5)
Net gain, tax	42	41
Unrealized (loss)/gain on commodity contract cash flow hedges, tax	$ 1,194	$ (756)

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2019		Dec. 31, 2018
Property, Plant and Equipment
Regulated Energy	$ 1,346,221		$ 1,297,416
Unregulated Energy	241,126		237,682
Other businesses and eliminations	30,282		34,585
Total property, plant and equipment	1,617,629		1,569,683
Less: Accumulated depreciation and amortization	(312,949)		(294,295)
Plus: Construction work in progress	90,453		108,584
Net property, plant and equipment	1,395,133		1,383,972
Current Assets
Cash and cash equivalents	7,975		6,089
Trade and other receivables (less allowance for uncollectible accounts of $1,054 and $1,108, respectively)	74,098		85,404
Accrued revenue	20,747		27,499
Propane inventory, at average cost	6,865		9,791
Other inventory, at average cost	8,122		7,127
Regulatory assets	7,913		4,796
Storage gas prepayments	1,327		6,603
Income taxes receivable	9,059		15,300
Prepaid expenses	7,192		10,079
Derivative assets, at fair value	9,221		13,165
Other current assets	1,121		5,684
Total current assets	153,640		191,537
Deferred Charges and Other Assets
Goodwill	25,785		25,837
Other intangible assets, net	5,909		6,207
Investments, at fair value	7,509		6,711
Operating Lease, Right-of-Use Asset	12,523
Regulatory assets	77,101		72,422
Other assets	5,197		6,985
Total deferred charges and other assets	134,024		118,162
Total Assets	1,682,797		1,693,671
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)	7,980		7,971
Additional paid-in capital	255,307		255,651
Retained earnings	284,111		261,530
Accumulated other comprehensive loss	(3,739)		(6,713)
Deferred compensation obligation	4,376		3,854
Treasury stock	(4,376)		(3,854)
Total stockholders’ equity	543,659	[1]	518,439	[2]
Long-term debt, net of current maturities	285,998		316,020
Total capitalization	829,657		834,459
Current Liabilities
Less: current maturities	71,509		11,935
Short-term borrowing	276,393		294,458
Accounts payable	75,277		129,804
Customer deposits and refunds	29,710		34,155
Accrued interest	4,505		2,317
Dividends payable	6,067		6,060
Accrued compensation	8,506		13,923
Regulatory liabilities	15,085		7,883
Derivative liabilities, at fair value	6,798		14,871
Other accrued liabilities	14,719		12,828
Total current liabilities	508,569		528,234
Deferred Credits and Other Liabilities
Deferred income taxes	160,912		156,820
Regulatory liabilities	132,686		135,039
Environmental liabilities	7,370		7,638
Other pension and benefit costs	29,822		28,513
Operating Lease, Liability, Noncurrent	10,873
Deferred investment tax credits and other liabilities	2,908		2,968
Total deferred credits and other liabilities	344,571		330,978
Environmental and other commitments and contingencies (Notes 5 and 6)
Total Capitalization and Liabilities	$ 1,682,797		$ 1,693,671
[1]	Includes 101,997 shares at March 31, 2019, 97,053 shares at December 31, 2018, 93,422 shares at March 31, 2018 and 90,961 shares at December 31, 2017, respectively, held in a Rabbi Trust related to our Non-Qualified Deferred Compensation Plan.
[2]	2,000,000 shares of preferred stock at $0.01 par value have been authorized. None has been issued or is 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	Mar. 31, 2019	Dec. 31, 2018
Statement of Financial Position [Abstract]
Allowance for uncollectible accounts	$ 1,054	$ 1,108
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	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Operating Activities
Net Income	$ 28,664	$ 26,855
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	11,074	9,704
Depreciation and accretion included in other costs	2,135	2,276
Deferred income taxes	3,430	6,469
Realized (gain) loss on commodity contracts/sale of assets/investments	(363)	3,416
Unrealized (gain) loss on investments/commodity contracts	(721)	44
Employee benefits and compensation	382	228
Share-based compensation	487	1,520
Other, net	0	(12)
Changes in assets and liabilities:
Accounts receivable and accrued revenue	18,147	9,649
Propane inventory, storage gas and other inventory	7,207	12,448
Regulatory assets/liabilities, net	3,121	11,511
Prepaid expenses and other current assets	11,873	8,095
Accounts payable and other accrued liabilities	(44,783)	(26,932)
Income taxes receivable	6,241	8,741
Customer deposits and refunds	(4,445)	44
Accrued compensation	(5,548)	(7,731)
Other assets and liabilities, net	3,585	347
Net cash provided by operating activities	40,486	66,672
Investing Activities
Property, plant and equipment expenditures	(43,216)	(63,116)
Proceeds from sales of assets	115	193
Environmental expenditures	(268)	(48)
Net cash used in investing activities	(43,369)	(62,971)
Financing Activities
Common stock dividends	(5,877)	(5,147)
Issuance of stock under the Dividend Reinvestment Plan	(183)	(164)
Tax Withholding payments related to net settled stock compensation	(692)	(719)
Change in cash overdrafts due to outstanding checks	84	2,352
Net repayment under line of credit agreements	(18,149)	(24,213)
Proceeds from long-term debt and long-term borrowing under the Revolver	30,000	25,000
Repayment of long-term debt, long-term borrowing under the Revolver and capital lease obligation	(414)	(428)
Net cash provided (used) by financing activities	4,769	(3,319)
Net Increase in Cash and Cash Equivalents	1,886	382
Cash and Cash Equivalents—Beginning of Period	6,089	5,614
Cash and Cash Equivalents—End of Period	$ 7,975	$ 5,996

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]
Beginning Balances (shares) at Dec. 31, 2017	[1]			16,344,442
Beginning Balances at Dec. 31, 2017		$ 486,294	[1]	$ 7,955	$ 253,470	$ 229,141	$ (4,272)	$ 3,395	$ (3,395)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		26,855				26,855
New Accounting Pronouncement or Change in Accounting Principle, Effect of Adoption, Quantification		(1,498)				(1,498)
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect		0				907	(907)
Other comprehensive income (loss)		(1,694)					(1,694)
Dividend declared		(5,381)				(5,381)
Retirement savings plan and dividend reinvestment plan (shares)				0
Dividend reinvestment plan		(1)		$ 0	(1)
Share-based compensation (shares)	[2],[3]			19,350
Share-based compensation and tax benefit	[2],[3]	666		$ 9	657
Treasury stock activities		0						178	(178)
Ending Balances (shares) at Mar. 31, 2018	[1],[4]			16,363,792
Ending Balances at Mar. 31, 2018		$ 505,241	[4]	$ 7,964	254,126	250,024	(6,873)	3,573	(3,573)
Preferred Stock, Shares Authorized		2,000,000
Preferred Stock, Par or Stated Value Per Share		$ 0.01
Beginning Balances (shares) at Dec. 31, 2018	[1]			16,378,545
Beginning Balances at Dec. 31, 2018		$ 518,439	[1]	$ 7,971	255,651	261,530	(6,713)	3,854	(3,854)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		28,664				28,664
Prior Period Reclassification Adjustment						115	(115)
Other comprehensive income (loss)		3,089					3,089
Dividend declared		(6,198)				(6,198)
Stock Issued During Period, Shares, Dividend Reinvestment Plan				0
Stock Issued During Period, Value, Dividend Reinvestment Plan		(1)		$ 0	(1)
Share-based compensation (shares)	[2],[3]			18,472
Share-based compensation and tax benefit	[2],[3]	(334)		$ 9	(343)
Treasury stock activities		0						522	(522)
Ending Balances (shares) at Mar. 31, 2019	[1],[4]			16,397,017
Ending Balances at Mar. 31, 2019		$ 543,659	[4]	$ 7,980	$ 255,307	$ 284,111	$ (3,739)	$ 4,376	$ (4,376)
Preferred Stock, Shares Authorized		2,000,000
Preferred Stock, Par or Stated Value Per Share		$ 0.01
[1]	2,000,000 shares of preferred stock at $0.01 par value have been authorized. None has been issued or is outstanding; accordingly, no information has been included in the statements of stockholders’ equity.
[2]	Includes amounts for shares issued for directors’ compensation.
[3]	The shares issued under the SICP are net of shares withheld for employee taxes. For the three months ended March 31, 2019 and 2018, we withheld 7,635 and 10,436 shares, respectively, for taxes.
[4]	Includes 101,997 shares at March 31, 2019, 97,053 shares at December 31, 2018, 93,422 shares at March 31, 2018 and 90,961 shares at December 31, 2017, respectively, held in a Rabbi Trust related to our Non-Qualified Deferred Compensation Plan.

Condensed Consolidated Statem_6

Condensed Consolidated Statements of Stockholders' Equity (Parenthetical) (Unaudited) - $ / shares	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018	Dec. 31, 2017
Statement of Stockholders' Equity [Abstract]
Dividend declared (in dollars per share)	$ 0.3700	$ 0.3250
Deferred compensation plan held Rabbi Trust (shares)	101,997	93,422	97,053	90,961
Preferred Stock, Shares Authorized	2,000,000		2,000,000
Preferred Stock, Par or Stated Value Per Share	$ 0.01		$ 0.01
Shares issued under the performance incentive plan withheld for employee taxes (shares)	7,635	10,436

Summary of Accounting Policies

Summary of Accounting Policies	3 Months Ended
	Mar. 31, 2019
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, 2018 . In the opinion of management, these financial statements reflect normal recurring adjustments that are necessary for a fair presentation of our results of operations, financial position and cash flows for the interim periods presented. 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. Marlin Gas Transport and Ohl Fuel Oil Acquisitions In December 2018, Marlin Gas Services acquired certain operating assets of Marlin Gas Transport. The acquisition will enable us to offer solutions to supply interruption scenarios and tailor other alternatives where pipeline supplies are unavailable or inadequate to meet customer requirements. In December 2018, Sharp acquired certain propane operating assets and customers of R. F. Ohl Fuel Oil, Inc. ("Ohl"), which provided propane distribution service to approximately 2,500 residential and commercial customers in Pennsylvania. We accounted for the purchases of the operating assets of Marlin Gas Transport and Ohl, which totaled approximately $18.4 million , as business combinations within our Unregulated Energy segment. Goodwill of $4.8 million , related to the Marlin Gas Transport acquisition, and $1.5 million , associated with the Ohl acquisition, were initially recorded at the close of these transactions. The amounts recorded in conjunction with these acquisitions are preliminary and subject to adjustment based on additional valuations performed during the measurement period. Due to the timing of these acquisitions, the revenue and net income from these acquisitions in 2018 were immaterial. For the quarter ended March 31, 2019, these acquisitions generated the following operating revenue and income: Three Months Ended March 31, 2019 Operating Revenue Operating Income (in thousands) Marlin Gas Services $ 2,434 $ 1,375 Ohl $ 822 $ 273 FASB Statements and Other Authoritative Pronouncements Recently Adopted Accounting Standards Leases (ASC 842) - In February 2016, the FASB issued ASU 2016-02, Leases, which requires lessees to recognize leases on the balance sheet and disclose key information about leasing arrangements. The standard establishes a right of use model that requires a lessee to recognize a right of use asset and lease liability for all leases with a term greater than 12 months. The update also expands the required quantitative and qualitative disclosures surrounding leases. ASC 842 was subsequently amended by ASU No. 2018-01, Land Easement Practical Expedient for Transition to Topic 842 ; ASU No. 2018-10, Codification Improvements to Topic 842, Lease s; ASU No. 2018-11, Targeted Improvements ; and ASU No. 2019-01, Codification Improvements . We adopted ASU 2016-02 and the related amendments on January 1, 2019, and used the optional transition method for all existing leases. The optional transition method enables us to adopt the new standard as of the beginning of the period of adoption and does not require restatement of prior period financial information. 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. At adoption, we elected the following practical expedients: (1) the ‘package of practical expedients,’ pursuant to which we did not need to reassess our prior conclusions about lease identification, lease classification and initial direct costs, (2) the ‘use-of-hindsight’ practical expedient, which allowed us to use hindsight in assessing impairment of our existing land easements, (3) creation of an accounting policy for short-term leases resulting in lease payments being recorded as an expense on a straight-line basis over the lease term, and (4) to not separate lease and non-lease components for all leases. See Note 15, Leases, for additional information with respect to the impact of the adoption of the lease accounting guidance and the disclosures required by ASU 2016-02 and the related amendments. Compensation - Stock Compensation (ASC 718) - In June 2018, the FASB issued ASU 2018-07, Improvements to Nonemployee Share-Based Payment Accounting , which expands the scope of Topic 718 to include share-based payment transactions for acquiring goods and services from nonemployees. We adopted ASU 2018-07 on January 1, 2019. Implementation of this new standard did not have a material impact on our financial position or results of operations. Recent Accounting Standards Yet to be Adopted 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 will be effective for our annual and interim financial statements beginning January 1, 2020, although early adoption is permitted. The amendments included in this ASU are to be applied prospectively. We believe that implementation of this new standard will not have a material impact on our financial position or results of operations. 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. ASU 2018-13 will be effective for our annual and interim financial statements beginning January 1, 2020 and, since the changes only impact disclosures, will not have a material impact on our financial position or results of operations.

