10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended: June 30, 2022

OR

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from                       to                      

Commission File Number: 001-11590 

CHESAPEAKE UTILITIES CORPORATION

(Exact name of registrant as specified in its charter)

Delaware	51-0064146
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

500 Energy Lane, Dover, Delaware 19901

(Address of principal executive offices, including Zip Code)

(302) 734-6799

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock - par value per share $0.4867	CPK	New York Stock Exchange, Inc.

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

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).  Yes  ☒    No  ☐

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

Large accelerated filer	☒	Accelerated filer	☐
Non-accelerated filer	☐	Smaller reporting company	☐
		Emerging growth company	☐

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

☐

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

Common Stock, par value $0.4867 — 17,737,871 shares outstanding as of July 29, 2022.

Table of Contents

PART I—FINANCIAL INFORMATION		1
ITEM 1.	FINANCIAL STATEMENTS	1
ITEM 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	32
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	60
ITEM 4.	CONTROLS AND PROCEDURES	61
PART II—OTHER INFORMATION		62
ITEM 1.	LEGAL PROCEEDINGS	62
ITEM 1A.	RISK FACTORS	62
ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	62
ITEM 3.	DEFAULTS UPON SENIOR SECURITIES	62
ITEM 5.	OTHER INFORMATION	62
ITEM 6.	EXHIBITS	63
SIGNATURES		64

GLOSSARY OF DEFINITIONS

Adjusted Gross Margin: a non-GAAP measure calculated by deducting the purchased cost of natural gas, propane and electricity and the cost of labor spent on direct revenue-producing activities from operating revenues. The costs included in Adjusted Gross Margin exclude depreciation and amortization and certain costs presented in operations and maintenance expenses in accordance with regulatory requirements

Aspire Energy: Aspire Energy of Ohio, LLC, a wholly-owned subsidiary of Chesapeake Utilities

Aspire Energy Express: Aspire Energy Express, LLC, a wholly-owned subsidiary of Chesapeake Utilities

ASU: Accounting Standards Update issued by the FASB

ATM: At-the-market

CARES Act: Coronavirus Aid, Relief, and Economic Security Act

CDC: U.S. Centers for Disease Control and Prevention

CDD: Cooling Degree-Day

CFG: Central Florida Gas Company

Chesapeake or Chesapeake Utilities: Chesapeake Utilities Corporation, its divisions and subsidiaries, as appropriate in the context of the disclosure

CHP: Combined Heat and Power Plant

Company: Chesapeake Utilities Corporation, its divisions and subsidiaries, as appropriate in the context of the disclosure

COVID-19: An infectious disease caused by a coronavirus

CNG: Compressed natural gas

Davenport Energy: An entity from whom we acquired certain propane operating assets in North Carolina.

Degree-day: A degree-day is the measure of the variation in the weather based on the extent to which the average daily temperature (from 10:00 am to 10:00 am) falls above (CDD) or below (HDD) 65 degrees Fahrenheit

Delmarva Peninsula: A peninsula on the east coast of the U.S. occupied by Delaware and portions of Maryland and Virginia

Diversified Energy: Diversified Energy Company an entity from whom we acquired certain propane operating assets in North Carolina, South Carolina, Virginia, and Pennsylvania

DRIP: Dividend Reinvestment and Direct Stock Purchase Plan

Dt(s): Dekatherm(s), which is a natural gas unit of measurement that includes a standard measure for heating value

Dts/d: Dekatherms per day

Eastern Shore: Eastern Shore Natural Gas Company, a wholly-owned subsidiary of Chesapeake Utilities

Eight Flags: Eight Flags Energy, LLC, a wholly-owned subsidiary of Chesapeake Utilities

Elkton Gas: Elkton Gas Company, a wholly-owned subsidiary of Chesapeake Utilities

Escambia Meter Station: A natural gas metering station owned by Peninsula Pipeline Company located in Escambia County,

Florida

ESG: Environmental, Social and Governance

FASB: Financial Accounting Standards Board

FERC: Federal Energy Regulatory Commission

FGT: Florida Gas Transmission Company

Florida OPC: The Office of Public Counsel, an agency established by the Florida legislature who advocates on behalf of Florida's utility consumers prior to actions or rule changes

FPU: Florida Public Utilities Company, a wholly-owned subsidiary of Chesapeake Utilities

GAAP: Generally Accepted Accounting Principles

Guernsey Power Station: Guernsey Power Station, LLC, a partner with Aspire Energy Express in the construction of a power generation facility in Ohio

GRIP: Gas Reliability Infrastructure Program

Gross Margin: a term under U.S. GAAP which is the excess of sales over costs of goods sold

Gulfstream: Gulfstream Natural Gas System, LLC, an unaffiliated pipeline network that supplies natural gas to FPU

HDD: Heating Degree-Day

LNG: Liquefied Natural Gas

Marlin Gas Services: Marlin Gas Services, LLC, a wholly-owned subsidiary of Chesapeake Utilities

MetLife: MetLife Investment Advisors, an institutional debt investment management firm, with which we have previously issued Senior Notes and which is a party to the current MetLife Shelf Agreement, as amended

MGP: Manufactured gas plant, which is a site where coal was previously used to manufacture gaseous fuel for industrial, commercial and residential use

Peninsula Pipeline: Peninsula Pipeline Company, Inc., a wholly-owned subsidiary of Chesapeake Utilities

Peoples Gas: Peoples Gas System, an Emera Incorporated subsidiary

Prudential: Prudential Investment Management Inc., an institutional investment management firm, with which Chesapeake Utilities entered into a previous Shelf Agreement and issued Shelf Notes

PSC: Public Service Commission, which is the state agency that regulates utility rates and/or services in certain of our jurisdictions

Revolver: Our $400.0 million unsecured revolving credit facility with certain lenders

RNG: Renewable natural gas

Sandpiper Energy: Sandpiper Energy, Inc., a wholly-owned subsidiary of Chesapeake Utilities

SEC: Securities and Exchange Commission

Senior Notes: Our unsecured long-term debt issued primarily to insurance companies on various dates

Sharp: Sharp Energy, Inc., a wholly-owned subsidiary of Chesapeake Utilities

Shelf Agreement: An agreement entered into by Chesapeake Utilities and a counterparty pursuant to which Chesapeake Utilities may request that the counterparty purchase our unsecured senior debt with a fixed interest rate and a maturity date not to exceed 20 years from the date of issuance

Shelf Notes: Unsecured senior promissory notes issuable under the Shelf Agreement executed with various counterparties

SICP: 2013 Stock and Incentive Compensation Plan

TCJA: Tax Cuts and Jobs Act enacted on December 22, 2017

TETLP: Texas Eastern Transmission, LP, an interstate pipeline interconnected with Eastern Shore's pipeline

Uncollateralized Senior Notes: Our unsecured long-term debt issued primarily to insurance companies on various dates

U.S.: The United States of America

PART I—FINANCIAL INFORMATION

Item 1. Financial Statements

Chesapeake Utilities Corporation and Subsidiaries

Condensed Consolidated Statements of Income (Unaudited)

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
(in thousands, except shares and per share data)
Operating Revenues
Regulated Energy	$	92,193	$	80,910	$	220,084	$	202,107
Unregulated Energy and other	47,277		30,172		142,266		100,161
Total Operating Revenues	139,470		111,082		362,350		302,268
Operating Expenses
Regulated natural gas and electric costs	21,573		14,447		67,016		57,491
Unregulated propane and natural gas costs	25,543		12,254		77,279		43,506
Operations	38,002		36,371		80,796		75,810
Maintenance	4,507		4,259		8,772		8,300
Depreciation and amortization	17,216		15,298		34,193		30,662
Other taxes	6,160		5,875		12,960		12,324
Total Operating Expenses	113,001		88,504		281,016		228,093
Operating Income	26,469		22,578		81,334		74,175
Other income, net	2,584		1,453		3,498		1,828
Interest charges	5,825		5,054		11,164		10,159
Income Before Income Taxes	23,228		18,977		73,668		65,844
Income Taxes	6,177		5,164		19,683		17,565
Net Income	$	17,051	$	13,813	$	53,985	$	48,279
Weighted Average Common Shares Outstanding:
Basic	17,730,833		17,546,346		17,704,592		17,516,273
Diluted	17,809,871		17,616,496		17,785,629		17,585,006
Earnings Per Share of Common Stock:
Basic	$	0.96	$	0.79	$	3.05	$	2.76
Diluted	$	0.96	$	0.78	$	3.04	$	2.75

    

The accompanying notes are an integral part of these financial statements.

1

Chesapeake Utilities Corporation and Subsidiaries

Condensed Consolidated Statements of Comprehensive Income (Unaudited)

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
(in thousands)
Net Income	$	17,051	$	13,813	$	53,985	$	48,279
Other Comprehensive Income (Loss), net of tax:
Employee Benefits, net of tax:
Amortization of prior service cost, net of tax of $(5), $(5), $(10) and $(10), respectively	(14)		(14)		(28)		(28)
Net gain, net of tax of $11, $28, $23 and $53, respectively	32		78		63		156
Cash Flow Hedges, net of tax:
Unrealized gain (loss) on commodity contract cash flow hedges, net of tax of $(188), $1,193, $(4) and $1,257, respectively	(498)		3,126		32		3,291
Unrealized gain on interest rate swap cash flow hedges, net of tax of $0, $2, $0 and $1, respectively	—		6		—		4
Total Other Comprehensive Income (Loss), net of tax	(480)		3,196		67		3,423
Comprehensive Income	$	16,571	$	17,009	$	54,052	$	51,702

The accompanying notes are an integral part of these financial statements.

2

Chesapeake Utilities Corporation and Subsidiaries

Condensed Consolidated Balance Sheets (Unaudited)

Assets	June 30, 2022		December 31, 2021
(in thousands, except shares and per share data)
Property, Plant and Equipment
Regulated Energy	$	1,765,915	$	1,720,287
Unregulated Energy	381,718		357,259
Other businesses and eliminations	30,713		35,418
Total property, plant and equipment	2,178,346		2,112,964
Less: Accumulated depreciation and amortization	(438,573)		(417,479)
Plus: Construction work in progress	34,027		49,393
Net property, plant and equipment	1,773,800		1,744,878
Current Assets
Cash and cash equivalents	4,186		4,976
Trade and other receivables	42,892		61,623
Less: Allowance for credit losses	(2,758)		(3,141)
Trade and other receivables, net	40,134		58,482
Accrued revenue	15,999		22,513
Propane inventory, at average cost	9,317		11,644
Other inventory, at average cost	11,449		9,345
Regulatory assets	28,729		19,794
Storage gas prepayments	3,695		3,691
Income taxes receivable	12,353		17,460
Prepaid expenses	11,398		17,121
Derivative assets, at fair value	6,772		7,076
Other current assets	1,014		1,033
Total current assets	145,046		173,135
Deferred Charges and Other Assets
Goodwill	45,158		44,708
Other intangible assets, net	14,088		13,192
Investments, at fair value	10,523		12,095
Operating lease right-of-use assets	15,767		10,139
Regulatory assets	99,497		104,173
Receivables and other deferred charges	13,463		12,549
Total deferred charges and other assets	198,496		196,856
Total Assets	$	2,117,342	$	2,114,869

The accompanying notes are an integral part of these financial statements.

3

Chesapeake Utilities Corporation and Subsidiaries

Condensed Consolidated Balance Sheets (Unaudited)

Capitalization and Liabilities	June 30, 2022		December 31, 2021
(in thousands, except shares and per share data)
Capitalization
Stockholders’ equity
Preferred stock, par value $0.01 per share (authorized 2,000,000 shares), no shares issued and outstanding	$	—	$	—
Common stock, par value $0.4867 per share (authorized 50,000,000 shares)	8,632		8,593
Additional paid-in capital	376,866		371,162
Retained earnings	428,833		393,072
Accumulated other comprehensive income	1,370		1,303
Deferred compensation obligation	7,018		7,240
Treasury stock	(7,018)		(7,240)
Total stockholders’ equity	815,701		774,130
Long-term debt, net of current maturities	585,805		549,903
Total capitalization	1,401,506		1,324,033
Current Liabilities
Current portion of long-term debt	21,472		17,962
Short-term borrowing	137,024		221,634
Accounts payable	38,110		52,628
Customer deposits and refunds	34,489		36,488
Accrued interest	3,320		2,775
Dividends payable	9,488		8,466
Accrued compensation	9,471		15,505
Regulatory liabilities	6,663		2,312
Derivative liabilities, at fair value	427		743
Other accrued liabilities	26,827		17,920
Total current liabilities	287,291		376,433
Deferred Credits and Other Liabilities
Deferred income taxes	244,978		233,550
Regulatory liabilities	143,188		142,488
Environmental liabilities	3,097		3,538
Other pension and benefit costs	21,458		24,120
Operating lease - liabilities	13,807		8,571
Deferred investment tax credits and other liabilities	2,017		2,136
Total deferred credits and other liabilities	428,545		414,403
Environmental and other commitments and contingencies (Notes 6 and 7)
Total Capitalization and Liabilities	$	2,117,342	$	2,114,869

The accompanying notes are an integral part of these financial statements.

4

Chesapeake Utilities Corporation and Subsidiaries

Condensed Consolidated Statements of Cash Flows (Unaudited)

	Six Months Ended
	June 30,
	2022		2021
(in thousands)
Operating Activities
Net income	$	53,985	$	48,279
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	34,193		30,662
Depreciation and accretion included in other costs	5,781		5,061
Deferred income taxes	11,434		12,810
Realized gain on commodity contracts and sale of assets	(6,980)		(5,342)
Unrealized loss (gain) on investments/commodity contracts	1,956		(988)
Employee benefits and compensation	(520)		(346)
Share-based compensation	3,555		3,315
Changes in assets and liabilities:
Accounts receivable and accrued revenue	24,766		23,664
Propane inventory, storage gas and other inventory	270		(1,085)
Regulatory assets/liabilities, net	(6,405)		7,711
Prepaid expenses and other current assets	10,326		2,789
Accounts payable and other accrued liabilities	(2,274)		6,563
Income taxes receivable	5,107		4,514
Customer deposits and refunds	(1,999)		681
Accrued compensation	(6,266)		(3,397)
Other assets and liabilities, net	(3,134)		(675)
Net cash provided by operating activities	123,795		134,216
Investing Activities
Property, plant and equipment expenditures	(65,087)		(104,631)
Proceeds from sale of assets	3,367		497
Acquisitions, net of cash acquired	(2,006)		—
Environmental expenditures	(441)		(395)
Net cash used in investing activities	(64,167)		(104,529)
Financing Activities
Common stock dividends	(16,575)		(15,047)
Issuance of stock under the Dividend Reinvestment Plan, net of offering fees	4,259		4,799
Tax withholding payments related to net settled stock compensation	(2,838)		(1,478)
Change in cash overdrafts due to outstanding checks	(1,202)		(1,101)
Net advances (repayments) under line of credit agreements	(83,424)		(5,249)
Proceeds from long-term debt, net of offering fees	49,890		—
Repayment of long-term debt	(10,528)		(10,099)
Net cash used in financing activities	(60,418)		(28,175)
Net Increase (Decrease) in Cash and Cash Equivalents	(790)		1,512
Cash and Cash Equivalents—Beginning of Period	4,976		3,499
Cash and Cash Equivalents—End of Period	$	4,186	$	5,011

The accompanying notes are an integral part of these financial statements.

5

Chesapeake Utilities Corporation and Subsidiaries

Condensed Consolidated Statements of Stockholders’ Equity (Unaudited)

	Common Stock (1)
(in thousands, except shares and per share data)	Number of Shares(2)	Par Value		Additional Paid-In Capital		Retained Earnings		Accumulated  Other Comprehensive Income/(Loss)		Deferred Compensation		Treasury Stock		Total
Balance at March 31, 2021	17,521,493	$	8,528	$	350,875	$	369,623	$	(2,638)	$	6,992	$	(6,992)	$	726,388
Net income	—	—		—		13,813		—		—		—		13,813
Other comprehensive income	—	—		—		—		3,196		—		—		3,196
Dividend declared ($0.480 per share)	—	—		—		(8,500)		—		—		—		(8,500)
Dividend reinvestment plan	39,605	19		4,602		—		—		—		—		4,621
Share-based compensation and tax benefit (3)(4)	6,830	3		2,043		—		—		—		—		2,046
Treasury stock activities	—	—		—		—		—		211		(211)		—
Balance at June 30, 2021	17,567,928	$	8,550	$	357,520	$	374,936	$	558	$	7,203	$	(7,203)	$	741,564
Balance at December 31, 2020	17,461,841	$	8,499	$	348,482	$	342,969	$	(2,865)	$	5,679	$	(5,679)	$	697,085
Net income	—	—		—		48,279		—		—		—		48,279
Other comprehensive income	—	—		—		—		3,423		—		—		3,423
Dividends declared ($0.920 per share)	—	—		—		(16,312)		—		—		—		(16,312)
Dividend reinvestment plan	60,116	29		6,806		—		—		—		—		6,835
Share-based compensation and tax benefit (3) (4)	45,971	22		2,232		—		—		—		—		2,254
Treasury stock activities	—	—		—		—		—		1,524		(1,524)		—
Balance at June 30, 2021	17,567,928	$	8,550	$	357,520	$	374,936	$	558	$	7,203	$	(7,203)	$	741,564
Balance at March 31, 2022	17,719,388	$	8,624	$	373,694	$	421,344	$	1,850	$	6,477	$	(6,477)	$	805,512
Net income	—	—		—		17,051		—		—		—		17,051
Other comprehensive loss	—	—		—		—		(480)		—		—		(480)
Dividend declared ($0.535 per share)	—	—		—		(9,562)		—		—		—		(9,562)
Issuance under various plans (5)	8,886	5		1,203		—		—		—		—		1,208
Share-based compensation and tax benefit (3) (4)	6,520	3		1,969		—		—		—		—		1,972
Treasury stock activities	—	—		—		—		—		541		(541)		—
Balance at June 30, 2022	17,734,794	$	8,632	$	376,866	$	428,833	$	1,370	$	7,018	$	(7,018)	$	815,701
Balance at December 31, 2021	17,655,410	$	8,593	$	371,162	$	393,072	$	1,303	$	7,240	$	(7,240)	$	774,130
Net income	—	—		—		53,985		—		—		—		53,985
Other comprehensive income	—	—		—		—		67		—		—		67
Dividends declared ($1.015 per share)	—	—		—		(18,224)		—		—		—		(18,224)
Issuance under various plans (5)	33,846	17		4,613		—		—		—		—		4,630
Share-based compensation and tax benefit (3) (4)	45,538	22		1,091		—		—		—		—		1,113
Treasury stock activities	—	—		—		—		—		(222)		222		—
Balance at June 30, 2022	17,734,794	$	8,632	$	376,866	$	428,833	$	1,370	$	7,018	$	(7,018)	$	815,701

(1)2,000,000 shares of preferred stock at $0.01 par value have been authorized. No shares have been issued or are outstanding; accordingly, no information has been included in the statements of stockholders’ equity.    

(2)Includes 110,835, 116,238, 117,193, and 105,087 shares at June 30, 2022, December 31, 2021, June 30, 2021 and December 31, 2020, respectively, held in a Rabbi Trust related to our Non-Qualified Deferred Compensation Plan.

(3)Includes amounts for shares issued for directors’ compensation.

(4)The shares issued under the SICP are net of shares withheld for employee taxes. For the six months ended June 30, 2022 and 2021, we withheld 21,832 and 14,020 shares, respectively, for employee taxes.

(5)Includes the Retirement Savings Plan, DRIP and ATM equity issuances.

The accompanying notes are an integral part of these financial statements.

6

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

1.    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, 2021. In the opinion of management, these financial statements reflect all adjustments that are necessary for a fair presentation of our results of operations, financial position and cash flows for the interim periods presented.

Where necessary to improve comparability, prior period amounts have been changed to conform to current period presentation.

Due to the seasonality of our business, results for interim periods are not necessarily indicative of results for the entire fiscal year. Revenue and earnings are typically greater during the first and fourth quarters, when consumption of energy is highest due to colder temperatures.

Effects of COVID-19

In March 2020, the CDC declared a national emergency due to the rapidly growing outbreak of COVID-19. In response to this declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the country imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to slow the spread of the illness. These restrictions significantly impacted economic conditions in the United States beginning in 2020 and to a lesser extent have continued into 2022. Chesapeake Utilities is considered an “essential business,” which allowed us to continue operational activities and construction projects while social distancing restrictions were in place. At this time, restrictions have predominantly been lifted as vaccines have become widely available in the United States. Previously existing states of emergency in all of our service territories expired during the second and third quarters of 2021 eliminating a majority of restrictions initially implemented to slow the spread of the virus. The expiration of the states of emergency along with the settlement of our limited proceeding in Florida concluded our ability to defer incremental pandemic related costs for consideration through the applicable regulatory process. We adjusted our operating practices accordingly to ensure the safety of our operations and will take the necessary actions to comply with the CDC, and the Occupational and Safety and Health Administration, as new developments occur.

Refer to Note 5, Rates and Other Regulatory Activities, for further information on the regulated assets established as a result of the incremental expenses associated with COVID-19.

Recent Accounting Standards Yet to be Adopted

Reference Rate Reform - (ASC 848) - In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting, which was subsequently amended by ASU 2021-01. The standard provides relief for companies preparing for the discontinuation of interest rates, such as LIBOR, and allows optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions affected by reference rate reform. The amendments included in this ASU are to be applied prospectively, and are not expected to have a material impact on our financial position or results of operations. Refer to Note 16, Short-Term Borrowings, for further information regarding the expected timing of implementing this update.

7

2.    Calculation of Earnings Per Share

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
(in thousands, except shares and per share data)
Calculation of Basic Earnings Per Share:
Net Income	$	17,051	$	13,813	$	53,985	$	48,279
Weighted average shares outstanding	17,730,833		17,546,346		17,704,592		17,516,273
Basic Earnings Per Share	$	0.96	$	0.79	$	3.05	$	2.76
Calculation of Diluted Earnings Per Share:
Net Income	$	17,051	$	13,813	$	53,985	$	48,279
Reconciliation of Denominator:
Weighted shares outstanding—Basic	17,730,833		17,546,346		17,704,592		17,516,273
Effect of dilutive securities—Share-based compensation	79,038		70,150		81,037		68,733
Adjusted denominator—Diluted	17,809,871		17,616,496		17,785,629		17,585,006
Diluted Earnings Per Share	$	0.96	$	0.78	$	3.04	$	2.75

3.     Acquisitions

Acquisition of Davenport Energy

On June 13, 2022, Sharp acquired the propane operating assets of Davenport Energy's Siler City propane division for approximately $2.0 million. In connection with this acquisition, we recorded a $0.1 million liability which is subject to the seller's adherence to various provisions contained in the purchase agreement through the first anniversary of the transaction closing. Included with the acquisition was less than $0.1 million of working capital from the Seller consisting predominantly of accounts receivable and propane inventory. Through this acquisition, the Company expands its operating footprint further into North Carolina, where customers will be served by Sharp Energy’s Diversified Energy division. Sharp added approximately 850 customers, along with expected distribution of approximately 0.4 million gallons of propane annually. We recorded $1.5 million in property plant and equipment, $0.5 million in goodwill, and immaterial amounts associated with customer relationships and non-compete agreements, all of which are deductible for income tax purposes. The amounts recorded in conjunction with the acquisition are preliminary, and subject to adjustment based on contractual provisions and finalization prior to the first anniversary of the transaction closing. The financial results associated with this acquisition will be included within Sharp's Diversified Energy division, primarily as a result of their geographic proximity, as well as other synergies they generate due to their service territory.

Acquisition of Diversified Energy

On December 15, 2021, Sharp acquired the propane operating assets of Diversified Energy for approximately $37.5 million, net of cash acquired. In connection with this acquisition, we recorded a $2.1 million liability which is subject to the seller's adherence to various provisions contained in the purchase agreement through the first anniversary of the transaction closing. Included with the acquisition, was approximately $1.7 million of working capital from the Seller consisting predominantly of accounts receivable and propane inventory. We accounted for this acquisition as a business combination within our Unregulated Energy Segment beginning in the fourth quarter of 2021. In January 2022, we recorded a post-closing true-up of $0.8 million related to the provision for working capital valuation at the time of closing. There were multiple strategic benefits to this acquisition including it: (i) expands our propane service territory into North Carolina and South Carolina (ii) builds upon our existing propane presence in Virginia and Pennsylvania, and (iii) includes an established customer base with opportunities for future growth. Through this acquisition, the Company added approximately 19,000 residential, commercial and agricultural customers, along with expected distribution of approximately 10.0 million gallons of propane annually. In connection with this acquisition, we recorded $23.1 million in property plant and equipment, $6.2 million in intangible assets associated with customer relationships and non-compete agreements and $5.9 million in goodwill, all of which is deductible for income tax purposes. The amounts recorded in conjunction with the acquisition are preliminary, and subject to adjustment based on contractual provisions and finalization prior to the first anniversary of the transaction closing.

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These acquisitions generated operating revenue and operating loss of $4.0 million and $0.8 million, respectively, for the three months ended June 30, 2022 . For the six months ended June 30, 2022, the acquisitions generated operating revenue and operating income of $14.3 million and $0.7 million, respectively.

4.     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 June 30, 2022 and 2021:

	Three months ended June 30, 2022								Three months ended June 30, 2021
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total		Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Energy distribution
Delaware natural gas division	$	13,086	$	—	$	—	$	13,086	$	10,068	$	—	$	—	$	10,068
Florida natural gas division	9,619		—		—		9,619		8,446		—		—		8,446
FPU electric distribution	20,305		—		—		20,305		18,898		—		—		18,898
FPU natural gas distribution	25,817		—		—		25,817		23,159		—		—		23,159
Maryland natural gas division	4,372		—		—		4,372		3,224		—		—		3,224
Sandpiper natural gas/propane operations	4,248		—		—		4,248		3,814		—		—		3,814
Elkton Gas	1,705		—		—		1,705		1,195		—		—		1,195
Total energy distribution	79,152		—		—		79,152		68,804		—		—		68,804
Energy transmission
Aspire Energy	—		10,808		—		10,808		—		5,578		—		5,578
Aspire Energy Express	369		—		—		369		47		—		—		47
Eastern Shore	18,875		—		—		18,875		18,617		—		—		18,617
Peninsula Pipeline	6,777		—		—		6,777		6,610		—		—		6,610
Total energy transmission	26,021		10,808		—		36,829		25,274		5,578		—		30,852
Energy generation
Eight Flags	—		5,916		—		5,916		—		4,173		—		4,173
Propane operations
Propane delivery operations	—		34,469		—		34,469		—		23,098		—		23,098
Compressed Natural Gas Services
Marlin Gas Services	—		2,380		—		2,380		—		1,989		—		1,989
Other and eliminations
Eliminations	(12,980)		(110)		(6,271)		(19,361)		(13,168)		(65)		(4,734)		(17,967)
Other	—		—		85		85		—		—		133		133
Total other and eliminations	(12,980)		(110)		(6,186)		(19,276)		(13,168)		(65)		(4,601)		(17,834)
Total operating revenues (1)	$	92,193	$	53,463	$	(6,186)	$	139,470	$	80,910	$	34,773	$	(4,601)	$	111,082

(1) Total operating revenues for the three months ended June 30, 2022, include other revenue (revenues from sources other than contracts with customers) of $(0.1) million for Regulated and $0.1 million Unregulated Energy segments, respectively, and $0.1 million for both our Regulated and Unregulated Energy segments, respectively, for the three months ended June 30, 2021. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the Maryland division and Sandpiper Energy and late fees.

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The following table displays our revenue by major source based on product and service type for the six months ended June 30, 2022 and 2021:

	Six Months Ended June 30, 2022								Six Months Ended June 30, 2021
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total		Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Energy distribution
Delaware natural gas division	$	47,568	$	—	$	—	$	47,568	$	43,340	$	—	$	—	$	43,340
Florida natural gas division	19,885		—		—		19,885		17,402		—		—		17,402
FPU electric distribution	39,394		—		—		39,394		37,449		—		—		37,449
FPU natural gas distribution	55,837		—		—		55,837		50,020		—		—		50,020
Maryland natural gas division	14,836		—		—		14,836		13,690		—		—		13,690
Sandpiper natural gas/propane operations	11,885		—		—		11,885		11,885		—		—		11,885
Elkton Gas	5,071		—		—		5,071		3,830		—		—		3,830
Total energy distribution	194,476		—		—		194,476		177,616		—		—		177,616
Energy transmission
Aspire Energy	—		28,844		—		28,844		—		18,484		—		18,484
Aspire Energy Express	632		—		—		632		93		—		—		93
Eastern Shore	39,196		—		—		39,196		38,589		—		—		38,589
Peninsula Pipeline	13,549		—		—		13,549		13,077		—		—		13,077
Total energy transmission	53,377		28,844		—		82,221		51,759		18,484		—		70,243
Energy generation
Eight Flags	—		11,455		—		11,455		—		8,502		—		8,502
Propane operations
Propane delivery operations	—		110,075		—		110,075		—		78,361		—		78,361
Compressed Natural Gas Services
Marlin Gas Services	—		4,589		—		4,589		—		4,340		—		4,340
Other and eliminations
Eliminations	(27,769)		(207)		(12,706)		(40,682)		(27,268)		(156)		(9,635)		(37,059)
Other	—		—		216		216		—		—		265		265
Total other and eliminations	(27,769)		(207)		(12,490)		(40,466)		(27,268)		(156)		(9,370)		(36,794)
Total operating revenues (1)	$	220,084	$	154,756	$	(12,490)	$	362,350	$	202,107	$	109,531	$	(9,370)	$	302,268

(1) Total operating revenues for the six months ended June 30, 2022, include other revenue (revenues from sources other than contracts with customers) of $0.1 million for Regulated and $0.2 million Unregulated Energy segments, respectively, and $(0.2) million and $0.2 million for our Regulated and Unregulated Energy segments, respectively, for the six months ended June 30, 2021. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the Maryland division and Sandpiper Energy and late fees.

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Contract balances

The timing of revenue recognition, customer billings and cash collections results in trade receivables, unbilled receivables (contract assets), and customer advances (contract liabilities) in our condensed consolidated balance sheets. The balances of our trade receivables, contract assets, and contract liabilities as of June 30, 2022 and December 31, 2021 were as follows:

	Trade Receivables		Contract Assets (Current)		Contract Assets (Non-current)		Contract Liabilities (Current)
(in thousands)
Balance at 12/31/2021	$	56,277	$	18	$	4,806	$	747
Balance at 6/30/2022	38,778		18		4,607		724
Decrease	$	(17,499)	$	—	$	(199)	$	(23)

Our trade receivables are included in trade and other receivables in the condensed consolidated balance sheets. Our current contract assets are included in other current assets in the condensed consolidated balance sheet. Our non-current contract assets are included in other assets in the condensed consolidated balance sheet and primarily relate to operations and maintenance costs incurred by Eight Flags that have not yet been recovered through rates for the sale of electricity to our electric distribution operation pursuant to a long-term service agreement.