Calculation of Earnings Per Sha

Calculation of Earnings Per Share	3 Months Ended
	Mar. 31, 2019
Earnings Per Share [Abstract]
Calculation of Earnings Per Share	Calculation of Earnings Per Share Three Months Ended March 31, 2019 2018 (in thousands, except shares and per share data) Calculation of Basic Earnings Per Share: Net Income $ 28,664 $ 26,855 Weighted average shares outstanding 16,384,927 16,351,338 Basic Earnings Per Share $ 1.75 $ 1.64 Calculation of Diluted Earnings Per Share: Reconciliation of Numerator: Net Income $ 28,664 $ 26,855 Reconciliation of Denominator: Weighted shares outstanding—Basic 16,384,927 16,351,338 Effect of dilutive securities—Share-based compensation 47,925 51,647 Adjusted denominator—Diluted 16,432,852 16,402,985 Diluted Earnings Per Share $ 1.74 $ 1.64

Revenue Recognition (Notes)

Revenue Recognition (Notes)	3 Months Ended
	Mar. 31, 2019
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 following table displays our revenue by major source based on product and service type for the three months ended March 31, 2019 and 2018 : Three months ended March 31, 2019 Three Months Ended March 31, 2018 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Regulated Energy Unregulated Energy Other and Eliminations Total Energy distribution Delaware natural gas division $ 27,549 $ — $ — $ 27,549 $ 32,072 $ — $ — $ 32,072 Florida natural gas division 7,900 — — 7,900 5,864 — — 5,864 FPU electric distribution 14,378 — — 14,378 18,741 — — 18,741 FPU natural gas distribution 23,786 — — 23,786 23,213 — — 23,213 Maryland natural gas division 10,047 — — 10,047 10,672 — — 10,672 Sandpiper natural gas/propane operations 7,082 — — 7,082 8,964 — — 8,964 Total energy distribution 90,742 — — 90,742 99,526 — — 99,526 Energy transmission Aspire Energy — 13,470 — 13,470 — 12,077 — 12,077 Eastern Shore 19,056 — — 19,056 15,597 — — 15,597 Peninsula Pipeline 3,565 — — 3,565 2,098 — — 2,098 Total energy transmission 22,621 13,470 — 36,091 17,695 12,077 — 29,772 Energy generation Eight Flags — 4,142 — 4,142 — 4,378 — 4,378 Propane operations Propane delivery operations — 46,125 — 46,125 — 52,104 — 52,104 Energy services Marlin Gas Services — 2,434 — 2,434 — — — — PESCO - Natural Gas Marketing — 77,022 — 77,022 81,559 — 81,559 Total energy services — 79,456 — 79,456 — 81,559 — 81,559 Other and eliminations Eliminations (9,745 ) (5,496 ) (14,236 ) (29,477 ) (7,828 ) (5,245 ) (15,598 ) (28,671 ) Other — 405 132 537 — 494 194 688 Total other and eliminations (9,745 ) (5,091 ) (14,104 ) (28,940 ) (7,828 ) (4,751 ) (15,404 ) (27,983 ) Total operating revenues (1) $ 103,618 $ 138,102 $ (14,104 ) $ 227,616 $ 109,393 $ 145,367 $ (15,404 ) $ 239,356 (1) Total operating revenues for the three months ended March 31, 2019 , include other revenue (revenues from sources other than contracts with customers) of $121,000 and $84,000 for our Regulated and Unregulated Energy segments, respectively and $(589,000) and $73,000 for our Regulated and Unregulated Energy segments, respectively, for the three months ended March 31, 2018 . 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 December 31, 2018 and March 31, 2019 were as follows: Trade Receivables Contract Assets (Non-current) Contract Liabilities (Current) (in thousands) Balance at 12/31/2018 $ 83,214 $ 2,614 $ 480 Balance at 3/31/2019 72,162 3,004 305 Increase (decrease) $ (11,052 ) $ 390 $ (175 ) Our trade receivables are included in trade and other receivables in the condensed consolidated balance sheets. Our non-current contract assets are included in other assets in the condensed consolidated balance sheet and relate to operations and maintenance costs incurred by Eight Flags that have not yet been recovered through rates for the sale of electricity to our electric distribution operation pursuant to a long-term service agreement. At times, we receive advances or deposits from our customers before we satisfy our performance obligation, resulting in contract liabilities. At March 31, 2019 and December 31, 2018 , we had a contract liability of $305,000 and $480,000 , respectively, which was included in other accrued liabilities in the condensed consolidated balance sheet, and which relates to non-refundable prepaid fixed fees for our Delmarva Peninsula 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 the three months ended March 31, 2019 and 2018, we recognized revenue of $287,000 and $251,000 , respectively. Remaining performance obligations Our businesses have long-term fixed fee contracts with customers in which revenues are recognized as performance obligations are satisfied over the contract term. Revenue for these businesses for the remaining performance obligations at March 31, 2019 are expected to be recognized as follows: (in thousands) 2019 2020 2021 2022 2023 2024 2025 and thereafter Eastern Shore and Peninsula Pipeline $ 28,754 $ 36,791 $ 33,510 $ 26,566 $ 21,146 $ 18,969 $ 193,651 Natural gas distribution operations 2,999 3,587 3,358 3,320 2,924 2,910 27,916 PESCO - Natural Gas Marketing 4,435 4,585 1,706 22 — — — FPU electric distribution 223 297 297 109 — — — Total revenue contracts with remaining performance obligations $ 36,411 $ 45,260 $ 38,871 $ 30,017 $ 24,070 $ 21,879 $ 221,567

Rates and Other Regulatory Acti

Rates and Other Regulatory Activities	3 Months Ended
	Mar. 31, 2019
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 by the Florida PSC. Delaware Effect of the TCJA on Customers: On January 31, 2019, the Delaware PSC approved the as-filed Delaware Division Delivery Service Rates reflecting the impact of the TCJA. The new rates went into effect March 1, 2019, and we will have to complete refunds retroactive to February 2018, by June 30, 2019. The order also provided for a line item billing credit that went into effect on April 1, 2019, for the return of the excess accumulated deferred income taxes ("ADIT"). Additional information on the TCJA impact is included in the table at the end of this Note 4, Rates and Other Regulatory Activities . Weather Normalization Adjustment: In January 2019, we filed with the Delaware PSC an application requesting approval to implement a weather normalization adjustment. The proposed weather normalization adjustment will provide either a billing credit (during colder than normal weather) or surcharge (during warmer than normal weather) designed to produce natural gas bills for customers that reflect normal temperatures. The weather normalization adjustment will ensure we do not over or under-collect Delaware PSC authorized levels of distribution revenues due to weather variability. The Delaware PSC issued an order on March 19, 2019 to open a docket and formally review the case. Florida Electric Limited Proceeding-Storm Recovery: 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 this filing, had a deficit of $779,000 . This matter went to hearing in December 2018 and was subsequently approved at the March 5, 2019 Agenda with the Final Order issued on March 25, 2019. FPU received approval to begin a surcharge of $1.54 per 1,000 kilowatt hour 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 100 percent of its customers losing electrical service. 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 has been recorded as new plant and equipment or charged against FPU’s storm reserve. In conjunction with the hurricane-related expenditures, we executed two 13 -month unsecured term loans as temporary financing, each in the amount of $30 million . The interest cost associated with these loans is LIBOR plus 75 points. One of the term loans was executed in December 2018; the other was executed in January 2019. While there is a short-term negative impact, the storm is not expected to have a significant impact going forward, assuming reasonable regulatory treatment. We have begun preparing the necessary regulatory filings to seek recovery of the costs incurred, including the financing costs for the temporary debt issued to fund the new plant and equipment. Effect of the TCJA on Customers: In February 2018, the Florida PSC opened dockets to consider the impacts associated with the TCJA. In May 2018, FPU’s natural gas divisions filed petitions and supporting testimony regarding the disposition of the related impacts of the TCJA. Hearings on this matter took place in November 2018, and the staff's recommendation was approved by the Florida PSC at the February 5, 2019 Agenda. Final orders were issued on February 25, 2019. Staff’s recommendations are summarized in the table at the end of this Note 4, Rates and Other Regulatory Activities . Imbalance Petition: In February 2019, FPU filed a petition, with the Florida PSC, to modify the pool manager cash out tiers and respective cash out rates. With this petition, FPU further facilitates consistency across the Florida business units and eliminates the unintentional arbitrage opportunity created by the tariff. The petition does not have a financial impact for FPU, and it will benefit customers by lowering costs. This petition was approved by the Florida PSC at the April 2, 2019 Agenda. Maryland Division and Sandpiper There were no material regulatory matters during the quarter. Eastern Shore Del-Mar Energy Pathway Project: In September 2018, Eastern Shore filed a Certificate Application with the FERC, requesting authorization to construct and operate the Del-Mar Energy Pathway project, which 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 Somerset County, 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. During the fourth quarter of 2018, the FERC held a full project area scoping meeting in Sussex County, Delaware and issued a Notice of Schedule for Environmental Review. The Environmental Assessment for the Del-Mar Energy Pathway project was issued on April 1, 2019. As of the date of this filing, final FERC authorization was still pending. Summary TCJA Table The following table summarizes the TCJA impact on our regulated businesses: Regulatory Liabilities related to 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 $900,000) in April 2018 - Customer rates adjusted in April, 2018 Delaware Division (Delaware PSC) $13,082 PSC approved amortization of ADIT in January 2019 Customer rates adjusted March 1, 2019. One-time bill credit to be implemented during the second quarter of 2019 Maryland Division (Maryland PSC) $4,171 PSC approved amortization of ADIT in May 2018 Implemented one-time bill credit (totaling $365,000) in July 2018 - Customer rates adjusted effective May 1, 2018 Sandpiper Energy (Maryland PSC) $3,803 PSC approved amortization of ADIT in May 2018 Implemented one-time bill credit (totaling $608,000) in July 2018 - Customer rates adjusted effective May 1, 2018 Chesapeake Florida Gas Division/Central Florida Gas (Florida PSC) $8,346 PSC issued order authorizing amortization and retention of net ADIT liability by the Company on February 25, 2019 PSC Staff recommendation issued on January 24, 2019; final order was issued on February 25, 2019; No one-time bill credit or adjustment in rates will be applied; the tax savings arising from the TCJA rate reduction will be retained by the Company FPU Natural Gas (includes FPU, Fort Meade, and Indiantown) (Florida PSC) $19,478 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 Electric (Florida PSC) $5,950 In January 2019, PSC issued order approving amortization of ADIT through purchased power cost recovery, storm reserve and rates TCJA benefit will flow back to its 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	3 Months Ended
	Mar. 31, 2019
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. We are also in discussions with the Maryland Department of Environment ("MDE") regarding another former MGP site located in Cambridge, Maryland. As of March 31, 2019 and December 31, 2018 , we had approximately $8.9 million and $9.1 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 March 31, 2019 and December 31, 2018 , we had recovered approximately $11.6 million and $11.5 million , respectively, leaving approximately $2.4 million and $2.5 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 other remaining portions, including the anticipated demolition of buildings on the site's west parcel in 2019. Between $4.5 million to $15.4 million, including costs associated with the relocation of FPU’s operations at this site, which is necessary to implement the remedial plan, 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 less than $10,000. It is unlikely that FPU will incur any significant future costs associated with the site. Winter Haven (Florida) Remediation is ongoing. Not expected to exceed $425,000, which includes costs of implementing institutional controls at the site. 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 to mitigate on-site impact will be implemented, after the Work Plan has been submitted and approved by DNREC. Between $273,000 and $465,000. Cambridge (Maryland) Currently in discussions with the MDE. Unable to estimate.

Other Commitments and Contingen

Other Commitments and Contingencies	3 Months Ended
	Mar. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Other Commitments and Contingencies	Other Commitments and Contingencies Natural Gas, Electric and Propane Supply Our Delmarva Peninsula natural gas distribution operations have asset management agreements with PESCO to manage their natural gas transportation and storage capacity. The agreements were effective as of April 1, 2017, and each has a three -year term, expiring on March 31, 2020. In May 2013, Sandpiper entered into a capacity, supply and operating agreement with Eastern Gas & Water Investment Company, LLC ("EGWIC") to purchase propane through May 2019. Sandpiper has the option to enter into either a fixed per-gallon price for some or all of the propane purchases or a market-based price utilizing one of two local propane pricing indices. Sandpiper's remaining commitment at March 31, 2019 was approximately 288,000 gallons. Sandpiper has entered into an agreement with EGWIC to purchase any remaining assets at the end of the lease term and will transfer them to Sharp. Also in May 2013, Sharp entered into a separate supply and operating agreement with EGWIC. Under this agreement, Sharp has a commitment to supply propane to EGWIC through May 2019. Sharp's remaining commitment as of March 31, 2019 was approximately 288,000 gallons. The agreement between Sharp and EGWIC is separate from the agreement between Sandpiper and EGWIC. Chesapeake Utilities' Florida Division has firm transportation service contracts with Florida Gas Transmission Company ("FGT") and Gulfstream. Pursuant to a capacity release program approved by the Florida PSC, all of the capacity under these agreements has been released to various third parties, including PESCO. 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. 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 March 31, 2019 , 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 We have issued corporate guarantees to certain vendors of our subsidiaries, primarily PESCO. These corporate guarantees provide for the payment of natural gas purchases in the event that PESCO defaults. PESCO has never defaulted on its obligations to pay its suppliers. The liabilities for these purchases are recorded when incurred. The aggregate amount guaranteed at March 31, 2019 was approximately $77.3 million , with the guarantees expiring on various dates through December 2020 . 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 14 , Long-Term Debt , for further details). As of March 31, 2019 , we have issued letters of credit totaling approximately $7.0 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, the payment of natural gas purchases for PESCO, and to our current and previous primary insurance carriers. These letters of credit have various expiration dates through March 2020 . There have been no draws on these letters of credit as of March 31, 2019 . 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.

Segment Information

Segment Information	3 Months Ended
	Mar. 31, 2019
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/or products or services, 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 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, the new mobile compressed natural gas utility and pipeline solutions subsidiary, and other energy services (natural gas marketing and related services). These operations are unregulated as to their rates and services. 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. The remainder of our operations is 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 March 31, 2019 2018 (in thousands) Operating Revenues, Unaffiliated Customers Regulated Energy $ 100,739 $ 105,954 Unregulated Energy 126,877 133,402 Total operating revenues, unaffiliated customers $ 227,616 $ 239,356 Intersegment Revenues (1) Regulated Energy $ 2,879 $ 3,439 Unregulated Energy 11,225 11,965 Other businesses 132 194 Total intersegment revenues $ 14,236 $ 15,598 Operating Income Regulated Energy $ 29,741 $ 26,711 Unregulated Energy 15,127 13,684 Other businesses and eliminations (875 ) 11 Operating income 43,993 40,406 Other income (expense), net (45 ) 68 Interest charges 5,710 3,664 Income before Income Taxes 38,238 36,810 Income taxes 9,574 9,955 Net Income $ 28,664 $ 26,855 (1) All significant intersegment revenues are billed at market rates and have been eliminated from consolidated operating revenues. (in thousands) March 31, 2019 December 31, 2018 Identifiable Assets Regulated Energy segment $ 1,343,061 $ 1,345,805 Unregulated Energy segment 296,836 306,045 Other businesses and eliminations 42,900 41,821 Total identifiable assets $ 1,682,797 $ 1,693,671 Our operations are entirely domestic.