At times, we receive advances or deposits from our customers before we satisfy our performance obligation, resulting in contract liabilities. Contract liabilities are included in other accrued liabilities in the condensed consolidated balance sheets and relate to non-refundable prepaid fixed fees for our Mid-Atlantic propane delivery operation's retail offerings. Our performance obligation is satisfied over the term of the respective customer retail program on a ratable basis. For the three months ended June 30, 2022 and 2021, we recognized revenue of $0.3 million and $0.2 million. For the six months ended June 30, 2022 and 2021, we recognized revenue of $0.7 million and $0.6 million.

Remaining performance obligations

Our businesses have long-term fixed fee contracts with customers in which revenues are recognized when performance obligations are satisfied over the contract term. Revenue for these businesses for the remaining performance obligations, at June 30, 2022, are expected to be recognized as follows:

(in thousands)	2022		2023		2024		2025		2026		2027		2028 and thereafter
Eastern Shore and Peninsula Pipeline	$	24,379	$	45,426	$	40,431	$	33,804	$	29,294	$	25,096	$	179,259
Natural gas distribution operations	3,433		6,238		6,050		5,698		5,515		5,100		33,113
FPU electric distribution	326		652		652		275		275		275		275
Total revenue contracts with remaining performance obligations	$	28,138	$	52,316	$	47,133	$	39,777	$	35,084	$	30,471	$	212,647

5.     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 and Aspire Energy Express, our intrastate pipeline subsidiaries, are subject to regulation (excluding cost of service) by the Florida PSC and Public Utilities Commission of Ohio, respectively.

Delaware

See the discussion below under COVID-19 impact.

Maryland

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Ocean City Maryland Reinforcement: In March 2022, we filed a Section 7(f) - Request for Service Area Determination with the FERC regarding plans to extend our natural gas facilities across the Delaware/Maryland state line from Sussex County, Delaware, to Worcester County, Maryland, to provide a secondary feed to Sandpiper Energy. The project will increase the reliability of the existing distribution system in those areas while also expanding infrastructure to serve new customers. Construction began in the second quarter of 2022, with estimated completion in the fourth quarter of 2022.

Strategic Infrastructure Development and Enhancement (“STRIDE”) Plan: In March 2021, Elkton Gas filed a STRIDE plan with the Maryland PSC. The STRIDE plan accelerates Elkton Gas' Aldyl-A pipeline replacement program as costs of the plan are recovered through a fixed charge rider which is effective for five years. Under Elkton Gas’ STRIDE plan, the Aldyl-A pipelines will be fully replaced by the end of 2023. In July 2021, Elkton Gas reached a settlement with the Maryland PSC Staff and the Maryland Office of Public Counsel that approved Elkton Gas’ STRIDE plan. The STRIDE plan allows for recovery of the associated revenue requirement through a monthly surcharge, which was implemented effective September 2021. We filed the annual STRIDE plan update with the Maryland PSC on November 1, 2021, which was approved for new rates effective January 1, 2022.

Florida

Natural Gas Rate Case: In May 2022, our natural gas distribution businesses in Florida, FPU, FPU-Indiantown division, FPU-Fort Meade division and Chesapeake Utilities CFG division (collectively, “Florida natural gas distribution businesses”) filed a consolidated natural gas rate case with the Florida PSC. In connection with the application, we are seeking approval of the following: (i) interim rate relief of approximately $7.2 million, subject to refund, pending the outcome of the rate case proceeding; (ii) permanent rate relief of approximately $24.1 million, effective January 1, 2023, (iii) a depreciation study also submitted with filing; (iv) authorization to make certain changes to tariffs to include the consolidation of rates and rate structure across the businesses and to unify the Florida natural gas distribution businesses under FPU; (v) authorization to retain the acquisition adjustment recorded at the time of the FPU merger in our revenue requirement; and (vi) authorization to establish an environmental remediation surcharge for the purposes of addressing future expected remediation costs for FPU MGP sites. In August 2022, interim rates were approved by the Florida PSC in the amount of approximately $7.7 million on an annualized basis, effective for all meter reading in September 2022. The interim rates are subject to refund pending the final outcome of the rate case proceeding. The discovery process has commenced and hearing for the proceeding has been scheduled for October 2022. The outcome of the application is subject to review and approval by the Florida PSC.

Winter Haven Expansion Project: In May 2021, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with CFG for an incremental 6,800 Dts/d of firm service in the Winter Haven, Florida area. As part of this agreement, Peninsula Pipeline will construct a new interconnect with FGT and a new regulator station for CFG. CFG will use the additional firm service to support new incremental load due to growth, including providing service to a new can manufacturing facility, as well as provide reliability and operational benefits to CFG’s existing distribution system in the area. In connection with Peninsula Pipeline’s new regulator station, CFG is also extending its distribution system to connect to the new station. The Transportation Service Agreement was approved by the Florida PSC in September 2021. Construction commenced in February 2021 and the expected in-service date is the third quarter of 2022.

Beachside Pipeline Extension: In June 2021, Peninsula Pipeline and Florida City Gas entered into a Transportation Service Agreement for an incremental 10,176 Dts/d of firm service in Indian River County, Florida, to support Florida City Gas’ growth along the Indian River's barrier island. As part of this agreement, Peninsula Pipeline will construct 11.3 miles of pipeline from its existing pipeline in the Sebastian, Florida area, which will travel east under the Intercoastal Waterway ("ICW") and southward on the barrier island. As required by Peninsula Pipeline’s tariff and Florida Statutes, Peninsula Pipeline filed the required company and customer affidavits with the Florida PSC in June 2021. Construction commenced in June 2021 and the expected in-service date is first quarter of 2023.

St.Cloud / Twin Lakes Expansion: In July 2022, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with our Florida natural gas division, FPU, for an additional 2,400 Dt/d of firm service in the St. Cloud, Florida area. As part of this agreement, Peninsula Pipeline will construct a pipeline extension and regulator station for FPU. The extension will be used to support new incremental load due to growth in the area, including providing service, most immediately, to the residential development Twin Lakes. The expansion will also improve reliability and operation benefits to FPU's existing distribution system in the area, supporting future growth in the area. We expect this expansion to be in service by the first quarter of 2023.

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Eastern Shore

Southern Expansion Project: In January 2022, Eastern Shore submitted a prior notice filing with the FERC pursuant to blanket certificate procedures, regarding its proposal to install an additional compressor unit and related facilities at Eastern Shore's existing compressor station in Bridgeville, Sussex County, Delaware. The project will enable Eastern Shore to provide additional firm natural gas transportation service to an existing shipper on Eastern Shore's pipeline system, with a projected in-service date in the fourth quarter of 2023. We are currently awaiting an order from the FERC on the Company's filing.

Capital Cost Surcharge: In June 2021, Eastern Shore submitted a filing with the FERC regarding a capital cost surcharge to recover capital costs associated with two mandated highway relocate projects that required the replacement of existing Eastern Shore facilities. The capital cost surcharge was an approved item in Eastern Shore’s last rate case. In conjunction with the filing of this surcharge, pursuant to the settlement agreement, a cumulative adjustment to the existing surcharge to reflect additional depreciation was included in this filing. The FERC issued an order approving the surcharge as filed on July 7, 2021. The combined revised surcharge became effective July 15, 2021.

COVID-19 Impact

In March 2020, the CDC declared a national emergency due to the rapidly growing outbreak of COVID-19. In response to this declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the country imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to slow the spread of the illness. These restrictions significantly impacted economic conditions in the United States in 2020 and continued to impact economic conditions, to a lesser extent, through 2021. Chesapeake Utilities is considered an “essential business,” which allowed us to continue operational activities and construction projects with appropriate safety precautions and personal protective equipment, while being mindful of the social distancing restrictions that were in place.

In response to the COVID-19 pandemic and related restrictions, we experienced reduced consumption of energy largely in the commercial and industrial sectors, higher bad debt expenses and incremental expenses associated with COVID-19, including expenditures associated with personal protective equipment and premium pay for field personnel. The additional operating expenses we incurred supported the ongoing delivery of our essential services during these unprecedented times. In April and May 2020, we were authorized by the Maryland and Delaware PSCs, respectively, to record regulatory assets for COVID-19 related costs which offers us the ability to seek recovery of those costs. In July 2021, the Florida PSC issued an order that approved incremental expenses we incurred due to COVID-19. The order allowed us to establish a regulatory asset in a total amount of $2.1 million as of June 30, 2021 for natural gas and electric distribution operations. The regulatory asset is amortized over two years and is recovered through the Purchased Gas Adjustment and Swing Service mechanisms for our natural gas distribution businesses and through the Fuel Purchased Power Cost Recovery clause for our electric division. As of June 30, 2022 and December 31, 2021, our total COVID-19 regulatory asset balance was $1.8 million and $2.3 million, respectively.

In 2021 and 2022, restrictions were gradually lifted as vaccines became widely available in the United States. The various state of emergencies associated with the COVID-19 pandemic that were previously declared in our service territories have been terminated and we have adjusted our operating practices accordingly to ensure the safety of our operations and will take the necessary actions to comply with the CDC, and the Occupational Safety and Health Administration, as new developments occur.

Storm Protection Plan

In 2020, the Florida PSC implemented the Storm Protection Plan ("SPP") and Storm Protection Plan Cost Recovery ("SPPCR") rules, which require electric utilities to petition the Florida PSC for approval of a Transmission and Distribution Storm Protection Plan that covers the utility’s immediate 10-year planning period with updates to the plan at least every 3 years. The SPPCR rules allow the utility to file for recovery of associated costs related to its SPP. The Company’s SPP plan was filed in April 2022, with hearings scheduled for early August 2022. The SPP cost recovery clause ("SPPCRC") was filed in May 2022 with requested rates effective January 1, 2023. The SPPCRC hearing is scheduled for November 2022.

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    Summary TCJA Table

Customer rates for our regulated businesses were adjusted as approved by the regulators, prior to 2020 with the exception of Elkton Gas, which implemented a one-time bill credit in May 2020. The following table summarizes the regulatory liabilities related to accumulated deferred taxes ("ADIT") associated with TCJA for our regulated businesses as of June 30, 2022 and December 31, 2021:

	Amount (in thousands)
Operation and Regulatory Jurisdiction	June 30, 2022	December 31, 2021	Status
Eastern Shore (FERC)	$34,190	$34,190	Will be addressed in Eastern Shore's next rate case filing.
Delaware natural gas division (Delaware PSC)	$12,510	$12,591	PSC approved amortization of ADIT in January 2019.
Maryland natural gas division (Maryland PSC)	$3,772	$3,840	PSC approved amortization of ADIT in May 2018.
Sandpiper Energy (Maryland PSC)	$3,626	$3,656	PSC approved amortization of ADIT in May 2018.
Chesapeake Florida natural gas division/CFG (Florida PSC)	$7,939	$8,032	PSC issued order authorizing amortization and retention of net ADIT liability by the Company in February 2019.
FPU natural gas (excludes Fort Meade and Indiantown) (Florida PSC)	$19,058	$19,189	Same treatment on a net basis as Chesapeake Florida Gas Division (above).
FPU Fort Meade and Indiantown natural gas divisions (Florida PSC)	$265	$271	Same treatment on a net basis as Chesapeake Florida Gas Division (above).
FPU electric division (Florida PSC)	$5,115	$5,237	In January 2019, PSC issued order approving amortization of ADIT through purchased power cost recovery, storm reserve and rates.
Elkton Gas (Maryland PSC)	$1,074	$1,091	PSC approved amortization of ADIT in March 2018.

6. Environmental Commitments and Contingencies

We are subject to federal, state and local laws and regulations governing environmental quality and pollution control. These laws and regulations require us to remove or remediate, at current and former operating sites, the effect on the environment of the disposal or release of specified substances.

MGP Sites

We have participated in the investigation, assessment or remediation of, and have exposures at, seven former MGP sites. We have received approval for recovery of clean-up costs in rates for sites located in Salisbury, Maryland; Seaford, Delaware; and Winter Haven, Key West, Pensacola, Sanford and West Palm Beach, Florida.

As of June 30, 2022 and December 31, 2021, we had approximately $4.8 million and $5.2 million, respectively, in environmental liabilities related to the former MGP sites. As of June 30, 2022 and December 31, 2021, we have cumulative regulatory assets of $1.0 million and $1.3 million, respectively, for future recovery of environmental costs for customers. Specific to FPU’s four MGP sites in Key West, Pensacola, Sanford and West Palm Beach, FPU has approval to recover, from insurance and through customer rates, up to $14.0 million of its environmental costs related to its MGP sites. As of June 30, 2022 and December 31, 2021, we had recovered approximately $13.1 million and $12.9 million, respectively, leaving approximately $0.9 million and $1.1 million, respectively, in regulatory assets for future recovery of environmental costs from FPU’s customers.

Environmental liabilities for our MGP sites are recorded on an undiscounted basis based on the estimate of future costs provided by independent consultants. We continue to expect that all costs related to environmental remediation and related activities, including any potential future remediation costs for which we do not currently have approval for regulatory recovery, will be recoverable from customers through rates.

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Remediation is ongoing for the MGPs in Winter Haven and Key West in Florida and in Seaford, Delaware and the remaining clean-up costs are estimated to be between $0.3 million to $0.9 million for these three sites. The Environmental Protection Agency has approved a "site-wide ready for anticipated use" status for the Sanford, Florida MGP site, which is the final step before delisting a site. The remaining remediation expenses for the Sanford MGP site are immaterial.

The remedial actions approved by the Florida Department of Environmental Protection have been implemented on the east parcel of our West Palm Beach Florida site. Similar remedial actions have been initiated on the site's west parcel, and construction of active remedial systems are expected to be completed in 2022. We expect the costs to clean-up the site to be between $3.3 million to $14.2 million, including costs associated with relocation of FPU's operations at this site, and any potential costs associated with future redevelopment of the properties.

7.     Other Commitments and Contingencies

Natural Gas, Electric and Propane Supply

In March 2020, our Delmarva Peninsula natural gas distribution operations entered into asset management agreements with a third party to manage their natural gas transportation and storage capacity. The agreements were effective as of April 1, 2020 and expire in March 2023.

FPU natural gas distribution operations and Eight Flags have separate asset management agreements with Emera Energy Services, Inc. to manage their natural gas transportation capacity. These agreements are for a 10-year term that commenced in November 2020 and expire in October 2030.

Chesapeake Utilities' natural gas division, CFG has firm transportation service contracts with FGT and Gulfstream. Pursuant to a capacity release program approved by the Florida PSC, all of the capacity under these agreements has been released to various third parties. Under the terms of these capacity release agreements, Chesapeake Utilities is contingently liable to FGT and Gulfstream should any party, that acquired the capacity through release, fail to pay the capacity charge. To date, Chesapeake Utilities has not been required to make a payment resulting from this contingency.

FPU’s electric supply contracts require FPU to maintain an acceptable standard of creditworthiness based on specific financial ratios. FPU’s agreement with Florida Power & Light Company requires FPU to meet or exceed a debt service coverage ratio of 1.25 times based on the results of the prior 12 months. If FPU fails to meet this ratio, it must provide an irrevocable letter of credit or pay all amounts outstanding under the agreement within five business days. FPU’s electric supply agreement with Gulf Power requires FPU to meet the following ratios based on the average of the prior six quarters: (a) funds from operations interest coverage ratio (minimum of two times), and (b) total debt to total capital (maximum of 65 percent). If FPU fails to meet the requirements, it has to provide the supplier a written explanation of actions taken, or proposed to be taken, to become compliant. Failure to comply with the ratios specified in the Gulf Power agreement could also result in FPU having to provide an irrevocable letter of credit. As of June 30, 2022, FPU was in compliance with all of the requirements of its fuel supply contracts.

Eight Flags provides electricity and steam generation services through its CHP plant located on Amelia Island, Florida. In June 2016, Eight Flags began selling power generated from the CHP plant to FPU pursuant to a 20-year power purchase agreement for distribution to our electric customers. In July 2016, Eight Flags also started selling steam, pursuant to a separate 20-year contract, to the landowner on which the CHP plant is located. The CHP plant is powered by natural gas transported by FPU through its distribution system and Peninsula Pipeline through its intrastate pipeline.

Corporate Guarantees

The Board of Directors has authorized us to issue corporate guarantees securing obligations of our subsidiaries and to obtain letters of credit securing our subsidiaries' obligations. The maximum authorized liability under such guarantees and letters of credit as of June 30, 2022 was $20.0 million. The aggregate amount guaranteed related to our subsidiaries at June 30, 2022 was approximately $11.4 million with the guarantees expiring on various dates through May 22, 2023. In addition, the Board has authorized us to issue specific purpose corporate guarantees. The amount of specific purpose guarantees outstanding at June 30, 2022 was $2.0 million. In July 2022, in connection with the Florida rate case, we entered into a guarantee in the amount of $7.1 million with the Florida PSC.

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As of June 30, 2022, we have issued letters of credit totaling approximately $5.3 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 capacity agreement between NEXUS and Aspire, and our current and previous primary insurance carriers. These letters of credit have various expiration dates through October 25, 2022. There have been no draws on these letters of credit as of June 30, 2022. 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.

8.    Segment Information

We use the management approach to identify operating segments. We organize our business around differences in regulatory environment and the operating results of each segment are regularly reviewed by the chief operating decision maker, our Chief Executive Officer, in order to make decisions about resources and to assess performance.

Our operations are entirely domestic and are comprised of two reportable segments:

•Regulated Energy. Includes energy distribution and transmission services (natural gas distribution, natural gas transmission and electric distribution operations). All operations in this segment are regulated, as to their rates and services, by the PSC having jurisdiction in each operating territory or by the FERC in the case of Eastern Shore.

•Unregulated Energy. Includes energy transmission, energy generation (the operations of our Eight Flags' CHP plant), propane operations, and mobile compressed natural gas distribution and pipeline solutions subsidiary. Also included in this segment are other unregulated energy services, such as energy-related merchandise sales and heating, ventilation and air conditioning, plumbing and electrical services. These operations are unregulated as to their rates and services.

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:

16

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
(in thousands)
Operating Revenues, Unaffiliated Customers
Regulated Energy	$	91,830	$	80,374	$	215,888	$	201,095
Unregulated Energy	47,640		30,708		146,462		101,173
Total operating revenues, unaffiliated customers	$	139,470	$	111,082	$	362,350	$	302,268
Intersegment Revenues (1)
Regulated Energy	$	363	$	536	$	4,196	$	1,012
Unregulated Energy	5,823		4,065		7,819		8,358
Other businesses	85		133		691		265
Total intersegment revenues	$	6,271	$	4,734	$	12,706	$	9,635
Operating Income
Regulated Energy	$	25,841	$	22,760	$	60,539	$	55,466
Unregulated Energy	560		(465)		20,613		18,575
Other businesses and eliminations	68		283		182		134
Operating income	26,469		22,578		81,334		74,175
Other income, net	2,584		1,453		3,498		1,828
Interest charges	5,825		5,054		11,164		10,159
Income before Income Taxes	23,228		18,977		73,668		65,844
Income Taxes	6,177		5,164		19,683		17,565
Net Income	$	17,051	$	13,813	$	53,985	$	48,279

    

(1) All significant intersegment revenues are billed at market rates and have been eliminated from consolidated operating revenues.

(in thousands)	June 30, 2022		December 31, 2021
Identifiable Assets
Regulated Energy segment	$	1,637,003	$	1,629,191
Unregulated Energy segment	447,209		439,114
Other businesses and eliminations	33,130		46,564
Total identifiable assets	$	2,117,342	$	2,114,869

17

9.    Stockholders' Equity

Common Stock Issuances

In June 2020, we filed a shelf registration statement with the SEC to facilitate the issuance of our common stock from time to time. In August 2020, we filed a prospectus supplement under the shelf registration statement for an ATM equity program under which we may issue and sell shares of our common stock up to an aggregate offering price of $75.0 million.

We maintain an effective shelf registration statement with the SEC for the issuance of shares under our DRIP. Depending on our capital needs and subject to market conditions, in addition to other possible debt and equity offerings, we may issue additional shares under the direct stock purchase component of the DRIP. In 2021, we issued just over 0.1 million shares at an average price per share of $125.71 and received net proceeds of $15.2 million under the DRIP. In the first six months of 2022, we issued less than 0.1 million shares at an average price per share of $137.24 and received net proceeds of $4.3 million under the DRIP.

We used the net proceeds from our share issuances, after fees, for general corporate purposes, including, but not limited to, financing of capital expenditures, repayment of short-term debt, financing acquisitions, investing in subsidiaries, and general working capital purposes.

Accumulated Other Comprehensive Gain (Loss)

Defined benefit pension and postretirement plan items, unrealized gains (losses) of our propane swap agreements designated as commodity contracts cash flow hedges, and the unrealized gains (losses) of our interest rate swap agreements designated as cash flow hedges are the components of our accumulated other comprehensive income (loss). The following tables present the changes in the balance of accumulated other comprehensive gain (loss) as of June 30, 2022 and 2021. All amounts in the following tables are presented net of tax.

	Defined Benefit		Commodity		Interest Rate
	Pension and		Contracts		Swap
	Postretirement		Cash Flow		Cash Flow
	Plan Items		Hedges		Hedges (1)		Total
(in thousands)
As of December 31, 2021	$	(3,268)	$	4,571	$	—	$	1,303
Other comprehensive income before reclassifications	—		2,206		—		2,206
Amounts reclassified from accumulated other comprehensive income/(loss)	35		(2,174)		—		(2,139)
Net current-period other comprehensive income	35		32		—		67
As of June 30, 2022	$	(3,233)	$	4,603	$	—	$	1,370

(in thousands)
As of December 31, 2020	$	(5,146)	$	2,309	$	(28)	$	(2,865)
Other comprehensive income before reclassifications	—		5,825		23		5,848
Amounts reclassified from accumulated other comprehensive income/(loss)	128		(2,534)		(19)		(2,425)
Net prior-period other comprehensive income	128		3,291		4		3,423
As of June 30, 2021	$	(5,018)	$	5,600	$	(24)	$	558

(1) All of our interest rate swaps expired at December 31, 2021

The following table presents amounts reclassified out of accumulated other comprehensive income (loss) for the three and six months ended June 30, 2022 and 2021. Deferred gains or losses for our commodity contracts and interest rate swap cash flow hedges are recognized in earnings upon settlement.

18

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
(in thousands)
Amortization of defined benefit pension and postretirement plan items:
Prior service credit (1)	$	19	$	19	$	38	$	38
Net loss(1)	(43)		(106)		(86)		(209)
Total before income taxes	(24)		(87)		(48)		(171)
Income tax benefit	6		23		13		43
Net of tax	$	(18)	$	(64)	$	(35)	$	(128)
Gains on commodity contracts cash flow hedges:
Propane swap agreements (2)	$	283	$	455	$	3,004	$	3,502
Income tax expense	(78)		(126)		(830)		(968)
Net of tax	$	205	$	329	$	2,174	$	2,534
Gains on interest rate swap cash flow hedges:
Interest rate swap agreements	$	—	$	22	$	—	$	26
Income tax expense	—		(6)		—		(7)
Net of tax	$	—	$	16	$	—	$	19
Total reclassifications for the period	$	187	$	281	$	2,139	$	2,425

(1) These amounts are included in the computation of net periodic costs (benefits). See Note 10, Employee Benefit Plans, for additional details.

(2) These amounts are included in the effects of gains and losses from derivative instruments. See Note 13, Derivative Instruments, for additional details.

Amortization of defined benefit pension and postretirement plan items are included in other expense, net gains and losses on propane swap agreements contracts are included in revenue and unregulated propane and natural gas, the realized gain or loss on interest rate swap agreements is recognized as a component of interest charges in the accompanying condensed consolidated statements of income. The income tax benefit is included in income tax expense in the accompanying condensed consolidated statements of income.

10.    Employee Benefit Plans

Net periodic benefit costs for our pension and post-retirement benefits plans for the three and six months ended June 30, 2022 and 2021 are set forth in the following tables:

	Chesapeake Pension Plan				FPU Pension Plan				Chesapeake SERP				Chesapeake Postretirement Plan				FPU Medical Plan
For the Three Months Ended June 30,	2022		2021		2022		2021		2022		2021		2022		2021		2022		2021
(in thousands)
Interest cost	$	—	$	34	$	449	$	429	$	13	$	12	$	6	$	6	$	6	$	6
Expected return on plan assets	—		(40)		(857)		(830)		—		—		—		—		—		—
Amortization of prior service credit	—		—		—		—		—		—		(19)		(19)		—		—
Amortization of net (gain) loss	—		60		124		155		7		7		12		10		—		(2)
Total periodic cost (benefit)	$	—	$	54	$	(284)	$	(246)	$	20	$	19	$	(1)	$	(3)	$	6	$	4

19

	Chesapeake Pension Plan				FPU Pension Plan				Chesapeake SERP				Chesapeake Postretirement Plan				FPU Medical Plan
For the Six Months Ended June 30,	2022		2021		2022		2021		2022		2021		2022		2021		2022		2021
(in thousands)
Interest cost	$	—	$	68	$	898	$	858	$	26	$	24	$	12	$	12	$	12	$	12
Expected return on plan assets	—		(80)		(1,714)		(1,660)		—		—		—		—		—		—
Amortization of prior service credit	—		—		—		—		—		—		(38)		(38)		—		—
Amortization of net (gain) loss	—		120		248		310		14		14		24		18		—		(4)
Total periodic cost (benefit)	$	—	$	108	$	(568)	$	(492)	$	40	$	38	$	(2)	$	(8)	$	12	$	8

In 2019, we began executing a de-risking strategy for the Chesapeake Pension Plan. In line with this strategy, we fully terminated the Chesapeake Pension Plan during the fourth quarter of 2021, and as of December 31, 2021, there were no remaining assets in the Chesapeake Pension Plan. Accordingly, a portion of the pension settlement expense associated with the termination was allocated to our Regulated Energy operations and was recorded as regulatory assets, previously approved in all of the impacted jurisdictions. The remaining portion of the pension settlement expense totaling $0.6 million was recorded in other expense in our consolidated statement of income in the fourth quarter 2021 which reflected the amount allocated to our Unregulated Energy operations or was deemed not recoverable through the regulatory process.

The components of our net periodic costs have been recorded or reclassified to other expense, net in the condensed consolidated statements of income. Pursuant to their respective regulatory orders, FPU and Chesapeake Utilities continue to record, as a regulatory asset, a portion of their unrecognized postretirement benefit costs related to their regulated operations. 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 income.

The following tables present the amounts included in the regulatory asset and accumulated other comprehensive income that were recognized as components of net periodic benefit cost during the three and six months ended June 30, 2022 and 2021: 

For the Three Months Ended June 30, 2022	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan		FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(19)	$	—	$	(19)
Net loss	—		124		7		12		—		143
Total recognized in net periodic benefit cost	—		124		7		(7)		—		124
Recognized from accumulated other comprehensive (income)/loss (1)	—		24		7		(7)		—		24
Recognized from regulatory asset	—		100		—		—		—		100
Total	$	—	$	124	$	7	$	(7)	$	—	$	124

20

For the Three Months Ended June 30, 2021	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan		FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(19)	$	—	$	(19)
Net loss	60		155		7		10		(2)		230
Total recognized in net periodic benefit cost	60		155		7		(9)		(2)		211
Recognized from accumulated other comprehensive (income)/loss (1)	60		29		7		(9)		—		87
Recognized from regulatory asset	—		126		—		—		(2)		124
Total	$	60	$	155	$	7	$	(9)	$	(2)	$	211

.

For the Six months ended June 30, 2022	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan		FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(38)	$	—	$	(38)
Net loss	—		248		14		24		—		286
Total recognized in net periodic benefit cost	—		248		14		(14)		—		248
Recognized from accumulated other comprehensive (income)/loss (1)	—		48		14		(14)		—		48
Recognized from regulatory asset	—		200		—		—		—		200
Total	$	—	$	248	$	14	$	(14)	$	—	$	248

For the Six months ended June 30, 2021	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan		FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(38)	$	—	$	(38)
Net loss	120		310		14		18		(4)		458
Total recognized in net periodic benefit cost	120		310		14		(20)		(4)		420
Recognized from accumulated other comprehensive (income)/loss (1)	120		58		14		(20)		(1)		171
Recognized from regulatory asset	—		252		—		—		(3)		249
Total	$	120	$	310	$	14	$	(20)	$	(4)	$	420

(1) See Note 9, Stockholders' Equity.

During the three and six months ended June 30, 2022, we contributed $0.1 million to the FPU Pension Plan. We expect to contribute approximately $0.3 million to the FPU Pension Plan during 2022, 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 and six months ended June 30, 2022 were less than $0.1 million in both periods. We expect to pay total cash benefits of approximately $0.2 million under the Chesapeake SERP in 2022. Cash benefits paid under the Chesapeake Postretirement Plan, primarily for medical claims for both the three and six months ended June 30, 2022 were $0.1 million. We estimate that approximately $0.1 million will be paid for such benefits under the Chesapeake Postretirement Plan in 2022. Cash benefits paid under the FPU Medical Plan, primarily for medical claims for the three and six months ended June 30, 2022, were immaterial. We estimate that approximately $0.1 million will be paid for such benefits under the FPU Medical Plan in 2022.

21

11.    Investments

The investment balances at June 30, 2022 and December 31, 2021, consisted of the following:

(in thousands)	June 30, 2022		December 31, 2021
Rabbi trust (associated with the Non-Qualified Deferred Compensation Plan)	$	10,499	$	12,069
Investments in equity securities	24		26
Total	$	10,523	$	12,095

We classify these investments as trading securities and report them at their fair value. For the three months ended June 30, 2022 and 2021, we recorded a net unrealized loss of $1.4 million and a net unrealized gain of $0.6 million, respectively, in other income, net in the condensed consolidated statements of income related to these investments. For the six months ended June 30, 2022 and 2021, we recorded a net unrealized loss of approximately $2.0 million and a net unrealized gain of approximately $1.0 million, respectively, in other expense, net in the condensed consolidated statements of income related to these investments. For the investment in the Rabbi Trust, we also have recorded an associated liability, which is included in other pension and benefit costs in the consolidated balance sheets and is adjusted each period for the gains and losses incurred by the investments in the Rabbi Trust.

12.    Share-Based Compensation

Our non-employee directors and key employees are granted share-based awards through our SICP. We record these share-based awards as compensation costs over the respective service period for which services are received in exchange for an award of equity or equity-based compensation. The compensation cost is based primarily on the fair value of the shares awarded, using the estimated fair value of each share on the date it was granted and the number of shares to be issued at the end of the service period.