Stockholder's Equity - Accumula

Stockholder's Equity - Accumulated Other Comprehensive Income (Loss)	3 Months Ended
	Mar. 31, 2019
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, call options natural gas swaps and futures contracts, designated as commodity contracts 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 March 31, 2019 and 2018 . All amounts except the stranded tax reclassification are presented net of tax. Defined Benefit Commodity Pension and Contracts Postretirement Cash Flow Plan Items Hedges Total (in thousands) As of December 31, 2018 $ (5,928 ) $ (785 ) $ (6,713 ) Other comprehensive income before reclassifications — 3,021 3,021 Amounts reclassified from accumulated other comprehensive income/(loss) 107 (39 ) 68 Net current-period other comprehensive income 107 2,982 3,089 Prior-year reclassification — (115 ) (115 ) As of March 31, 2019 $ (5,821 ) $ 2,082 $ (3,739 ) (in thousands) As of December 31, 2017 $ (4,743 ) $ 471 $ (4,272 ) Other comprehensive loss before reclassifications — (2,232 ) (2,232 ) Amounts reclassified from accumulated other comprehensive income/(loss) 94 444 538 Net prior-period other comprehensive income/(loss) 94 (1,788 ) (1,694 ) Stranded tax reclassification to retained earnings (1,022 ) 115 (907 ) As of March 31, 2018 $ (5,671 ) $ (1,202 ) $ (6,873 ) The following table presents amounts reclassified out of accumulated other comprehensive loss for the three months ended March 31, 2019 and 2018 . Deferred gains or losses for our commodity contracts cash flow hedges are recognized in earnings upon settlement. Three Months Ended March 31, 2019 2018 (in thousands) Amortization of defined benefit pension and postretirement plan items: Prior service credit (1) $ 19 $ 19 Net loss (1) (163 ) (149 ) Total before income taxes (144 ) (130 ) Income tax benefit 37 36 Net of tax $ (107 ) $ (94 ) Gains and losses on commodity contracts cash flow hedges: Propane swap agreements (2) $ 606 $ (464 ) Natural gas swaps (2) 11 (450 ) Natural gas futures (2) (573 ) 298 Total before income taxes 44 (616 ) Income tax benefit (expense) (5 ) 172 Net of tax 39 (444 ) Total reclassifications for the period $ (68 ) $ (538 ) (1) These amounts are included in the computation of net periodic costs (benefits). See Note 9 , Employee Benefit Plans , for additional details. (2) These amounts are included in the effects of gains and losses from derivative instruments. See Note 12, Derivative Instruments , for additional details. Amortization of defined benefit pension and postretirement plan items is included in operations expense, and gains and losses on propane swap agreements, call options and natural gas futures contracts are included in cost of sales 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	3 Months Ended
	Mar. 31, 2019
Retirement Benefits [Abstract]
Employee Benefit Plans	Employee Benefit Plans Net periodic benefit costs for our pension and post-retirement benefits plans for the three months ended March 31, 2019 and 2018 are set forth in the following tables: Chesapeake FPU Chesapeake SERP Chesapeake FPU For the Three Months Ended March 31, 2019 2018 2019 2018 2019 2018 2019 2018 2019 2018 (in thousands) Interest cost $ 105 $ 97 $ 615 $ 592 $ 21 $ 21 $ 10 $ 10 $ 12 $ 12 Expected return on plan assets (127 ) (138 ) (693 ) (774 ) — — — — — — Amortization of prior service credit — — — — — — (19 ) (19 ) — — Amortization of net loss 101 88 129 109 26 25 12 15 — — Net periodic cost (benefit) 79 47 51 (73 ) 47 46 3 6 12 12 Amortization of pre-merger regulatory asset — — 190 191 — — — — 2 2 Total periodic cost $ 79 $ 47 $ 241 $ 118 $ 47 $ 46 $ 3 $ 6 $ 14 $ 14 We expect to record pension and postretirement benefit costs of approximately $1.3 million for 2019. Included in these costs is approximately $543,000 related to continued amortization of the FPU pension regulatory asset, which represents the portion attributable to FPU’s regulated energy operations for the changes in funded status that occurred, but were not recognized, as part of net periodic benefit costs prior to the FPU merger in 2009. This was deferred as a regulatory asset by FPU prior to the merger, to be recovered through rates pursuant to a previous order by the Florida PSC. The unamortized balance of this regulatory asset was approximately $351,000 and approximately $543,000 at March 31, 2019 and December 31, 2018 , respectively. The other than service cost components of the net periodic costs have been recorded or reclassified to other income (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 pension and 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 months ended March 31, 2019 and 2018 : For the Three Months Ended March 31, 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 (1) 101 24 26 (7 ) — 144 Recognized from regulatory asset — 105 — — — 105 Total $ 101 $ 129 $ 26 $ (7 ) $ — $ 249 For the Three Months Ended March 31, 2018 Chesapeake FPU Chesapeake SERP Chesapeake FPU Total (in thousands) Prior service credit $ — $ — $ — $ (19 ) $ — $ (19 ) Net loss 88 109 25 15 — 237 Total recognized in net periodic benefit cost 88 109 25 (4 ) — 218 Recognized from accumulated other comprehensive loss (1) 88 21 25 (4 ) — 130 Recognized from regulatory asset — 88 — — — 88 Total $ 88 $ 109 $ 25 $ (4 ) $ — $ 218 (1) See Note 8 , Stockholder's Equity . During the three months ended March 31, 2019 , we contributed approximately $33,000 to the Chesapeake Pension Plan and approximately $233,000 to the FPU Pension Plan. We expect to contribute a total of approximately $163,000 and approximately $1.2 million to the Chesapeake Pension Plan and FPU Pension Plan, respectively, during 2019 , which represents the minimum annual contribution payments required. 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 months ended March 31, 2019 , were approximately $38,000 . We expect to pay total cash benefits of approximately $383,000 under the Chesapeake SERP in 2019 . Cash benefits paid under the Chesapeake Postretirement Plan, primarily for medical claims for the three months ended March 31, 2019 , were approximately $1,000 . We estimate that approximately $96,000 will be paid for such benefits under the Chesapeake Postretirement Plan in 2019 . Cash benefits paid under the FPU Medical Plan, primarily for medical claims for the three months ended March 31, 2019 , were approximately $6,000 . We estimate that approximately $94,000 will be paid for such benefits under the FPU Medical Plan in 2019 .

Investments

Investments	3 Months Ended
	Mar. 31, 2019
Investments, Debt and Equity Securities [Abstract]
Investments	Investments The investment balances at March 31, 2019 and December 31, 2018 , consisted of the following: (in thousands) March 31, December 31, Rabbi trust (associated with the Non-Qualified Deferred Compensation Plan) $ 7,484 $ 6,689 Investments in equity securities 25 22 Total $ 7,509 $ 6,711 We classify these investments as trading securities and report them at their fair value. For the three months ended March 31, 2019 and 2018 , we recorded a net unrealized gain of approximately $727,000 and a net unrealized loss of approximately $44,000 , 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	3 Months Ended
	Mar. 31, 2019
Disclosure of Compensation Related Costs, Share-based Payments [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 months ended March 31, 2019 and 2018 : Three Months Ended March 31, 2019 2018 (in thousands) Awards to non-employee directors $ 149 $ 135 Awards to key employees 338 1,385 Total compensation expense 487 1,520 Less: tax benefit (127 ) (416 ) Share-based compensation amounts included in net income $ 360 $ 1,104 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 prepaid expense equal to the fair value of the shares issued and amortize the expense equally over a service period of one year. In May 2018, each of our non-employee directors received an annual retainer of 792 shares of common stock under the SICP for service as a director through the 2019 Annual Meeting of Stockholders. Our former President and Chief Executive Officer, Michael P. McMasters, retired on December 31, 2018 and continued as a member of the Board of Directors beginning January 1, 2019. Mr. McMasters received a pro-rated grant of 276 shares of common stock under the SICP for service as a non-employee director from January 1, 2019 through the 2019 Annual Meeting of Stockholders. These shares were issued and vested in January 2019 at a weighted average fair value of $75.70 . At March 31, 2019 , there was approximately $52,000 of unrecognized compensation expense related to shares granted to non-employee directors. This expense will be recognized over the remaining service period ending April 30, 2019. See Note 1, Summary of Accounting Policies , for additional information regarding ASU 2018-07 and its impact on the accounting for non-employee share-based payments. Key Employees The table below presents the summary of the stock activity for awards to key employees for the three months ended March 31, 2019 : Number of Shares Weighted Average Fair Value Outstanding—December 31, 2018 131,741 $ 67.24 Granted 45,016 $ 91.19 Vested (25,831 ) $ 67.08 Expired (15,086 ) $ 69.28 Outstanding—March 31, 2019 135,840 $ 74.05 In February 2019, our Board of Directors granted awards of 45,016 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, 2021. 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 Black-Scholes pricing model to estimate the fair value of each market-based award granted. In March 2019, upon the election 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 2019 for the performance period ended December 31, 2018, remitted the cash to the appropriate taxing authorities, and paid the balance of such awarded shares to each such executive officer. We withheld 7,635 shares, based on the value of the shares on their award date, determined by the average of the high and low prices of our common stock. Total combined payments for the employees’ tax obligations to the taxing authorities were approximately $692,000 . At March 31, 2019 , the aggregate intrinsic value of the SICP awards granted to key employees was approximately $12.4 million . At March 31, 2019 , there was approximately $4.3 million of unrecognized compensation cost related to these awards, which is expected to be recognized as expense from 2019 through 2021. Stock Options We did not have any stock options outstanding at March 31, 2019 or 2018 , nor were any stock options issued during these periods.

Derivative Instruments

Derivative Instruments	3 Months Ended
	Mar. 31, 2019
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. 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. Both our propane distribution and natural gas marketing 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. As of March 31, 2019 , our natural gas and electric distribution operations did not have any outstanding derivative contracts. Volume of Derivative Activity As of March 31, 2019 , the volume of our open commodity derivative contracts were as follows: Business unit Commodity Quantity hedged (in millions) Designation Longest Expiration date of hedge PESCO Natural gas (Dts) 21.7 Cash flows hedges December 2022 PESCO Natural gas (Dts) 3.8 Not designated March 2021 Sharp Propane (gallons) 5.4 Cash flows hedges June 2021 PESCO entered into natural gas futures contracts associated with the purchase and sale of natural gas to specific customers. We designated and accounted for them as cash flow hedges. The change in fair value of the natural gas futures contracts 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 $2.1 million from accumulated other comprehensive loss to earnings during the next 12 -month period ending March 31, 2020. 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 in August 2018 through June 2021), 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 $503,000 from accumulated other comprehensive income (loss) to earnings during the next 12-month period ending March 31, 2020. Balance Sheet Offsetting PESCO has entered into master netting agreements with counterparties that enable it to net the counterparties' outstanding accounts receivable and payable, which are presented on a net basis in the condensed consolidated balance sheets. The following table summarizes the accounts receivable and payable on a gross and net basis at March 31, 2019 and December 31, 2018 : At March 31, 2019 (in thousands) Gross amounts Amounts offset Net amounts Accounts receivable $ 8,832 $ 3,264 $ 5,568 Accounts payable $ 15,906 $ 3,264 $ 12,642 At December 31, 2018 (in thousands) Gross amounts Amounts offset Net amounts Accounts receivable $ 12,368 $ 3,834 $ 8,534 Accounts payable $ 24,741 $ 3,834 $ 20,907 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 MTM relative to maintenance margin requirements. We maintain separate broker margin accounts for Sharp and PESCO. The balances are as follows: (in thousands) Balance Sheet Location At March 31, 2019 At December 31, 2018 PESCO Other Current Assets $ (335 ) $ 2,810 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. The fair values of the derivative contracts recorded in the condensed consolidated balance sheets as of March 31, 2019 and December 31, 2018 , are as follows: Asset Derivatives Fair Value As Of (in thousands) Balance Sheet Location March 31, 2019 December 31, 2018 Derivatives not designated as hedging instruments Natural gas futures contracts Derivative assets, at fair value $ 2,122 $ 4,024 Derivatives designated as fair value hedges Propane put options Derivative assets, at fair value — 71 Derivatives designated as cash flow hedges Natural gas futures contracts Derivative assets, at fair value 7,055 9,059 Propane swap agreements Derivative assets, at fair value 44 11 Total asset derivatives $ 9,221 $ 13,165 Liability Derivatives Fair Value As Of (in thousands) Balance Sheet Location March 31, 2019 December 31, 2018 Derivatives not designated as hedging instruments Natural gas futures contracts Derivative liabilities, at fair value $ 2,638 $ 4,562 Derivatives designated as cash flow hedges Natural gas futures contracts Derivative liabilities, at fair value 3,533 8,705 Propane swap agreements Derivative liabilities, at fair value 627 1,604 Total liability derivatives $ 6,798 $ 14,871 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 March 31, (in thousands) (Loss) on Derivatives 2019 2018 Derivatives not designated as hedging instruments Natural gas futures contracts Cost of sales $ (22 ) $ (2,835 ) Propane swap agreements Cost of sales — (9 ) Derivatives designated as cash flow hedges Propane swap agreements Cost of sales 606 (464 ) Propane swap agreements Other comprehensive income (loss) 1,009 (992 ) Natural gas futures contracts Cost of sales (573 ) 298 Natural gas swap contracts Cost of sales 11 (450 ) Natural gas swap contracts Other comprehensive income (loss) 3,226 (1,617 ) Natural gas futures contracts Other comprehensive income (loss) (59 ) 65 Total $ 4,198 $ (6,004 ) As of March 31, 2019 , the following amounts were recorded in the condensed consolidated balance sheets related to fair value hedges: (in thousands) Carrying Amount of Hedged Item Cumulative Adjustment Included in Carrying Amount of Hedged Item Balance Sheet Location of Hedged Items At March 31, 2019 At December 31, 2018 At March 31, 2019 At December 31, 2018 Inventory $ 6 $ 212 $ — $ —

Fair Value of Financial Instrum

Fair Value of Financial Instruments	3 Months Ended
	Mar. 31, 2019
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 values of forward contracts are measured using market transactions in either the listed or over-the-counter markets. The fair value of the propane put/call options, swap agreements and natural gas futures contracts 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 March 31, 2019 and December 31, 2018 : Fair Value Measurements Using: As of March 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 $ 25 $ 25 $ — $ — Investments—guaranteed income fund 695 — — 695 Investments—mutual funds and other 6,789 6,789 — — Total investments 7,509 6,814 — 695 Derivative assets 9,221 — 9,221 — Total assets $ 16,730 $ 6,814 $ 9,221 $ 695 Liabilities: Derivative liabilities $ 6,798 $ — $ 6,798 $ — Fair Value Measurements Using: As of December 31, 2018 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 $ 22 $ 22 $ — $ — Investments—guaranteed income fund 686 — — 686 Investments—mutual funds and other 6,003 6,003 — — Total investments 6,711 6,025 — 686 Derivative assets 13,165 — 13,165 — Total assets $ 19,876 $ 6,025 $ 13,165 $ 686 Liabilities: Derivative liabilities $ 14,871 $ — $ 14,871 $ — The following table sets forth the summary of the changes in the fair value of Level 3 investments for the three months ended March 31, 2019 and 2018 : Three Months Ended 2019 2018 (in thousands) Beginning Balance $ 686 $ 648 Purchases and adjustments 6 (48 ) Investment income 3 2 Ending Balance $ 695 $ 602 Investment income from the Level 3 investments is reflected in other expense, (net) in the consolidated statements of income. At March 31, 2019 , 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 short maturities and because interest rates approximate current market rates (Level 3 measurement). At March 31, 2019 , long-term debt which includes current maturities but excludes capital lease obligations, had a carrying value of approximately $357.2 million , compared to the estimated fair value of $361.3 million , 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. At December 31, 2018 , long-term debt, which includes the current maturities but excludes a capital lease obligation, had a carrying value of approximately $327.2 million , compared to a fair value of approximately $323.8 million . 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	3 Months Ended
	Mar. 31, 2019
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Our outstanding long-term debt is shown below: March 31, December 31, (in thousands) 2019 2018 FPU secured first mortgage bonds (1) : 9.08% bond, due June 1, 2022 $ 7,987 $ 7,986 Uncollateralized senior notes: 5.50% note, due October 12, 2020 4,000 4,000 5.93% note, due October 31, 2023 15,000 15,000 5.68% note, due June 30, 2026 23,200 23,200 6.43% note, due May 2, 2028 7,000 7,000 3.73% note, due December 16, 2028 20,000 20,000 3.88% note, due May 15, 2029 50,000 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 Term Note due January 21, 2020 30,000 30,000 Term Note due February 28, 2020 30,000 — Promissory notes — 26 Finance lease obligation 909 1,310 Less: debt issuance costs (589 ) (567 ) Total long-term debt 357,507 327,955 Less: current maturities (71,509 ) (11,935 ) Total long-term debt, net of current maturities $ 285,998 $ 316,020 (1) FPU secured first mortgage bonds are guaranteed by Chesapeake Utilities. Term Notes In December 2018, we issued a $30.0 million unsecured term note through PNC Bank N.A. with maturity date of January 21, 2020. The interest rate at March 31, 2019 and December 31, 2018 was 3.24% and 3.23% , respectively, which equals one month LIBOR rate plus 75 basis points. In January 2019, we issued a $30.0 million unsecured term note through Branch Banking and Trust Company, with a maturity date of February 28, 2020. The interest rate at March 31, 2019 was 3.24% , which equals the one month LIBOR rate plus 75 basis points. As of March 31, 2019 , these term notes totaling $60.0 million are included in the current maturities of long-term debt. Shelf Agreements We have entered into Shelf Agreements with Prudential, MetLife and NYL, whom are under no obligation to purchase any unsecured debt. We entered into the Prudential Shelf Agreement, totaling $150.0 million , in October 2015, and we issued $70.0 million of 3.25% unsecured debt in April 2017. The Prudential Shelf Agreement was then amended in September 2018 to increase the borrowing capacity back up to $150.0 million , and Prudential accepted our request to purchase our unsecured debt of $100.0 million at an interest rate of 3.98% on or before August 20, 2019. We entered into the NYL Shelf Agreement, totaling $100.0 million , in March 2017, and we issued unsecured debt totaling $100.0 million during 2018. The NYL Shelf Agreement was amended in November 2018 to add incremental borrowing capacity of $50.0 million . As of March 31, 2019 , we had not requested that MetLife purchase unsecured senior debt under the MetLife Shelf Agreement, which we entered into in March 2017. The following table summarizes the borrowing information under our Shelf Agreements at March 31, 2019: Total Borrowing Capacity Less: Amount of Debt Issued Less: Unfunded Commitments Remaining Borrowing Capacity (in thousands) Shelf Agreement Prudential Shelf Agreement $ 220,000 $ (70,000 ) $ (100,000 ) $ 50,000 MetLife Shelf Agreement 150,000 — — 150,000 NYL Shelf Agreement 150,000 (100,000 ) — 50,000 Total $ 520,000 $ (170,000 ) $ (100,000 ) $ 250,000 The 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.

Leases Leases

Leases Leases	3 Months Ended
	Mar. 31, 2019
Lease Disclosure [Abstract]
Lessee, Operating Leases [Text Block]	We have entered into lease arrangements for office space, land, equipment, pipeline facilities and warehouses. These leases have been entered into to better enable us to conduct our 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 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 March 31, 2019 , 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. We utilize our incremental borrowing rate, as the basis to calculate the present value of future lease payments, at lease commencement. Our incremental borrowing rate represents the rate that we would have to pay to borrow funds on a collateralized basis over a similar term and in a similar economic environment. Leases with an initial term of 12 months or less are not recorded on our balance sheet; we recognize lease expense for these leases on a straight-line basis over the lease term. We have elected not to separate non-lease components from all classes of our existing leases. Non-lease components have been accounted for as part of the single lease component to which they are related. As of March 31, 2019 , 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 March 31, ( in thousands) Classification 2019 2018 Operating lease cost (1) Operations expense $ 635 $ 1,107 Finance lease cost Amortization of lease assets Depreciation and amortization 401 358 Interest on lease liabilities Interest expense 4 17 Net lease cost $ 1,040 $ 1,482 (1) Includes short-term leases and variable lease costs, which are immaterial The following table presents the balance and classifications of our right of use assets and lease liabilities included in our consolidated balance sheet at March 31, 2019: (in thousands) Balance sheet classification Amount Assets Operating lease assets Operating lease right-of-use assets $ 12,523 Finance lease assets Property, plant and equipment 1,839 Total lease assets $ 14,362 Liabilities Current Operating lease liabilities Other accrued liabilities $ 1,642 Finance lease liabilities Current portion of long-term debt 909 Noncurrent Operating lease liabilities Other liabilities 10,873 Finance lease liabilities Long-term debt — Total lease liabilities $ 13,424 The following table presents our weighted-average remaining lease terms and weighted-average discount rates for our operating and financing leases at March 31, 2019: At March 31, 2019 Weighted-average remaining lease term ( in years ) Operating leases 9.32 Finance leases 0.17 Weighted-average discount rate Operating leases 3.8 % Finance leases 3.5 % 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 March 31, 2019 and March 31, 2018: Three Months Ended March 31, (in thousands) 2019 2018 Operating cash flows from operating leases $ 537 $ 1,018 Operating cash flows from finance leases 4 17 Financing cash flows from finance leases 401 358 The following table presents the future undiscounted maturities of our operating and financing leases at March 31, 2019 and for each of the next five years and thereafter: (in thousands) Operating Leases (1) Finance Leases Total Remainder of 2019 $ 1,539 $ 910 $ 2,449 2020 2,045 — 2,045 2021 1,765 — 1,765 2022 1,659 — 1,659 2023 1,669 — 1,669 2024 1,431 — 1,431 Thereafter 4,860 — 4,860 Total lease payments $ 14,968 $ 910 $ 15,878 Less: Interest 2,453 1 2,454 Present value of lease liabilities $ 12,515 $ 909 13,424 (1) Operating lease payments include $3.8 million related to options to extend lease terms that are reasonably certain of being exercised. The following table presents future minimum lease payments for our operating leases at December 31, 2018 under ASC 840 and is being presented for comparative purposes: Year(s) 2019 2020 2021 2022 2023 Thereafter Total (in thousands) Expected payments $2,349 $1,998 $1,761 $1,689 $1,642 $5,398 $14,837

Summary of Accounting Policies

Summary of Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2019
Accounting Policies [Abstract]
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, 2018 . In the opinion of management, these financial statements reflect normal recurring adjustments that are necessary for a fair presentation of our results of operations, financial position and cash flows for the interim periods presented. 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.
Business Acquisition [Line Items]
Schedule of Business Acquisitions, by Acquisition [Table Text Block]	Marlin Gas Transport and Ohl Fuel Oil Acquisitions In December 2018, Marlin Gas Services acquired certain operating assets of Marlin Gas Transport. The acquisition will enable us to offer solutions to supply interruption scenarios and tailor other alternatives where pipeline supplies are unavailable or inadequate to meet customer requirements. In December 2018, Sharp acquired certain propane operating assets and customers of R. F. Ohl Fuel Oil, Inc. ("Ohl"), which provided propane distribution service to approximately 2,500 residential and commercial customers in Pennsylvania. We accounted for the purchases of the operating assets of Marlin Gas Transport and Ohl, which totaled approximately $18.4 million , as business combinations within our Unregulated Energy segment. Goodwill of $4.8 million , related to the Marlin Gas Transport acquisition, and $1.5 million , associated with the Ohl acquisition, were initially recorded at the close of these transactions. The amounts recorded in conjunction with these acquisitions are preliminary and subject to adjustment based on additional valuations performed during the measurement period. Due to the timing of these acquisitions, the revenue and net income from these acquisitions in 2018 were immaterial
FASB Statements and Other Authoritative Pronouncements	FASB Statements and Other Authoritative Pronouncements Recently Adopted Accounting Standards Leases (ASC 842) - In February 2016, the FASB issued ASU 2016-02, Leases, which requires lessees to recognize leases on the balance sheet and disclose key information about leasing arrangements. The standard establishes a right of use model that requires a lessee to recognize a right of use asset and lease liability for all leases with a term greater than 12 months. The update also expands the required quantitative and qualitative disclosures surrounding leases. ASC 842 was subsequently amended by ASU No. 2018-01, Land Easement Practical Expedient for Transition to Topic 842 ; ASU No. 2018-10, Codification Improvements to Topic 842, Lease s; ASU No. 2018-11, Targeted Improvements ; and ASU No. 2019-01, Codification Improvements . We adopted ASU 2016-02 and the related amendments on January 1, 2019, and used the optional transition method for all existing leases. The optional transition method enables us to adopt the new standard as of the beginning of the period of adoption and does not require restatement of prior period financial information. 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. At adoption, we elected the following practical expedients: (1) the ‘package of practical expedients,’ pursuant to which we did not need to reassess our prior conclusions about lease identification, lease classification and initial direct costs, (2) the ‘use-of-hindsight’ practical expedient, which allowed us to use hindsight in assessing impairment of our existing land easements, (3) creation of an accounting policy for short-term leases resulting in lease payments being recorded as an expense on a straight-line basis over the lease term, and (4) to not separate lease and non-lease components for all leases. See Note 15, Leases, for additional information with respect to the impact of the adoption of the lease accounting guidance and the disclosures required by ASU 2016-02 and the related amendments. Compensation - Stock Compensation (ASC 718) - In June 2018, the FASB issued ASU 2018-07, Improvements to Nonemployee Share-Based Payment Accounting , which expands the scope of Topic 718 to include share-based payment transactions for acquiring goods and services from nonemployees. We adopted ASU 2018-07 on January 1, 2019. Implementation of this new standard did not have a material impact on our financial position or results of operations. Recent Accounting Standards Yet to be Adopted 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 will be effective for our annual and interim financial statements beginning January 1, 2020, although early adoption is permitted. The amendments included in this ASU are to be applied prospectively. We believe that implementation of this new standard will not have a material impact on our financial position or results of operations. 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. ASU 2018-13 will be effective for our annual and interim financial statements beginning January 1, 2020 and, since the changes only impact disclosures, will not have a material impact on our financial position or results of operations.

Summary of Accounting Policie_2

Summary of Accounting Policies Results of Operations for Acquisitions (Tables)	3 Months Ended
	Mar. 31, 2019
Accounting Policies [Abstract]
Acquisition results [Table Text Block]	For the quarter ended March 31, 2019, these acquisitions generated the following operating revenue and income: Three Months Ended March 31, 2019 Operating Revenue Operating Income (in thousands) Marlin Gas Services $ 2,434 $ 1,375 Ohl $ 822 $ 273

Calculation of Earnings Per S_2

Calculation of Earnings Per Share (Tables)	3 Months Ended
	Mar. 31, 2019
Earnings Per Share [Abstract]
Calculation of Basic and Diluted Earnings Per Share	Three Months Ended March 31, 2019 2018 (in thousands, except shares and per share data) Calculation of Basic Earnings Per Share: Net Income $ 28,664 $ 26,855 Weighted average shares outstanding 16,384,927 16,351,338 Basic Earnings Per Share $ 1.75 $ 1.64 Calculation of Diluted Earnings Per Share: Reconciliation of Numerator: Net Income $ 28,664 $ 26,855 Reconciliation of Denominator: Weighted shares outstanding—Basic 16,384,927 16,351,338 Effect of dilutive securities—Share-based compensation 47,925 51,647 Adjusted denominator—Diluted 16,432,852 16,402,985 Diluted Earnings Per Share $ 1.74 $ 1.64

Revenue Recognition (Tables)

Revenue Recognition (Tables)	3 Months Ended
	Mar. 31, 2019
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue [Table Text Block]	The following table displays our revenue by major source based on product and service type for the three months ended March 31, 2019 and 2018 : Three months ended March 31, 2019 Three Months Ended March 31, 2018 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Regulated Energy Unregulated Energy Other and Eliminations Total Energy distribution Delaware natural gas division $ 27,549 $ — $ — $ 27,549 $ 32,072 $ — $ — $ 32,072 Florida natural gas division 7,900 — — 7,900 5,864 — — 5,864 FPU electric distribution 14,378 — — 14,378 18,741 — — 18,741 FPU natural gas distribution 23,786 — — 23,786 23,213 — — 23,213 Maryland natural gas division 10,047 — — 10,047 10,672 — — 10,672 Sandpiper natural gas/propane operations 7,082 — — 7,082 8,964 — — 8,964 Total energy distribution 90,742 — — 90,742 99,526 — — 99,526 Energy transmission Aspire Energy — 13,470 — 13,470 — 12,077 — 12,077 Eastern Shore 19,056 — — 19,056 15,597 — — 15,597 Peninsula Pipeline 3,565 — — 3,565 2,098 — — 2,098 Total energy transmission 22,621 13,470 — 36,091 17,695 12,077 — 29,772 Energy generation Eight Flags — 4,142 — 4,142 — 4,378 — 4,378 Propane operations Propane delivery operations — 46,125 — 46,125 — 52,104 — 52,104 Energy services Marlin Gas Services — 2,434 — 2,434 — — — — PESCO - Natural Gas Marketing — 77,022 — 77,022 81,559 — 81,559 Total energy services — 79,456 — 79,456 — 81,559 — 81,559 Other and eliminations Eliminations (9,745 ) (5,496 ) (14,236 ) (29,477 ) (7,828 ) (5,245 ) (15,598 ) (28,671 ) Other — 405 132 537 — 494 194 688 Total other and eliminations (9,745 ) (5,091 ) (14,104 ) (28,940 ) (7,828 ) (4,751 ) (15,404 ) (27,983 ) Total operating revenues (1) $ 103,618 $ 138,102 $ (14,104 ) $ 227,616 $ 109,393 $ 145,367 $ (15,404 ) $ 239,356 (1) Total operating revenues for the three months ended March 31, 2019 , include other revenue (revenues from sources other than contracts with customers) of $121,000 and $84,000 for our Regulated and Unregulated Energy segments, respectively and $(589,000) and $73,000 for our Regulated and Unregulated Energy segments, respectively, for the three months ended March 31, 2018 . 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 December 31, 2018 and March 31, 2019 were as follows: Trade Receivables Contract Assets (Non-current) Contract Liabilities (Current) (in thousands) Balance at 12/31/2018 $ 83,214 $ 2,614 $ 480 Balance at 3/31/2019 72,162 3,004 305 Increase (decrease) $ (11,052 ) $ 390 $ (175 )
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block]	(in thousands) 2019 2020 2021 2022 2023 2024 2025 and thereafter Eastern Shore and Peninsula Pipeline $ 28,754 $ 36,791 $ 33,510 $ 26,566 $ 21,146 $ 18,969 $ 193,651 Natural gas distribution operations 2,999 3,587 3,358 3,320 2,924 2,910 27,916 PESCO - Natural Gas Marketing 4,435 4,585 1,706 22 — — — FPU electric distribution 223 297 297 109 — — — Total revenue contracts with remaining performance obligations $ 36,411 $ 45,260 $ 38,871 $ 30,017 $ 24,070 $ 21,879 $ 221,567