The table below presents the amounts included in net income related to share-based compensation expense for the three and six months ended June 30, 2022 and 2021:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
(in thousands)
Awards to non-employee directors	$	220	$	192	$	454	$	380
Awards to key employees	1,122		1,247		3,101		2,935
Total compensation expense	1,342		1,439		3,555		3,315
Less: tax benefit	(346)		(384)		(917)		(885)
Share-based compensation amounts included in net income	$	996	$	1,055	$	2,638	$	2,430

Non-employee Directors

Shares granted to non-employee directors are issued in advance of the directors’ service periods and are fully vested as of the grant date. We record a deferred expense equal to the fair value of the shares issued and amortize the expense equally over a service period of one year. In May 2022, after the most recent election of directors, each of our non-employee directors received an annual retainer of 652 shares of common stock under the SICP for service as a director through the 2023 Annual Meeting of Stockholders; accordingly, 6,520 shares, with a weighted average fair value of $130.36 per share, were issued and vested in 2022.

At June 30, 2022, there was approximately $0.7 million of unrecognized compensation expense related to shares granted to non-employee directors. This expense will be recognized over the remaining service period ending in May of 2023.

22

In July, 2022, we announced the appointment of two new non-employee directors to our current Board. These newly appointed directors will be granted share-based awards through the SICP that will be pro-rated in accordance with the beginning of their service period. The associated expense will be recognized in the same manner utilized for our current non-employee directors.

Key Employees

The table below presents the summary of the stock activity for awards to key employees for the six months ended June 30, 2022: 

	Number of Shares	Weighted Average Fair Value
Outstanding—December 31, 2021	197,398	$	94.15
Granted	66,942	$	119.77
Vested	(60,850)	$	90.60
Expired	557	$	91.42
Outstanding—June 30, 2022	204,047	$	102.91

During the six months ended June 30, 2022, we granted awards of 66,942 shares of common stock to key employees under the SICP, including awards granted in February 2022 and to key employees appointed in officer positions. The shares granted are multi-year awards that will vest no later than the three-year service period ending December 31, 2024. All of these stock awards are earned based upon the successful achievement of long-term financial results, which are comprised of market-based and performance-based conditions or targets. The fair value of each performance-based condition or target is equal to the market price of our common stock on the grant date of each award. For the market-based conditions, we used the Monte Carlo valuation to estimate the fair value of each market-based award granted.

In March 2022, upon the election by 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 vested and were paid in February 2022 for the performance period ended December 31, 2021, paid the balance of such awarded shares to each such executive officer net cash remitted to the appropriate taxing authorities. We withheld 21,832 shares, based on the value of the shares on their award date. Total combined payments for the employees’ tax obligations to the taxing authorities were approximately $2.8 million.

At June 30, 2022, the aggregate intrinsic value of the SICP awards granted to key employees was approximately $26.4 million. At June 30, 2022, there was approximately $8.8 million of unrecognized compensation cost related to these awards, which will be recognized through 2024.

Stock Options

There were no stock options outstanding or issued during the six months ended June 30, 2022 and 2021.

13.    Derivative Instruments

We use derivative and non-derivative contracts to manage risks related to obtaining adequate supplies and the price fluctuations of natural gas, electricity and propane and to mitigate interest rate risk. Our natural gas, electric and propane distribution operations have entered into agreements with suppliers to purchase natural gas, electricity and propane for resale to our customers. Our natural gas gathering and transmission company has entered into contracts with producers to secure natural gas to meet its obligations. Purchases under these contracts typically either do not meet the definition of derivatives or are considered “normal purchases and normal sales” and are accounted for on an accrual basis. Our propane distribution operations may also enter into fair value hedges of their inventory or cash flow hedges of their future purchase commitments in order to mitigate the impact of wholesale price fluctuations. Occasionally, we may enter into interest rate swap agreements to mitigate risk associated with changes in short-term borrowing rates. As of June 30, 2022, our natural gas and electric distribution operations did not have any outstanding derivative contracts.

23

Volume of Derivative Activity

As of June 30, 2022, the volume of our commodity derivative contracts were as follows:

Business unit	Commodity	Contract Type	Quantity hedged (in millions)	Designation	Longest Expiration date of hedge
Sharp	Propane (gallons)	Purchases	16.0	Cash flows hedges	June 2024
Sharp	Propane (gallons)	Sales	3.8	Cash flows hedges	March 2023

Sharp entered into futures and swap agreements to mitigate the risk of fluctuations in wholesale propane index prices associated with the propane volumes that are expected to be purchased and/or sold during the heating season. Under the futures and swap agreements, Sharp will receive the difference between (i) the index prices (Mont Belvieu prices in June 2022 through June 2024) 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 contract prices, Sharp will pay the difference. We designated and accounted for the propane swaps as cash flows hedges. The change in the fair value of the swap agreements is recorded as unrealized gain (loss) in other comprehensive income (loss) and later recognized in the statement of income in the same period and in the same line item as the hedged transaction. We expect to reclassify approximately $3.8 million from accumulated other comprehensive income to earnings during the next 12-month period ended June 30, 2023.

Interest Rate Swap Activities

We manage interest rate risk by entering into derivative contracts to hedge the variability in cash flows attributable to changes in the short-term borrowing rates. In the fourth quarter of 2020, we entered into two $30.0 million interest rate swaps with a total notional amount of $60.0 million through September and December 2021 with pricing of 0.205 and 0.20 percent, respectively, for the period associated with our outstanding borrowing under the Revolver. In February 2021, we entered into an additional interest rate swap with a notional amount of $40.0 million through December 2021 with pricing of 0.17 percent. Our short-term borrowing is based on the 30-day LIBOR rate. The interest swaps were cash settled monthly as the counter-party pays us the 30-day LIBOR rate less the fixed rate. At December 31, 2021 all of our interest rate swaps had expired and we have not entered into any new derivative contracts associated with our outstanding short-term borrowings in 2022.

We designated and accounted for interest rate swaps as cash flows hedges. Accordingly, unrealized gains and losses associated with the interest rate swaps were recorded as a component of accumulated other comprehensive income (loss). When the interest rate swaps settled, the realized gain or loss was recorded in the income statement and recognized as a component of interest charges.

Broker Margin

Futures exchanges have contract specific margin requirements that require the posting of cash or cash equivalents relating to traded contracts. Margin requirements consist of initial margin that is posted upon the initiation of a position, maintenance margin that is usually expressed as a percent of initial margin, and variation margin that fluctuates based on the daily mark-to-market relative to maintenance margin requirements. We currently maintain a broker margin account for Sharp as follows:

(in thousands)	Balance Sheet Location	June 30, 2022		December 31, 2021
Sharp	Other Accrued Liabilities	$	4,418	$	4,081

24

Financial Statements Presentation

The following tables present information about the fair value and related gains and losses of our derivative contracts. We did not have any derivative contracts with a credit-risk-related contingency. Fair values of the derivative contracts recorded in the consolidated balance sheets as of June 30, 2022 and December 31, 2021, are as follows: 

	Derivative Assets
		Fair Value As Of
(in thousands)	Balance Sheet Location	June 30, 2022		December 31, 2021
Derivatives not designated as hedging instruments
Propane swap agreements	Derivative assets, at fair value	$	—	$	16
Derivatives designated as cash flow hedges
Propane swap agreements	Derivative assets, at fair value	6,772		7,060
Total Derivative Assets		$	6,772	$	7,076

	Derivative Liabilities
		Fair Value As Of
(in thousands)	Balance Sheet Location	June 30, 2022		December 31, 2021
Derivatives designated as cash flow hedges
Propane swap agreements	Derivative liabilities, at fair value	$	427	$	743

The effects of gains and losses from derivative instruments on the condensed consolidated financial statements are as follows:

		Amount of Gain (Loss) on Derivatives:
	Location of Gain	For the Three Months Ended June 30,				For the Six Months Ended June 30,
(in thousands)	(Loss) on Derivatives	2022		2021		2022		2021
Derivatives not designated as hedging instruments
Propane swap agreements	Unregulated propane and natural gas costs	$	—	$	—	$	56	$	—
Derivatives designated as fair value hedges
Propane put options	Unregulated propane and natural gas costs	—		—		—		(24)
Derivatives designated as cash flow hedges
Propane swap agreements	Revenues	—		—		(826)		—
Propane swap agreements	Unregulated propane and natural gas costs	283		455		3,830		3,502
Propane swap agreements	Other comprehensive income (loss)	(686)		4,319		28		4,548
Interest rate swap agreements	Interest expense	—		22		—		26
Interest rate swap agreements	Other comprehensive income	—		8		—		5
Total		$	(403)	$	4,804	$	3,088	$	8,057

25

14.    Fair Value of Financial Instruments

GAAP establishes a fair value hierarchy that prioritizes the inputs to valuation methods used to measure fair value. The three levels of the fair value hierarchy are the following:

Fair Value Hierarchy	Description of Fair Value Level	Fair Value Technique Utilized
Level 1	Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities	Investments - equity securities - The fair values of these trading securities are recorded at fair value based on unadjusted quoted prices in active markets for identical securities. Investments - mutual funds and other - The fair values of these investments, comprised of money market and mutual funds, are recorded at fair value based on quoted net asset values of the shares.
Level 2	Quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability	Derivative assets and liabilities - The fair value of the propane put/call options, propane and interest rate swap agreements are measured using market transactions for similar assets and liabilities in either the listed or over-the-counter markets.
Level 3	Prices or valuation techniques requiring inputs that are both significant to the fair value measurement and unobservable (i.e. supported by little or no market activity)	Investments - guaranteed income fund - The fair values of these investments are recorded at the contract value, which approximates their fair value.

Financial Assets and Liabilities Measured at Fair Value

The following tables summarize our financial assets and liabilities that are measured at fair value on a recurring basis and the fair value measurements, by level, within the fair value hierarchy as of June 30, 2022 and December 31, 2021:

			Fair Value Measurements Using:
As of June 30, 2022	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	$	24	$	24	$	—	$	—
Investments—guaranteed income fund	2,102		—		—		2,102
Investments—mutual funds and other	8,397		8,397		—		—
Total investments	10,523		8,421		—		2,102
Derivative assets	6,772		—		6,772		—
Total assets	$	17,295	$	8,421	$	6,772	$	2,102
Liabilities:
Derivative liabilities	$	427	$	—	$	427	$	—

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			Fair Value Measurements Using:
As of December 31, 2021	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	$	26	$	26	$	—	$	—
Investments—guaranteed income fund	2,036		—		—		2,036
Investments—mutual funds and other	10,033		10,033		—		—
Total investments	12,095		10,059		—		2,036
Derivative assets	7,076		—		7,076		—
Total assets	$	19,171	$	10,059	$	7,076	$	2,036
Liabilities:
Derivative liabilities	$	743	$	—	$	743	$	—

The following table sets forth the summary of the changes in the fair value of Level 3 investments for the six months ended June 30, 2022 and 2021:

	Six months ended June 30,
	2022		2021
(in thousands)
Beginning Balance	$	2,036	$	2,156
Purchases and adjustments	132		70
Transfers	—		—
Distribution	(83)		(51)
Investment income	17		16
Ending Balance	$	2,102	$	2,191

Investment income from the Level 3 investments is reflected in other expense, (net) in the condensed consolidated statements of income.

At June 30, 2022, there were no non-financial assets or liabilities required to be reported at fair value. We review our non-financial assets for impairment at least on an annual basis, as required.

Other Financial Assets and Liabilities

Financial assets with carrying values approximating fair value include cash and cash equivalents and accounts receivable. Financial liabilities with carrying values approximating fair value include accounts payable and other accrued liabilities and short-term debt. The fair value of cash and cash equivalents is measured using the comparable value in the active market and approximates its carrying value (Level 1 measurement). The fair value of short-term debt approximates the carrying value due to its near-term maturities and because interest rates approximate current market rates (Level 3 measurement).

At June 30, 2022, long-term debt, which includes current maturities but excludes debt issuance costs, had a carrying value of approximately $608.3 million, compared to the estimated fair value of $540.6 million. At December 31, 2021, long-term debt, which includes the current maturities but excludes debt issuance costs, had a carrying value of approximately $568.8 million, compared to a fair value of approximately $597.2 million. The fair value was calculated using a discounted cash flow methodology that incorporates a market interest rate based on published corporate borrowing rates for debt instruments with similar terms and average maturities, and with adjustments for duration, optionality, and risk profile. The valuation technique used to estimate the fair value of long-term debt would be considered a Level 3 measurement.

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15.    Long-Term Debt

Our outstanding long-term debt is shown below: 

	June 30,		December 31,
(in thousands)	2022		2021
Uncollateralized senior notes:
5.93% note, due October 31, 2023	$	4,500	$	6,000
5.68% note, due June 30, 2026	11,600		14,500
6.43% note, due May 2, 2028	4,200		4,900
3.73% note, due December 16, 2028	14,000		14,000
3.88% note, due May 15, 2029	35,000		40,000
3.25% note, due April 30, 2032	70,000		70,000
3.48% note, due May 31, 2038	50,000		50,000
3.58% note, due November 30, 2038	50,000		50,000
3.98% note, due August 20, 2039	100,000		100,000
2.98% note, due December 20, 2034	70,000		70,000
3.00% note, due July 15, 2035	50,000		50,000
2.96% note, due August 15, 2035	40,000		40,000
2.49% notes Due January 25, 2037	50,000		50,000
2.95% notes Due March 15, 2042	50,000		—
Equipment security note
2.46% note, due September 24, 2031	8,950		9,378
Less: debt issuance costs	(973)		(913)
Total long-term debt	607,277		567,865
Less: current maturities	(21,472)		(17,962)
Total long-term debt, net of current maturities	$	585,805	$	549,903

    

Note Purchase Agreement

On March 15, 2022 we issued 2.95 percent Senior Notes due March 15, 2042 to MetLife in the aggregate principal amount of $50 million. We used the proceeds received from the issuances of the Senior Notes to reduce short-term borrowings under the Revolver and to fund capital expenditures. These Senior Notes have similar covenants and default provisions as our other Senior Notes, and have an annual principal payment beginning in the eleventh year after the issuance.

Equipment Security Note

On September 24, 2021, we entered into an Equipment Financing Agreement with Banc of America Leasing & Capital, LLC to issue $9.6 million in sustainable financing to finance the purchase of equipment by our subsidiary, Marlin Gas Services. The equipment security note bears a 2.46 percent interest rate and has a term of ten years. Under the terms of the agreement, we granted a security interest in the equipment to the lender, to serve as collateral.

Shelf Agreements

We have entered into Shelf Agreements with Prudential and MetLife, whom are under no obligation to purchase any unsecured debt. The following table summarizes our Shelf Agreements at June 30, 2022:

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(in thousands)	Total Borrowing Capacity		Less: Amount of Debt Issued		Less: Unfunded Commitments		Remaining Borrowing Capacity
Shelf Agreement
Prudential Shelf Agreement (1)	$	370,000	$	(220,000)	$	—	$	150,000
MetLife Shelf Agreement (1)	150,000		(50,000)		—		100,000
Total Shelf Agreements as of June 30, 2022	$	520,000	$	(270,000)	$	—	$	250,000

     (1) The Prudential and MetLife Shelf Agreements expire in April 2023 and May 2023, respectively.

The Uncollateralized Senior Notes, Shelf Agreements or Shelf Notes set forth certain business covenants to which we are subject when any note is outstanding, including covenants that limit or restrict our ability, and the ability of our subsidiaries, to incur indebtedness, or place or permit liens and encumbrances on any of our property or the property of our subsidiaries.

16.    Short-Term Borrowings

We are authorized by our Board of Directors to borrow up to $400.0 million of short-term debt, as required. At June 30, 2022 and December 31, 2021, we had $137.0 million and $221.6 million, respectively, of short-term borrowings outstanding at a weighted average interest rate of 2.38 percent and 0.83 percent, respectively.

In August 2021, we amended and restated our Revolver into a multi-tranche facility totaling $400.0 million with multiple participating lenders. The two tranches of the Revolver consist of a $200.0 million 364-day short-term debt tranche and a $200.0 million five-year tranche, both of which have three (3) one-year extension options, which can be authorized by our Chief Financial Officer. We are eligible to establish the repayment term for individual borrowings under the five year tranche of the Revolver and to the extent that an individual loan under the Revolver exceeded 12 months, the outstanding balance would be classified as a component of long-term debt.

The availability of funds under the Revolver is subject to conditions specified in the credit agreement, all of which we currently satisfy. These conditions include our compliance with financial covenants and the continued accuracy of representations and warranties contained in the Revolver's loan documents. We are required by the financial covenants in the Revolver to maintain, at the end of each fiscal year, a funded indebtedness ratio of no greater than 65 percent. As of June 30, 2022, we are in compliance with this covenant.

The 364-day tranche of the Revolver expires in August 2022 and the five-year tranche expires in August 2026 both are available to fund for our short-term cash needs to meet seasonal working capital requirements and to temporarily fund portions of our capital expenditures. Borrowings under both tranches of the Revolver are subject to a pricing grid, including the commitment fee and the interest rate charged. Our pricing is adjusted each quarter based upon a total indebtedness to total capitalization ratio. As of June 30, 2022, the pricing under the 364-day tranche of the Revolver does not include an unused commitment fee and maintains an interest rate of 0.70 percent over LIBOR. As of June 30, 2022, the pricing under the five-year tranche of the Revolver included an unused commitment fee of 0.09 percent and an interest rate of 0.95 percent over LIBOR.

We are currently in discussions with the various lending institutions regarding the renewal of the 364-day tranche. At that time, the reference interest rate for the 364-day and five-year tranche will transition from LIBOR which is being retired by financial institutions to the Standard Overnight Financing Rate ("SOFR"). We do not expect this transition to have a material impact on our financial condition.

Our total available credit under the Revolver at June 30, 2022 was $257.7 million. As of June 30, 2022, we had issued $5.3 million in letters of credit to various counterparties under the syndicated Revolvers. These letters of credit are not included in the outstanding short-term borrowings and we do not anticipate that they will be drawn upon by the counterparties. The letters of credit reduce the available borrowings under our syndicated Revolver.

In the fourth quarter of 2020, we entered into two $30.0 million interest rate swaps with a notional amount of $60.0 million through September and December 2021 at a pricing of 0.205 and 0.20 percent, respectively. In February 2021, we entered into an additional interest rate swap with a notional amount of $40.0 million through December 2021 with pricing of 0.17 percent. Our short-term borrowing is based on the 30-day LIBOR rate. At December 31, 2021, all of our interest rate swaps had expired and we have not entered into any new derivative contracts associated with our outstanding short-term borrowings.

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17.    Leases

    We have entered into lease arrangements for office space, land, equipment, pipeline facilities and warehouses. These lease arrangements enable us to better conduct business operations in the regions in which we operate. Office space is leased to provide adequate workspace for our employees in several locations throughout our service territories. We lease land at various locations throughout our service territories to enable us to inject natural gas into underground storage and distribution systems, for bulk storage capacity, for our propane operations and for storage of equipment used in repairs and maintenance of our infrastructure. We lease natural gas compressors to ensure timely and reliable transportation of natural gas to our customers. Additionally, we lease a pipeline to deliver natural gas to an industrial customer in Polk County, Florida. We also lease warehouses to store equipment and materials used in repairs and maintenance for our businesses.

Some of our leases are subject to annual changes in the Consumer Price Index (“CPI”). While lease liabilities are not re-measured as a result of changes to the CPI, changes to the CPI are treated as variable lease payments and recognized in the period in which the obligation for those payments was incurred. A 100-basis-point increase in CPI would not have resulted in material additional annual lease costs. Most of our leases include options to renew, with renewal terms that can extend the lease term from one to 25 years or more. The exercise of lease renewal options is at our sole discretion. The amounts disclosed in our consolidated balance sheet at June 30, 2022, pertaining to the right-of-use assets and lease liabilities, are measured based on our current expectations of exercising our available renewal options. Our existing leases are not subject to any restrictions or covenants that would preclude our ability to pay dividends, obtain financing or enter into additional leases. As of June 30, 2022, we have not entered into any leases, which have not yet commenced, that would entitle us to significant rights or create additional obligations. The following table presents information related to our total lease cost included in our consolidated statements of income:

		Three Months Ended		Six Months Ended
		June 30,		June 30,
( in thousands)	Classification	2022	2021	2022	2021
Operating lease cost (1)	Operations expense	$726	$515	$1,377	$1,038

(1) Includes short-term leases and variable lease costs, which are immaterial.

The following table presents the balance and classifications of our right of use assets and lease liabilities included in our condensed consolidated balance sheet at June 30, 2022 and December 31, 2021:

(in thousands)	Balance sheet classification	June 30, 2022		December 31, 2021
Assets
Operating lease assets	Operating lease right-of-use assets	$	15,767	$	10,139
Liabilities
Current
Operating lease liabilities	Other accrued liabilities	$	2,501	$	1,996
Noncurrent
Operating lease liabilities	Operating lease - liabilities	13,807		8,571
Total lease liabilities		$	16,308	$	10,567

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The following table presents our weighted-average remaining lease terms and weighted-average discount rates for our operating and financing leases at June 30, 2022 and December 31, 2021:

	June 30, 2022		December 31, 2021
Weighted-average remaining lease term (in years)
Operating leases	8.32		8.10
Weighted-average discount rate
Operating leases	3.3	%	3.6	%

The following table presents additional information related to cash paid for amounts included in the measurement of lease liabilities included in our condensed consolidated statements of cash flows as of June 30, 2022 and 2021:

	Six Months Ended
	June 30,
(in thousands)	2022		2021
Operating cash flows from operating leases	$	1,428	$	936

The following table presents the future undiscounted maturities of our operating and financing leases at June 30, 2022 and for each of the next five years and thereafter:

(in thousands)	Operating  Leases (1)
Remainder of 2022	$	1,392
2023	2,844
2024	2,629
2025	2,260
2026	1,746
2027	1,501
Thereafter	5,994
Total lease payments	18,366
Less: Interest	(2,058)
Present value of lease liabilities	$	16,308

    (1) Operating lease payments include $2.1 million related to options to extend lease terms that are reasonably certain of being exercised.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Management’s Discussion and Analysis of Financial Condition and Results of Operations is designed to provide a reader of the financial statements with a narrative report on our financial condition, results of operations and liquidity. This discussion and analysis should be read in conjunction with the attached unaudited condensed consolidated financial statements and notes thereto and our Annual Report on Form 10-K for the year ended December 31, 2021, including the audited consolidated financial statements and notes thereto.

Safe Harbor for Forward-Looking Statements

We make statements in this Quarterly Report on Form 10-Q (this " Quarterly Report") that do not directly or exclusively relate to historical facts. Such statements are “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, Section 21E of the Securities Exchange Act of 1934, as amended, and the Private Securities Litigation Reform Act of 1995. One can typically identify forward-looking statements by the use of forward-looking words, such as “project,” “believe,” “expect,” “anticipate,” “intend,” “plan,” “estimate,” “continue,” “potential,” “forecast” or other similar words, or future or conditional verbs such as “may,” “will,” “should,” “would” or “could.” These statements represent our intentions, plans, expectations, assumptions and beliefs about future financial performance, business strategy, projected plans and objectives of the Company. Forward-looking statements speak only as of the date they are made or as of the date indicated and we do not undertake any obligation to update forward-looking statements as a result of new information, future events or otherwise. These statements are subject to many risks and uncertainties. In addition to the risk factors described under Item 1A, Risk Factors in our 2021 Annual Report on Form 10-K, the following important factors, among others, could cause actual future results to differ materially from those expressed in the forward-looking statements:

•state and federal legislative and regulatory initiatives that affect cost and investment recovery, have an impact on rate structures, and affect the speed and the degree to which competition enters the electric and natural gas industries;

•the outcomes of regulatory, environmental and legal matters, including whether pending matters are resolved within current estimates and whether the related costs are adequately covered by insurance or recoverable in rates;

•the impact of climate change, including the impact of greenhouse gas emissions or other legislation or regulations intended to address climate change;

•the impact of significant changes to current tax regulations and rates;

•the timing of certification authorizations associated with new capital projects and the ability to construct facilities at or below estimated costs;

•changes in environmental and other laws and regulations to which we are subject and environmental conditions of property that we now, or may in the future, own or operate;

•possible increased federal, state and local regulation of the safety of our operations;

•the inherent hazards and risks involved in transporting and distributing natural gas, electricity and propane;

•the economy in our service territories or markets, the nation, and worldwide, including the impact of economic conditions (which we do not control) on demand for natural gas, electricity, propane or other fuels;

•risks related to cyber-attacks or cyber-terrorism that could disrupt our business operations or result in failure of information technology systems or result in the loss or exposure of confidential or sensitive customer, employee or Company information;

•adverse weather conditions, including the effects of hurricanes, ice storms and other damaging weather events;

•customers' preferred energy sources;

•industrial, commercial and residential growth or contraction in our markets or service territories;

•the effect of competition on our businesses from other energy suppliers and alternative forms of energy;

•the timing and extent of changes in commodity prices and interest rates;

•the effect of spot, forward and future market prices on our various energy businesses;

•the extent of our success in connecting natural gas and electric supplies to our transmission systems, establishing and maintaining key supply sources, and expanding natural gas and electric markets;

•the creditworthiness of counterparties with which we are engaged in transactions;

•the capital-intensive nature of our regulated energy businesses;

•our ability to access the credit and capital markets to execute our business strategy, including our ability to obtain financing on favorable terms, which can be affected by various factors, including credit ratings and general economic conditions;

•the ability to successfully execute, manage and integrate a merger, acquisition or divestiture of assets or businesses and the related regulatory or other conditions associated with the merger, acquisition or divestiture;

•the impact on our costs and funding obligations, under our pension and other post-retirement benefit plans, of potential downturns in the financial markets, lower discount rates, and costs associated with health care legislation and regulation;

•the ability to continue to hire, train and retain appropriately qualified personnel;

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•the availability of, and competition for, qualified personnel supporting our natural gas, electricity and propane businesses;

•the effect of accounting pronouncements issued periodically by accounting standard-setting bodies; and

•the impacts associated with the outbreak of a pandemic, including the duration and scope of the pandemic the corresponding impact on our supply chains, our personnel, our contract counterparties, general economic conditions and growth, the financial markets and any costs to comply with governmental mandates.

Introduction

We are an energy delivery company engaged in the distribution of natural gas, electricity and propane; the transmission of natural gas; the generation of electricity and steam, and in providing related services to our customers.

Our strategy is focused on growing earnings from a stable regulated energy delivery foundation and investing in related businesses and services that provide opportunities for returns greater than traditional utility returns. We seek to identify and develop opportunities across the energy value chain, with emphasis on midstream and downstream investments that are accretive to earnings per share, consistent with our long-term growth strategy and create opportunities to continue our record of top tier returns on equity relative to our peer group.

Currently, our growth strategy is focused on the following platforms, including:

•Optimizing the earnings growth in our existing businesses, which includes organic growth, territory expansions, and new products and services as well as increased opportunities to transform the Company with a focus on people, process, technology and organizational structure.

•Identification and pursuit of additional pipeline expansions, including new interstate and intrastate transmission projects.

•Growth of Marlin Gas Services’ CNG transport business and expansion into LNG and RNG transport services as well as methane capture.

•Identifying and undertaking additional strategic propane acquisitions that provide a larger foundation in current markets and expand our brand and presence into new strategic growth markets.

•Pursuit of growth opportunities that enable us to utilize our integrated set of energy delivery businesses to participate in sustainable energy opportunities.

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 normally highest due to colder temperatures.

Earnings per share information is presented on a diluted basis, unless otherwise noted.

The following discussions and those later in the document on operating income and segment results include the use of the term Adjusted Gross Margin which is a non-GAAP measure throughout our discussion on operating results. Adjusted Gross Margin is calculated by deducting the purchased cost of natural gas, propane and electricity and the cost of labor spent on direct revenue-producing activities from operating revenues. The costs included in Adjusted Gross Margin exclude depreciation and amortization and certain costs presented in operations and maintenance expenses in accordance with regulatory requirements. Adjusted Gross Margin should not be considered an alternative to Gross Margin under U.S. GAAP which is defined as the excess of sales over cost of goods sold. We believe that Adjusted Gross Margin, although a non-GAAP measure, is useful and meaningful to investors as a basis for making investment decisions. It provides investors with information that demonstrates the profitability achieved by us under our allowed rates for regulated energy operations and under our competitive pricing structures for our unregulated energy operations. Our management uses Adjusted Gross Margin as one of the financial measures in assessing our business units’ performance. Other companies may calculate Adjusted Gross Margin in a different manner.

The below tables reconcile Gross Margin as defined under GAAP to our non-GAAP measure of Adjusted Gross Margin for the three and six months ended June 30, 2022 and 2021:

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	For the Three Months Ended June 30, 2022
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Operating Revenues	$	92,193	$	53,463	$	(6,186)	$	139,470
Cost of Sales:
Natural gas, propane and electric costs	(21,573)		(31,701)		6,158		(47,116)
Depreciation & amortization	(13,140)		(4,074)		(2)		(17,216)
Operations & maintenance expense (1)	(8,324)		(6,699)		(521)		(15,544)
Gross Margin (GAAP)	49,156		10,989		(551)		59,594
Operations & maintenance expense (1)	8,324		6,699		521		15,544
Depreciation & amortization	13,140		4,074		2		17,216
Adjusted Gross Margin (Non-GAAP)	$	70,620	$	21,762	$	(28)	$	92,354

	For the Three Months Ended June 30, 2021
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Operating Revenues	$	80,910	$	34,773	$	(4,601)	$	111,082
Cost of Sales:
Natural gas, propane and electric costs	(14,447)		(16,821)		4,567		(26,701)
Depreciation & amortization	(11,830)		(3,456)		(12)		(15,298)
Operations & maintenance expense (1)	(8,320)		(5,807)		67		(14,060)
Gross Margin (GAAP)	46,313		8,689		21		55,023
Operations & maintenance expense (1)	8,320		5,807		(67)		14,060
Depreciation & amortization	11,830		3,456		12		15,298
Adjusted Gross Margin (Non-GAAP)	$	66,463	$	17,952	$	(34)	$	84,381

	For the Six Months Ended June 30, 2022
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Operating Revenues	$	220,084	$	154,754	$	(12,488)	$	362,350
Cost of Sales:
Natural gas, propane and electric costs	(67,016)		(89,708)		12,427		(144,297)
Depreciation & amortization	(26,225)		(7,954)		(14)		(34,193)
Operations & maintenance expense (1)	(16,485)		(13,756)		(944)		(31,185)
Gross Margin (GAAP)	110,358		43,336		(1,019)		152,675
Operations & maintenance expense (1)	16,485		13,756		944		31,185
Depreciation & amortization	26,225		7,954		14		34,193
Adjusted Gross Margin (Non-GAAP)	$	153,068	$	65,046	$	(61)	$	218,053

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	For the Six Months Ended June 30, 2021
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Operating Revenues	$	202,107	$	109,532	$	(9,371)	$	302,268
Cost of Sales:
Natural gas, propane and electric costs	(57,491)		(52,804)		9,298		(100,997)
Depreciation & amortization	(23,860)		(6,780)		(22)		(30,662)
Operations & maintenance expense (1)	(16,585)		(12,120)		292		(28,413)
Gross Margin (GAAP)	104,171		37,828		197		142,196
Operations & maintenance expense (1)	16,585		12,120		(292)		28,413
Depreciation & amortization	23,860		6,780		22		30,662
Adjusted Gross Margin (Non-GAAP)	$	144,616	$	56,728	$	(73)	$	201,271

(1)Operations & maintenance expenses within the Consolidated Statements of Income are presented in accordance with regulatory requirements and to provide comparability within the industry. Operations & maintenance expenses which are deemed to be directly attributable to revenue producing activities have been separately presented above in order to calculate Gross Margin as defined under U.S. GAAP.

2022 to 2021 Gross Margin (GAAP) Variance – Regulated Energy

Gross Margin (GAAP) for the Regulated Energy segment for the quarter ended June 30, 2022 was $49.2 million, an increase of $2.8 million, or 6.1 percent, compared to the same period in 2021. Higher gross margin reflects continued pipeline expansions by Eastern Shore, Peninsula Pipeline, and Aspire Energy Express through contributions from the new Guernsey pipeline, organic growth in the natural gas distribution businesses and operating results from the 2021 Escambia Meter acquisition. These increases were partially offset by higher depreciation and amortization related to recent capital investments.

Gross Margin (GAAP) for the Regulated Energy segment for the six months ended June 30, 2022 was $110.4 million, an increase of $6.2 million, or 5.9 percent, compared to the same period in 2021. Higher gross margin reflects continued pipeline expansions by Eastern Shore, Peninsula Pipeline, and Aspire Energy Express through contributions from the new Guernsey pipeline, organic growth in the natural gas distribution businesses and operating results from the 2021 Escambia Meter acquisition. These increases were partially offset by higher depreciation and amortization related to recent capital investments

as well as, increased payroll, benefits and other employee related costs.

2022 to 2021 Gross Margin (GAAP) Variance – Unregulated Energy

Gross Margin (GAAP) for the Unregulated Energy segment for the quarter ended June 30, 2022 was $11.0 million, an increase of $2.3 million, or 26.5 percent, compared to the same period in 2021. Higher gross margin is a result of increased propane margins per gallon and service fees, along with improved performance in our other unregulated businesses. These increases were partially offset by higher depreciation, amortization and property taxes related to recent capital investments and acquisitions and higher vehicle expenses primarily driven by increased fuel costs.

Gross Margin (GAAP) for the Unregulated Energy segment for the six months ended June 30, 2022 was $43.3 million, an increase of $5.5 million, or 14.6 percent, compared to the same period in 2021. Higher gross margin is a result of contributions from the propane acquisition of Diversified Energy completed in 2021, increased propane margins per gallon and service fees, along with increased demand for CNG services and higher rates for Aspire Energy. These increases were partially offset by higher depreciation, amortization and property taxes related to recent capital investments and acquisitions, increased payroll, benefits and employee related costs and higher vehicle expenses primarily driven by increased fuel costs.

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Results of Operations for the Three and Six Months Ended June 30, 2022

Overview

Chesapeake Utilities is a Delaware corporation formed in 1947. We are a diversified energy company engaged, through our operating divisions and subsidiaries, in regulated energy, unregulated energy and other businesses. We operate primarily on the east coast of the United States and provide natural gas distribution and transmission; electric distribution and generation; propane gas distribution; mobile compressed natural gas services; steam generation; and other energy-related services.

In March 2020, the CDC declared a national emergency due to the rapidly growing outbreak of COVID-19. In response to this declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the country imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to slow the spread of the illness. These restrictions significantly impacted economic conditions in the United States beginning in 2020 and persisted throughout 2021, though to a lesser extent. Chesapeake Utilities is considered an “essential business,” which allowed us to continue operational activities and construction projects while social distancing restrictions were in place.

As of June 30, 2022, these restrictions have predominantly been lifted as vaccines have become widely available in the United States. Previously existing states of emergency in all of our service territories expired during the second and third quarters of 2021, eliminating a majority of restrictions initially implemented to slow the spread of the virus. The expiration of the states of emergency along with the settlement of our limited proceeding in Florida, has concluded our ability to defer incremental pandemic related costs for consideration through the applicable regulatory process. We have adjusted our operating practices accordingly to ensure the safety of our operations and will take the necessary actions to comply with the CDC, and the Occupational Safety and Health Administration, as new developments occur.

Environmental, Social and Governance Initiatives

ESG initiatives are at the core of our well-established culture, guiding our strategy and informing our ongoing business decisions. In February 2022, Chesapeake Utilities published its inaugural sustainability report. In the report, we outline our ESG commitments:

•Chesapeake Utilities will be a leader in the transition to a lower carbon future.

•We will continue to promote a diverse and inclusive workplace and further the sustainability of the communities we serve.

•Our businesses will be operated with integrity and the highest ethical standards.

These commitments guide our mission to deliver energy that makes life better for the people and communities we serve. They impact every aspect of our company and the relationships we have with our stakeholders. We encourage our investors to review the report and welcome feedback as we continue to enhance our ESG disclosures.

Some of our most recent ESG advancements include the following:

Environmental:

•We were joined by the Governor of the state of Maryland to celebrate the public-private partnership resulting from the extension of natural gas transmission and distribution pipeline into Somerset County, MD, enabling conversion for two state-funded entities to natural gas, improving their facilities’ environmental profile.

•In our Florida operating area, we participated in an event that showcases model homes filled with the latest designs and technologies for energy conservation.

Social:

•We announced Sharon Grant's appointment as our new assistant vice president and diversity officer; Ms. Grant will have direct oversight responsibilities for our equity, diversity, and inclusion (EDI) strategy and will collaborate across the organization with the teams responsible for the enterprise-wide environmental, social, and governance plan.

•We participated in events and made donations to organizations and fundraising initiatives within our local communities through our Employee Resource Groups and company community giving programs.

Governance:

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•In July 2022, we announced the appointment of Stephanie N. Gary and Sheree M. Petrone to serve as members of our Board of Directors as part of an ongoing succession planning strategy. that is aligned with our EDI commitments.

•We recently joined governance leaders as a member of the Advisory Board for the John L. Weinberg Center for Corporate Governance.

•We were recognized for the Best Corporate Governance in the U.S. for 2022 by World Finance magazine.

Earlier this year, we established our Environmental Sustainability Office ("ESO") and ESG Committee ("ESGC"). The ESO was established to identify and manage emission-reducing projects both internally, as well as those that support our customers’ sustainability goals. The ESGC was established to bring together a cross-functional team of leaders across the organization to identify, assess, execute and advance the Company’s strategic ESG initiatives.

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Operational Highlights

Our net income for the three months ended June 30, 2022 was $17.1 million, or $0.96 per share, compared to $13.8 million, or $0.78 per share, for the same quarter of 2021. Operating income for the three months ended June 30, 2022 increased by $3.9 million, or 17.2 percent, over the same period in 2021. Higher performance in the second quarter of 2022 was generated primarily from continued pipeline expansion projects, increased propane margins per gallon and fees, incremental contributions associated with regulated infrastructure programs, organic growth in our natural gas distribution businesses, increased customer consumption, and improved performance in our other unregulated businesses. We recorded higher depreciation, amortization and property taxes related to recent capital investments and higher operating expenses associated primarily with growth initiatives. We closely managed our operating expense increases, given anticipated future interest and other inflationary expense increases.

	Three Months Ended
	June 30,				Increase
	2022		2021		(decrease)
(in thousands except per share)
Adjusted Gross Margin
Regulated Energy segment	$	70,620	$	66,463	$	4,157
Unregulated Energy segment	21,762		17,952		3,810
Other businesses and eliminations	(28)		(34)		6
Total Adjusted Gross Margin	$	92,354	$	84,381	$	7,973
Operating Income
Regulated Energy segment	$	25,841	$	22,760	$	3,081
Unregulated Energy segment	560		(465)		1,025
Other businesses and eliminations	68		283		(215)
Total Operating Income	26,469		22,578		3,891
Other income, net	2,584		1,453		1,131
Interest charges	5,825		5,054		771
Income from Before Income Taxes	23,228		18,977		4,251
Income Taxes	6,177		5,164		1,013
Net Income	$	17,051	$	13,813	$	3,238
Basic Earnings Per Share of Common Stock	$	0.96	$	0.79	$	0.17
Diluted Earnings Per Share of Common Stock	$	0.96	$	0.78	$	0.18

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Key variances between the second quarter of 2022 and the second quarter of 2021, included: 

(in thousands, except per share data)	Pre-tax Income		Net Income		Earnings Per Share
Second Quarter of 2021 Reported Results	$	18,977	$	13,813	$	0.78
Adjusting for Unusual Items:
Gain from sales of assets	1,902		1,396		0.08
	1,902		1,396		0.08
Increased (Decreased) Adjusted Gross Margins:
Contributions from acquisitions*	1,657		1,216		0.07
Natural gas transmission service expansions*	1,291		948		0.05
Increased propane margins and fees	1,104		810		0.05
Contributions from regulated infrastructure programs *	1,080		793		0.04
Natural gas growth (excluding service expansions)	938		689		0.04
Increased customer consumption - Inclusive of weather	773		567		0.03
Increased margins related to demand for Marlin Gas Services*	547		402		0.02
Higher operating results from Aspire Energy	203		149		0.01
	7,593		5,574		0.31
(Increased) Decreased Operating Expenses (Excluding Natural Gas, Propane, and Electric Costs):
Operating expenses from recent acquisitions	(2,258)		(1,657)		(0.09)
Depreciation, amortization and property taxes	(1,899)		(1,394)		(0.08)
Vehicle expenses	(407)		(299)		(0.02)
Customer service related costs	(200)		(147)		(0.01)
Facilities expenses, maintenance costs and outside services	559		410		0.02
Payroll, benefits and other employee-related expenses	343		252		0.01
	(3,862)		(2,835)		(0.17)
Interest charges	(771)		(566)		(0.03)
Net other changes	(611)		(331)		(0.01)
	(1,382)		(897)		(0.04)
Second Quarter of 2022 Reported Results	$	23,228	$	17,051	$	0.96

*See the Major Projects and Initiatives table.

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Our net income for the six months ended June 30, 2022 was $54.0 million, or $3.04 per share, compared to $48.3 million, or $2.75 per share, for the same period of 2021. Operating income for the six months ended June 30, 2022 increased by $7.2 million, or 9.7 percent, over the same period in 2021. Higher performance in the first six months of 2022 was generated from propane and natural gas acquisitions completed in 2021, continued pipeline expansion projects, organic growth in our natural gas distribution businesses, incremental contributions associated with regulated infrastructure programs, increased propane margins per gallon and fees and improved performance in our other unregulated businesses. We recorded higher depreciation, amortization and property taxes related to recent capital investments and operating expenses associated primarily with growth initiatives, as well as increased vehicle expenses due to higher fuel costs.

	Six Months Ended
	June 30,				Increase
	2022		2021		(decrease)
(in thousands except per share)
Adjusted Gross Margin
Regulated Energy segment	$	153,068	$	144,616	$	8,452
Unregulated Energy segment	65,046		56,728		8,318
Other businesses and eliminations	(61)		(73)		12
Total Adjusted Gross Margin	$	218,053	$	201,271	$	16,782
Operating Income
Regulated Energy segment	$	60,539	$	55,466	$	5,073
Unregulated Energy segment	20,613		18,575		2,038
Other businesses and eliminations	182		134		48
Total Operating Income	81,334		74,175		7,159
Other income, net	3,498		1,828		1,670
Interest charges	11,164		10,159		1,005
Income from Before Income Taxes	73,668		65,844		7,824
Income Taxes	19,683		17,565		2,118
Net Income	$	53,985	$	48,279	$	5,706
Basic Earnings Per Share of Common Stock	$	3.05	$	2.76	$	0.29
Diluted Earnings Per Share of Common Stock	$	3.04	$	2.75	$	0.29

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Key variances between the six months ended June 30, 2022 and the six months ended June 30, 2021, included: 

(in thousands, except per share data)	Pre-tax Income		Net Income		Earnings Per Share
Six Months Ended June 30, 2021 Reported Results	$	65,844	$	48,279	$	2.75
Adjusting for Unusual Items:
Gain from sales of assets	1,902		1,394		0.08
	1,902		1,394		0.08
Increased (Decreased) Adjusted Gross Margins:
Contributions from acquisitions*	5,882		4,312		0.24
Natural gas transmission service expansions*	2,518		1,846		0.10
Natural gas growth (excluding service expansions)	2,132		1,563		0.09
Contributions from regulated infrastructure programs *	2,004		1,469		0.08
Increased propane margins and fees	1,823		1,336		0.08
Higher operating results from Aspire Energy	1,131		829		0.05
Increased margins related to demand for Marlin Gas Services*	612		448		0.03
Increased customer consumption - Inclusive of weather	337		247		0.01
	16,439		12,050		0.68
(Increased) Decreased Operating Expenses (Excluding Natural Gas, Propane, and Electric Costs):
Operating expenses from recent acquisitions	(4,708)		(3,451)		(0.19)
Depreciation, amortization and property tax costs	(3,436)		(2,519)		(0.14)
Vehicle expenses	(662)		(485)		(0.03)
Payroll, benefits and other employee-related expenses	(503)		(369)		(0.02)
Facilities expenses, maintenance costs and outside services	615		451		0.03
	(8,694)		(6,373)		(0.35)
Interest charges	(1,004)		(736)		(0.04)
Net other changes	(819)		(629)		(0.05)
Change in shares outstanding due to 2021 and 2022 equity offerings	—		—		(0.03)
	(1,823)		(1,365)		(0.12)
Six Months Ended June 30, 2022 Reported Results	$	73,668	$	53,985	$	3.04

*See the Major Projects and Initiatives table.

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Summary of Key Factors

Recently Completed and Ongoing Major Projects and Initiatives

We constantly pursue and develop additional projects and initiatives to serve existing and new customers, and to further grow our businesses and earnings, with the intention to increase shareholder value. The following table includes the major projects/initiatives recently completed and currently underway. Major projects and initiatives that have generated consistent year-over-year adjusted gross margin contributions are removed from the table. In the future, we will add new projects and initiatives to this table once negotiations are substantially completed and the associated earnings can be estimated.

	Adjusted Gross Margin
	Three Months Ended				Six Months Ended				Year Ended		Estimate for
	June 30,				June 30,				December 31,		Fiscal
in thousands	2022		2021		2022		2021		2021		2022		2023
Pipeline Expansions:
Western Palm Beach County, Florida Expansion (1)	$	1,307	$	1,172	$	2,615	$	2,340	$	4,729	$	5,227	$	5,227
Del-Mar Energy Pathway (1) (2)	1,728		921		3,450		1,805		4,584		6,980		6,980
Guernsey Power Station	368		47		631		94		187		1,380		1,486
Southern Expansion	—		—		—		—		—		—		586
Winter Haven Expansion	28		—		61		—		—		401		976
Beachside Pipeline Expansion	—		—		—		—		—		—		1,825
North Ocean City Connector	—		—		—		—		—		—		400
St. Cloud / Twin Lakes Expansion	—		—		—		—		—		—		584
Total Pipeline Expansions	3,431		2,140		6,757		4,239		9,500		13,988		18,064
CNG/RNG/LNG Transportation and Infrastructure	2,427		1,708		4,660		3,785		7,566		9,500		10,500
Acquisitions:
Propane Acquisitions	1,491		—		5,466		—		603		11,300		12,000
Escambia Meter Station	249		83		499		83		583		1,000		1,000
Total Acquisitions	1,740		83		5,965		83		1,186		12,300		13,000
Regulatory Initiatives:
Florida GRIP	4,950		4,181		9,802		8,236		16,995		18,797		19,475
Capital Cost Surcharge Programs	497		120		1,014		257		1,199		2,018		1,936
Elkton Gas STRIDE Plan	66		—		140		—		26		241		354
Florida Rate Case Proceeding(3)	—		—		—		—		—		TBD		TBD
Total Regulatory Initiatives	5,513		4,301		10,956		8,493		18,220		21,056		21,765
Total	$	13,111	$	8,232	$	28,338	$	16,600	$	36,472	$	56,844	$	63,329

(1) Includes adjusted gross margin generated from interim services.

(2) Includes adjusted gross margin from natural gas distribution services.

(3) Subject to approval from the Florida PSC.

Detailed Discussion of Major Projects and Initiatives

Pipeline Expansions

West Palm Beach County, Florida Expansion

Peninsula Pipeline has constructed four transmission lines to bring additional natural gas to our distribution system in West Palm Beach, Florida. The first phase of this project was placed into service in December 2018 with multiple phases placed into service leading up to the project's final completion in the fourth quarter of 2021. The project generated incremental adjusted gross margin for the three and six months ended June 30, 2022 of $0.1 million and $0.3 million, respectively, compared to 2021. We estimate that the project will generate annual adjusted gross margin of $5.2 million in 2022 and beyond.

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Del-Mar Energy Pathway

In December 2019, the FERC issued an order approving the construction of the Del-Mar Energy Pathway project. The project was placed into service in the fourth quarter of 2021. The new facilities: (i) include an additional 14,300 Dts/d of firm service to four customers, (ii) provide additional natural gas transmission pipeline infrastructure in eastern Sussex County, Delaware, and (iii) represent the first extension of Eastern Shore’s pipeline system into Somerset County, Maryland. Including interim services in advance of completion, the project generated additional adjusted gross margin for the three and six months ended June 30, 2022 of $0.8 million and $1.6 million, respectively. The estimated annual adjusted gross margin from this project, including natural gas distribution service in Somerset County, Maryland, is approximately $7.0 million in 2022 and beyond.

Guernsey Power Station

Guernsey Power Station and the Company's affiliate, Aspire Energy Express, entered into a precedent agreement for firm transportation capacity whereby Guernsey Power Station will construct a power generation facility and Aspire Energy Express will provide firm natural gas transportation service to this facility. Guernsey Power Station commenced construction of the project in October 2019. Aspire Energy Express completed construction of the gas transmission facilities in the fourth quarter of 2021. This project added $0.3 million and $0.5 million of adjusted gross margin for the three and six months ended June 30, 2022, respectively, and is expected to produce adjusted gross margin of approximately $1.4 million in 2022 and $1.5 million in 2023 and beyond.

Southern Expansion

Pending FERC authorization, Eastern Shore plans to install a new natural gas driven compressor skid unit at its existing Bridgeville, Delaware compressor station that will provide 7,300 Dts of incremental firm transportation pipeline capacity. The project is currently estimated to go into service in the fourth quarter of 2023. Eastern Shore expects the Southern Expansion project to generate annual adjusted gross margin of $0.6 million in 2023 and annual adjusted gross margin of $2.3 million in 2024 and thereafter.

Winter Haven Expansion

In May 2021, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with CFG for an incremental 6,800 Dts/d of firm service in the Winter Haven, Florida area. As part of this agreement, Peninsula Pipeline will construct a new interconnect with FGT and a new regulator station for CFG. The additional firm service will be used to support new incremental load due to growth in the area, including providing service, most immediately, to a new can manufacturing facility, as well as reliability and operational benefits to CFG’s existing distribution system in the area. In connection with Peninsula Pipeline’s new regulator station, CFG is also extending its distribution system to connect to the new station. We expect this expansion to be in service in the third quarter of 2022 and expect to generate adjusted gross margin of $0.4 million in 2022 once complete and $1.0 million in 2023 and thereafter.

Beachside Pipeline Expansion

In June 2021, Peninsula Pipeline and Florida City Gas entered into a Transportation Service Agreement for an incremental 10,176 Dts/d of firm service in Indian River County, Florida, to support Florida City Gas’ growth along the Indian River's barrier island. As part of this agreement, Peninsula Pipeline will construct approximately 11.3 miles of pipeline from its existing pipeline in the Sebastian, Florida, area east under the Intercoastal Waterway and southward on the barrier island. Construction is underway and is expected to be complete in the second quarter of 2023. We expect this extension to generate additional annual adjusted gross margin of $1.8 million in 2023 and $2.5 million thereafter.

North Ocean City Connector

During the second quarter, we began construction of an extension of service into North Ocean City, Maryland. Our Delaware natural gas division and Sandpiper plan to install approximately 5.7 miles of pipeline across southern Sussex County, Delaware to Fenwick Island, Delaware and Worcester County, Maryland. The project will produce additional capacity to serve new customers and reinforce our existing system in Ocean City, Maryland. We expect this expansion to generate additional annual adjusted gross margin of $0.4 million in 2023 and beyond, with additional margin opportunities from incremental growth.

St.Cloud / Twin Lakes Expansion

In July 2022, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with FPU for an additional 2,400 Dt/day of firm service in the St. Cloud, Florida area. As part of this agreement, Peninsula Pipeline will construct a pipeline extension and regulator station for FPU. The extension will be used to support new incremental load due to growth in the area, including providing service, most immediately, to the residential development Twin Lakes. The expansion will also improve reliability and operational benefits to FPU’s existing distribution system in the area, supporting future growth in the area. We expect this expansion to be in service in the first quarter of 2023 and generate adjusted gross margin of $0.6 million in 2023 and thereafter.

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CNG/RNG/LNG Transportation and Infrastructure

We have made a commitment to meet customer demand for CNG, RNG and LNG in the markets we serve. This has included making investments within Marlin Gas Services to be able to transport these products through its virtual pipeline fleet to customers.To date, we have also made an infrastructure investment in Ohio, enabling RNG to fuel a third party landfill fleet and to transport RNG to end use customers off our pipeline system. Similarly, we announced in March 2022, the opening of a high-capacity CNG truck and tube trailer fueling station in Port Wentworth, Georgia. As one of the largest public access CNG stations on the East Coast, it will offer a RNG option to customers in the near future. We constructed the station in partnership with Atlanta Gas Light, a subsidiary of Southern Company Gas. In 2020, Atlanta Gas Light announced that Chesapeake Utilities would be constructing, maintaining the station and ensuring access to CNG and RNG for the many customers expected to fuel at the station.

We are also involved in various other projects, all at various stages and all with different opportunities to participate across the energy value chain. In many of these projects, Marlin will play a key role in ensuring the RNG is transported to one of our many pipeline systems where it will be injected. Accordingly, given the overlapping role of Marlin in many of these projects, we have combined our transportation services and infrastructure adjusted gross margin discussion into one section.

For the three and six months ended June 30, 2022, the Company generated $0.7 million and $0.9 million in additional adjusted gross margin associated with the transportation of CNG and RNG by Marlin’s virtual pipeline and Aspire Energy’s Noble Road RNG pipeline. The Company estimates annual adjusted gross margin of approximately $9.5 million in 2022, and $10.5 million in 2023 for these transportation related services, with potential for additional growth in future years.

Discussed below are some of the recently completed projects as well as a sample of the growth projects in which we are currently involved. As new projects are solidified, we will provide additional detail on those projects at that time.

Noble Road Landfill RNG Project

In October 2021, Aspire Energy completed construction of its Noble Road Landfill RNG pipeline project, a 33.1-mile pipeline, which transports RNG generated from the Noble Road landfill to Aspire Energy’s pipeline system, displacing conventionally produced natural gas. In conjunction with this expansion, Aspire Energy also upgraded an existing compressor station and installed two new metering and regulation sites. The RNG volume is expected to represent nearly 10 percent of Aspire Energy’s gas gathering volumes.

Bioenergy DevCo

In June 2020, our Delmarva natural gas operations and Bioenergy DevCo (“BDC”), a developer of anaerobic digestion facilities that create renewable energy and healthy soil products from organic material, entered into an agreement related to a project to extract RNG from poultry production waste. BDC and our affiliates are collaborating on this project in addition to several other project sites where organic waste can be converted into a carbon-negative energy source.

Marlin Gas Services will transport the RNG created from the organic waste from the BDC facility to an Eastern Shore interconnection, where the sustainable fuel will be introduced into our transmission system and ultimately distributed to our natural gas customers.

CleanBay Project

In July 2020, our Delmarva natural gas operations and CleanBay Renewables Inc. ("CleanBay") announced a new partnership to bring RNG to our operations. As part of this partnership, we will transport the RNG produced at CleanBay's planned Westover, Maryland bio-refinery, to our natural gas infrastructure in the Delmarva Peninsula region. Eastern Shore and Marlin Gas Services, will transport the RNG from CleanBay to our Delmarva natural gas distribution system where it is ultimately delivered to the Delmarva natural gas distribution end use customers.

Acquisitions

Propane Acquisitions

On December 15, 2021, Sharp Energy acquired the propane operating assets of Diversified Energy for approximately $37.5 million net of cash acquired. There are multiple strategic benefits to this acquisition including it: (i) expanded the Company's propane territory into North Carolina and South Carolina while also expanding our existing footprint in Pennsylvania and Virginia, and (ii) included an established customer base with opportunities for future growth. Through this acquisition, the Company added approximately 19,000 residential, commercial and agricultural customers, along with distribution of approximately 10.0 million gallons of propane annually.

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On June 13, 2022, Sharp acquired the propane operating assets of Davenport Energy's Siler City propane division for approximately $2.0 million. Through this acquisition, the Company expands its operating footprint further into North Carolina, where customers will be served by Sharp Energy’s Diversified Energy division. The acquisition adds approximately 850 customers and distribution of approximately 406,000 gallons of propane annually to Sharp Energy’s territory.

For the three and six months ended June 30, 2022, these acquisitions contributed $1.5 million and $5.5 million, respectively, in adjusted gross margin and are expected to generate $11.3 million of additional adjusted gross margin in 2022 and $12.0 million in 2023.

Escambia Meter Station

In June 2021, Peninsula Pipeline purchased the Escambia Meter Station from Florida Power and Light and entered into a Transportation Service Agreement with Gulf Power Company to provide up to 530,000 Dts/d of firm service from an interconnect with FGT to Florida Power & Light’s Crist Lateral pipeline. The Florida Power & Light Crist Lateral provides gas supply to their natural gas fired power plant owned by Florida Power & Light in Pensacola, Florida. The Company generated $0.2 million and $0.4 million, respectively, in additional adjusted gross margin for the three and six months ended June 30, 2022 and estimates that this acquisition will generate adjusted gross margin of approximately $1.0 million in 2022 and beyond.

Regulatory Initiatives

Florida GRIP

Florida GRIP is a natural gas pipe replacement program approved by the Florida PSC that allows automatic recovery, through rates, of costs associated with the replacement of mains and services. Since the program's inception in August 2012, the Company has invested $198.7 million of capital expenditures to replace 351 miles of qualifying distribution mains, including $9.2 million of new pipes during the first six month of 2022. GRIP generated additional gross margin of $0.8 million and $1.6 million, respectively, for the three and six months ended June 30, 2022 compared to 2021. We are currently projecting to complete this program in 2022 and expect to generate adjusted gross margin of $18.8 million and $19.5 million in 2022 and 2023, respectively. The adjusted gross margin on GRIP investments will continue to be generated as we have included the investments, and the associated expenses, in the base rate proceeding that was filed in May 2022.

Capital Cost Surcharge Programs

In December 2019, the FERC approved Eastern Shore’s capital cost surcharge to become effective January 1, 2020. The surcharge, an approved item in the settlement of Eastern Shore’s last general rate case, allows Eastern Shore to recover capital costs associated with mandated highway or railroad relocation projects that required the replacement of existing Eastern Shore facilities. For the three and six months ended June 30, 2022, there was $0.4 million and $0.8 million, respectively, of adjusted gross margin generated pursuant to the program. Eastern Shore expects to produce adjusted gross margin of approximately $2.0 million in 2022 and $1.9 million in 2023 from relocation projects, which is ultimately dependent upon the timing of filings and the completion of construction.

Elkton Gas STRIDE Plan

In June 2021, we reached a settlement with the Maryland PSC Staff and the Maryland Office of the Peoples Counsel regarding a five-year plan to replace Aldyl-A pipelines and recover the associated costs of those replacements through a fixed charge rider.The STRIDE plan went into service in September 2021 and is expected to generate $0.2 million of adjusted gross margin in 2022 and $0.4 million annually thereafter.

COVID-19 Regulatory Proceeding

In October 2020, the Florida PSC approved a joint petition of our natural gas and electric distribution utilities in Florida to establish a regulatory asset to record incremental expenses incurred due to COVID-19. The regulatory asset allows us to seek recovery of these costs in the next base rate proceedings. In November 2020, the Office of Public Counsel filed a protest to the order approving the establishment of this regulatory asset treatment. The Company’s Florida regulated business units reached a settlement with the Florida OPC in June 2021. The settlement allowed the business units to establish a regulatory asset of $2.1 million. This amount includes COVID-19 related incremental expenses for bad debt write-offs, personnel protective equipment, cleaning and business information services for remote work. Our Florida regulated business units are amortizing the amount over two years effective January 1, 2022 and recover the regulatory asset through the Purchased Gas Adjustment and Swing Service mechanisms for the natural gas business units and through the Fuel Purchased Power Cost Recovery clause for the electric division. This results in annual additional adjusted gross margin of $1.0 million that will be offset by a corresponding amortization of regulatory asset expense for both 2022 and 2023.

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Florida Natural Gas Base Rate Proceeding

In May 2022, our natural gas distribution businesses in Florida, FPU, FPU-Indiantown division, FPU-Fort Meade division and Chesapeake Utilities CFG division (collectively, “Florida natural gas distribution businesses”) filed a consolidated natural gas rate case with the Florida PSC. In connection with the application, the Company is seeking approval of the following: (i) interim rate relief of approximately $7.2 million on an annualized basis, subject to refund, pending the outcome of the rate case proceeding; (ii) a permanent rate relief of approximately $24.1 million, effective January 1, 2023, (iii) a depreciation study also submitted with filing; (iv) authorization to make certain changes to tariffs to include the consolidation of rates and rate structure across the businesses and to unify the Florida natural gas distribution businesses under FPU; (v) authorization to retain acquisition adjustment in the revenue requirement; and (vi) authorization to establish an environmental remediation surcharge for the purposes of addressing future expected remediation costs for manufactured gas plant sites. In August 2022, interim rates were approved by the Florida PSC in the amount of approximately $7.7 million on an annualized basis, effective for all meter readings in September 2022. The interim rates are subject to refund pending the final outcome of the rate case proceeding. The discovery process has commenced and hearing for the proceeding has been scheduled for October 2022. The outcome of the application is subject to review and approval by the Florida PSC.

Storm Protection Plan

In 2020, the Florida PSC implemented the SPP and SPPCR rules, which require electric utilities to petition the Florida PSC for approval of a Transmission and Distribution Storm Protection Plan that covers the utility’s immediate 10-year planning period with updates to the plan at least every 3 years. The SPPCR rules allow the utility to file for recovery of associated costs related to its SPP. The Company’s SPP plan was filed in April 2022, with hearings scheduled for early August 2022. The SPPCRC was filed in May 2022 with requested rates effective January 1, 2023. The SPPCRC hearing is scheduled for November 2022.

Other major factors influencing adjusted gross margin

Weather Impact

Weather was not a significant factor during the second quarter and the first half of 2022. The following table summarizes HDD and CDD variances from the 10-year average HDD/CDD ("Normal") for the three and six months ended June 30, 2022 and 2021.