Rates and Other Regulatory Ac_2

Rates and Other Regulatory Activities Rates and Regulatory Activities (Tables)	3 Months Ended
	Mar. 31, 2019
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 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 $900,000) in April 2018 - Customer rates adjusted in April, 2018 Delaware Division (Delaware PSC) $13,082 PSC approved amortization of ADIT in January 2019 Customer rates adjusted March 1, 2019. One-time bill credit to be implemented during the second quarter of 2019 Maryland Division (Maryland PSC) $4,171 PSC approved amortization of ADIT in May 2018 Implemented one-time bill credit (totaling $365,000) in July 2018 - Customer rates adjusted effective May 1, 2018 Sandpiper Energy (Maryland PSC) $3,803 PSC approved amortization of ADIT in May 2018 Implemented one-time bill credit (totaling $608,000) in July 2018 - Customer rates adjusted effective May 1, 2018 Chesapeake Florida Gas Division/Central Florida Gas (Florida PSC) $8,346 PSC issued order authorizing amortization and retention of net ADIT liability by the Company on February 25, 2019 PSC Staff recommendation issued on January 24, 2019; final order was issued on February 25, 2019; No one-time bill credit or adjustment in rates will be applied; the tax savings arising from the TCJA rate reduction will be retained by the Company FPU Natural Gas (includes FPU, Fort Meade, and Indiantown) (Florida PSC) $19,478 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 Electric (Florida PSC) $5,950 In January 2019, PSC issued order approving amortization of ADIT through purchased power cost recovery, storm reserve and rates TCJA benefit will flow back to its 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)	3 Months Ended
	Mar. 31, 2019
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 other remaining portions, including the anticipated demolition of buildings on the site's west parcel in 2019. Between $4.5 million to $15.4 million, including costs associated with the relocation of FPU’s operations at this site, which is necessary to implement the remedial plan, 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 less than $10,000. It is unlikely that FPU will incur any significant future costs associated with the site. Winter Haven (Florida) Remediation is ongoing. Not expected to exceed $425,000, which includes costs of implementing institutional controls at the site. 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 to mitigate on-site impact will be implemented, after the Work Plan has been submitted and approved by DNREC. Between $273,000 and $465,000. Cambridge (Maryland) Currently in discussions with the MDE. Unable to estimate.

Segment Information (Tables)

Segment Information (Tables)	3 Months Ended
	Mar. 31, 2019
Segment Reporting [Abstract]
Schedule of Segment Reporting Information by Segment	The following table presents financial information about our reportable segments: Three Months Ended March 31, 2019 2018 (in thousands) Operating Revenues, Unaffiliated Customers Regulated Energy $ 100,739 $ 105,954 Unregulated Energy 126,877 133,402 Total operating revenues, unaffiliated customers $ 227,616 $ 239,356 Intersegment Revenues (1) Regulated Energy $ 2,879 $ 3,439 Unregulated Energy 11,225 11,965 Other businesses 132 194 Total intersegment revenues $ 14,236 $ 15,598 Operating Income Regulated Energy $ 29,741 $ 26,711 Unregulated Energy 15,127 13,684 Other businesses and eliminations (875 ) 11 Operating income 43,993 40,406 Other income (expense), net (45 ) 68 Interest charges 5,710 3,664 Income before Income Taxes 38,238 36,810 Income taxes 9,574 9,955 Net Income $ 28,664 $ 26,855 (1) All significant intersegment revenues are billed at market rates and have been eliminated from consolidated operating revenues. (in thousands) March 31, 2019 December 31, 2018 Identifiable Assets Regulated Energy segment $ 1,343,061 $ 1,345,805 Unregulated Energy segment 296,836 306,045 Other businesses and eliminations 42,900 41,821 Total identifiable assets $ 1,682,797 $ 1,693,671

Stockholder's Equity - Accumul

Stockholder's Equity - Accumulated Other Comprehensive Income (Loss) (Tables)	3 Months Ended
	Mar. 31, 2019
Equity [Abstract]
Changes in Accumulated Other Comprehensive Loss	Defined Benefit Commodity Pension and Contracts Postretirement Cash Flow Plan Items Hedges Total (in thousands) As of December 31, 2018 $ (5,928 ) $ (785 ) $ (6,713 ) Other comprehensive income before reclassifications — 3,021 3,021 Amounts reclassified from accumulated other comprehensive income/(loss) 107 (39 ) 68 Net current-period other comprehensive income 107 2,982 3,089 Prior-year reclassification — (115 ) (115 ) As of March 31, 2019 $ (5,821 ) $ 2,082 $ (3,739 ) (in thousands) As of December 31, 2017 $ (4,743 ) $ 471 $ (4,272 ) Other comprehensive loss before reclassifications — (2,232 ) (2,232 ) Amounts reclassified from accumulated other comprehensive income/(loss) 94 444 538 Net prior-period other comprehensive income/(loss) 94 (1,788 ) (1,694 ) Stranded tax reclassification to retained earnings (1,022 ) 115 (907 ) As of March 31, 2018 $ (5,671 ) $ (1,202 ) $ (6,873 )
Reclassifications out of Accumulated Other Comprehensive Income (Loss)	The following table presents amounts reclassified out of accumulated other comprehensive loss for the three months ended March 31, 2019 and 2018 . Deferred gains or losses for our commodity contracts cash flow hedges are recognized in earnings upon settlement. Three Months Ended March 31, 2019 2018 (in thousands) Amortization of defined benefit pension and postretirement plan items: Prior service credit (1) $ 19 $ 19 Net loss (1) (163 ) (149 ) Total before income taxes (144 ) (130 ) Income tax benefit 37 36 Net of tax $ (107 ) $ (94 ) Gains and losses on commodity contracts cash flow hedges: Propane swap agreements (2) $ 606 $ (464 ) Natural gas swaps (2) 11 (450 ) Natural gas futures (2) (573 ) 298 Total before income taxes 44 (616 ) Income tax benefit (expense) (5 ) 172 Net of tax 39 (444 ) Total reclassifications for the period $ (68 ) $ (538 ) (1) These amounts are included in the computation of net periodic costs (benefits). See Note 9 , Employee Benefit Plans , for additional details. (2) These amounts are included in the effects of gains and losses from derivative instruments. See Note 12, Derivative Instruments , for additional details.

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	3 Months Ended
	Mar. 31, 2019
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 months ended March 31, 2019 and 2018 are set forth in the following tables: Chesapeake FPU Chesapeake SERP Chesapeake FPU For the Three Months Ended March 31, 2019 2018 2019 2018 2019 2018 2019 2018 2019 2018 (in thousands) Interest cost $ 105 $ 97 $ 615 $ 592 $ 21 $ 21 $ 10 $ 10 $ 12 $ 12 Expected return on plan assets (127 ) (138 ) (693 ) (774 ) — — — — — — Amortization of prior service credit — — — — — — (19 ) (19 ) — — Amortization of net loss 101 88 129 109 26 25 12 15 — — Net periodic cost (benefit) 79 47 51 (73 ) 47 46 3 6 12 12 Amortization of pre-merger regulatory asset — — 190 191 — — — — 2 2 Total periodic cost $ 79 $ 47 $ 241 $ 118 $ 47 $ 46 $ 3 $ 6 $ 14 $ 14
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 months ended March 31, 2019 and 2018 : For the Three Months Ended March 31, 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 (1) 101 24 26 (7 ) — 144 Recognized from regulatory asset — 105 — — — 105 Total $ 101 $ 129 $ 26 $ (7 ) $ — $ 249 For the Three Months Ended March 31, 2018 Chesapeake FPU Chesapeake SERP Chesapeake FPU Total (in thousands) Prior service credit $ — $ — $ — $ (19 ) $ — $ (19 ) Net loss 88 109 25 15 — 237 Total recognized in net periodic benefit cost 88 109 25 (4 ) — 218 Recognized from accumulated other comprehensive loss (1) 88 21 25 (4 ) — 130 Recognized from regulatory asset — 88 — — — 88 Total $ 88 $ 109 $ 25 $ (4 ) $ — $ 218

Investments (Tables)

Investments (Tables)	3 Months Ended
	Mar. 31, 2019
Investments, Debt and Equity Securities [Abstract]
Investments schedule [Table Text Block]	The investment balances at March 31, 2019 and December 31, 2018 , consisted of the following: (in thousands) March 31, December 31, Rabbi trust (associated with the Non-Qualified Deferred Compensation Plan) $ 7,484 $ 6,689 Investments in equity securities 25 22 Total $ 7,509 $ 6,711

Share-Based Compensation (Table

Share-Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2019
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 months ended March 31, 2019 and 2018 : Three Months Ended March 31, 2019 2018 (in thousands) Awards to non-employee directors $ 149 $ 135 Awards to key employees 338 1,385 Total compensation expense 487 1,520 Less: tax benefit (127 ) (416 ) Share-based compensation amounts included in net income $ 360 $ 1,104
Awards to non-employee directors [Member]
Shares awarded to non-employee directors [Line Items]
Schedule of Share-based Compensation, Activity	.
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 three months ended March 31, 2019 : Number of Shares Weighted Average Fair Value Outstanding—December 31, 2018 131,741 $ 67.24 Granted 45,016 $ 91.19 Vested (25,831 ) $ 67.08 Expired (15,086 ) $ 69.28 Outstanding—March 31, 2019 135,840 $ 74.05

Derivative Instruments (Tables)

Derivative Instruments (Tables)	3 Months Ended
	Mar. 31, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments [Table Text Block]	As of March 31, 2019 , the volume of our open commodity derivative contracts were as follows: Business unit Commodity Quantity hedged (in millions) Designation Longest Expiration date of hedge PESCO Natural gas (Dts) 21.7 Cash flows hedges December 2022 PESCO Natural gas (Dts) 3.8 Not designated March 2021 Sharp Propane (gallons) 5.4 Cash flows hedges June 2021
Offsetting Assets and Liabilities [Table Text Block]	The following table summarizes the accounts receivable and payable on a gross and net basis at March 31, 2019 and December 31, 2018 : At March 31, 2019 (in thousands) Gross amounts Amounts offset Net amounts Accounts receivable $ 8,832 $ 3,264 $ 5,568 Accounts payable $ 15,906 $ 3,264 $ 12,642 At December 31, 2018 (in thousands) Gross amounts Amounts offset Net amounts Accounts receivable $ 12,368 $ 3,834 $ 8,534 Accounts payable $ 24,741 $ 3,834 $ 20,907
Schedule of Due to (from) Broker-Dealers and Clearing Organizations [Table Text Block]	We maintain separate broker margin accounts for Sharp and PESCO. The balances are as follows: (in thousands) Balance Sheet Location At March 31, 2019 At December 31, 2018 PESCO Other Current Assets $ (335 ) $ 2,810
Fair Values of Derivative Contracts Recorded in Condensed Consolidated Balance Sheet	The fair values of the derivative contracts recorded in the condensed consolidated balance sheets as of March 31, 2019 and December 31, 2018 , are as follows: Asset Derivatives Fair Value As Of (in thousands) Balance Sheet Location March 31, 2019 December 31, 2018 Derivatives not designated as hedging instruments Natural gas futures contracts Derivative assets, at fair value $ 2,122 $ 4,024 Derivatives designated as fair value hedges Propane put options Derivative assets, at fair value — 71 Derivatives designated as cash flow hedges Natural gas futures contracts Derivative assets, at fair value 7,055 9,059 Propane swap agreements Derivative assets, at fair value 44 11 Total asset derivatives $ 9,221 $ 13,165 Liability Derivatives Fair Value As Of (in thousands) Balance Sheet Location March 31, 2019 December 31, 2018 Derivatives not designated as hedging instruments Natural gas futures contracts Derivative liabilities, at fair value $ 2,638 $ 4,562 Derivatives designated as cash flow hedges Natural gas futures contracts Derivative liabilities, at fair value 3,533 8,705 Propane swap agreements Derivative liabilities, at fair value 627 1,604 Total liability derivatives $ 6,798 $ 14,871
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 March 31, (in thousands) (Loss) on Derivatives 2019 2018 Derivatives not designated as hedging instruments Natural gas futures contracts Cost of sales $ (22 ) $ (2,835 ) Propane swap agreements Cost of sales — (9 ) Derivatives designated as cash flow hedges Propane swap agreements Cost of sales 606 (464 ) Propane swap agreements Other comprehensive income (loss) 1,009 (992 ) Natural gas futures contracts Cost of sales (573 ) 298 Natural gas swap contracts Cost of sales 11 (450 ) Natural gas swap contracts Other comprehensive income (loss) 3,226 (1,617 ) Natural gas futures contracts Other comprehensive income (loss) (59 ) 65 Total $ 4,198 $ (6,004 )
Schedule of Fair Value Hedging Instruments, Statements of Financial Performance and Financial Position, Location [Table Text Block]	As of March 31, 2019 , the following amounts were recorded in the condensed consolidated balance sheets related to fair value hedges: (in thousands) Carrying Amount of Hedged Item Cumulative Adjustment Included in Carrying Amount of Hedged Item Balance Sheet Location of Hedged Items At March 31, 2019 At December 31, 2018 At March 31, 2019 At December 31, 2018 Inventory $ 6 $ 212 $ — $ —