	Three Months Ended			Six Months Ended
	June 30,			June 30,
	2022	2021	Variance	2022	2021	Variance
Delmarva Peninsula
Actual HDD	394	400	(6)	2,575	2,586	(11)
10-Year Average HDD ("Normal")	412	396	16	2,667	2,676	(9)
Variance from Normal	(18)	4		(92)	(90)
Florida
Actual HDD	37	69	(32)	534	572	(38)
10-Year Average HDD ("Normal")	45	43	2	542	549	(7)
Variance from Normal	(8)	26		(8)	23
Ohio
Actual HDD	604	676	(72)	3,530	3,448	82
10-Year Average HDD ("Normal")	630	623	7	3,542	3,582	(40)
Variance from Normal	(26)	53		(12)	(134)
Florida
Actual CDD	988	826	162	1,183	1,010	173
10-Year Average CDD ("Normal")	945	966	(21)	1,142	1,161	(19)
Variance from Normal	43	(140)		41	(151)

Natural Gas Distribution Adjusted Gross Margin Growth

Customer growth for our natural gas distribution operations, as a result of the addition of new customers and the conversion of customers from alternative fuel sources to natural gas service, generated $0.9 million and $2.1 million of additional adjusted gross margin for the three and six months ended June 30, 2022. The average number of residential customers served on the

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Delmarva Peninsula increased by 5.7 percent and 5.5 percent for the three and six months ended June 30, 2022, while Florida customers increased by 4.1 percent for both the three and six month periods. A larger percentage of the adjusted gross margin growth was generated from residential growth given the expansion of natural gas into new housing communities and conversions to natural gas as our distribution infrastructure continues to build out. We anticipate continued customer growth, as new communities continue to build out due to population growth and additional infrastructure is added to support the growth. The details for the three and six months ended June 30, 2022 are provided in the following table:

	Three Months Ended				Six Months Ended
	June 30, 2022				June 30, 2022
(in thousands)	Delmarva Peninsula		Florida		Delmarva Peninsula		Florida
Customer Growth:
Residential	$	552	$	223	$	1,256	$	494
Commercial and industrial	68		95		159		223
Total Customer Growth	$	620	$	318	$	1,415	$	717

Regulated Energy Segment

For the quarter ended June 30, 2022, compared to the quarter ended June 30, 2021:

	Three Months Ended
	June 30,				Increase
	2022		2021		(decrease)
(in thousands)
Revenue	$	92,193	$	80,910	$	11,283
Regulated natural gas and electric costs	21,573		14,447		7,126
Adjusted gross margin (1)	70,620		66,463		4,157
Operations & maintenance	26,489		26,930		(441)
Depreciation & amortization	13,140		11,830		1,310
Other taxes	5,150		4,943		207
Total operating expenses	44,779		43,703		1,076
Operating income	$	25,841	$	22,760	$	3,081

(1) Adjusted Gross Margin is a non-GAAP measure utilized by Management to review business unit performance. For a more detailed discussion on the differences between Gross Margin (GAAP) and Adjusted Gross Margin, see the Reconciliation of GAAP to Non-GAAP Measures presented above.

Operating income for the Regulated Energy segment for the second quarter of 2022 was $25.8 million, an increase of $3.1 million, or 13.5 percent, over the same period in 2021. Higher operating income reflects continued pipeline expansions by Eastern Shore, Peninsula Pipeline and Aspire Energy Express, incremental contributions from regulated infrastructure programs, organic growth in our natural gas distribution businesses, increased customer consumption, and operating results from the Escambia Meter Station acquisition completed in 2021. Operating expenses increased by $1.1 million compared to the prior year quarter due to higher depreciation, amortization and property taxes and increased vehicle expense resulting from higher fuel costs. The increase was partially offset by reductions in various areas including facilities, maintenance and outside services costs, as well as a lower level of payroll and benefits expenses.

Items contributing to the quarter-over-quarter increase in adjusted gross margin are listed in the following table:

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(in thousands)
Natural gas transmission service expansions	$	1,291
Contributions from regulated infrastructure programs	1,080
Natural gas growth (excluding service expansions)	938
Changes in customer consumption	636
Escambia Meter Station acquisition	166
Other variances	46
Quarter-over-quarter increase in adjusted gross margin	$	4,157

The following narrative discussion provides further detail and analysis of the significant items in the foregoing table.

Natural Gas Transmission Service Expansions

We generated increased adjusted gross margin of $1.3 million for the three months ended June 30, 2022 from natural gas transmission service expansions including, Peninsula Pipeline's Western Palm Beach County project, Eastern Shore's Del-Mar Energy Pathway project and the Guernsey pipeline expansion.

Contributions from Regulated Infrastructure Programs

Contributions from regulated infrastructure programs generated incremental adjusted gross margin of $1.1 million in the second quarter of 2022. The increase in adjusted gross margin was primarily related to continued investment in the Florida GRIP, Eastern Shore's capital surcharge program and the Elkton Gas STRIDE Plan. Refer to Note 5, Rates and Other Regulatory Activities, in the condensed consolidated financial statements for additional information.

Natural Gas Distribution Customer Growth

We generated additional adjusted gross margin of $0.9 million from natural gas customer growth. Adjusted gross margin increased by $0.3 million in Florida and $0.6 million on the Delmarva Peninsula for the three months ended June 30, 2022, as compared to the same period in 2021, due primarily to residential customer growth of 4.1 percent and 5.7 percent in Florida and on the Delmarva Peninsula, respectively.

Changes in Customer Consumption

Increased customer consumption contributed additional adjusted gross margin of $0.6 million in the second quarter of 2022.

Acquisitions

Adjusted gross margin increased by $0.2 million due to the acquisition of the Escambia Meter Station which was consummated in June 2021.

Operating Expenses

Items contributing to the quarter-over-quarter increase in operating expenses are listed in the following table:

(in thousands)
Depreciation, amortization and property taxes	$	1,643
Vehicle expenses	207
Facilities maintenance costs and outside services	(635)
Payroll, benefits and other employee related costs	(506)
Other variances	367
Quarter-over-quarter increase in operating expenses	$	1,076

For the six months ended June 30, 2022, compared to the six months ended June 30, 2021:

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	Six Months Ended
	June 30,				Increase
	2022		2021		(decrease)
(in thousands)
Revenue	$	220,084	$	202,107	$	17,977
Regulated natural gas and electric costs	67,016		57,491		9,525
Adjusted gross margin (1)	153,068		144,616		8,452
Operations & maintenance	55,621		55,093		528
Depreciation & amortization	26,225		23,860		2,365
Other taxes	10,683		10,197		486
Total operating expenses	92,529		89,150		3,379
Operating income	$	60,539	$	55,466	$	5,073

(1) Adjusted Gross Margin is a non-GAAP measure utilized by Management to review business unit performance. For a more detailed discussion on the differences between Gross Margin (GAAP) and Adjusted Gross Margin, see the Reconciliation of GAAP to Non-GAAP Measures presented above.

Operating income for the Regulated Energy segment for the six months ended June 30, 2022 was $60.5 million, an increase of $5.1 million, or 9.1 percent, over the same period in 2021. Higher operating income reflects continued pipeline expansions by Eastern Shore, Peninsula Pipeline and Aspire Energy Express, organic growth in our natural gas distribution businesses, incremental contributions from regulated infrastructure programs, increased customer consumption, and operating results from the Escambia Meter Station acquisition completed in 2021. Operating expenses increased by $3.4 million compared to the prior year due to higher depreciation, amortization and property taxes, payroll, benefits and other employee related expenses.

Items contributing to the period-over-period increase in adjusted gross margin are listed in the following table:

(in thousands)
Natural gas transmission service expansions	$	2,518
Natural gas growth (excluding service expansions)	2,132
Contributions from regulated infrastructure programs	2,004
Changes in customer consumption	449
Escambia Meter Station acquisition	416
Other variances	933
Period-over-period increase in adjusted gross margin	$	8,452

The following narrative discussion provides further detail and analysis of the significant items in the foregoing table.

Natural Gas Transmission Service Expansions

We generated increased adjusted gross margin of $2.5 million for the six months ended June 30, 2022 from natural gas transmission service expansions including, Peninsula Pipeline's Western Palm Beach County project, Eastern Shore's Del-Mar Energy Pathway project and the Guernsey pipeline expansion.

Natural Gas Distribution Customer Growth

We generated additional adjusted gross margin of $2.1 million from natural gas customer growth. Adjusted gross margin increased by $0.7 million in Florida and $1.4 million on the Delmarva Peninsula for the six months ended June 30, 2022, as compared to the same period in 2021, due primarily to residential customer growth of 4.1 percent and 5.5 percent in Florida and on the Delmarva Peninsula, respectively.

Contributions from Regulated Infrastructure Programs

Contributions from regulated infrastructure programs generated incremental adjusted gross margin of $2.0 million for the six months ended June 30, 2022. The increase in adjusted gross margin was primarily related to continued investment in the Florida GRIP, Eastern Shore's capital surcharge program and the Elkton Gas STRIDE Plan. Refer to Note 5, Rates and Other Regulatory Activities, in the condensed consolidated financial statements for additional information.

Changes in Customer Consumption

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Increased customer consumption contributed additional adjusted gross margin of $0.4 million for the six months ended June 30, 2022.

Acquisitions

Adjusted gross margin increased by $0.4 million due to the acquisition of the Escambia Meter Station which was consummated in June 2021.

Operating Expenses

Items contributing to the period-over-period increase in operating expenses are listed in the following table:

(in thousands)
Depreciation, amortization and property taxes	$	2,977
Customer service related costs	414
Payroll, benefits and other employee-related expenses	188
Other variances	(200)
Period-over-period increase in operating expenses	$	3,379

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Unregulated Energy Segment

For the quarter ended June 30, 2022, compared to the quarter ended June 30, 2021:

	Three Months Ended
	June 30,				Increase
	2022		2021		(decrease)
(in thousands)
Revenue	$	53,463	$	34,773	$	18,690
Unregulated propane and natural gas costs	31,701		16,821		14,880
Adjusted gross margin (1)	21,762		17,952		3,810
Operations & maintenance	16,127		14,037		2,090
Depreciation & amortization	4,074		3,456		618
Other taxes	1,001		924		77
Total operating expenses	21,202		18,417		2,785
Operating Income (loss)	$	560	$	(465)	$	1,025

(1) Adjusted Gross Margin is a non-GAAP measure utilized by Management to review business unit performance. For a more detailed discussion on the differences between Gross Margin (GAAP) and Adjusted Gross Margin, see the Reconciliation of GAAP to Non-GAAP Measures presented above.

Operating results for the Unregulated Energy segment for the second quarter of 2022 increased by $1.0 million compared to the same period in 2021. The operating results for this segment typically are impacted by seasonal variances, with the first and fourth quarters generating a significantly larger portion of adjusted gross margin as a result of colder temperatures generally contributing to higher customer demand. Operating results for the second and third quarters historically have been lower due to reduced customer demand during the warmer periods of the year. The impact to operating income may not align with the seasonal variations as many of the operating expenses are recognized ratably over the course of the year.

Higher operating results during the second quarter were driven by contributions from the acquisition of Diversified Energy, increased propane margins including higher service fees, increased demand for CNG from Marlin Gas Services and margin improvement from Aspire Energy. Additionally, we experienced increased operating expenses associated with the acquisition of Diversified Energy as well as depreciation, amortization and property taxes and increased vehicle expenses due to rising fuel costs.

Items contributing to the quarter-over-quarter increase in adjusted gross margin are listed in the following table:

(in thousands)
Propane Operations
Diversified Energy acquisition (completed in December 2021)	$	1,491
Increased propane margins and service fees	1,104
Marlin Gas Services
Increased demand for CNG services	547
Aspire Energy
Increased margins - rate changes and natural gas liquid processing	203
Other variances	465
Quarter-over-quarter increase in adjusted gross margin	$	3,810

The following narrative discussion provides further detail and analysis of the significant items in the foregoing table.

Propane Operations

•Acquisition of Diversified Energy - Adjusted gross margin increased by $1.5 million due to the acquisition of Diversified Energy, which was acquired by Sharp in December 2021.

•Increased Retail Propane Margins and Service Fees - Adjusted gross margin increased by $1.1 million for the three months ended June 30, 2022, mainly due to increased customer service fees. Propane margins also increased due to gains with our SWAP agreements. These market conditions, which include market pricing and competition with other

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propane suppliers, as well as the availability and price of alternative energy sources, may fluctuate based on changes in demand, supply and other energy commodity prices.

Marlin Gas Services

•Increased demand for CNG services - Adjusted gross margin increased by $0.5 million during the second quarter as compared to the same period in the prior year due to higher demand for CNG hold services.

Aspire Energy

•Increased Margins - Adjusted gross margin increased by $0.2 million during the second quarter of 2022 over the same period in 2021, including rate changes and improvements from natural gas liquid processing.

Operating Expenses

Items contributing to the quarter-over-quarter increase in operating expenses are listed in the following table:

(in thousands)
Operating expenses from the Diversified Energy acquisition	$	2,258
Increased depreciation, amortization and property tax costs	264
Increased vehicle expenses due to higher fuel costs	199
Other variances	64
Quarter-over-quarter increase in operating expenses	$	2,785

Diversified Energy's operating results reflected lower adjusted gross margins during the second quarter of 2022 which is in line with the seasonality typically experienced during the second and third quarters by our legacy propane distribution businesses.

For the six months ended June 30, 2022, compared to the six months ended June 30, 2021:

	Six Months Ended
	June 30,				Increase
	2022		2021		(decrease)
(in thousands)
Revenue	$	154,754	$	109,532	$	45,222
Unregulated propane and natural gas costs	89,708		52,804		36,904
Adjusted gross margin (1)	65,046		56,728		8,318
Operations & maintenance	34,211		29,263		4,948
Depreciation & amortization	7,954		6,780		1,174
Other taxes	2,268		2,110		158
Total operating expenses	44,433		38,153		6,280
Operating Income	$	20,613	$	18,575	$	2,038

(1) Adjusted Gross Margin is a non-GAAP measure utilized by Management to review business unit performance. For a more detailed discussion on the differences between Gross Margin (GAAP) and Adjusted Gross Margin, see the Reconciliation of GAAP to Non-GAAP Measures presented above.

Operating results for the Unregulated Energy segment for the for the six months ended June 30, 2022 increased by $2.0 million or, 11.0 percent compared to the same period in 2021.

Higher operating results during the first half of 2022 were driven by contributions from the acquisition of Diversified Energy, increased propane margins including higher service fees margin, increased demand for CNG from Marlin Gas Services and margin improvement from Aspire Energy. These increases were partially offset by reduced consumption in our propane operations. Additionally, we experienced increased operating expenses associated with the acquisition of Diversified Energy as well as increased payroll, benefits and employee related expenses, depreciation, amortization and property taxes, and increased vehicle expenses due to rising fuel costs.

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Items contributing to the period-over-period increase in adjusted gross margin are listed in the following table:

(in thousands)
Propane Operations
Diversified Energy acquisition (completed in December 2021)	$	5,466
Increased propane margins and service fees	1,823
Decreased customer consumption - intra-quarter weather volatility	(577)
Decreased customer consumption due to conversion of customers to our natural gas system	(478)
Marlin Gas Services
Increased demand for CNG services	612
Aspire Energy
Increased margins - rate changes and natural gas liquid processing	1,131
Increased customer consumption - primarily weather related	465
Other variances	(124)
Period-over-period increase in adjusted gross margin	$	8,318

The following narrative discussion provides further detail and analysis of the significant items in the foregoing table.

Propane Operations

•Acquisition of Diversified Energy - Adjusted gross margin increased by $5.5 million due to the acquisition of Diversified Energy, which was acquired by Sharp in December 2021.

•Increased Retail Propane Margins and Service Fees - Adjusted gross margin increased by $1.8 million for the six months ended June 30, 2022, mainly due to increased customer service fees. Propane margins also increased due to gains with our SWAP agreements. These market conditions, which include market pricing and competition with other propane suppliers, as well as the availability and price of alternative energy sources, may fluctuate based on changes in demand, supply and other energy commodity prices.

•Decreased Customer Consumption due to weather - Adjusted gross margin decreased by $0.6 million due to reduced customer consumption during the first quarter of 2022 compared to the same period in 2021 due to intra-quarter weather volatility.

•Decreased customer consumption due to conversion of customers to natural gas - Adjusted gross margin decreased by $0.5 million as more customers converted from propane to natural gas.

Marlin Gas Services

•Increased demand for CNG services - Adjusted gross margin increased by $0.6 million during the second quarter as compared to the same period in the prior year due to higher demand for CNG hold services.

Aspire Energy

•Increased Margins - Adjusted gross margin increased by $1.1 million during the second quarter of 2022 over the same period in 2021, including rate changes and improvements from natural gas liquid processing.

•Increased Customer Consumption Primarily Weather Related - Adjusted gross margin increased by $0.5 million due to higher consumption of gas as weather in Ohio was approximately 2 percent colder for the six months ended June 30, 2022 over the same period in 2021.

Operating Expenses

Items contributing to the period-over-period increase in operating expenses are listed in the following table:

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(in thousands)
Operating expenses from the Diversified Energy acquisition	$	4,708
Increased payroll, benefits and other employee-related expenses	607
Increased depreciation, amortization and property tax costs	476
Increased vehicle expenses due to higher fuel costs	385
Other variances	104
Period-over-period increase in operating expenses	$	6,280

OTHER INCOME, NET

For the quarter ended June 30, 2022 compared to the quarter ended June 30, 2021

Other income, net, which includes non-operating investment income, interest income, late fees charged to customers, gains or losses from the sale of assets and pension and other benefits expense, increased by $1.1 million in the second quarter of 2022, compared to the same period in 2021. The increase was primarily due to gains recognized on the sale of assets.

For the six months ended June 30, 2022 compared to the six months ended June 30, 2021

Other income, net, which includes non-operating investment income, interest income, late fees charged to customers, gains or losses from the sale of assets and pension and other benefits expense, increased by $1.7 million in the six months of 2022, compared to the same period in 2021. The increase was primarily due to gains recognized on the sale of assets.

INTEREST CHARGES

For the quarter ended June 30, 2022 compared to the quarter ended June 30, 2021

Interest charges for the three months ended June 30, 2022 increased by $0.8 million, compared to the same period in 2021, attributable primarily to an increase of $0.6 million in interest expense as a result of a long-term debt placement in 2022, $0.1 million due to lower capitalized interest associated with growth projects, $0.1 million related to amounts assessed by state and local taxing authorities, and $0.1 million of an amortization credit/increase in interest expense associated with a regulatory liability that was established in connection with the Hurricane Michael regulatory proceeding settlement in 2020. Partially offsetting the interest charges was a $0.1 million decrease in lower interest expense from lower levels of outstanding borrowings under our Revolver. During the second quarter of 2022, the interest rate associated with our Revolver increased by 1.22 percent as a result of Federal Reserve raising interest rates. Any additional increases in interest rates by the Federal Reserve would have a corresponding increase in the interest rates charged under our Revolver.

For the six months ended June 30, 2022 compared to the six months ended June 30, 2021

Interest charges for the six months ended June 30, 2022 increased by $1.0 million, compared to the same period in 2021, attributable primarily to an increase of $0.9 million in interest expense as a result of a long-term debt placement in 2022, $0.2 million due to lower capitalized interest associated with growth projects, $0.1 million related to amounts assessed by state and local taxing authorities, and $0.1 million of an amortization credit/increase in interest expense associated with a regulatory liability that was established in connection with the Hurricane Michael regulatory proceeding settlement in 2020. Partially offsetting the interest charges was a $0.3 million decrease in lower interest expense from lower levels of outstanding borrowings under our Revolver. During the first six months of 2022, the interest rate associated with our Revolver increased by 1.56 percent as a result of Federal Reserve raising interest rates. Any additional increases in interest rates by the Federal Reserve would have a corresponding increase in the interest rates charged under our Revolver.

INCOME TAXES

For the quarter ended June 30, 2022 compared to the quarter ended June 30, 2021

Income tax expense was $6.2 million for the quarter ended June 30, 2022, compared to $5.2 million for the quarter ended June 30, 2021. Our effective income tax rate was 26.6 percent and 27.2 percent, for the three months ended June 30, 2022 and 2021, respectively.

For the six months ended June 30, 2022 compared to the six months ended June 30, 2021

Income tax expense was $19.7 million for the six months ended June 30, 2022, compared to $17.6 million for the six months ended June 30, 2021. Our effective income tax rate was 26.7 percent for both the six months ended June 30, 2022 and 2021, respectively.

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FINANCIAL POSITION, LIQUIDITY AND CAPITAL RESOURCES

Our capital requirements reflect the capital-intensive and seasonal nature of our business and are principally attributable to investment in new plant and equipment, retirement of outstanding debt and seasonal variability in working capital. We rely on cash generated from operations, short-term borrowings, and other sources to meet normal working capital requirements and to temporarily finance capital expenditures. We may also issue long-term debt and equity to fund capital expenditures and to maintain our capital structure within our target capital structure range. We maintain an effective shelf registration statement with the SEC for the issuance of shares of common stock in various types of equity offerings, including shares of common stock under our ATM equity program, as well as an effective registration statement with respect to the DRIP. Depending on our capital needs and subject to market conditions, in addition to other possible debt and equity offerings, we may consider issuing additional shares under the direct share purchase component of the DRIP and/or under the ATM equity program.

Our energy businesses are weather-sensitive and seasonal. We normally generate a large portion of our annual net income and subsequent increases in our accounts receivable in the first and fourth quarters of each year due to significant volumes of natural gas, electricity, and propane delivered by our distribution operations, and our natural gas transmission operations to customers during the peak-heating season. In addition, our natural gas and propane inventories, which usually peak in the fall months, are largely drawn down in the heating season and provide a source of cash as the inventory is used to satisfy winter sales demand.

Capital expenditures for investments in new or acquired plant and equipment are our largest capital requirements. Our capital expenditures were $61.0 million for the six months ended June 30, 2022. In the table below, we have provided an updated range of our forecasted capital expenditures for 2022:

	2022
(dollars in thousands)	Low		High
Regulated Energy:
Natural gas distribution	$	72,000	$	81,000
Natural gas transmission	32,000		36,000
Electric distribution	7,000		12,000
Total Regulated Energy	111,000		129,000
Unregulated Energy:
Propane distribution	10,000		14,000
Energy transmission	7,000		10,000
Other unregulated energy	10,000		18,000
Total Unregulated Energy	27,000		42,000
Other:
Corporate and other businesses	2,000		4,000
Total Other	2,000		4,000
Total 2022 Forecasted Capital Expenditures	$	140,000	$	175,000

The 2022 forecast, excluding acquisitions, includes capital expenditures associated with the following: Pipeline expansions related to the Eastern Shore Southern Expansion project and the Florida Beachside Pipeline as well as amounts for the expansion into Somerset County, Maryland. Furthermore, the 2022 forecast includes continued expenditures under the Florida GRIP, the capital cost surcharge program and the Elkton Gas STRIDE program as well as further expansion of our natural gas distribution and transmission systems, information technology systems, and other strategic initiatives and investments.

The capital expenditure projection is subject to continuous review and modification. During the first half of 2022, the Company experienced a reduced level of new capital investments due to regulatory delays and supply chain disruptions. As a result, the Company is decreasing its capital expenditure guidance range to $140 million to $175 million for 2022. The Company expects these delays in timing to be temporary.Actual capital requirements may vary from the above estimates due to a number of factors, including changing economic conditions, supply chain disruptions, capital delays that are greater than currently anticipated, customer growth in existing areas, regulation, new growth or acquisition opportunities and availability of capital. Historically, actual capital expenditures have typically lagged behind the budgeted amounts.

The timing of capital expenditures can vary based on delays in regulatory approvals, securing environmental approvals and other permits. The regulatory application and approval process has lengthened in the past few years, and we expect this trend to continue.

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Capital Structure

We are committed to maintaining a sound capital structure and strong credit ratings. This commitment, along with adequate and timely rate relief for our regulated energy operations, is intended to ensure our ability to attract capital from outside sources at a reasonable cost, which will benefit our customers, creditors, employees and stockholders.

The following table presents our capitalization, excluding and including short-term borrowings, as of June 30, 2022 and December 31, 2021:

	June 30, 2022				December 31, 2021
(in thousands)
Long-term debt, net of current maturities	$	585,805	42	%	$	549,903	42	%
Stockholders’ equity	815,701		58	%	774,130		58	%
Total capitalization, excluding short-term debt	$	1,401,506	100	%	$	1,324,033	100	%
	June 30, 2022				December 31, 2021
(in thousands)
Short-term debt	$	137,024	9	%	$	221,634	14	%
Long-term debt, including current maturities	607,277		39	%	567,865		36	%
Stockholders’ equity	815,701		52	%	774,130		50	%
Total capitalization, including short-term debt	$	1,560,002	100	%	$	1,563,629	100	%

Our target ratio of equity to total capitalization, including short-term borrowings, is between 50 and 60 percent. Our equity to total capitalization ratio, including short-term borrowings, was 52 percent as of June 30, 2022. We seek to align permanent financing with the in-service dates of our capital projects. We may utilize more temporary short-term debt when the financing cost is attractive as a bridge to the permanent long-term financing or if the equity markets are volatile.

In 2022, we issued less than 0.1 million shares at an average price per share of $137.24 and received net proceeds of $4.3 million under the DRIP. See Note 9, Stockholders’ Equity, in the condensed consolidated financial statements for additional information on commissions and fees paid in connection with these issuances.

Shelf Agreements

We have entered into Shelf Agreements with Prudential and MetLife, whom are under no obligation to purchase any unsecured debt. The following table summarizes our Shelf Agreements at June 30, 2022:

(in thousands)	Total Borrowing Capacity		Less: Amount of Debt Issued		Less: Unfunded Commitments		Remaining Borrowing Capacity
Shelf Agreement
Prudential Shelf Agreement (1)	$	370,000	$	(220,000)	$	—	$	150,000
MetLife Shelf Agreement (1)	150,000		(50,000)		—		100,000
Total Shelf Agreements as of March 31, 2022	$	520,000	$	(270,000)	$	—	$	250,000

(1) The Prudential and MetLife Shelf Agreements expire in April 2023 and May 2023.

The Senior Notes, Shelf Agreements or Shelf Notes set forth certain business covenants to which we are subject when any note is outstanding, including covenants that limit or restrict our ability, and the ability of our subsidiaries, to incur indebtedness, or place or permit liens and encumbrances on any of our property or the property of our subsidiaries.

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Short-term Borrowings

We are authorized by our Board of Directors to borrow up to $400.0 million of short-term debt, as required. At June 30, 2022 and December 31, 2021, we had $137.0 million and $221.6 million, respectively, of short-term borrowings outstanding at a weighted average interest rate of 2.38 percent and 0.83 percent respectively.

In August 2021 we amended and restated our Revolver into a multi-tranche facility totaling $400.0 million with multiple participating lenders. The two tranches of the facility consist of one $200.0 million 364-day short-term debt tranche and a $200.0 million five-year tranche, both of which have three one-year extension options, which can be authorized by the Chief Financial Officer. We are eligible to establish the repayment term for individual borrowings under the five year tranche of the facility and to the extent that an individual loan under the revolver exceeded 12 months, the outstanding balance would be classified as a component of long-term debt.

The availability of funds under the Revolver is subject to conditions specified in the credit agreement, all of which we currently satisfy. These conditions include our compliance with financial covenants and the continued accuracy of representations and warranties contained in these agreements. We are required by the financial covenants in the Revolver to maintain, at the end of each fiscal year, a funded indebtedness ratio of no greater than 65 percent. As of June 30, 2022, we are in compliance with this covenant.

The 364-day tranche of the Revolver expires in August 2022 and the five-year tranche expires in August 2026. Both tranches are available to fund our short-term cash needs to meet seasonal working capital requirements and to temporarily fund portions of our capital expenditures. Borrowings under both tranches of the Revolver are subject to a pricing grid, including the commitment fee and the interest rate charged. Our pricing is adjusted each quarter based upon total indebtedness to total capitalization ratio. As of June 30, 2022, the pricing under the 364-day tranche of the Revolver does not include an unused commitment fee and maintains an interest rate of 0.70 percent over LIBOR. As of June 30, 2022, the pricing under the five-year tranche of the Revolver included an unused commitment fee of 0.09 percent and an interest rate of 0.95 percent over LIBOR.

We are currently in discussions with the various lending institutions regarding the renewal of the 364-day tranche. At that time, the reference interest rate for the 364-day and five-year tranche will transition from LIBOR which is being retired by financial institutions to the Standard Overnight Financing Rate ("SOFR"). We do not expect this transition to have a material impact on our financial condition.

Our total available credit under the Revolver at June 30, 2022 was $257.7 million. As of June 30, 2022, we had issued $5.3 million in letters of credit to various counterparties under the syndicated Revolvers. These letters of credit are not included in the outstanding short-term borrowings and we do not anticipate that they will be drawn upon by the counterparties. The letters of credit reduce the available borrowings under our syndicated Revolver.

In the fourth quarter of 2020, we entered into two $30.0 million interest rate swaps with a total notional amount of $60.0 million through December 2021 with pricing of 0.205 and 0.20 percent, respectively. In February 2021, we entered into an additional interest rate swap with a notional amount of $40.0 million through December 2021 with pricing of 0.17 percent. Our short-term borrowing is based on the 30-day LIBOR rate. At December 31, 2021, all of our interest rate swaps had expired and we have not entered into any new derivative contracts associated with our outstanding short-term borrowings.

Long-Term Debt

On March 15, 2022 we issued 2.95 percent Senior Notes due March 15, 2042 to MetLife in the aggregate principal amount of $50 million. We used the proceeds received from the issuances of the Senior Notes to reduce short-term borrowings under our Revolver and to fund capital expenditures. These Senior Notes have similar covenants and default provisions as the existing senior notes, and have an annual principal payment beginning in the eleventh year after the issuance.

57

Cash Flows

The following table provides a summary of our operating, investing and financing cash flows for the six months ended June 30, 2022 and 2021:

	Six Months Ended
	June 30,
(in thousands)	2022		2021
Net cash provided by (used in):
Operating activities	$	123,795	$	134,216
Investing activities	(64,167)		(104,529)
Financing activities	(60,418)		(28,175)
Net increase in cash and cash equivalents	(790)		1,512
Cash and cash equivalents—beginning of period	4,976		3,499
Cash and cash equivalents—end of period	$	4,186	$	5,011

Cash Flows Provided By Operating Activities

Changes in our cash flows from operating activities are attributable primarily to changes in net income, adjusted for non-cash items such as depreciation and changes in deferred income taxes, and working capital. Working capital requirements are determined by a variety of factors, including weather, the prices of natural gas, electricity and propane, the timing of customer collections, payments for purchases of natural gas, electricity and propane, and deferred fuel cost recoveries.

During the six months ended June 30, 2022, net cash provided by operating activities was $123.8 million. Operating cash flows were primarily impacted by the following:

•Net income, adjusted for non-cash adjustments, provided a $92.0 million source of cash;

•An increased level of deferred taxes associated with incremental tax depreciation from growth investments resulted in a source of cash of $11.4 million;

•Changes in net regulatory assets and liabilities due primarily to the change in fuel costs collected through the various cost recovery mechanisms resulted in a $6.4 million outflow of cash;

•Other working capital changes, impacted primarily by propane inventory purchases and hedging activities, resulted in a $21.7 million use of cash; and

•A decrease in income tax receivables increased cash inflows by $5.1 million.

Cash Flows Used in Investing Activities

Net cash used in investing activities totaled $64.2 million during the six months ended June 30, 2022, largely driven by $65.1 million for new capital expenditures.

Cash Flows Used in Financing Activities

Net cash used in financing activities totaled $60.4 million during the six months ended June 30, 2022. Net cash used in financing activities:

•Repayments under lines of credit resulted in a use of cash of $83.4 million;

•Net increase in long-term debt borrowings resulted in a source of cash of $39.4 million to permanently finance investment in growth initiatives, $49.9 million, offset by long-term repayments of $10.5 million;

•Source of cash of $4.3 million from issuance of stock under the DRIP; and

•A use of cash of $16.6 million for dividend payments in 2022.

Off-Balance Sheet Arrangements

The Board of Directors has authorized us to issue corporate guarantees securing obligations of our subsidiaries and to obtain letters of credit securing our subsidiaries' obligations. The maximum authorized liability under such guarantees and letters of credit as of June 30, 2022 was $20.0 million. The aggregate amount guaranteed related to our subsidiaries at June 30, 2022 was $11.4 million, with the guarantees expiring on various dates through May 22, 2023. In addition, the Board has authorized us to issue specific

58

purpose corporate guarantees. The amount of specific purpose guarantees outstanding at June 30, 2022 was $2.0 million. In July 2022, in connection with the Florida rate case, we entered into a guarantee in the amount of $7.1 million with the Florida PSC.

As of June 30, 2022, we have issued letters of credit totaling approximately $5.3 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, to our current and previous primary insurance carriers. These letters of credit have various expiration dates through October 25, 2022. We have not drawn upon these letters of credit as of June 30, 2022 and do not anticipate that the counterparties will draw upon these letters of credit. We expect that they will be renewed to the extent necessary in the future. Additional information is presented in Note 7, Other Commitments and Contingencies, in the condensed consolidated financial statements.

Contractual Obligations

There has been no material change in the contractual obligations presented in our 2021 Annual Report on Form 10-K, except for commodity purchase obligations entered into in the ordinary course of our business. The following table summarizes commodity purchase contract obligations at June 30, 2022:

	Payments Due by Period
	Less than 1 year		1 - 3 years		3 - 5 years		More than 5 years		Total
(in thousands)
Purchase obligations - Commodity (1)	$	45,935	$	40,058	$	—	$	—	$	85,993
Total	$	45,935	$	40,058	$	—	$	—	$	85,993

(1) In addition to the obligations noted above, we have agreements with commodity suppliers that have provisions with no minimum purchase requirements. There are no monetary penalties for reducing the amounts purchased; however, the propane contracts allow the suppliers to reduce the amounts available in the winter season if we do not purchase specified amounts during the summer season. Under these contracts, the commodity prices will fluctuate as market prices fluctuate.

Rates and Regulatory Matters

Our natural gas distribution operations in Delaware, Maryland and Florida and electric distribution operation in Florida are subject to regulation by the respective state PSC; Eastern Shore is subject to regulation by the FERC; and Peninsula Pipeline and Aspire Energy Express, our intrastate pipeline subsidiaries, are subject to regulation (excluding cost of service) by the Florida PSC and Public Utilities Commission of Ohio, respectively. We regularly are involved in regulatory matters in each of the jurisdictions in which we operate. Our significant regulatory matters are fully described in Note 5, Rates and Other Regulatory Activities, to the condensed consolidated financial statements in this Quarterly Report on Form 10-Q.

Recent Authoritative Pronouncements on Financial Reporting and Accounting

Recent accounting developments, applicable to us, and their impact on our financial position, results of operations and cash flows are described in Note 1, Summary of Accounting Policies, to the condensed consolidated financial statements in this Quarterly Report on Form 10-Q.

59

Item 3. Quantitative and Qualitative Disclosures about Market Risk

INTEREST RATE RISK

Long-term debt is subject to potential losses based on changes in interest rates. We evaluate whether to refinance existing debt or permanently refinance existing short-term borrowings based in part on the fluctuation in interest rates. Increases in interest rates expose us to potential increased costs we could incur when we (i) issue new debt instruments or (ii) provide financing and liquidity for our business activities. We utilize interest rate swap agreements to mitigate short-term borrowing rate risk. Additional information about our long-term debt and short-term borrowing is disclosed in Note 15, Long-Term Debt, and Note 16, Short-Term Borrowings, respectively, in the condensed consolidated financial statements.

COMMODITY PRICE RISK

Regulated Energy Segment

We have entered into agreements with various wholesale suppliers to purchase natural gas and electricity for resale to our customers. Our regulated energy distribution businesses that sell natural gas or electricity to end-use customers have fuel cost recovery mechanisms authorized by the respective PSCs that allow us to recover all of the costs prudently incurred in purchasing natural gas and electricity for our customers. Therefore, our regulated energy distribution operations have limited commodity price risk exposure.

Unregulated Energy Segment

Our propane operations are exposed to commodity price risk as a result of the competitive nature of retail pricing offered to our customers. In order to mitigate this risk, we utilize propane storage activities and forward contracts for supply.

We can store up to approximately 8.9 million gallons of propane (including leased storage and rail cars) during the winter season to meet our customers’ peak requirements and to serve metered customers. Decreases in the wholesale price of propane may cause the value of stored propane to decline, particularly if we utilize fixed price forward contracts for supply. To mitigate the risk of propane commodity price fluctuations on the inventory valuation, we have adopted a Risk Management Policy that allows our propane distribution operation to enter into fair value hedges, cash flow hedges or other economic hedges of our inventory.

Aspire Energy is exposed to commodity price risk, primarily during the winter season, to the extent we are not successful in balancing our natural gas purchases and sales and have to secure natural gas from alternative sources at higher spot prices. In order to mitigate this risk, we procure firm capacity that meets our estimated volume requirements and we continue to seek out new producers in order to fulfill our natural gas purchase requirements.

The following table reflects the changes in the fair market value of financial derivatives contracts related to propane purchases and sales from December 31, 2021 to June 30, 2022:

(in thousands)	Balance at December 31, 2021		Increase (Decrease) in Fair Market Value		Less Amounts Settled		Balance at June 30, 2022
Sharp	$	6,334	$	(3,050)	$	3,061	$	6,345

There were no changes in methods of valuations during the six months ended June 30, 2022.

The following is a summary of fair market value of financial derivatives as of June 30, 2022, by method of valuation and by maturity for each fiscal year period.

(in thousands)	2022		2023		2024		Total Fair Value
Price based on Mont Belvieu - Sharp	$	1,723	$	3,446	$	1,176	$	6,345

60

WHOLESALE CREDIT RISK

The Risk Management Committee reviews credit risks associated with counterparties to commodity derivative contracts prior to such contracts being approved.

Additional information about our derivative instruments is disclosed in Note 13, Derivative Instruments, in the condensed consolidated financial statements.

INFLATION

Inflation affects the cost of supply, labor, products and services required for operations, maintenance and capital improvements. To help cope with the effects of inflation on our capital investments and returns, we periodically seek rate increases from regulatory commissions for our regulated operations and closely monitor the returns of our unregulated energy business operations. To compensate for fluctuations in propane gas prices, we adjust propane sales prices to the extent allowed by the market.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

The Chief Executive Officer and Chief Financial Officer of Chesapeake Utilities, with the participation of other Company officials, have evaluated our “disclosure controls and procedures” (as such term is defined under Rules 13a-15(e) and 15d-15(e), promulgated under the Securities Exchange Act of 1934, as amended) as of June 30, 2022. Based upon their evaluation, the Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of June 30, 2022.

Changes in Internal Control over Financial Reporting

During the quarter ended June 30, 2022, there was no change in our internal control over financial reporting that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

61

PART II—OTHER INFORMATION

Item 1. Legal Proceedings

As disclosed in Note 7, Other Commitments and Contingencies, of the condensed consolidated financial statements in this Quarterly Report on Form 10-Q, we are involved in certain legal actions and claims arising in the normal course of business. We are also involved in certain legal and administrative proceedings before various governmental or regulatory agencies concerning rates and other regulatory actions. In the opinion of management, the ultimate disposition of these proceedings and claims will not have a material effect on our condensed consolidated financial position, results of operations or cash flows.

Item 1A. Risk Factors

Our business, operations, and financial condition are subject to various risks and uncertainties. The risk factors described in Part I, “Item 1A. Risk Factors” in our Annual Report on Form 10-K, for the year ended December 31, 2021, should be carefully considered, together with the other information contained or incorporated by reference in this Quarterly Report on Form 10-Q and in our other filings with the SEC in connection with evaluating Chesapeake Utilities, our business and the forward-looking statements contained in this Quarterly Report on Form 10-Q.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds 

	Total Number of Shares	Average Price Paid		Total Number of Shares Purchased as Part of Publicly Announced Plans	Maximum Number of Shares That May Yet Be Purchased Under the Plans
Period	Purchased	per Share		or Programs (2)	or Programs (2)
April 1, 2022 through April 30, 2022(1)	368	$	142.10	—	—
May 1, 2022 through May 31, 2022	—	—		—	—
June 1, 2022 through June 30, 2022	—	—		—	—
Total	368	$	142.10	—	—

(1) Chesapeake Utilities purchased shares of common stock on the open market for the purpose of reinvesting the dividend on shares held in the Rabbi Trust accounts for certain directors and senior executives under the Non-Qualified Deferred Compensation Plan. The Non-Qualified Deferred Compensation Plan is discussed in detail in Item 8 under the heading “Notes to the Consolidated Financial Statements—Note 9, Employee Benefit Plans,” in our latest Annual Report on Form 10-K for the year ended December 31, 2021. During the quarter ended June 30, 2022, 368 shares were purchased through the reinvestment of dividends on deferred stock units.

(2) Except for the purposes described in Footnote (1), Chesapeake Utilities has no publicly announced plans or programs to repurchase its shares.

Item 3. Defaults upon Senior Securities

None.

Item 5. Other Information

    None.

62

Item 6.     Exhibits

31.1*	Certificate of Chief Executive Officer of Chesapeake Utilities Corporation pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934.
31.2*	Certificate of Chief Financial Officer of Chesapeake Utilities Corporation pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934.
32.1*	Certificate of Chief Executive Officer of Chesapeake Utilities Corporation pursuant to 18 U.S.C. Section 1350.
32.2*	Certificate of Chief Financial Officer of Chesapeake Utilities Corporation pursuant to 18 U.S.C. Section 1350.
101.INS*	XBRL Instance Document.
101.SCH*	XBRL Taxonomy Extension Schema Document.
101.CAL*	XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF*	XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB*	XBRL Taxonomy Extension Label Linkbase Document.
101.PRE*	XBRL Taxonomy Extension Presentation Linkbase Document.
104	Cover Page Interactive Data File - formatted in Inline XBRL and contained in Exhibit 101

*Filed herewith

63

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

CHESAPEAKE UTILITIES CORPORATION

/S/ BETH W. COOPER

Beth W. Cooper
Executive Vice President, Chief Financial Officer, Treasurer and Assistant Corporate Secretary

Date: August 3, 2022

64

EX-31.1

EXHIBIT 31.1

CERTIFICATE PURSUANT TO RULE 13A-14(A)

UNDER THE SECURITIES EXCHANGE ACT OF 1934

I, Jeffry M. Householder, certify that:

1.I have reviewed this quarterly report on Form 10-Q for the quarter ended June 30, 2022 of Chesapeake Utilities Corporation;

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

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

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

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

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

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

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

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

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

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

Date: August 3, 2022

/s/ JEFFRY M. HOUSEHOLDER

Jeffry M. Householder
President and Chief Executive Officer

EX-31.2

EXHIBIT 31.2

CERTIFICATE PURSUANT TO RULE 13A-14(A)

UNDER THE SECURITIES EXCHANGE ACT OF 1934

I, Beth W. Cooper, certify that:

1.I have reviewed this quarterly report on Form 10-Q for the quarter ended June 30, 2022 of Chesapeake Utilities Corporation;

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

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

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

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

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

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

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

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

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

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

Date: August 3, 2022

/S/ BETH W. COOPER

Beth W. Cooper
Executive Vice President, Chief Financial Officer, Treasurer and Assistant Corporate Secretary

EX-32.1

EXHIBIT 32.1

Certificate of Chief Executive Officer

of

Chesapeake Utilities Corporation

(pursuant to 18 U.S.C. Section 1350)

I, Jeffry M. Householder, President and Chief Executive Officer of Chesapeake Utilities Corporation, certify that, to the best of my knowledge, the Quarterly Report on Form 10-Q of Chesapeake Utilities Corporation (“Chesapeake”) for the period ended June 30, 2022, filed with the Securities and Exchange Commission on the date hereof (i) fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended, and (ii) the information contained therein fairly presents, in all material respects, the financial condition and results of operations of Chesapeake.

/s/ JEFFRY M. HOUSEHOLDER

Jeffry M. Householder

August 3, 2022

A signed original of this written statement required by Section 906 of the Sarbanes-Oxley Act of 2002, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to Chesapeake Utilities Corporation and will be retained by Chesapeake Utilities Corporation and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

EXHIBIT 32.2

Certificate of Chief Financial Officer

of

Chesapeake Utilities Corporation

(pursuant to 18 U.S.C. Section 1350)

I, Beth W. Cooper, Executive Vice President, Chief Financial Officer, Treasurer and Assistant Corporate Secretary of Chesapeake Utilities Corporation, certify that, to the best of my knowledge, the Quarterly Report on Form 10-Q of Chesapeake Utilities Corporation (“Chesapeake”) for the period ended June 30, 2022, filed with the Securities and Exchange Commission on the date hereof (i) fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended, and (ii) the information contained therein fairly presents, in all material respects, the financial condition and results of operations of Chesapeake.

/S/ BETH W. COOPER

Beth W. Cooper

August 3, 2022

A signed original of this written statement required by Section 906 of the Sarbanes-Oxley Act of 2002, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to Chesapeake Utilities Corporation and will be retained by Chesapeake Utilities Corporation and furnished to the Securities and Exchange Commission or its staff upon request.

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Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2022	Jul. 29, 2022
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2022
Document Transition Report	false
Entity File Number	001-11590
Entity Registrant Name	CHESAPEAKE UTILITIES CORP
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	51-0064146
Entity Address, Address Line One	500 Energy Lane
Entity Address, City or Town	Dover
Entity Address, State or Province	DE
Entity Address, Postal Zip Code	19901
City Area Code	302
Local Phone Number	734-6799
Title of 12(b) Security	Common Stock - par value per share $0.4867
Trading Symbol	CPK
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		17,737,871
Entity Central Index Key	0000019745
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q2
Amendment Flag	false

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Condensed Consolidated Statements of Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Operating Revenues
Regulated Energy	$ 92,193	$ 80,910	$ 220,084	$ 202,107
Unregulated Energy and other	47,277	30,172	142,266	100,161
Total Operating Revenues	139,470	111,082	362,350	302,268
Operating Expenses
Regulated natural gas and electric costs	21,573	14,447	67,016	57,491
Unregulated propane and natural gas costs	25,543	12,254	77,279	43,506
Operations	38,002	36,371	80,796	75,810
Maintenance	4,507	4,259	8,772	8,300
Depreciation and amortization	17,216	15,298	34,193	30,662
Other taxes	6,160	5,875	12,960	12,324
Total Operating Expenses	113,001	88,504	281,016	228,093
Total operating income	26,469	22,578	81,334	74,175
Other income, net	2,584	1,453	3,498	1,828
Interest charges	5,825	5,054	11,164	10,159
Income Before Income Taxes	23,228	18,977	73,668	65,844
Income Taxes	6,177	5,164	19,683	17,565
Net Income	$ 17,051	$ 13,813	$ 53,985	$ 48,279
Weighted Average Common Shares Outstanding:
Basic (shares)	17,730,833	17,546,346	17,704,592	17,516,273
Diluted (shares)	17,809,871	17,616,496	17,785,629	17,585,006
Earnings Per Share of Common Stock:
Income (Loss) from Continuing Operations, Per Basic Share	$ 0.96	$ 0.79	$ 3.05	$ 2.76
Basic (in dollars per share)	0.96	0.79	3.05	2.76
Earnings Per Share, Diluted [Abstract]
Income (Loss) from Continuing Operations, Per Diluted Share	0.96	0.78	3.04	2.75
Diluted (in dollars per share)	$ 0.96	$ 0.78	$ 3.04	$ 2.75

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Statement of Comprehensive Income [Abstract]
Net Income	$ 17,051	$ 13,813	$ 53,985	$ 48,279
Amortization of prior service cost, net of tax of $(5), $(5), $(10) and $(10), respectively	(14)	(14)	(28)	(28)
Net gain, net of tax of $28, $28, $53 and $55, respectively	(32)	(78)	(63)	(156)
Unrealized gain (loss) on commodity contract cash flow hedges, net of tax of $(188), $1,193, $(4) and $1,257, respectively	(498)	3,126	32	3,291
Unrealized gain/(loss) on interest rate swap cash flow hedges, net of tax of $2, $(14), $1 and $(14), respectively	0	6	0	4
Other comprehensive income (loss)	(480)	3,196	67	3,423
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	$ 16,571	$ 17,009	$ 54,052	$ 51,702

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Condensed Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Statement of Other Comprehensive Income [Abstract]
Amortization of prior service cost, tax	$ (5)	$ (5)	$ (10)	$ (10)
Net gain, tax	11	28	23	53
Unrealized (loss)/gain on commodity contract cash flow hedges, tax	(188)	1,193	(4)	1,257
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Interest Rate Swaps During Period, Tax	$ 0	$ 2	$ 0	$ 1

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Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2022		Dec. 31, 2021
Property, Plant and Equipment
Regulated Energy	$ 1,765,915		$ 1,720,287
Unregulated Energy	381,718		357,259
Other businesses and eliminations	30,713		35,418
Total property, plant and equipment	2,178,346		2,112,964
Less: Accumulated depreciation and amortization	(438,573)		(417,479)
Net property, plant and equipment	1,773,800		1,744,878
Current Assets
Cash and cash equivalents	4,186		4,976
Trade and other receivables	40,134		58,482
Accounts Receivable, Allowance for Credit Loss, Current	(2,758)		(3,141)
Accounts Receivable, before Allowance for Credit Loss, Current	42,892		61,623
Accrued revenue	15,999		22,513
Propane inventory, at average cost	9,317		11,644
Other inventory, at average cost	11,449		9,345
Regulatory assets	28,729		19,794
Storage gas prepayments	3,695		3,691
Income taxes receivable	12,353		17,460
Prepaid expenses	11,398		17,121
Derivative assets, at fair value	6,772		7,076
Other current assets	1,014		1,033
Total current assets	145,046		173,135
Deferred Charges and Other Assets
Goodwill	45,158		44,708
Other intangible assets, net	14,088		13,192
Investments, at fair value	10,523		12,095
Operating Lease, Right-of-Use Asset	15,767		10,139
Regulatory assets	99,497		104,173
Receivables and other deferred charges	13,463		12,549
Total deferred charges and other assets	198,496		196,856
Total Assets	2,117,342		2,114,869
Stockholders’ equity
Preferred stock, par value $0.01 per share (authorized 2,000,000 shares), no shares issued and outstanding	0		0
Common stock, par value $0.4867 per share (authorized 50,000,000 shares)	8,632		8,593
Additional paid-in capital	376,866		371,162
Retained earnings	428,833		393,072
Accumulated other comprehensive income	1,370		1,303
Deferred compensation obligation	7,018		7,240
Treasury stock	(7,018)		(7,240)
Total stockholders’ equity	815,701	[1]	774,130
Total capitalization	1,401,506		1,324,033
Current Liabilities
Less: current maturities	21,472		17,962
Short-term borrowing	137,024		221,634
Accounts payable	38,110		52,628
Customer deposits and refunds	34,489		36,488
Accrued interest	3,320		2,775
Dividends payable	9,488		8,466
Accrued compensation	9,471		15,505
Regulatory liabilities	6,663		2,312
Derivative liabilities, at fair value	427		743
Other accrued liabilities	26,827		17,920
Total current liabilities	287,291		376,433
Deferred Credits and Other Liabilities
Deferred income taxes	244,978		233,550
Regulatory liabilities	143,188		142,488
Environmental liabilities	3,097		3,538
Other pension and benefit costs	21,458		24,120
Operating Lease, Liability, Noncurrent	13,807		8,571
Deferred investment tax credits and other liabilities	2,017		2,136
Total deferred credits and other liabilities	428,545		414,403
Environmental and other commitments and contingencies (Notes 5 and 6)
Total Capitalization and Liabilities	2,117,342		2,114,869
Other businesses and eliminations	30,713		35,418
Property, Plant and Equipment, Gross	2,178,346		2,112,964
Construction Work in Progress	34,027		49,393
Property, Plant and Equipment, Net	1,773,800		1,744,878
Trade and other receivables	40,134		58,482
Income taxes receivable	12,353		17,460
Other current assets	1,014		1,033
Assets, Current	145,046		173,135
Receivables and other deferred charges	13,463		12,549
Deferred Charges And Other Assets	198,496		196,856
Total identifiable assets	2,117,342		2,114,869
Regulated Energy	1,765,915		1,720,287
Unregulated Energy	381,718		357,259
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	438,573		417,479
Cash and cash equivalents	4,186		4,976
Accounts Receivable, before Allowance for Credit Loss, Current	42,892		61,623
Allowance for uncollectible accounts	2,758		3,141
Accrued revenue	15,999		22,513
Propane inventory, at average cost	9,317		11,644
Other inventory, at average cost	11,449		9,345
Regulatory assets	28,729		19,794
Storage gas prepayments	3,695		3,691
Prepaid expenses	11,398		17,121
Derivative assets, at fair value	6,772		7,076
Goodwill	45,158		44,708
Other intangible assets, net	14,088		13,192
Investments, at fair value	10,523		12,095
Operating Lease, Right-of-Use Asset	15,767		10,139
Regulatory assets	99,497		104,173
Preferred stock, par value $0.01 per share (authorized 2,000,000 shares), no shares issued and outstanding	0		0
Stockholders' Equity Attributable to Parent	815,701	[1]	774,130
Capitalization, Long-term Debt and Equity	1,401,506		1,324,033
Accounts payable	38,110		52,628
Other accrued liabilities	26,827		17,920
Liabilities, Current	287,291		376,433
Regulatory liabilities	143,188		142,488
Operating Lease, Liability, Noncurrent	13,807		8,571
Deferred investment tax credits and other liabilities	2,017		2,136
Deferred Credits and Other Liabilities	428,545		414,403
Environmental and other commitments and contingencies (Notes 5 and 6)
Liabilities and Equity	2,117,342		2,114,869
Common stock, par value $0.4867 per share (authorized 50,000,000 shares)	8,632		8,593
Additional paid-in capital	376,866		371,162
Retained earnings	428,833		393,072
Accumulated other comprehensive income	1,370		1,303
Deferred compensation obligation	7,018		7,240
Treasury Stock, Value	7,018		7,240
Long-term Debt and Capital Lease Obligations, Net of Current Maturities	585,805		549,903
Less: current maturities	21,472		17,962
Short-term borrowing	137,024		221,634
Customer deposits and refunds	34,489		36,488
Accrued interest	3,320		2,775
Dividends payable	9,488		8,466
Accrued compensation	9,471		15,505
Regulatory liabilities	6,663		2,312
Energy Marketing Contract Liabilities, Current	427		743
Deferred income taxes	244,978		233,550
Environmental liabilities	3,097		3,538
Other pension and benefit costs	$ 21,458		$ 24,120

[1] 2,000,000 shares of preferred stock at $0.01 par value have been authorized. No shares have been issued or are outstanding; accordingly, no information has been included in the statements of stockholders’ equity.    

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Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
Statement of Financial Position [Abstract]
Allowance for uncollectible accounts	$ 2,758	$ 3,141
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

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Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Operating Activities
Net Income	$ 53,985	$ 48,279
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	34,193	30,662
Depreciation and accretion included in other costs	5,781	5,061
Deferred income taxes	11,434	12,810
Realized gain on commodity contracts and sale of assets	(6,980)	(5,342)
Unrealized loss (gain) on investments/commodity contracts	1,956	(988)
Employee benefits and compensation	(520)	(346)
Share-based compensation	3,555	3,315
Changes in assets and liabilities:
Accounts receivable and accrued revenue	24,766	23,664
Propane inventory, storage gas and other inventory	270	(1,085)
Regulatory assets/liabilities, net	(6,405)	7,711
Prepaid expenses and other current assets	10,326	2,789
Accounts payable and other accrued liabilities	(2,274)	6,563
Income taxes receivable	5,107	4,514
Customer deposits and refunds	(1,999)	681
Accrued compensation	(6,266)	(3,397)
Other assets and liabilities, net	(3,134)	(675)
Net cash provided by operating activities	123,795	134,216
Investing Activities
Property, plant and equipment expenditures	(65,087)	(104,631)
Proceeds from sale of assets	3,367	497
Environmental expenditures	441	395
Net cash used in investing activities	(64,167)	(104,529)
Financing Activities
Common stock dividends	(16,575)	(15,047)
Issuance of stock under the Dividend Reinvestment Plan, net of offering fees	4,259	4,799
Tax withholding payments related to net settled stock compensation	(2,838)	(1,478)
Change in cash overdrafts due to outstanding checks	(1,202)	(1,101)
Net advances (repayments) under line of credit agreements	(83,424)	(5,249)
Proceeds from long-term debt, net of offering fees	49,890	0
Repayment of long-term debt	(10,528)	(10,099)
Net cash used in financing activities	(60,418)	(28,175)
Net Increase (Decrease) in Cash and Cash Equivalents	(790)	1,512
Cash and Cash Equivalents—Beginning of Period	4,976	3,499
Cash and Cash Equivalents—End of Period	4,186	5,011
Payments to Acquire Businesses, Gross	$ (2,006)	$ 0

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Condensed Consolidated Statements of Stockholders' Equity (Unaudited) - USD ($) $ in Thousands		Total		Common Stock [Member]		Additional Paid-In Capital [Member]		Retained Earnings [Member]	Accumulated Other Comprehensive Loss [Member]	Deferred Compensation [Member]	Treasury Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares Held In Trust For Deferred Compensation Plan		105,087
Common Stock, Dividends, Per Share, Declared		$ 0.92
Beginning Balances (shares) at Dec. 31, 2020	[1],[2]			17,461,841
Beginning Balances at Dec. 31, 2020		$ 697,085	[1],[2]	$ 8,499	[1],[2]	$ 348,482		$ 342,969	$ (2,865)	$ 5,679	$ (5,679)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		48,279						48,279
Other comprehensive income (loss)		3,423							3,423
Other Comprehensive Income (Loss), Net of Tax		3,423
Dividend declared		(16,312)						(16,312)
Retirement savings plan and dividend reinvestment plan (shares)				60,116
Dividend reinvestment plan		6,835		$ 29		6,806
Share-based compensation (shares)	[3],[4]			45,971
Share-based compensation and tax benefit		2,254		$ 22	[3],[4]	2,232	[3],[4]
Treasury stock activities		0								1,524	(1,524)
Ending Balances (shares) at Jun. 30, 2021	[1]			17,567,928
Ending Balances at Jun. 30, 2021		$ 741,564	[1]	$ 8,550	[1]	357,520		374,936	558	7,203	(7,203)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation		14,020
Common Stock, Dividends, Per Share, Declared		$ 0.4800
Beginning Balances (shares) at Mar. 31, 2021				17,521,493
Beginning Balances at Mar. 31, 2021		$ 726,388		$ 8,528		350,875		369,623	(2,638)	6,992	(6,992)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		13,813						13,813
Other comprehensive income (loss)		3,196							3,196
Other Comprehensive Income (Loss), Net of Tax		3,196
Dividend declared		(8,500)						(8,500)
Retirement savings plan and dividend reinvestment plan (shares)				39,605
Dividend reinvestment plan		4,621		$ 19		4,602
Share-based compensation (shares)				6,830
Share-based compensation and tax benefit		2,046		$ 3		2,043
Treasury stock activities		0								211	(211)
Ending Balances (shares) at Jun. 30, 2021	[1]			17,567,928
Ending Balances at Jun. 30, 2021		$ 741,564	[1]	$ 8,550	[1]	357,520		374,936	558	7,203	(7,203)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares Held In Trust For Deferred Compensation Plan		117,193
Preferred Stock, Shares Authorized		2,000,000
Preferred Stock, Par or Stated Value Per Share		$ 0.01
Shares Held In Trust For Deferred Compensation Plan		116,238
Common Stock, Dividends, Per Share, Declared		$ 1.015
Beginning Balances (shares) at Dec. 31, 2021	[1],[2]			17,655,410
Beginning Balances at Dec. 31, 2021		$ 774,130		$ 8,593	[1],[2]	371,162		393,072	1,303	7,240	(7,240)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		53,985						53,985
Other comprehensive income (loss)		67							67
Other Comprehensive Income (Loss), Net of Tax		67
Dividend declared		(18,224)						(18,224)
Retirement savings plan and dividend reinvestment plan (shares)				33,846
Dividend reinvestment plan		4,630		$ 17		4,613
Share-based compensation (shares)	[3],[4]			45,538
Share-based compensation and tax benefit	[3],[4]	1,113		$ 22		1,091
Treasury stock activities								0		(222)	222
Ending Balances (shares) at Jun. 30, 2022	[1]			17,734,794
Ending Balances at Jun. 30, 2022		$ 815,701	[1]	$ 8,632	[1]	376,866		428,833	1,370	7,018	(7,018)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation		21,832
Common Stock, Dividends, Per Share, Declared		$ 0.5350
Beginning Balances (shares) at Mar. 31, 2022				17,719,388
Beginning Balances at Mar. 31, 2022		$ 805,512		$ 8,624		373,694		421,344	1,850	6,477	(6,477)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		17,051						17,051
Other comprehensive income (loss)		(480)							(480)
Other Comprehensive Income (Loss), Net of Tax		(480)
Dividend declared		(9,562)						(9,562)
Retirement savings plan and dividend reinvestment plan (shares)				8,886
Dividend reinvestment plan		1,208		$ 5		1,203
Share-based compensation (shares)				6,520
Share-based compensation and tax benefit		1,972		$ 3		1,969
Treasury stock activities								0		541	(541)
Ending Balances (shares) at Jun. 30, 2022	[1]			17,734,794
Ending Balances at Jun. 30, 2022		$ 815,701	[1]	$ 8,632	[1]	$ 376,866		$ 428,833	$ 1,370	$ 7,018	$ (7,018)
Preferred Stock, Shares Authorized		2,000,000
Preferred Stock, Par or Stated Value Per Share		$ 0.01
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares Held In Trust For Deferred Compensation Plan		110,835

[1] 2,000,000 shares of preferred stock at $0.01 par value have been authorized. No shares have been issued or are outstanding; accordingly, no information has been included in the statements of stockholders’ equity.    