Fair Value of Financial Instr_2

Fair Value of Financial Instruments (Tables)	3 Months Ended
	Mar. 31, 2019
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 March 31, 2019 and December 31, 2018 : Fair Value Measurements Using: As of March 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 $ 25 $ 25 $ — $ — Investments—guaranteed income fund 695 — — 695 Investments—mutual funds and other 6,789 6,789 — — Total investments 7,509 6,814 — 695 Derivative assets 9,221 — 9,221 — Total assets $ 16,730 $ 6,814 $ 9,221 $ 695 Liabilities: Derivative liabilities $ 6,798 $ — $ 6,798 $ — Fair Value Measurements Using: As of December 31, 2018 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 $ 22 $ 22 $ — $ — Investments—guaranteed income fund 686 — — 686 Investments—mutual funds and other 6,003 6,003 — — Total investments 6,711 6,025 — 686 Derivative assets 13,165 — 13,165 — Total assets $ 19,876 $ 6,025 $ 13,165 $ 686 Liabilities: Derivative liabilities $ 14,871 $ — $ 14,871 $ —
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 three months ended March 31, 2019 and 2018 : Three Months Ended 2019 2018 (in thousands) Beginning Balance $ 686 $ 648 Purchases and adjustments 6 (48 ) Investment income 3 2 Ending Balance $ 695 $ 602

Long-Term Debt (Tables)

Long-Term Debt (Tables)	3 Months Ended
	Mar. 31, 2019
Schedule of Line of Credit Facilities [Line Items]
Schedule of Line of Credit Facilities [Table Text Block]	Total Borrowing Capacity Less: Amount of Debt Issued Less: Unfunded Commitments Remaining Borrowing Capacity (in thousands) Shelf Agreement Prudential Shelf Agreement $ 220,000 $ (70,000 ) $ (100,000 ) $ 50,000 MetLife Shelf Agreement 150,000 — — 150,000 NYL Shelf Agreement 150,000 (100,000 ) — 50,000 Total $ 520,000 $ (170,000 ) $ (100,000 ) $ 250,000
Outstanding Long-Term Debt	Our outstanding long-term debt is shown below: March 31, December 31, (in thousands) 2019 2018 FPU secured first mortgage bonds (1) : 9.08% bond, due June 1, 2022 $ 7,987 $ 7,986 Uncollateralized senior notes: 5.50% note, due October 12, 2020 4,000 4,000 5.93% note, due October 31, 2023 15,000 15,000 5.68% note, due June 30, 2026 23,200 23,200 6.43% note, due May 2, 2028 7,000 7,000 3.73% note, due December 16, 2028 20,000 20,000 3.88% note, due May 15, 2029 50,000 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 Term Note due January 21, 2020 30,000 30,000 Term Note due February 28, 2020 30,000 — Promissory notes — 26 Finance lease obligation 909 1,310 Less: debt issuance costs (589 ) (567 ) Total long-term debt 357,507 327,955 Less: current maturities (71,509 ) (11,935 ) Total long-term debt, net of current maturities $ 285,998 $ 316,020 (1) FPU secured first mortgage bonds are guaranteed by Chesapeake Utilities.

Leases Leases (Tables)

Leases Leases (Tables)	3 Months Ended
	Mar. 31, 2019
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 March 31, ( in thousands) Classification 2019 2018 Operating lease cost (1) Operations expense $ 635 $ 1,107 Finance lease cost Amortization of lease assets Depreciation and amortization 401 358 Interest on lease liabilities Interest expense 4 17 Net lease cost $ 1,040 $ 1,482 (1) Includes short-term leases and variable lease costs, which are immaterial
Schedule of Leases Reported on Consolidated Statement of Financial Position [Table Text Block]	The following table presents the balance and classifications of our right of use assets and lease liabilities included in our consolidated balance sheet at March 31, 2019: (in thousands) Balance sheet classification Amount Assets Operating lease assets Operating lease right-of-use assets $ 12,523 Finance lease assets Property, plant and equipment 1,839 Total lease assets $ 14,362 Liabilities Current Operating lease liabilities Other accrued liabilities $ 1,642 Finance lease liabilities Current portion of long-term debt 909 Noncurrent Operating lease liabilities Other liabilities 10,873 Finance lease liabilities Long-term debt — Total lease liabilities $ 13,424
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 March 31, 2019: At March 31, 2019 Weighted-average remaining lease term ( in years ) Operating leases 9.32 Finance leases 0.17 Weighted-average discount rate Operating leases 3.8 % Finance leases 3.5 %
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 March 31, 2019 and March 31, 2018: Three Months Ended March 31, (in thousands) 2019 2018 Operating cash flows from operating leases $ 537 $ 1,018 Operating cash flows from finance leases 4 17 Financing cash flows from finance leases 401 358
Schedule of Maturities of Leases [Table Text Block]	The following table presents the future undiscounted maturities of our operating and financing leases at March 31, 2019 and for each of the next five years and thereafter: (in thousands) Operating Leases (1) Finance Leases Total Remainder of 2019 $ 1,539 $ 910 $ 2,449 2020 2,045 — 2,045 2021 1,765 — 1,765 2022 1,659 — 1,659 2023 1,669 — 1,669 2024 1,431 — 1,431 Thereafter 4,860 — 4,860 Total lease payments $ 14,968 $ 910 $ 15,878 Less: Interest 2,453 1 2,454 Present value of lease liabilities $ 12,515 $ 909 13,424 (1) Operating lease payments include $3.8 million related to options to extend lease terms that are reasonably certain of being exercised.
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]	The following table presents future minimum lease payments for our operating leases at December 31, 2018 under ASC 840 and is being presented for comparative purposes: Year(s) 2019 2020 2021 2022 2023 Thereafter Total (in thousands) Expected payments $2,349 $1,998 $1,761 $1,689 $1,642 $5,398 $14,837

Summary of Accounting Policie_3

Summary of Accounting Policies Acquisitions Additional information (Details) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2018USD ($)
Business Acquisition [Line Items]
Revenues	$ 227,616	$ 239,356
Operating Income (Loss)	43,993	40,406
Marlin and Ohl [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transferred			$ 18,400
Unregulated Energy [Member]
Business Acquisition [Line Items]
Operating Income (Loss)	$ 15,127	$ 13,684
Unregulated Energy [Member] | Ohl [Member]
Business Acquisition [Line Items]
Goodwill, Acquired During Period			$ 1,500
Number of customers acquired through acquisition			2,500
Unregulated Energy [Member] | Marlin [Member]
Business Acquisition [Line Items]
Goodwill, Acquired During Period			$ 4,800

Summary of Accounting Policie_4

Summary of Accounting Policies Summary of Effect of Adoption on Consolidated Financial Statements (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Item Effected [Line Items]
Accrued revenue	$ 20,747		$ 27,499
Regulated Energy Operating Revenue	103,618	$ 109,393
Regulated Energy cost of sales	36,516	48,231
Depreciation and amortization	11,074	9,704
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest	38,238	36,810
Income taxes	9,574	9,955
Net Income	28,664	$ 26,855
Other assets	5,197		6,985
Retained earnings	$ 284,111		$ 261,530

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
	Mar. 31, 2019	Mar. 31, 2018
Calculation of Basic Earnings Per Share:
Net Income	$ 28,664	$ 26,855
Weighted shares outstanding (shares)	16,384,927	16,351,338
Basic Earnings Per Share (in dollars per share)	$ 1.75	$ 1.64
Reconciliation of Numerator:
Net Income	$ 28,664	$ 26,855
Reconciliation of Denominator:
Weighted shares outstanding - Basic (shares)	16,384,927	16,351,338
Effect of dilutive securities:
Share-based compensation (shares)	47,925	51,647
Adjusted denominator-Diluted (shares)	16,432,852	16,402,985
Diluted Earnings Per Share (in dollars per share)	$ 1.74	$ 1.64

Revenue Recognition Disegragati

Revenue Recognition Disegragation of Revenue (Details) - USD ($)		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Disaggregation of Revenue [Line Items]
Revenues		$ 227,616,000	$ 239,356,000
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	227,616,000	239,356,000
Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	103,618,000	109,393,000
Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	138,102,000	145,367,000
Other Segments And Intersegments Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(14,104,000)	(15,404,000)
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	(14,104,000)	(15,404,000)
Consolidation, Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(28,940,000)	(27,983,000)
Eliminations [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(9,745,000)	(7,828,000)
Other [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenues		121,000	(589,000)
Other [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenues		84,000	73,000
Revenue from Contract with Customer, Excluding Assessed Tax		(5,091,000)	(4,751,000)
Energy Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		90,742,000	99,526,000
Energy Distribution [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		90,742,000	99,526,000
Energy Distribution [Member] | Delaware natural gas division [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		27,549,000	32,072,000
Energy Distribution [Member] | Delaware natural gas division [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		27,549,000	32,072,000
Energy Distribution [Member] | Central Florida Gas Division [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		7,900,000	5,864,000
Energy Distribution [Member] | Central Florida Gas Division [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		7,900,000	5,864,000
Energy Distribution [Member] | FPU Electric Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		14,378,000	18,741,000
Energy Distribution [Member] | FPU Electric Distribution [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		14,378,000	18,741,000
Energy Distribution [Member] | Florida Public Utilities Company [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		23,786,000	23,213,000
Energy Distribution [Member] | Florida Public Utilities Company [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		23,786,000	23,213,000
Energy Distribution [Member] | Maryland Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		10,047,000	10,672,000
Energy Distribution [Member] | Maryland Natural Gas [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		10,047,000	10,672,000
Energy Distribution [Member] | Sandpiper [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		7,082,000	8,964,000
Energy Distribution [Member] | Sandpiper [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		7,082,000	8,964,000
Energy Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		36,091,000	29,772,000
Energy Transmission [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		22,621,000	17,695,000
Energy Transmission [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		13,470,000	12,077,000
Energy Transmission [Member] | Aspire [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		13,470,000	12,077,000
Energy Transmission [Member] | Aspire [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		13,470,000	12,077,000
Energy Transmission [Member] | Eastern Shore Gas Company [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		19,056,000	15,597,000
Energy Transmission [Member] | Eastern Shore Gas Company [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		19,056,000	15,597,000
Energy Transmission [Member] | Peninsula Pipeline [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		3,565,000	2,098,000
Energy Transmission [Member] | Peninsula Pipeline [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		3,565,000	2,098,000
Energy Generation [Member] | Eight Flags [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		4,142,000	4,378,000
Energy Generation [Member] | Eight Flags [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		4,142,000	4,378,000
Propane Delivery [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		46,125,000	52,104,000
Propane Delivery [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		46,125,000	52,104,000
Energy Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		79,456,000	81,559,000
Energy Services [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		79,456,000	81,559,000
Energy Services [Member] | Marlin Gas Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		2,434,000
Energy Services [Member] | Marlin Gas Services [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		2,434,000
Energy Services [Member] | PESCO [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		77,022,000	81,559,000
Energy Services [Member] | PESCO [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		77,022,000	81,559,000
Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(29,477,000)	(28,671,000)
Eliminations [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(9,745,000)	(7,828,000)
Eliminations [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(5,496,000)	(5,245,000)
Eliminations [Member] | Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(14,236,000)	(15,598,000)
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		537,000	688,000
Other [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		405,000	494,000
Other [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		$ 132,000	$ 194,000
[1]	(1) Total operating revenues for the three months ended March 31, 2019, include other revenue (revenues from sources other than contracts with customers) of $121,000 and $84,000 for our Regulated and Unregulated Energy segments, respectively and $(589,000) and $73,000 for our Regulated and Unregulated Energy segments, respectively, for the three months ended March 31, 2018. 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
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Receivables from Customers	$ 72,162		$ 83,214
Contract with Customer, Asset, Net, Noncurrent	3,004		2,614
Contract with Customer, Liability, Current	305		$ 480
Increase (Decrease) in Receivables	(11,052)
Increase (Decrease) in Other Noncurrent Assets	390
Increase (Decrease) in Other Current Liabilities	(175)
Contract with Customer, Liability, Revenue Recognized	$ 287	$ 251

Revenue Recognition Remaining P

Revenue Recognition Remaining Performance Obligations (Details) $ in Thousands	Mar. 31, 2019USD ($)
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 223
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	297
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	297
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	109
PESCO - Natural Gas Marketing [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	4,435
PESCO - Natural Gas Marketing [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	4,585
PESCO - Natural Gas Marketing [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	1,706
PESCO - Natural Gas Marketing [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	22
Natural gas distribution operations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	2,999
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	3,587
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	3,358
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	3,320
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	2,924
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	2,910
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	27,916
Eastern Shore and Peninsula Pipeline [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	28,754
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	36,791
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	33,510
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	26,566
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	21,146
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	18,969
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	193,651
Total for Segments [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	36,411
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	45,260
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	38,871
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	30,017
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	24,070
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	21,879
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	$ 221,567

Rates and Other Regulatory Ac_3

Rates and Other Regulatory Activities - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2019USD ($)kWh
Electric Limited Proceedings [Member]
Rates and Other Regulatory Activities [Line Items]
Dollar Amount of Term Notes to Finance Hurricane Michael Costs	$ 30,000,000
Extent of Customers Losing Service	100.00%
Basis Plus LIBOR for Term Notes to Finance Hurricane Michael Costs	75
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 1.54
Asset Recovery Damaged Property Costs, Noncurrent	1,500,000
Deferred Storm and Property Reserve Deficiency, Noncurrent	$ 779,000
Public Utilities Approved Rate Increase (Decrease), Units | kWh	1,000
Number of Years to Recover Storm Related Costs	2 years
Number of Months for Term Notes to Finance Hurricane Michael	13 months
Amounts Spent to Restore Service	$ 65,000,000
Number of Term Notes to Finance Hurricane Michael	2
Delaware natural gas division [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	$ 13,082,000
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	19,478,000
Central Florida Gas Division [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	8,346,000
Maryland Division [Member]
Rates and Other Regulatory Activities [Line Items]
One time bill credit related to TCJA	365,000
Regulatory Liabilities	4,171,000
Sandpiper [Member]
Rates and Other Regulatory Activities [Line Items]
One time bill credit related to TCJA	608,000
Regulatory Liabilities	3,803,000
FPU electric division [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	$ 5,950,000

Environmental Commitments and_3

Environmental Commitments and Contingencies - Additional Information (Detail)	3 Months Ended	12 Months Ended
	Mar. 31, 2019USD ($)site	Dec. 31, 2018USD ($)
Environmental Commitments And Contingencies [Line Items]
Company's exposure in number of former Manufactured Gas Plant Sites | site	7
Environmental liabilities	$ 7,370,000	$ 7,638,000
West Palm Beach Florida [Member] | Minimum [Member]
Environmental Commitments And Contingencies [Line Items]
Estimated costs of remediation range, minimum	4,500,000
West Palm Beach Florida [Member] | Maximum [Member]
Environmental Commitments And Contingencies [Line Items]
Estimated costs of remediation range, minimum	15,400,000
Sanford Florida [Member]
Environmental Commitments And Contingencies [Line Items]
Environmental remediation expense	10,000
Winter Haven Florida [Member] | Maximum [Member]
Environmental Commitments And Contingencies [Line Items]
Environmental remediation expense	425,000
Seaford [Member] | Minimum [Member]
Environmental Commitments And Contingencies [Line Items]
Estimated costs of remediation range, minimum	273,000
Seaford [Member] | Maximum [Member]
Environmental Commitments And Contingencies [Line Items]
Estimated costs of remediation range, minimum	465,000
FPU [Member]
Environmental Commitments And Contingencies [Line Items]
Environmental liabilities	8,900,000	9,100,000
Approval of recovery of environmental costs	14,000,000
Environmental costs recovered	11,600,000	11,500,000
FPU [Member] | Manufactured Gas Plant [Member]
Environmental Commitments And Contingencies [Line Items]
Regulatory Assets for future recovery of environmental costs	$ 2,400,000	$ 2,500,000

Other Commitments and Conting_2

Other Commitments and Contingencies - Additional Information (Detail) gal in Thousands, $ in Millions	3 Months Ended
	Mar. 31, 2019USD ($)gal
Other Commitments [Line Items]
Number of Years for Asset Management Agreement	3 years
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 | $	$ 77.3
Draws on letters of credit | $	$ 7
Sandpiper [Member]
Other Commitments [Line Items]
Annual Estimate Of Volume Of Propane To Be Purchased | gal	288
Sharp Energy Inc [Member]
Other Commitments [Line Items]
Annual Estimate Of Volume Of Propane To Be Purchased | gal	288

Segment Information - Schedule

Segment Information - Schedule of Segment Reporting Information by Segment (Detail) $ in Thousands		3 Months Ended
		Mar. 31, 2019USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2018USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments		2
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers		$ 227,616	$ 239,356
Operating Income
Total operating income		43,993	40,406
Other expense, net		(45)	68
Interest		5,710	3,664
Income Before Income Taxes		38,238	36,810
Income taxes		9,574	9,955
Net Income		28,664	26,855
Identifiable Assets
Total identifiable assets		1,682,797		$ 1,693,671
Regulated Energy [Member]
Operating Income
Total operating income		29,741	26,711
Identifiable Assets
Total identifiable assets		1,343,061		1,345,805
Unregulated Energy [Member]
Operating Income
Total operating income		15,127	13,684
Identifiable Assets
Total identifiable assets		296,836		306,045
Other [Member]
Identifiable Assets
Total identifiable assets		42,900		$ 41,821
Other and eliminations [Member]
Operating Income
Total operating income		(875)	11
Operating Revenues, Unaffiliated Customers [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers		227,616	239,356
Operating Revenues, Unaffiliated Customers [Member] | Regulated Energy [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers		100,739	105,954
Operating Revenues, Unaffiliated Customers [Member] | Unregulated Energy [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers		126,877	133,402
Intersegment Revenues [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	[1]	14,236	15,598
Intersegment Revenues [Member] | Regulated Energy [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	[1]	2,879	3,439
Intersegment Revenues [Member] | Unregulated Energy [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	[1]	11,225	11,965
Intersegment Revenues [Member] | Other [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	[1]	$ 132	$ 194
[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
	Mar. 31, 2019	Mar. 31, 2018
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance	$ (6,713)	$ (4,272)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	3,021	(2,232)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	68	538
Net current-period other comprehensive income (loss)	3,089	(1,694)
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect		0
Ending balance	(3,739)	(6,873)
UnrealizedGainsLossesFromDefinedBenefitPensionAndPostretirementPlanItems [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance	(5,928)	(4,743)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	107	94
Net current-period other comprehensive income (loss)	107	94
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect		(1,022)
Ending balance	(5,821)	(5,671)
Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance	(785)	471
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	3,021	(2,232)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(39)	444
Net current-period other comprehensive income (loss)	2,982	(1,788)
Prior Period Reclassification Adjustment	(115)
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect		115
Ending balance	2,082	(1,202)
AOCI Attributable to Parent [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Prior Period Reclassification Adjustment	$ (115)
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect		$ (907)

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
		Mar. 31, 2019	Mar. 31, 2018
Amortization of pension and postretirement items:
Tax benefit		$ (9,574)	$ (9,955)
Reclassification out of Accumulated Other Comprehensive Income [Member]
Amortization of pension and postretirement items:
Net of tax		(68)	(538)
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
Net loss	[1]	(163)	(149)
Total before tax		(144)	(130)
Tax benefit		37	36
Net of tax		(107)	(94)
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		44	(616)
Tax benefit		(5)	172
Net of tax		39	(444)
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]	606	(464)
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]	11	(450)
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]	$ (573)	$ 298
[1]	These amounts are included in the computation of net periodic costs (benefits). See Note 9, Employee Benefit Plans, for additional details.
[2]	These amounts are included in the effects of gains and losses from derivative instruments. See Note 12, Derivative Instruments, for additional details.

Stockholder's Equity Stockholde

Stockholder's Equity Stockholder's Equity Additional Information (Details) - $ / shares	Mar. 31, 2019	Dec. 31, 2018
Equity [Abstract]
Preferred Stock, Shares Authorized	2,000,000	2,000,000
Preferred Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01

Employee Benefit Plans (Detail)

Employee Benefit Plans (Detail) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost		$ (19)	$ (19)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		268	237
Chesapeake Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost		105	97
Expected return on plan assets		(127)	(138)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		101	88
Net periodic cost (benefit)	[1]	79	47
Total periodic cost		79	47
Florida Public Utilities Company Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost		615	592
Expected return on plan assets		(693)	(774)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		129	109
Net periodic cost (benefit)	[1]	51	(73)
Amortization of pre-merger regulatory asset		190	191
Total periodic cost		241	118
Chesapeake Pension SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost		21	21
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		26	25
Net periodic cost (benefit)	[1]	47	46
Total periodic cost		47	46
Chesapeake Postretirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost		10	10
Amortization of prior service cost		(19)	(19)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		12	15
Net periodic cost (benefit)	[1]	3	6
Total periodic cost		3	6
Florida Public Utilities Company Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost		12	12
Net periodic cost (benefit)	[1]	12	12
Amortization of pre-merger regulatory asset		2	2
Total periodic cost		$ 14	$ 14
[1]	See Note 8, Stockholder's Equity.

Employee Benefit Plans - Additi

Employee Benefit Plans - Additional Information (Detail) $ in Thousands	3 Months Ended
	Mar. 31, 2019USD ($)
Defined Benefit Plan Disclosure [Line Items]
Expected pension and postretirement benefit costs	$ 1,310
Expected amortization of pre merger regulatory asset	543
Florida Public Utilities Company Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Unamortized balance of regulatory asset	351
Contribution to pension plan	233
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	1,200
Chesapeake Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Contribution to pension plan	33
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	163
Chesapeake Pension SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Contribution to pension plan	38
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	383
Chesapeake Postretirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Contribution to pension plan	1
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	96
Florida Public Utilities Company Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Contribution to pension plan	6
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	$ 94

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
		Mar. 31, 2019	Mar. 31, 2018
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Prior service cost (credit)		$ (19)	$ (19)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		268	237
Recognized from accumulated other comprehensive loss	[1]	144	130
Recognized from regulatory asset		105	88
Total recognized in net periodic benefit cost		249	218
Chesapeake Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		101	88
Recognized from accumulated other comprehensive loss	[1]	101	88
Total recognized in net periodic benefit cost		101	88
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)		129	109
Recognized from accumulated other comprehensive loss	[1]	24	21
Recognized from regulatory asset		105	88
Total recognized in net periodic benefit cost		129	109
Chesapeake Pension SERP [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		26	25
Recognized from accumulated other comprehensive loss	[1]	26	25
Total recognized in net periodic benefit cost		26	25
Chesapeake Postretirement Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Prior service cost (credit)		(19)	(19)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		12	15
Recognized from accumulated other comprehensive loss	[1]	(7)	(4)
Total recognized in net periodic benefit cost		$ (7)	$ (4)
[1]	See Note 8, Stockholder's Equity.

Investments - Schedule of Inves

Investments - Schedule of Investments (Details) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Investments schedule [Line Items]
Investments, at fair value	$ 7,509	$ 6,711
Rabbi Trust Associated With Deferred Compensation Plan [Member]
Investments schedule [Line Items]
Investments, at fair value	7,484	6,689
Equity Securities [Member]
Investments schedule [Line Items]
Investments, at fair value	$ 25	$ 22

Investments - Additional Inform

Investments - Additional Information (Detail) - USD ($)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Investments, Debt and Equity Securities [Abstract]
Unrealized gain (loss), net of other expenses	$ 727,000	$ (44,000)

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
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	$ 487	$ 1,520
Less: tax benefit	(127)	(416)
Share-Based Compensation amounts included in net income	$ 360	1,104
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	792
Total compensation expense	$ 149	135
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	135,840		131,741
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	45,016
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	25,831
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Expired In Period	15,086
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 74.05		$ 67.24
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	91.19
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	67.08
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Expirations Weighted Average Grant Date Fair Value	$ 69.28
Total compensation expense	$ 338	$ 1,385

Share-Based Compensation - Summ

Share-Based Compensation - Summary of Stock Activity under the SICP (Detail)	3 Months Ended
	Mar. 31, 2019shares
Awards to non-employee directors [Member]
Number of Shares
Granted awards (shares)	792

Share-Based Compensation - Addi

Share-Based Compensation - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares Paid for Tax Withholding for Share Based Compensation	7,635	10,436
Payments Related to Tax Withholding for Share-based Compensation	$ 692	$ 719
Unrecognized compensation cost	$ 4,300
Awards to non-employee directors [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Amortization of expense equally over a service period	1 year
Granted awards (shares)	792
Unrecognized compensation expense related to the awards to non-employee directors	$ 52
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	$ 75.70
Granted awards (shares)	276
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, Grants in Period, Weighted Average Grant Date Fair Value	$ 91.19
Granted awards (shares)	45,016
Vesting period	3 years
Payments Related to Tax Withholding for Share-based Compensation	$ 692
Intrinsic value of the SICP awards	$ 12,400
Accelerated Vested Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares Paid for Tax Withholding for Share Based Compensation	7,635

Derivative Instruments Volume o

Derivative Instruments Volume of Derivative Activity (Details) $ in Thousands, gal in Millions, Mcf in Millions	3 Months Ended
	Mar. 31, 2019USD ($)galMcf
PESCO [Member]
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months | $	$ (2,077)
PESCO [Member] | Natural Gas Futures [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | Mcf	21.7
Sharp Energy Inc [Member]
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months | $	$ (503)
Sharp Energy Inc [Member] | Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | gal	5.4
Not Designated as Hedging Instrument [Member] | PESCO [Member] | Natural Gas Futures [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | Mcf	3.8

Derivative Instruments - Additi

Derivative Instruments - Additional Information (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Derivative [Line Items]
Accounts Receivable Subject to Master Netting Arrangement	$ 3,264	$ 3,834
Accounts Payable Subject To Master Netting Arrangement	3,264	3,834
Other Payables to Broker-Dealers and Clearing Organizations	(335)
Other Receivables from Broker-Dealers and Clearing Organizations		2,810
Energy Marketing Contracts Assets, Current	9,221	13,165
Energy Marketing Contract Liabilities, Current	(6,798)	(14,871)
Derivative, Amount of Hedged Item	6	212
Hedging Liability [Member] | Natural Gas Futures [Member]
Derivative [Line Items]
Energy Marketing Contract Liabilities, Current	(3,533)	(8,705)
Designated as Hedging Instrument [Member] | Mark To Market Energy Assets [Member] | Put Option [Member]
Derivative [Line Items]
Energy Marketing Contracts Assets, Current	0	71
Designated as Hedging Instrument [Member] | Mark To Market Energy Assets [Member] | Natural Gas Futures [Member]
Derivative [Line Items]
Energy Marketing Contracts Assets, Current	7,055	9,059
Designated as Hedging Instrument [Member] | Mark To Market Energy Assets [Member] | Propane Swap Agreement [Member]
Derivative [Line Items]
Energy Marketing Contracts Assets, Current	44	11
Designated as Hedging Instrument [Member] | Mark-to-market energy liabilities [Member] | Propane Swap Agreement [Member]
Derivative [Line Items]
Energy Marketing Contract Liabilities, Current	(627)	(1,604)
Not Designated as Hedging Instrument [Member] | Mark To Market Energy Assets [Member] | Natural Gas Futures [Member]
Derivative [Line Items]
Energy Marketing Contracts Assets, Current	2,122	4,024
Not Designated as Hedging Instrument [Member] | Mark-to-market energy liabilities [Member] | Natural Gas Futures [Member]
Derivative [Line Items]
Energy Marketing Contract Liabilities, Current	(2,638)	(4,562)
Gross [Member]
Derivative [Line Items]
Accounts Receivable Subject to Master Netting Arrangement	8,832	12,368
Accounts Payable Subject To Master Netting Arrangement	15,906	24,741
Net [Member]
Derivative [Line Items]
Accounts Receivable Subject to Master Netting Arrangement	5,568	8,534
Accounts Payable Subject To Master Netting Arrangement	$ 12,642	$ 20,907

Derivative Instruments - Fair V

Derivative Instruments - Fair Values of Derivative Contracts Recorded in Condensed Consolidated Balance Sheet (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Energy Marketing Contracts Assets, Current	$ 9,221	$ 13,165
Energy Marketing Contract Liabilities, Current	6,798	14,871
Mark To Market Energy Assets [Member] | Natural Gas Futures [Member] | Derivatives not designated as hedging instruments [Member]
Derivatives, Fair Value [Line Items]
Energy Marketing Contracts Assets, Current	2,122	4,024
Mark To Market Energy Assets [Member] | Natural Gas Futures [Member] | Derivatives designated as hedging instrument [Member]
Derivatives, Fair Value [Line Items]
Energy Marketing Contracts Assets, Current	7,055	9,059
Mark To Market Energy Assets [Member] | Put Option [Member] | Derivatives designated as hedging instrument [Member]
Derivatives, Fair Value [Line Items]
Energy Marketing Contracts Assets, Current	0	71
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	44	11
Mark-to-market energy liabilities [Member] | Natural Gas Futures [Member] | Derivatives not designated as hedging instruments [Member]
Derivatives, Fair Value [Line Items]
Energy Marketing Contract Liabilities, Current	2,638	4,562
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	627	1,604
Hedging Liability [Member] | Natural Gas Futures [Member]
Derivatives, Fair Value [Line Items]
Energy Marketing Contract Liabilities, Current	$ 3,533	$ 8,705