[2] Includes 110,835, 116,238, 117,193, and 105,087 shares at June 30, 2022, December 31, 2021, June 30, 2021 and December 31, 2020, respectively, held in a Rabbi Trust related to our Non-Qualified Deferred Compensation Plan.

[3] Includes amounts for shares issued for directors’ compensation.

[4] The shares issued under the SICP are net of shares withheld for employee taxes. For the six months ended June 30, 2022 and 2021, we withheld 21,832 and 14,020 shares, respectively, for employee taxes.(5)Includes the Retirement Savings Plan, DRIP and ATM equity issuances.

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Condensed Consolidated Statements of Stockholders' Equity (Parenthetical) (Unaudited) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021	Dec. 31, 2020
Statement of Stockholders' Equity [Abstract]
Dividend declared (in dollars per share)	$ 0.5350	$ 0.4800	$ 1.015	$ 0.92
Deferred compensation plan held Rabbi Trust (shares)	110,835	117,193	110,835	117,193	116,238	105,087
Preferred Stock, Shares Authorized	2,000,000		2,000,000		2,000,000
Preferred Stock, Par or Stated Value Per Share	$ 0.01		$ 0.01		$ 0.01
Shares issued under the performance incentive plan withheld for employee taxes (shares)			21,832	14,020

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Summary of Accounting Policies

6 Months Ended

Jun. 30, 2022

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, 2021. In the opinion of management, these financial statements reflect all adjustments that are necessary for a fair presentation of our results of operations, financial position and cash flows for the interim periods presented.

Where necessary to improve comparability, prior period amounts have been changed to conform to current period presentation.

Due to the seasonality of our business, results for interim periods are not necessarily indicative of results for the entire fiscal year. Revenue and earnings are typically greater during the first and fourth quarters, when consumption of energy is highest due to colder temperatures.

Effects of COVID-19

In March 2020, the CDC declared a national emergency due to the rapidly growing outbreak of COVID-19. In response to this declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the country imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to slow the spread of the illness. These restrictions significantly impacted economic conditions in the United States beginning in 2020 and to a lesser extent have continued into 2022. Chesapeake Utilities is considered an “essential business,” which allowed us to continue operational activities and construction projects while social distancing restrictions were in place. At this time, restrictions have predominantly been lifted as vaccines have become widely available in the United States. Previously existing states of emergency in all of our service territories expired during the second and third quarters of 2021 eliminating a majority of restrictions initially implemented to slow the spread of the virus. The expiration of the states of emergency along with the settlement of our limited proceeding in Florida concluded our ability to defer incremental pandemic related costs for consideration through the applicable regulatory process. We adjusted our operating practices accordingly to ensure the safety of our operations and will take the necessary actions to comply with the CDC, and the Occupational and Safety and Health Administration, as new developments occur.

Refer to Note 5, Rates and Other Regulatory Activities, for further information on the regulated assets established as a result of the incremental expenses associated with COVID-19.

Recent Accounting Standards Yet to be Adopted

Reference Rate Reform - (ASC 848) - In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting, which was subsequently amended by ASU 2021-01. The standard provides relief for companies preparing for the discontinuation of interest rates, such as LIBOR, and allows optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions affected by reference rate reform. The amendments included in this ASU are to be applied prospectively, and are not expected to have a material impact on our financial position or results of operations. Refer to Note 16, Short-Term Borrowings, for further information regarding the expected timing of implementing this update.

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Calculation of Earnings Per Share

6 Months Ended

Jun. 30, 2022

Earnings Per Share [Abstract]

Calculation of Earnings Per Share

Calculation of Earnings Per Share

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
(in thousands, except shares and per share data)
Calculation of Basic Earnings Per Share:
Net Income	$	17,051	$	13,813	$	53,985	$	48,279
Weighted average shares outstanding	17,730,833		17,546,346		17,704,592		17,516,273
Basic Earnings Per Share	$	0.96	$	0.79	$	3.05	$	2.76
Calculation of Diluted Earnings Per Share:
Net Income	$	17,051	$	13,813	$	53,985	$	48,279
Reconciliation of Denominator:
Weighted shares outstanding—Basic	17,730,833		17,546,346		17,704,592		17,516,273
Effect of dilutive securities—Share-based compensation	79,038		70,150		81,037		68,733
Adjusted denominator—Diluted	17,809,871		17,616,496		17,785,629		17,585,006
Diluted Earnings Per Share	$	0.96	$	0.78	$	3.04	$	2.75

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Acquisitions and Divestitures (Notes)

6 Months Ended

Jun. 30, 2022

Discontinued Operations and Disposal Groups [Abstract]

Business Combination Disclosure [Text Block]

3.     Acquisitions

Acquisition of Davenport Energy

On June 13, 2022, Sharp acquired the propane operating assets of Davenport Energy's Siler City propane division for approximately $2.0 million. In connection with this acquisition, we recorded a $0.1 million liability which is subject to the seller's adherence to various provisions contained in the purchase agreement through the first anniversary of the transaction closing. Included with the acquisition was less than $0.1 million of working capital from the Seller consisting predominantly of accounts receivable and propane inventory. Through this acquisition, the Company expands its operating footprint further into North Carolina, where customers will be served by Sharp Energy’s Diversified Energy division. Sharp added approximately 850 customers, along with expected distribution of approximately 0.4 million gallons of propane annually. We recorded $1.5 million in property plant and equipment, $0.5 million in goodwill, and immaterial amounts associated with customer relationships and non-compete agreements, all of which are deductible for income tax purposes. The amounts recorded in conjunction with the acquisition are preliminary, and subject to adjustment based on contractual provisions and finalization prior to the first anniversary of the transaction closing. The financial results associated with this acquisition will be included within Sharp's Diversified Energy division, primarily as a result of their geographic proximity, as well as other synergies they generate due to their service territory.

Acquisition of Diversified Energy

On December 15, 2021, Sharp acquired the propane operating assets of Diversified Energy for approximately $37.5 million, net of cash acquired. In connection with this acquisition, we recorded a $2.1 million liability which is subject to the seller's adherence to various provisions contained in the purchase agreement through the first anniversary of the transaction closing. Included with the acquisition, was approximately $1.7 million of working capital from the Seller consisting predominantly of accounts receivable and propane inventory. We accounted for this acquisition as a business combination within our Unregulated Energy Segment beginning in the fourth quarter of 2021. In January 2022, we recorded a post-closing true-up of $0.8 million related to the provision for working capital valuation at the time of closing. There were multiple strategic benefits to this acquisition including it: (i) expands our propane service territory into North Carolina and South Carolina (ii) builds upon our existing propane presence in Virginia and Pennsylvania, and (iii) includes an established customer base with opportunities for future growth. Through this acquisition, the Company added approximately 19,000 residential, commercial and agricultural customers, along with expected distribution of approximately 10.0 million gallons of propane annually. In connection with this acquisition, we recorded $23.1 million in property plant and equipment, $6.2 million in intangible assets associated with customer relationships and non-compete agreements and $5.9 million in goodwill, all of which is deductible for income tax purposes. The amounts recorded in conjunction with the acquisition are preliminary, and subject to adjustment based on contractual provisions and finalization prior to the first anniversary of the transaction closing.

These acquisitions generated operating revenue and operating loss of $4.0 million and $0.8 million, respectively, for the three months ended June 30, 2022 . For the six months ended June 30, 2022, the acquisitions generated operating revenue and operating income of $14.3 million and $0.7 million, respectively.

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Revenue Recognition (Notes)

6 Months Ended

Jun. 30, 2022

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 June 30, 2022 and 2021:

	Three months ended June 30, 2022								Three months ended June 30, 2021
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total		Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Energy distribution
Delaware natural gas division	$	13,086	$	—	$	—	$	13,086	$	10,068	$	—	$	—	$	10,068
Florida natural gas division	9,619		—		—		9,619		8,446		—		—		8,446
FPU electric distribution	20,305		—		—		20,305		18,898		—		—		18,898
FPU natural gas distribution	25,817		—		—		25,817		23,159		—		—		23,159
Maryland natural gas division	4,372		—		—		4,372		3,224		—		—		3,224
Sandpiper natural gas/propane operations	4,248		—		—		4,248		3,814		—		—		3,814
Elkton Gas	1,705		—		—		1,705		1,195		—		—		1,195
Total energy distribution	79,152		—		—		79,152		68,804		—		—		68,804
Energy transmission
Aspire Energy	—		10,808		—		10,808		—		5,578		—		5,578
Aspire Energy Express	369		—		—		369		47		—		—		47
Eastern Shore	18,875		—		—		18,875		18,617		—		—		18,617
Peninsula Pipeline	6,777		—		—		6,777		6,610		—		—		6,610
Total energy transmission	26,021		10,808		—		36,829		25,274		5,578		—		30,852
Energy generation
Eight Flags	—		5,916		—		5,916		—		4,173		—		4,173
Propane operations
Propane delivery operations	—		34,469		—		34,469		—		23,098		—		23,098
Compressed Natural Gas Services
Marlin Gas Services	—		2,380		—		2,380		—		1,989		—		1,989
Other and eliminations
Eliminations	(12,980)		(110)		(6,271)		(19,361)		(13,168)		(65)		(4,734)		(17,967)
Other	—		—		85		85		—		—		133		133
Total other and eliminations	(12,980)		(110)		(6,186)		(19,276)		(13,168)		(65)		(4,601)		(17,834)
Total operating revenues (1)	$	92,193	$	53,463	$	(6,186)	$	139,470	$	80,910	$	34,773	$	(4,601)	$	111,082

(1) Total operating revenues for the three months ended June 30, 2022, include other revenue (revenues from sources other than contracts with customers) of $(0.1) million for Regulated and $0.1 million Unregulated Energy segments, respectively, and $0.1 million for both our Regulated and Unregulated Energy segments, respectively, for the three months ended June 30, 2021. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the Maryland division and Sandpiper Energy and late fees.

The following table displays our revenue by major source based on product and service type for the six months ended June 30, 2022 and 2021:

	Six Months Ended June 30, 2022								Six Months Ended June 30, 2021
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total		Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Energy distribution
Delaware natural gas division	$	47,568	$	—	$	—	$	47,568	$	43,340	$	—	$	—	$	43,340
Florida natural gas division	19,885		—		—		19,885		17,402		—		—		17,402
FPU electric distribution	39,394		—		—		39,394		37,449		—		—		37,449
FPU natural gas distribution	55,837		—		—		55,837		50,020		—		—		50,020
Maryland natural gas division	14,836		—		—		14,836		13,690		—		—		13,690
Sandpiper natural gas/propane operations	11,885		—		—		11,885		11,885		—		—		11,885
Elkton Gas	5,071		—		—		5,071		3,830		—		—		3,830
Total energy distribution	194,476		—		—		194,476		177,616		—		—		177,616
Energy transmission
Aspire Energy	—		28,844		—		28,844		—		18,484		—		18,484
Aspire Energy Express	632		—		—		632		93		—		—		93
Eastern Shore	39,196		—		—		39,196		38,589		—		—		38,589
Peninsula Pipeline	13,549		—		—		13,549		13,077		—		—		13,077
Total energy transmission	53,377		28,844		—		82,221		51,759		18,484		—		70,243
Energy generation
Eight Flags	—		11,455		—		11,455		—		8,502		—		8,502
Propane operations
Propane delivery operations	—		110,075		—		110,075		—		78,361		—		78,361
Compressed Natural Gas Services
Marlin Gas Services	—		4,589		—		4,589		—		4,340		—		4,340
Other and eliminations
Eliminations	(27,769)		(207)		(12,706)		(40,682)		(27,268)		(156)		(9,635)		(37,059)
Other	—		—		216		216		—		—		265		265
Total other and eliminations	(27,769)		(207)		(12,490)		(40,466)		(27,268)		(156)		(9,370)		(36,794)
Total operating revenues (1)	$	220,084	$	154,756	$	(12,490)	$	362,350	$	202,107	$	109,531	$	(9,370)	$	302,268

(1) Total operating revenues for the six months ended June 30, 2022, include other revenue (revenues from sources other than contracts with customers) of $0.1 million for Regulated and $0.2 million Unregulated Energy segments, respectively, and $(0.2) million and $0.2 million for our Regulated and Unregulated Energy segments, respectively, for the six months ended June 30, 2021. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the Maryland division and Sandpiper Energy and late fees.

Contract balances

The timing of revenue recognition, customer billings and cash collections results in trade receivables, unbilled receivables (contract assets), and customer advances (contract liabilities) in our condensed consolidated balance sheets. The balances of our trade receivables, contract assets, and contract liabilities as of June 30, 2022 and December 31, 2021 were as follows:

	Trade Receivables		Contract Assets (Current)		Contract Assets (Non-current)		Contract Liabilities (Current)
(in thousands)
Balance at 12/31/2021	$	56,277	$	18	$	4,806	$	747
Balance at 6/30/2022	38,778		18		4,607		724
Decrease	$	(17,499)	$	—	$	(199)	$	(23)

Our trade receivables are included in trade and other receivables in the condensed consolidated balance sheets. Our current contract assets are included in other current assets in the condensed consolidated balance sheet. Our non-current contract assets are included in other assets in the condensed consolidated balance sheet and primarily relate to operations and maintenance costs incurred by Eight Flags that have not yet been recovered through rates for the sale of electricity to our electric distribution operation pursuant to a long-term service agreement.

At times, we receive advances or deposits from our customers before we satisfy our performance obligation, resulting in contract liabilities. Contract liabilities are included in other accrued liabilities in the condensed consolidated balance sheets and relate to non-refundable prepaid fixed fees for our Mid-Atlantic propane delivery operation's retail offerings. Our performance obligation is satisfied over the term of the respective customer retail program on a ratable basis. For the three months ended June 30, 2022 and 2021, we recognized revenue of $0.3 million and $0.2 million. For the six months ended June 30, 2022 and 2021, we recognized revenue of $0.7 million and $0.6 million.

Remaining performance obligations

Our businesses have long-term fixed fee contracts with customers in which revenues are recognized when performance obligations are satisfied over the contract term. Revenue for these businesses for the remaining performance obligations, at June 30, 2022, are expected to be recognized as follows:

(in thousands)	2022		2023		2024		2025		2026		2027		2028 and thereafter
Eastern Shore and Peninsula Pipeline	$	24,379	$	45,426	$	40,431	$	33,804	$	29,294	$	25,096	$	179,259
Natural gas distribution operations	3,433		6,238		6,050		5,698		5,515		5,100		33,113
FPU electric distribution	326		652		652		275		275		275		275
Total revenue contracts with remaining performance obligations	$	28,138	$	52,316	$	47,133	$	39,777	$	35,084	$	30,471	$	212,647

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Rates and Other Regulatory Activities

6 Months Ended

Jun. 30, 2022

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 and Aspire Energy Express, our intrastate pipeline subsidiaries, are subject to regulation (excluding cost of service) by the Florida PSC and Public Utilities Commission of Ohio, respectively.

Delaware

See the discussion below under COVID-19 impact.

Maryland

Ocean City Maryland Reinforcement: In March 2022, we filed a Section 7(f) - Request for Service Area Determination with the FERC regarding plans to extend our natural gas facilities across the Delaware/Maryland state line from Sussex County, Delaware, to Worcester County, Maryland, to provide a secondary feed to Sandpiper Energy. The project will increase the reliability of the existing distribution system in those areas while also expanding infrastructure to serve new customers. Construction began in the second quarter of 2022, with estimated completion in the fourth quarter of 2022.

Strategic Infrastructure Development and Enhancement (“STRIDE”) Plan: In March 2021, Elkton Gas filed a STRIDE plan with the Maryland PSC. The STRIDE plan accelerates Elkton Gas' Aldyl-A pipeline replacement program as costs of the plan are recovered through a fixed charge rider which is effective for five years. Under Elkton Gas’ STRIDE plan, the Aldyl-A pipelines will be fully replaced by the end of 2023. In July 2021, Elkton Gas reached a settlement with the Maryland PSC Staff and the Maryland Office of Public Counsel that approved Elkton Gas’ STRIDE plan. The STRIDE plan allows for recovery of the associated revenue requirement through a monthly surcharge, which was implemented effective September 2021. We filed the annual STRIDE plan update with the Maryland PSC on November 1, 2021, which was approved for new rates effective January 1, 2022.

Florida

Natural Gas Rate Case: In May 2022, our natural gas distribution businesses in Florida, FPU, FPU-Indiantown division, FPU-Fort Meade division and Chesapeake Utilities CFG division (collectively, “Florida natural gas distribution businesses”) filed a consolidated natural gas rate case with the Florida PSC. In connection with the application, we are seeking approval of the following: (i) interim rate relief of approximately $7.2 million, subject to refund, pending the outcome of the rate case proceeding; (ii) permanent rate relief of approximately $24.1 million, effective January 1, 2023, (iii) a depreciation study also submitted with filing; (iv) authorization to make certain changes to tariffs to include the consolidation of rates and rate structure across the businesses and to unify the Florida natural gas distribution businesses under FPU; (v) authorization to retain the acquisition adjustment recorded at the time of the FPU merger in our revenue requirement; and (vi) authorization to establish an environmental remediation surcharge for the purposes of addressing future expected remediation costs for FPU MGP sites. In August 2022, interim rates were approved by the Florida PSC in the amount of approximately $7.7 million on an annualized basis, effective for all meter reading in September 2022. The interim rates are subject to refund pending the final outcome of the rate case proceeding. The discovery process has commenced and hearing for the proceeding has been scheduled for October 2022. The outcome of the application is subject to review and approval by the Florida PSC.

Winter Haven Expansion Project: In May 2021, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with CFG for an incremental 6,800 Dts/d of firm service in the Winter Haven, Florida area. As part of this agreement, Peninsula Pipeline will construct a new interconnect with FGT and a new regulator station for CFG. CFG will use the additional firm service to support new incremental load due to growth, including providing service to a new can manufacturing facility, as well as provide reliability and operational benefits to CFG’s existing distribution system in the area. In connection with Peninsula Pipeline’s new regulator station, CFG is also extending its distribution system to connect to the new station. The Transportation Service Agreement was approved by the Florida PSC in September 2021. Construction commenced in February 2021 and the expected in-service date is the third quarter of 2022.

Beachside Pipeline Extension: In June 2021, Peninsula Pipeline and Florida City Gas entered into a Transportation Service Agreement for an incremental 10,176 Dts/d of firm service in Indian River County, Florida, to support Florida City Gas’ growth along the Indian River's barrier island. As part of this agreement, Peninsula Pipeline will construct 11.3 miles of pipeline from its existing pipeline in the Sebastian, Florida area, which will travel east under the Intercoastal Waterway ("ICW") and southward on the barrier island. As required by Peninsula Pipeline’s tariff and Florida Statutes, Peninsula Pipeline filed the required company and customer affidavits with the Florida PSC in June 2021. Construction commenced in June 2021 and the expected in-service date is first quarter of 2023.

St.Cloud / Twin Lakes Expansion: In July 2022, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with our Florida natural gas division, FPU, for an additional 2,400 Dt/d of firm service in the St. Cloud, Florida area. As part of this agreement, Peninsula Pipeline will construct a pipeline extension and regulator station for FPU. The extension will be used to support new incremental load due to growth in the area, including providing service, most immediately, to the residential development Twin Lakes. The expansion will also improve reliability and operation benefits to FPU's existing distribution system in the area, supporting future growth in the area. We expect this expansion to be in service by the first quarter of 2023.

Eastern Shore

Southern Expansion Project: In January 2022, Eastern Shore submitted a prior notice filing with the FERC pursuant to blanket certificate procedures, regarding its proposal to install an additional compressor unit and related facilities at Eastern Shore's existing compressor station in Bridgeville, Sussex County, Delaware. The project will enable Eastern Shore to provide additional firm natural gas transportation service to an existing shipper on Eastern Shore's pipeline system, with a projected in-service date in the fourth quarter of 2023. We are currently awaiting an order from the FERC on the Company's filing.

Capital Cost Surcharge: In June 2021, Eastern Shore submitted a filing with the FERC regarding a capital cost surcharge to recover capital costs associated with two mandated highway relocate projects that required the replacement of existing Eastern Shore facilities. The capital cost surcharge was an approved item in Eastern Shore’s last rate case. In conjunction with the filing of this surcharge, pursuant to the settlement agreement, a cumulative adjustment to the existing surcharge to reflect additional depreciation was included in this filing. The FERC issued an order approving the surcharge as filed on July 7, 2021. The combined revised surcharge became effective July 15, 2021.

COVID-19 Impact

In March 2020, the CDC declared a national emergency due to the rapidly growing outbreak of COVID-19. In response to this declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the country imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to slow the spread of the illness. These restrictions significantly impacted economic conditions in the United States in 2020 and continued to impact economic conditions, to a lesser extent, through 2021. Chesapeake Utilities is considered an “essential business,” which allowed us to continue operational activities and construction projects with appropriate safety precautions and personal protective equipment, while being mindful of the social distancing restrictions that were in place.

In response to the COVID-19 pandemic and related restrictions, we experienced reduced consumption of energy largely in the commercial and industrial sectors, higher bad debt expenses and incremental expenses associated with COVID-19, including expenditures associated with personal protective equipment and premium pay for field personnel. The additional operating expenses we incurred supported the ongoing delivery of our essential services during these unprecedented times. In April and May 2020, we were authorized by the Maryland and Delaware PSCs, respectively, to record regulatory assets for COVID-19 related costs which offers us the ability to seek recovery of those costs. In July 2021, the Florida PSC issued an order that approved incremental expenses we incurred due to COVID-19. The order allowed us to establish a regulatory asset in a total amount of $2.1 million as of June 30, 2021 for natural gas and electric distribution operations. The regulatory asset is amortized over two years and is recovered through the Purchased Gas Adjustment and Swing Service mechanisms for our natural gas distribution businesses and through the Fuel Purchased Power Cost Recovery clause for our electric division. As of June 30, 2022 and December 31, 2021, our total COVID-19 regulatory asset balance was $1.8 million and $2.3 million, respectively.

In 2021 and 2022, restrictions were gradually lifted as vaccines became widely available in the United States. The various state of emergencies associated with the COVID-19 pandemic that were previously declared in our service territories have been terminated and we have adjusted our operating practices accordingly to ensure the safety of our operations and will take the necessary actions to comply with the CDC, and the Occupational Safety and Health Administration, as new developments occur.

Storm Protection Plan

In 2020, the Florida PSC implemented the Storm Protection Plan ("SPP") and Storm Protection Plan Cost Recovery ("SPPCR") rules, which require electric utilities to petition the Florida PSC for approval of a Transmission and Distribution Storm Protection Plan that covers the utility’s immediate 10-year planning period with updates to the plan at least every 3 years. The SPPCR rules allow the utility to file for recovery of associated costs related to its SPP. The Company’s SPP plan was filed in April 2022, with hearings scheduled for early August 2022. The SPP cost recovery clause ("SPPCRC") was filed in May 2022 with requested rates effective January 1, 2023. The SPPCRC hearing is scheduled for November 2022.

    Summary TCJA Table

Customer rates for our regulated businesses were adjusted as approved by the regulators, prior to 2020 with the exception of Elkton Gas, which implemented a one-time bill credit in May 2020. The following table summarizes the regulatory liabilities related to accumulated deferred taxes ("ADIT") associated with TCJA for our regulated businesses as of June 30, 2022 and December 31, 2021:

	Amount (in thousands)
Operation and Regulatory Jurisdiction	June 30, 2022	December 31, 2021	Status
Eastern Shore (FERC)	$34,190	$34,190	Will be addressed in Eastern Shore's next rate case filing.
Delaware natural gas division (Delaware PSC)	$12,510	$12,591	PSC approved amortization of ADIT in January 2019.
Maryland natural gas division (Maryland PSC)	$3,772	$3,840	PSC approved amortization of ADIT in May 2018.
Sandpiper Energy (Maryland PSC)	$3,626	$3,656	PSC approved amortization of ADIT in May 2018.
Chesapeake Florida natural gas division/CFG (Florida PSC)	$7,939	$8,032	PSC issued order authorizing amortization and retention of net ADIT liability by the Company in February 2019.
FPU natural gas (excludes Fort Meade and Indiantown) (Florida PSC)	$19,058	$19,189	Same treatment on a net basis as Chesapeake Florida Gas Division (above).
FPU Fort Meade and Indiantown natural gas divisions (Florida PSC)	$265	$271	Same treatment on a net basis as Chesapeake Florida Gas Division (above).
FPU electric division (Florida PSC)	$5,115	$5,237	In January 2019, PSC issued order approving amortization of ADIT through purchased power cost recovery, storm reserve and rates.
Elkton Gas (Maryland PSC)	$1,074	$1,091	PSC approved amortization of ADIT in March 2018.

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Environmental Commitments and Contingencies

6 Months Ended

Jun. 30, 2022

Environmental Remediation Obligations [Abstract]

Environmental Commitments and Contingencies

Environmental Commitments and Contingencies

We are subject to federal, state and local laws and regulations governing environmental quality and pollution control. These laws and regulations require us to remove or remediate, at current and former operating sites, the effect on the environment of the disposal or release of specified substances.

MGP Sites

We have participated in the investigation, assessment or remediation of, and have exposures at, seven former MGP sites. We have received approval for recovery of clean-up costs in rates for sites located in Salisbury, Maryland; Seaford, Delaware; and Winter Haven, Key West, Pensacola, Sanford and West Palm Beach, Florida.

As of June 30, 2022 and December 31, 2021, we had approximately $4.8 million and $5.2 million, respectively, in environmental liabilities related to the former MGP sites. As of June 30, 2022 and December 31, 2021, we have cumulative regulatory assets of $1.0 million and $1.3 million, respectively, for future recovery of environmental costs for customers. Specific to FPU’s four MGP sites in Key West, Pensacola, Sanford and West Palm Beach, FPU has approval to recover, from insurance and through customer rates, up to $14.0 million of its environmental costs related to its MGP sites. As of June 30, 2022 and December 31, 2021, we had recovered approximately $13.1 million and $12.9 million, respectively, leaving approximately $0.9 million and $1.1 million, respectively, in regulatory assets for future recovery of environmental costs from FPU’s customers.

Environmental liabilities for our MGP sites are recorded on an undiscounted basis based on the estimate of future costs provided by independent consultants. We continue to expect that all costs related to environmental remediation and related activities, including any potential future remediation costs for which we do not currently have approval for regulatory recovery, will be recoverable from customers through rates.

Remediation is ongoing for the MGPs in Winter Haven and Key West in Florida and in Seaford, Delaware and the remaining clean-up costs are estimated to be between $0.3 million to $0.9 million for these three sites. The Environmental Protection Agency has approved a "site-wide ready for anticipated use" status for the Sanford, Florida MGP site, which is the final step before delisting a site. The remaining remediation expenses for the Sanford MGP site are immaterial. The remedial actions approved by the Florida Department of Environmental Protection have been implemented on the east parcel of our West Palm Beach Florida site. Similar remedial actions have been initiated on the site's west parcel, and construction of active remedial systems are expected to be completed in 2022. We expect the costs to clean-up the site to be between $3.3 million to $14.2 million, including costs associated with relocation of FPU's operations at this site, and any potential costs associated with future redevelopment of the properties.

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Other Commitments and Contingencies

6 Months Ended

Jun. 30, 2022

Commitments and Contingencies Disclosure [Abstract]

Other Commitments and Contingencies

Other Commitments and Contingencies

Natural Gas, Electric and Propane Supply

In March 2020, our Delmarva Peninsula natural gas distribution operations entered into asset management agreements with a third party to manage their natural gas transportation and storage capacity. The agreements were effective as of April 1, 2020 and expire in March 2023.

FPU natural gas distribution operations and Eight Flags have separate asset management agreements with Emera Energy Services, Inc. to manage their natural gas transportation capacity. These agreements are for a 10-year term that commenced in November 2020 and expire in October 2030.

Chesapeake Utilities' natural gas division, CFG has firm transportation service contracts with FGT and Gulfstream. Pursuant to a capacity release program approved by the Florida PSC, all of the capacity under these agreements has been released to various third parties. Under the terms of these capacity release agreements, Chesapeake Utilities is contingently liable to FGT and Gulfstream should any party, that acquired the capacity through release, fail to pay the capacity charge. To date, Chesapeake Utilities has not been required to make a payment resulting from this contingency.

FPU’s electric supply contracts require FPU to maintain an acceptable standard of creditworthiness based on specific financial ratios. FPU’s agreement with Florida Power & Light Company requires FPU to meet or exceed a debt service coverage ratio of 1.25 times based on the results of the prior 12 months. If FPU fails to meet this ratio, it must provide an irrevocable letter of credit or pay all amounts outstanding under the agreement within five business days. FPU’s electric supply agreement with Gulf Power requires FPU to meet the following ratios based on the average of the prior six quarters: (a) funds from operations interest coverage ratio (minimum of two times), and (b) total debt to total capital (maximum of 65 percent). If FPU fails to meet the requirements, it has to provide the supplier a written explanation of actions taken, or proposed to be taken, to become compliant. Failure to comply with the ratios specified in the Gulf Power agreement could also result in FPU having to provide an irrevocable letter of credit. As of June 30, 2022, FPU was in compliance with all of the requirements of its fuel supply contracts.

Eight Flags provides electricity and steam generation services through its CHP plant located on Amelia Island, Florida. In June 2016, Eight Flags began selling power generated from the CHP plant to FPU pursuant to a 20-year power purchase agreement for distribution to our electric customers. In July 2016, Eight Flags also started selling steam, pursuant to a separate 20-year contract, to the landowner on which the CHP plant is located. The CHP plant is powered by natural gas transported by FPU through its distribution system and Peninsula Pipeline through its intrastate pipeline.

Corporate Guarantees

The Board of Directors has authorized us to issue corporate guarantees securing obligations of our subsidiaries and to obtain letters of credit securing our subsidiaries' obligations. The maximum authorized liability under such guarantees and letters of credit as of June 30, 2022 was $20.0 million. The aggregate amount guaranteed related to our subsidiaries at June 30, 2022 was approximately $11.4 million with the guarantees expiring on various dates through May 22, 2023. In addition, the Board has authorized us to issue specific purpose corporate guarantees. The amount of specific purpose guarantees outstanding at June 30, 2022 was $2.0 million. In July 2022, in connection with the Florida rate case, we entered into a guarantee in the amount of $7.1 million with the Florida PSC.

As of June 30, 2022, we have issued letters of credit totaling approximately $5.3 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 capacity agreement between NEXUS and Aspire, and our current and previous primary insurance carriers. These letters of credit have various expiration dates through October 25, 2022. There have been no draws on these letters of credit as of June 30, 2022. 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.

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Segment Information

6 Months Ended

Jun. 30, 2022

Segment Reporting [Abstract]

Segment Information

Segment Information

We use the management approach to identify operating segments. We organize our business around differences in regulatory environment and the operating results of each segment are regularly reviewed by the chief operating decision maker, our Chief Executive Officer, in order to make decisions about resources and to assess performance.