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
	Mar. 31, 2019	Mar. 31, 2018
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 4,198	$ (6,004)
Cost of Sales [Member] | Derivatives not designated as hedging instruments [Member] | Future [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(22)	(2,835)
Cost of Sales [Member] | Derivatives not designated as hedging instruments [Member] | Propane Swap Agreement [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0	(9)
Cost of Sales [Member] | Derivatives designated as hedging instrument [Member] | Future [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(573)	298
Cost of Sales [Member] | Derivatives designated as hedging instrument [Member] | Swap [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	11	(450)
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	606	(464)
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	3,226	(1,617)
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	1,009	(992)
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	$ (59)	$ 65

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	Mar. 31, 2019	Dec. 31, 2018
Assets:
Investments	$ 7,509	$ 6,711
Energy Marketing Contracts Assets, Current	9,221	13,165
Liabilities:
Energy Marketing Contract Liabilities, Current	6,798	14,871
Equity Securities [Member]
Assets:
Investments	25	22
Quoted Prices in Active Markets (Level 1) [Member]
Assets:
Assets, Fair Value Disclosure	6,814	6,025
Quoted Prices in Active Markets (Level 1) [Member] | Equity Securities [Member]
Assets:
Investments	25	22
Quoted Prices in Active Markets (Level 1) [Member] | Investments - Mutual funds and other [Member]
Assets:
Investments	6,789	6,003
Quoted Prices in Active Markets (Level 1) [Member] | Total Investments [Member]
Assets:
Investments	6,814	6,025
Significant Other Observable Inputs (Level 2) [Member]
Assets:
Assets, Fair Value Disclosure	9,221	13,165
Liabilities:
Energy Marketing Contract Liabilities, Current	6,798
Significant Other Observable Inputs (Level 2) [Member] | Mark To Market Energy Assets incl. natural gas and swap agreements[Member]
Assets:
Derivative assets	9,221
Significant Unobservable Inputs (Level 3) [Member]
Assets:
Assets, Fair Value Disclosure	695	686
Significant Unobservable Inputs (Level 3) [Member] | Investments in guaranteed income fund [Member]
Assets:
Investments	695	686
Significant Unobservable Inputs (Level 3) [Member] | Total Investments [Member]
Assets:
Investments	695	686
Recurring [Member]
Assets:
Assets, Fair Value Disclosure	16,730	19,876
Liabilities:
Energy Marketing Contract Liabilities, Current	6,798	14,871
Recurring [Member] | Equity Securities [Member]
Assets:
Investments	25	22
Recurring [Member] | Investments in guaranteed income fund [Member]
Assets:
Investments	695	686
Recurring [Member] | Investments - Mutual funds and other [Member]
Assets:
Investments	6,789	6,003
Recurring [Member] | Total Investments [Member]
Assets:
Investments	7,509	6,711
Recurring [Member] | Mark To Market Energy Assets incl. natural gas and swap agreements[Member]
Assets:
Derivative assets	$ 9,221	$ 13,165

Fair Value of Financial Instr_4

Fair Value of Financial Instruments - Summary of Changes in Fair Value of Investments (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	$ 686	$ 648
Purchases and adjustments	6	(48)
Investment Income	3	2
Ending Balance	$ 695	$ 602

Fair Value of Financial Instr_5

Fair Value of Financial Instruments - Additional Information (Detail) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Fair Value Disclosures [Abstract]
Long-term debt including current maturities	$ 357.2	$ 327.2
Fair value of long-term debt	$ 361.3	$ 323.8

Long-Term Debt - Outstanding Lo

Long-Term Debt - Outstanding Long-Term Debt (Detail) - USD ($) $ in Thousands		Mar. 31, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Total long-term debt		$ (357,200)	$ (327,200)
Debt Instrument, Unused Borrowing Capacity, Amount		250,000
Finance lease obligation		909	1,310
Total Long-term debt		357,507	327,955
Less: current maturities		(71,509)	(11,935)
Less: debt issuance costs		589	567
Total long-term debt, net of current maturities		285,998	316,020
Aggregated Unfunded Commitments [Member]
Debt Instrument [Line Items]
Total long-term debt		(100,000)
Prudential Unfunded Commitments [Member]
Debt Instrument [Line Items]
Total long-term debt		(100,000)
New York Life [Member]
Debt Instrument [Line Items]
Total long-term debt		(100,000)
9.08% bond, due June 1, 2022 [Member]
Debt Instrument [Line Items]
Total long-term debt	[1]	(7,987)	(7,986)
5.50% note, due October 12, 2020 [Member]
Debt Instrument [Line Items]
Total long-term debt		(4,000)	(4,000)
5.93% note, due October 31, 2023 [Member]
Debt Instrument [Line Items]
Total long-term debt		(15,000)	(15,000)
5.68% note, due June 30, 2026 [Member]
Debt Instrument [Line Items]
Total long-term debt		(23,200)	(23,200)
6.43% note, due May 2, 2028 [Member]
Debt Instrument [Line Items]
Total long-term debt		(7,000)	(7,000)
3.73% note, due December 16, 2028 [Member]
Debt Instrument [Line Items]
Total long-term debt		(20,000)	(20,000)
3.88% note, due May 15, 2029 [Member]
Debt Instrument [Line Items]
Total long-term debt		(50,000)	(50,000)
3.25% note, due April 30, 2032 [Member]
Debt Instrument [Line Items]
Total long-term debt		(70,000)	(70,000)
3.48% note, due May 31, 2038 [Member]
Debt Instrument [Line Items]
Total long-term debt		(50,000)	(50,000)
Uncollateralized Senior Note Due November Two Thousand Thirty Eight [Member]
Debt Instrument [Line Items]
Total long-term debt		(50,000)	(50,000)
Term Note Due January Two Thousand Twenty [Member]
Debt Instrument [Line Items]
Total long-term debt	[2]	(30,000)	(30,000)
Term Note Due February Two Thousand Twenty [Member]
Debt Instrument [Line Items]
Total long-term debt	[2]	(30,000)
Promissory note [Member]
Debt Instrument [Line Items]
Total long-term debt		0	$ (26)
Aggregate Shelf Agreements [Member]
Debt Instrument [Line Items]
Total long-term debt		(170,000)
Aggregate Shelf Agreements [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		520,000
Prudential [Member]
Debt Instrument [Line Items]
Total long-term debt		(70,000)
Debt Instrument, Unused Borrowing Capacity, Amount		50,000
Prudential [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		220,000
MetLife [Member]
Debt Instrument [Line Items]
Debt Instrument, Unused Borrowing Capacity, Amount		150,000
MetLife [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		150,000
New York Life [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		100,000
Debt Instrument, Unused Borrowing Capacity, Amount		50,000
New York Life [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 150,000
[1]	FPU secured first mortgage bonds are guaranteed by Chesapeake Utilities.
[2]	In December 2018, we issued a $30.0 million unsecured term note through PNC Bank N.A. with maturity date of January 21, 2020. The interest rate at March 31, 2019 and December 31, 2018 was 3.24% and 3.23%, respectively, which equals one month LIBOR rate plus 75 basis points.

Long-Term Debt - Outstanding _2

Long-Term Debt - Outstanding Long-Term Debt- Supplemental Information (Detail)	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
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
Term Note Due January Two Thousand Twenty [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage	3.24%	3.23%
Long-term Debt, Percentage Bearing Fixed Interest, Percentage Rate	0.75%
Debt instrument, maturity date	Jan. 21, 2020
Term Note Due February Two Thousand Twenty [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage	3.24%
Long-term Debt, Percentage Bearing Fixed Interest, Percentage Rate	0.75%
Debt instrument, maturity date	Feb. 28, 2020
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Long-term debt, interest percentage
Debt instrument, maturity date

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information (Detail) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Document Period End Date		Mar. 31, 2019
Long-term debt including current maturities		$ 357,200	$ 327,200
Debt Instrument, Unused Borrowing Capacity, Amount		250,000
Term Note Due January Two Thousand Twenty [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities	[1]	$ 30,000	$ 30,000
Debt Instrument, Interest Rate, Stated Percentage		3.24%	3.23%
Term Note Due February Two Thousand Twenty [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities	[1]	$ 30,000
Debt Instrument, Interest Rate, Stated Percentage		3.24%
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage
3.48% note, due May 31, 2038 [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities		$ 50,000	$ 50,000
3.25% note, due April 30, 2032 [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities		$ 70,000	$ 70,000
Shelf Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		3.98%
MetLife [Member] | Notes Payable, Other Payables [Member] | Shelf Notes [Member]
Debt Instrument [Line Items]
Maturity date term		20 years
New York Life [Member] | Notes Payable, Other Payables [Member] | Shelf Notes [Member]
Debt Instrument [Line Items]
Maturity date term		20 years
Prudential [Member]
Debt Instrument [Line Items]
Senior notes		$ 100,000
Prudential [Member] | Notes Payable, Other Payables [Member] | Shelf Notes [Member]
Debt Instrument [Line Items]
Senior notes		$ 150,000
Maturity date term		20 years
Debt Instrument, Interest Rate, Stated Percentage		3.25%
Prudential [Member] | Shelf Notes [Member]
Debt Instrument [Line Items]
Senior notes		$ 150,000
New York Life [Member]
Debt Instrument [Line Items]
Senior notes		100,000
Debt Instrument, Unused Borrowing Capacity, Amount		50,000
Electric Limited Proceedings [Member]
Debt Instrument [Line Items]
Combined Dollar Amount of Term Notes to Finance Hurricane Michael Costs		$ 60,000
[1]	In December 2018, we issued a $30.0 million unsecured term note through PNC Bank N.A. with maturity date of January 21, 2020. The interest rate at March 31, 2019 and December 31, 2018 was 3.24% and 3.23%, respectively, which equals one month LIBOR rate plus 75 basis points.

Leases (Details)

Leases (Details)	3 Months Ended
	Mar. 31, 2019yr
Lease Disclosure [Abstract]
Effect of CPI Basis Point Change	100
Minimum Renewal Term Length in Years - Lessee	1
Maximum Renewal Term Length in Years - Lessee	25

Leases Leases - Lease Cost Addi

Leases Leases - Lease Cost Additional Information (Details) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Lease, Cost [Abstract]
Operating Lease, Cost	[1]	$ 635	$ 1,107
Financing Cash Flows from Finance Leases		401	358
Operating Cash Flows from Finance Leases		4	17
Lease, Cost		$ 1,040	$ 1,482
[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) $ in Thousands	Mar. 31, 2019USD ($)
Leases - Right of Use Asset and Lease Liability Balance Sheet Classification [Abstract]
Operating Lease, Right-of-Use Asset	$ 12,523
Finance Lease, Right-of-Use Asset	1,839
Total Finance and Operating Lease Right-of-Use Asset	14,362
Operating Lease, Liability, Current	1,642
Finance Lease, Liability, Current	909
Operating Lease, Liability, Noncurrent	10,873
Total Operating and Finance Lease Liabilities	$ 13,424

Leases Leases - Weighted Averag

Leases Leases - Weighted Average Remaining Lease Term Additional Information (Details)	Mar. 31, 2019
Leases - Weighted Average Remaining Lease term Additional Information [Abstract]
Finance Lease, Weighted Average Discount Rate, Percent	3.50%
Operating Lease, Weighted Average Discount Rate, Percent	3.78%
Finance Lease, Weighted Average Remaining Lease Term	2 months 1 day
Operating Lease, Weighted Average Remaining Lease Term	9 years 3 months 26 days

Leases Leases - Cash Flow Addit

Leases Leases - Cash Flow Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Leases - Cash Flow Additional Information [Abstract]
Operating Cash Flow from Operating Leases	$ 537	$ 1,018
Operating Cash Flows from Finance Leases	4	17
Finance Lease, Interest Expense	$ 401	$ 358

Leases Leases - Schedule of Fut

Leases Leases - Schedule of Future Maturities Additional Information (Details) $ in Thousands	Mar. 31, 2019USD ($)
Leases - Schedule of Future Maturities Additional Information [Abstract]
Lessee, Operating Lease, Liability, Payments, Remainder of Fiscal Year	$ 1,539	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Two	2,045	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Three	1,765	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Four	1,659	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Five	1,669	[1]
Lessee, Operating Lease Liability, Payments, Due Year Six	1,431	[1]
Lessee, Operating Lease Liability, Payments, Due After Year Six	4,860	[1]
Lessee, Operating Lease, Liability, Payments, Due	14,968	[1]
Lessee, Operating Lease, Liability, Undiscounted Excess Amount	2,453	[1]
Operating Lease, Liability	12,515	[1]
Finance Lease, Liability, Payments, Remainder of Fiscal Year	910
Finance Lease, Liability, Payments, Due	910
Finance Lease, Liability, Undiscounted Excess Amount	1
Finance Lease, Liability	909
Lease Liability Payments Remainder of Fiscal Year	2,449
Lease Liability Payments Due Year Two	2,045
Lease Liability Payments Due Year Three	1,765
Lease Liability Payments Due Year Four	1,659
Lease Liability Payments Due Year Five	1,669
Lease Liability Payments Due Year Six	1,431
Lease Liability Payments Due After Year Six	4,860
Lease Liability Payments Due	15,878
Lease Liability Undiscounted Excess Amount	2,454
Lease Liability	13,424
Lessee Future Operating Lease Option Payments	$ 3,800
[1]	Operating lease payments include $3.8 million related to options to extend lease terms that are reasonably certain of being exercised.

Leases Schedule of Future Minim

Leases Schedule of Future Minimum Rental Payment for Operating Leases (Details) $ in Thousands	Mar. 31, 2019USD ($)
Schedule of Future Minimum Rental Payment for Operating Leases [Abstract]
Operating Leases, Future Minimum Payments, Remainder of Fiscal Year	$ 2,349
Operating Leases, Future Minimum Payments, Due in Two Years	1,998
Operating Leases, Future Minimum Payments, Due in Three Years	1,761
Operating Leases, Future Minimum Payments, Due in Four Years	1,689
Operating Leases, Future Minimum Payments, Due in Five Years	1,642
Operating Leases, Future Minimum Payments, Due Thereafter	5,398
Operating Leases, Future Minimum Payments Due	$ 14,837