Our operations are entirely domestic and are comprised of two reportable segments:

•Regulated Energy. Includes energy distribution and transmission services (natural gas distribution, natural gas transmission and electric distribution operations). All operations in this segment are regulated, as to their rates and services, by the PSC having jurisdiction in each operating territory or by the FERC in the case of Eastern Shore.

•Unregulated Energy. Includes energy transmission, energy generation (the operations of our Eight Flags' CHP plant), propane operations, and mobile compressed natural gas distribution and pipeline solutions subsidiary. Also included in this segment are other unregulated energy services, such as energy-related merchandise sales and heating, ventilation and air conditioning, plumbing and electrical services. These operations are unregulated as to their rates and services.

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				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
(in thousands)
Operating Revenues, Unaffiliated Customers
Regulated Energy	$	91,830	$	80,374	$	215,888	$	201,095
Unregulated Energy	47,640		30,708		146,462		101,173
Total operating revenues, unaffiliated customers	$	139,470	$	111,082	$	362,350	$	302,268
Intersegment Revenues (1)
Regulated Energy	$	363	$	536	$	4,196	$	1,012
Unregulated Energy	5,823		4,065		7,819		8,358
Other businesses	85		133		691		265
Total intersegment revenues	$	6,271	$	4,734	$	12,706	$	9,635
Operating Income
Regulated Energy	$	25,841	$	22,760	$	60,539	$	55,466
Unregulated Energy	560		(465)		20,613		18,575
Other businesses and eliminations	68		283		182		134
Operating income	26,469		22,578		81,334		74,175
Other income, net	2,584		1,453		3,498		1,828
Interest charges	5,825		5,054		11,164		10,159
Income before Income Taxes	23,228		18,977		73,668		65,844
Income Taxes	6,177		5,164		19,683		17,565
Net Income	$	17,051	$	13,813	$	53,985	$	48,279

    

(1) All significant intersegment revenues are billed at market rates and have been eliminated from consolidated operating revenues.

(in thousands)	June 30, 2022		December 31, 2021
Identifiable Assets
Regulated Energy segment	$	1,637,003	$	1,629,191
Unregulated Energy segment	447,209		439,114
Other businesses and eliminations	33,130		46,564
Total identifiable assets	$	2,117,342	$	2,114,869

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Stockholder's Equity - Accumulated Other Comprehensive Income (Loss)

6 Months Ended

Jun. 30, 2022

Equity [Abstract]

Accumulated Other Comprehensive Income (Loss)

Stockholders' Equity

Common Stock Issuances

In June 2020, we filed a shelf registration statement with the SEC to facilitate the issuance of our common stock from time to time. In August 2020, we filed a prospectus supplement under the shelf registration statement for an ATM equity program under which we may issue and sell shares of our common stock up to an aggregate offering price of $75.0 million.

We maintain an effective shelf registration statement with the SEC for the issuance of shares under our DRIP. Depending on our capital needs and subject to market conditions, in addition to other possible debt and equity offerings, we may issue additional shares under the direct stock purchase component of the DRIP. In 2021, we issued just over 0.1 million shares at an average price per share of $125.71 and received net proceeds of $15.2 million under the DRIP. In the first six months of 2022, we issued less than 0.1 million shares at an average price per share of $137.24 and received net proceeds of $4.3 million under the DRIP.

We used the net proceeds from our share issuances, after fees, for general corporate purposes, including, but not limited to, financing of capital expenditures, repayment of short-term debt, financing acquisitions, investing in subsidiaries, and general working capital purposes.

Accumulated Other Comprehensive Gain (Loss)

Defined benefit pension and postretirement plan items, unrealized gains (losses) of our propane swap agreements designated as commodity contracts cash flow hedges, and the unrealized gains (losses) of our interest rate swap agreements designated as cash flow hedges are the components of our accumulated other comprehensive income (loss). The following tables present the changes in the balance of accumulated other comprehensive gain (loss) as of June 30, 2022 and 2021. All amounts in the following tables are presented net of tax.

	Defined Benefit		Commodity		Interest Rate
	Pension and		Contracts		Swap
	Postretirement		Cash Flow		Cash Flow
	Plan Items		Hedges		Hedges (1)		Total
(in thousands)
As of December 31, 2021	$	(3,268)	$	4,571	$	—	$	1,303
Other comprehensive income before reclassifications	—		2,206		—		2,206
Amounts reclassified from accumulated other comprehensive income/(loss)	35		(2,174)		—		(2,139)
Net current-period other comprehensive income	35		32		—		67
As of June 30, 2022	$	(3,233)	$	4,603	$	—	$	1,370

(in thousands)
As of December 31, 2020	$	(5,146)	$	2,309	$	(28)	$	(2,865)
Other comprehensive income before reclassifications	—		5,825		23		5,848
Amounts reclassified from accumulated other comprehensive income/(loss)	128		(2,534)		(19)		(2,425)
Net prior-period other comprehensive income	128		3,291		4		3,423
As of June 30, 2021	$	(5,018)	$	5,600	$	(24)	$	558

(1) All of our interest rate swaps expired at December 31, 2021

The following table presents amounts reclassified out of accumulated other comprehensive income (loss) for the three and six months ended June 30, 2022 and 2021. Deferred gains or losses for our commodity contracts and interest rate swap cash flow hedges are recognized in earnings upon settlement.

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
(in thousands)
Amortization of defined benefit pension and postretirement plan items:
Prior service credit (1)	$	19	$	19	$	38	$	38
Net loss(1)	(43)		(106)		(86)		(209)
Total before income taxes	(24)		(87)		(48)		(171)
Income tax benefit	6		23		13		43
Net of tax	$	(18)	$	(64)	$	(35)	$	(128)
Gains on commodity contracts cash flow hedges:
Propane swap agreements (2)	$	283	$	455	$	3,004	$	3,502
Income tax expense	(78)		(126)		(830)		(968)
Net of tax	$	205	$	329	$	2,174	$	2,534
Gains on interest rate swap cash flow hedges:
Interest rate swap agreements	$	—	$	22	$	—	$	26
Income tax expense	—		(6)		—		(7)
Net of tax	$	—	$	16	$	—	$	19
Total reclassifications for the period	$	187	$	281	$	2,139	$	2,425

(1) These amounts are included in the computation of net periodic costs (benefits). See Note 10, Employee Benefit Plans, for additional details.

(2) These amounts are included in the effects of gains and losses from derivative instruments. See Note 13, Derivative Instruments, for additional details.

Amortization of defined benefit pension and postretirement plan items are included in other expense, net gains and losses on propane swap agreements contracts are included in revenue and unregulated propane and natural gas, the realized gain or loss on interest rate swap agreements is recognized as a component of interest charges in the accompanying condensed consolidated statements of income. The income tax benefit is included in income tax expense in the accompanying condensed consolidated statements of income.

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Employee Benefit Plans

6 Months Ended

Jun. 30, 2022

Retirement Benefits [Abstract]

Employee Benefit Plans

Employee Benefit Plans

Net periodic benefit costs for our pension and post-retirement benefits plans for the three and six months ended June 30, 2022 and 2021 are set forth in the following tables:

	Chesapeake Pension Plan				FPU Pension Plan				Chesapeake SERP				Chesapeake Postretirement Plan				FPU Medical Plan
For the Three Months Ended June 30,	2022		2021		2022		2021		2022		2021		2022		2021		2022		2021
(in thousands)
Interest cost	$	—	$	34	$	449	$	429	$	13	$	12	$	6	$	6	$	6	$	6
Expected return on plan assets	—		(40)		(857)		(830)		—		—		—		—		—		—
Amortization of prior service credit	—		—		—		—		—		—		(19)		(19)		—		—
Amortization of net (gain) loss	—		60		124		155		7		7		12		10		—		(2)
Total periodic cost (benefit)	$	—	$	54	$	(284)	$	(246)	$	20	$	19	$	(1)	$	(3)	$	6	$	4

	Chesapeake Pension Plan				FPU Pension Plan				Chesapeake SERP				Chesapeake Postretirement Plan				FPU Medical Plan
For the Six Months Ended June 30,	2022		2021		2022		2021		2022		2021		2022		2021		2022		2021
(in thousands)
Interest cost	$	—	$	68	$	898	$	858	$	26	$	24	$	12	$	12	$	12	$	12
Expected return on plan assets	—		(80)		(1,714)		(1,660)		—		—		—		—		—		—
Amortization of prior service credit	—		—		—		—		—		—		(38)		(38)		—		—
Amortization of net (gain) loss	—		120		248		310		14		14		24		18		—		(4)
Total periodic cost (benefit)	$	—	$	108	$	(568)	$	(492)	$	40	$	38	$	(2)	$	(8)	$	12	$	8

In 2019, we began executing a de-risking strategy for the Chesapeake Pension Plan. In line with this strategy, we fully terminated the Chesapeake Pension Plan during the fourth quarter of 2021, and as of December 31, 2021, there were no remaining assets in the Chesapeake Pension Plan. Accordingly, a portion of the pension settlement expense associated with the termination was allocated to our Regulated Energy operations and was recorded as regulatory assets, previously approved in all of the impacted jurisdictions. The remaining portion of the pension settlement expense totaling $0.6 million was recorded in other expense in our consolidated statement of income in the fourth quarter 2021 which reflected the amount allocated to our Unregulated Energy operations or was deemed not recoverable through the regulatory process.

The components of our net periodic costs have been recorded or reclassified to other expense, net in the condensed consolidated statements of income. Pursuant to their respective regulatory orders, FPU and Chesapeake Utilities continue to record, as a regulatory asset, a portion of their unrecognized postretirement benefit costs related to their regulated operations. 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 income.

The following tables present the amounts included in the regulatory asset and accumulated other comprehensive income that were recognized as components of net periodic benefit cost during the three and six months ended June 30, 2022 and 2021: 

For the Three Months Ended June 30, 2022	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan		FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(19)	$	—	$	(19)
Net loss	—		124		7		12		—		143
Total recognized in net periodic benefit cost	—		124		7		(7)		—		124
Recognized from accumulated other comprehensive (income)/loss (1)	—		24		7		(7)		—		24
Recognized from regulatory asset	—		100		—		—		—		100
Total	$	—	$	124	$	7	$	(7)	$	—	$	124

For the Three Months Ended June 30, 2021	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan		FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(19)	$	—	$	(19)
Net loss	60		155		7		10		(2)		230
Total recognized in net periodic benefit cost	60		155		7		(9)		(2)		211
Recognized from accumulated other comprehensive (income)/loss (1)	60		29		7		(9)		—		87
Recognized from regulatory asset	—		126		—		—		(2)		124
Total	$	60	$	155	$	7	$	(9)	$	(2)	$	211

.

For the Six months ended June 30, 2022	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan		FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(38)	$	—	$	(38)
Net loss	—		248		14		24		—		286
Total recognized in net periodic benefit cost	—		248		14		(14)		—		248
Recognized from accumulated other comprehensive (income)/loss (1)	—		48		14		(14)		—		48
Recognized from regulatory asset	—		200		—		—		—		200
Total	$	—	$	248	$	14	$	(14)	$	—	$	248

For the Six months ended June 30, 2021	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan		FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(38)	$	—	$	(38)
Net loss	120		310		14		18		(4)		458
Total recognized in net periodic benefit cost	120		310		14		(20)		(4)		420
Recognized from accumulated other comprehensive (income)/loss (1)	120		58		14		(20)		(1)		171
Recognized from regulatory asset	—		252		—		—		(3)		249
Total	$	120	$	310	$	14	$	(20)	$	(4)	$	420

(1) See Note 9, Stockholders' Equity.

During the three and six months ended June 30, 2022, we contributed $0.1 million to the FPU Pension Plan. We expect to contribute approximately $0.3 million to the FPU Pension Plan during 2022, 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 and six months ended June 30, 2022 were less than $0.1 million in both periods. We expect to pay total cash benefits of approximately $0.2 million under the Chesapeake SERP in 2022. Cash benefits paid under the Chesapeake Postretirement Plan, primarily for medical claims for both the three and six months ended June 30, 2022 were $0.1 million. We estimate that approximately $0.1 million will be paid for such benefits under the Chesapeake Postretirement Plan in 2022. Cash benefits paid under the FPU Medical Plan, primarily for medical claims for the three and six months ended June 30, 2022, were immaterial. We estimate that approximately $0.1 million will be paid for such benefits under the FPU Medical Plan in 2022.

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Investments

6 Months Ended

Jun. 30, 2022

Investments, Debt and Equity Securities [Abstract]

Investments

Investments

The investment balances at June 30, 2022 and December 31, 2021, consisted of the following:

(in thousands)	June 30, 2022		December 31, 2021
Rabbi trust (associated with the Non-Qualified Deferred Compensation Plan)	$	10,499	$	12,069
Investments in equity securities	24		26
Total	$	10,523	$	12,095

We classify these investments as trading securities and report them at their fair value. For the three months ended June 30, 2022 and 2021, we recorded a net unrealized loss of $1.4 million and a net unrealized gain of $0.6 million, respectively, in other income, net in the condensed consolidated statements of income related to these investments. For the six months ended June 30, 2022 and 2021, we recorded a net unrealized loss of approximately $2.0 million and a net unrealized gain of approximately $1.0 million, respectively, in other expense, net in the condensed consolidated statements of income related to these investments. For the investment in the Rabbi Trust, we also have recorded an associated liability, which is included in other pension and benefit costs in the consolidated balance sheets and is adjusted each period for the gains and losses incurred by the investments in the Rabbi Trust.

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Share-Based Compensation

6 Months Ended

Jun. 30, 2022

Share-based Payment Arrangement [Abstract]

Share-Based Compensation

Share-Based Compensation

Our non-employee directors and key employees are granted share-based awards through our SICP. We record these share-based awards as compensation costs over the respective service period for which services are received in exchange for an award of equity or equity-based compensation. The compensation cost is based primarily on the fair value of the shares awarded, using the estimated fair value of each share on the date it was granted and the number of shares to be issued at the end of the service period.

The table below presents the amounts included in net income related to share-based compensation expense for the three and six months ended June 30, 2022 and 2021:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
(in thousands)
Awards to non-employee directors	$	220	$	192	$	454	$	380
Awards to key employees	1,122		1,247		3,101		2,935
Total compensation expense	1,342		1,439		3,555		3,315
Less: tax benefit	(346)		(384)		(917)		(885)
Share-based compensation amounts included in net income	$	996	$	1,055	$	2,638	$	2,430

Non-employee Directors

Shares granted to non-employee directors are issued in advance of the directors’ service periods and are fully vested as of the grant date. We record a deferred expense equal to the fair value of the shares issued and amortize the expense equally over a service period of one year. In May 2022, after the most recent election of directors, each of our non-employee directors received an annual retainer of 652 shares of common stock under the SICP for service as a director through the 2023 Annual Meeting of Stockholders; accordingly, 6,520 shares, with a weighted average fair value of $130.36 per share, were issued and vested in 2022.

At June 30, 2022, there was approximately $0.7 million of unrecognized compensation expense related to shares granted to non-employee directors. This expense will be recognized over the remaining service period ending in May of 2023.

In July, 2022, we announced the appointment of two new non-employee directors to our current Board. These newly appointed directors will be granted share-based awards through the SICP that will be pro-rated in accordance with the beginning of their service period. The associated expense will be recognized in the same manner utilized for our current non-employee directors.

Key Employees

The table below presents the summary of the stock activity for awards to key employees for the six months ended June 30, 2022: 

	Number of Shares	Weighted Average Fair Value
Outstanding—December 31, 2021	197,398	$	94.15
Granted	66,942	$	119.77
Vested	(60,850)	$	90.60
Expired	557	$	91.42
Outstanding—June 30, 2022	204,047	$	102.91

During the six months ended June 30, 2022, we granted awards of 66,942 shares of common stock to key employees under the SICP, including awards granted in February 2022 and to key employees appointed in officer positions. The shares granted are multi-year awards that will vest no later than the three-year service period ending December 31, 2024. All of these stock awards are earned based upon the successful achievement of long-term financial results, which are comprised of market-based and performance-based conditions or targets. The fair value of each performance-based condition or target is equal to the market price of our common stock on the grant date of each award. For the market-based conditions, we used the Monte Carlo valuation to estimate the fair value of each market-based award granted.

In March 2022, upon the election by 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 vested and were paid in February 2022 for the performance period ended December 31, 2021, paid the balance of such awarded shares to each such executive officer net cash remitted to the appropriate taxing authorities. We withheld 21,832 shares, based on the value of the shares on their award date. Total combined payments for the employees’ tax obligations to the taxing authorities were approximately $2.8 million.

At June 30, 2022, the aggregate intrinsic value of the SICP awards granted to key employees was approximately $26.4 million. At June 30, 2022, there was approximately $8.8 million of unrecognized compensation cost related to these awards, which will be recognized through 2024.

Stock Options

There were no stock options outstanding or issued during the six months ended June 30, 2022 and 2021.

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Derivative Instruments

6 Months Ended

Jun. 30, 2022

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments

Derivative Instruments We use derivative and non-derivative contracts to manage risks related to obtaining adequate supplies and the price fluctuations of natural gas, electricity and propane and to mitigate interest rate risk. Our natural gas, electric and propane distribution operations have entered into agreements with suppliers to purchase natural gas, electricity and propane for resale to our customers. Our natural gas gathering and transmission company has entered into contracts with producers to secure natural gas to meet its obligations. Purchases under these contracts typically either do not meet the definition of derivatives or are considered “normal purchases and normal sales” and are accounted for on an accrual basis. Our propane distribution operations may also enter into fair value hedges of their inventory or cash flow hedges of their future purchase commitments in order to mitigate the impact of wholesale price fluctuations. Occasionally, we may enter into interest rate swap agreements to mitigate risk associated with changes in short-term borrowing rates. As of June 30, 2022, our natural gas and electric distribution operations did not have any outstanding derivative contracts.

Volume of Derivative Activity

As of June 30, 2022, the volume of our commodity derivative contracts were as follows:

Business unit	Commodity	Contract Type	Quantity hedged (in millions)	Designation	Longest Expiration date of hedge
Sharp	Propane (gallons)	Purchases	16.0	Cash flows hedges	June 2024
Sharp	Propane (gallons)	Sales	3.8	Cash flows hedges	March 2023

Sharp entered into futures and swap agreements to mitigate the risk of fluctuations in wholesale propane index prices associated with the propane volumes that are expected to be purchased and/or sold during the heating season. Under the futures and swap agreements, Sharp will receive the difference between (i) the index prices (Mont Belvieu prices in June 2022 through June 2024) 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 contract prices, Sharp will pay the difference. We designated and accounted for the propane swaps as cash flows hedges. The change in the fair value of the swap agreements is recorded as unrealized gain (loss) in other comprehensive income (loss) and later recognized in the statement of income in the same period and in the same line item as the hedged transaction. We expect to reclassify approximately $3.8 million from accumulated other comprehensive income to earnings during the next 12-month period ended June 30, 2023.

Interest Rate Swap Activities

We manage interest rate risk by entering into derivative contracts to hedge the variability in cash flows attributable to changes in the short-term borrowing rates. In the fourth quarter of 2020, we entered into two $30.0 million interest rate swaps with a total notional amount of $60.0 million through September and December 2021 with pricing of 0.205 and 0.20 percent, respectively, for the period associated with our outstanding borrowing under the Revolver. In February 2021, we entered into an additional interest rate swap with a notional amount of $40.0 million through December 2021 with pricing of 0.17 percent. Our short-term borrowing is based on the 30-day LIBOR rate. The interest swaps were cash settled monthly as the counter-party pays us the 30-day LIBOR rate less the fixed rate. At December 31, 2021 all of our interest rate swaps had expired and we have not entered into any new derivative contracts associated with our outstanding short-term borrowings in 2022.

We designated and accounted for interest rate swaps as cash flows hedges. Accordingly, unrealized gains and losses associated with the interest rate swaps were recorded as a component of accumulated other comprehensive income (loss). When the interest rate swaps settled, the realized gain or loss was recorded in the income statement and recognized as a component of interest charges.

Broker Margin

Futures exchanges have contract specific margin requirements that require the posting of cash or cash equivalents relating to traded contracts. Margin requirements consist of initial margin that is posted upon the initiation of a position, maintenance margin that is usually expressed as a percent of initial margin, and variation margin that fluctuates based on the daily mark-to-market relative to maintenance margin requirements. We currently maintain a broker margin account for Sharp as follows:

(in thousands)	Balance Sheet Location	June 30, 2022		December 31, 2021
Sharp	Other Accrued Liabilities	$	4,418	$	4,081

Financial Statements Presentation

The following tables present information about the fair value and related gains and losses of our derivative contracts. We did not have any derivative contracts with a credit-risk-related contingency. Fair values of the derivative contracts recorded in the consolidated balance sheets as of June 30, 2022 and December 31, 2021, are as follows: 

	Derivative Assets
		Fair Value As Of
(in thousands)	Balance Sheet Location	June 30, 2022		December 31, 2021
Derivatives not designated as hedging instruments
Propane swap agreements	Derivative assets, at fair value	$	—	$	16
Derivatives designated as cash flow hedges
Propane swap agreements	Derivative assets, at fair value	6,772		7,060
Total Derivative Assets		$	6,772	$	7,076

	Derivative Liabilities
		Fair Value As Of
(in thousands)	Balance Sheet Location	June 30, 2022		December 31, 2021
Derivatives designated as cash flow hedges
Propane swap agreements	Derivative liabilities, at fair value	$	427	$	743

The effects of gains and losses from derivative instruments on the condensed consolidated financial statements are as follows:

		Amount of Gain (Loss) on Derivatives:
	Location of Gain	For the Three Months Ended June 30,				For the Six Months Ended June 30,
(in thousands)	(Loss) on Derivatives	2022		2021		2022		2021
Derivatives not designated as hedging instruments
Propane swap agreements	Unregulated propane and natural gas costs	$	—	$	—	$	56	$	—
Derivatives designated as fair value hedges
Propane put options	Unregulated propane and natural gas costs	—		—		—		(24)
Derivatives designated as cash flow hedges
Propane swap agreements	Revenues	—		—		(826)		—
Propane swap agreements	Unregulated propane and natural gas costs	283		455		3,830		3,502
Propane swap agreements	Other comprehensive income (loss)	(686)		4,319		28		4,548
Interest rate swap agreements	Interest expense	—		22		—		26
Interest rate swap agreements	Other comprehensive income	—		8		—		5
Total		$	(403)	$	4,804	$	3,088	$	8,057

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Fair Value of Financial Instruments

6 Months Ended

Jun. 30, 2022

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments

Fair Value of Financial Instruments

GAAP establishes a fair value hierarchy that prioritizes the inputs to valuation methods used to measure fair value. The three levels of the fair value hierarchy are the following:

Fair Value Hierarchy	Description of Fair Value Level	Fair Value Technique Utilized
Level 1	Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities	Investments - equity securities - The fair values of these trading securities are recorded at fair value based on unadjusted quoted prices in active markets for identical securities. Investments - mutual funds and other - The fair values of these investments, comprised of money market and mutual funds, are recorded at fair value based on quoted net asset values of the shares.
Level 2	Quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability	Derivative assets and liabilities - The fair value of the propane put/call options, propane and interest rate swap agreements are measured using market transactions for similar assets and liabilities in either the listed or over-the-counter markets.
Level 3	Prices or valuation techniques requiring inputs that are both significant to the fair value measurement and unobservable (i.e. supported by little or no market activity)	Investments - guaranteed income fund - The fair values of these investments are recorded at the contract value, which approximates their fair value.

Financial Assets and Liabilities Measured at Fair Value

The following tables summarize our financial assets and liabilities that are measured at fair value on a recurring basis and the fair value measurements, by level, within the fair value hierarchy as of June 30, 2022 and December 31, 2021:

			Fair Value Measurements Using:
As of June 30, 2022	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	$	24	$	24	$	—	$	—
Investments—guaranteed income fund	2,102		—		—		2,102
Investments—mutual funds and other	8,397		8,397		—		—
Total investments	10,523		8,421		—		2,102
Derivative assets	6,772		—		6,772		—
Total assets	$	17,295	$	8,421	$	6,772	$	2,102
Liabilities:
Derivative liabilities	$	427	$	—	$	427	$	—

			Fair Value Measurements Using:
As of December 31, 2021	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	$	26	$	26	$	—	$	—
Investments—guaranteed income fund	2,036		—		—		2,036
Investments—mutual funds and other	10,033		10,033		—		—
Total investments	12,095		10,059		—		2,036
Derivative assets	7,076		—		7,076		—
Total assets	$	19,171	$	10,059	$	7,076	$	2,036
Liabilities:
Derivative liabilities	$	743	$	—	$	743	$	—

The following table sets forth the summary of the changes in the fair value of Level 3 investments for the six months ended June 30, 2022 and 2021:

	Six months ended June 30,
	2022		2021
(in thousands)
Beginning Balance	$	2,036	$	2,156
Purchases and adjustments	132		70
Transfers	—		—
Distribution	(83)		(51)
Investment income	17		16
Ending Balance	$	2,102	$	2,191

Investment income from the Level 3 investments is reflected in other expense, (net) in the condensed consolidated statements of income.

At June 30, 2022, there were no non-financial assets or liabilities required to be reported at fair value. We review our non-financial assets for impairment at least on an annual basis, as required.

Other Financial Assets and Liabilities

Financial assets with carrying values approximating fair value include cash and cash equivalents and accounts receivable. Financial liabilities with carrying values approximating fair value include accounts payable and other accrued liabilities and short-term debt. The fair value of cash and cash equivalents is measured using the comparable value in the active market and approximates its carrying value (Level 1 measurement). The fair value of short-term debt approximates the carrying value due to its near-term maturities and because interest rates approximate current market rates (Level 3 measurement).

At June 30, 2022, long-term debt, which includes current maturities but excludes debt issuance costs, had a carrying value of approximately $608.3 million, compared to the estimated fair value of $540.6 million. At December 31, 2021, long-term debt, which includes the current maturities but excludes debt issuance costs, had a carrying value of approximately $568.8 million, compared to a fair value of approximately $597.2 million. The fair value was calculated using a discounted cash flow methodology that incorporates a market interest rate based on published corporate borrowing rates for debt instruments with similar terms and average maturities, and with adjustments for duration, optionality, and risk profile. The valuation technique used to estimate the fair value of long-term debt would be considered a Level 3 measurement.

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Long-Term Debt

6 Months Ended

Jun. 30, 2022

Debt Disclosure [Abstract]

Long-Term Debt

Long-Term Debt

Our outstanding long-term debt is shown below: 

	June 30,		December 31,
(in thousands)	2022		2021
Uncollateralized senior notes:
5.93% note, due October 31, 2023	$	4,500	$	6,000
5.68% note, due June 30, 2026	11,600		14,500
6.43% note, due May 2, 2028	4,200		4,900
3.73% note, due December 16, 2028	14,000		14,000
3.88% note, due May 15, 2029	35,000		40,000
3.25% note, due April 30, 2032	70,000		70,000
3.48% note, due May 31, 2038	50,000		50,000
3.58% note, due November 30, 2038	50,000		50,000
3.98% note, due August 20, 2039	100,000		100,000
2.98% note, due December 20, 2034	70,000		70,000
3.00% note, due July 15, 2035	50,000		50,000
2.96% note, due August 15, 2035	40,000		40,000
2.49% notes Due January 25, 2037	50,000		50,000
2.95% notes Due March 15, 2042	50,000		—
Equipment security note
2.46% note, due September 24, 2031	8,950		9,378
Less: debt issuance costs	(973)		(913)
Total long-term debt	607,277		567,865
Less: current maturities	(21,472)		(17,962)
Total long-term debt, net of current maturities	$	585,805	$	549,903

    

Note Purchase Agreement

On March 15, 2022 we issued 2.95 percent Senior Notes due March 15, 2042 to MetLife in the aggregate principal amount of $50 million. We used the proceeds received from the issuances of the Senior Notes to reduce short-term borrowings under the Revolver and to fund capital expenditures. These Senior Notes have similar covenants and default provisions as our other Senior Notes, and have an annual principal payment beginning in the eleventh year after the issuance.

Equipment Security Note

On September 24, 2021, we entered into an Equipment Financing Agreement with Banc of America Leasing & Capital, LLC to issue $9.6 million in sustainable financing to finance the purchase of equipment by our subsidiary, Marlin Gas Services. The equipment security note bears a 2.46 percent interest rate and has a term of ten years. Under the terms of the agreement, we granted a security interest in the equipment to the lender, to serve as collateral.

Shelf Agreements

We have entered into Shelf Agreements with Prudential and MetLife, whom are under no obligation to purchase any unsecured debt. The following table summarizes our Shelf Agreements at June 30, 2022:

(in thousands)	Total Borrowing Capacity		Less: Amount of Debt Issued		Less: Unfunded Commitments		Remaining Borrowing Capacity
Shelf Agreement
Prudential Shelf Agreement (1)	$	370,000	$	(220,000)	$	—	$	150,000
MetLife Shelf Agreement (1)	150,000		(50,000)		—		100,000
Total Shelf Agreements as of June 30, 2022	$	520,000	$	(270,000)	$	—	$	250,000

     (1) The Prudential and MetLife Shelf Agreements expire in April 2023 and May 2023, respectively.

The Uncollateralized Senior Notes, Shelf Agreements or Shelf Notes set forth certain business covenants to which we are subject when any note is outstanding, including covenants that limit or restrict our ability, and the ability of our subsidiaries, to incur indebtedness, or place or permit liens and encumbrances on any of our property or the property of our subsidiaries.

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Short-Term Borrowings (Notes)

6 Months Ended

Jun. 30, 2022

Short-Term Borrowing [Abstract]

Short-term Debt [Text Block]

16.    Short-Term Borrowings

We are authorized by our Board of Directors to borrow up to $400.0 million of short-term debt, as required. At June 30, 2022 and December 31, 2021, we had $137.0 million and $221.6 million, respectively, of short-term borrowings outstanding at a weighted average interest rate of 2.38 percent and 0.83 percent, respectively.

In August 2021, we amended and restated our Revolver into a multi-tranche facility totaling $400.0 million with multiple participating lenders. The two tranches of the Revolver consist of a $200.0 million 364-day short-term debt tranche and a $200.0 million five-year tranche, both of which have three (3) one-year extension options, which can be authorized by our Chief Financial Officer. We are eligible to establish the repayment term for individual borrowings under the five year tranche of the Revolver and to the extent that an individual loan under the Revolver exceeded 12 months, the outstanding balance would be classified as a component of long-term debt.

The availability of funds under the Revolver is subject to conditions specified in the credit agreement, all of which we currently satisfy. These conditions include our compliance with financial covenants and the continued accuracy of representations and warranties contained in the Revolver's loan documents. We are required by the financial covenants in the Revolver to maintain, at the end of each fiscal year, a funded indebtedness ratio of no greater than 65 percent. As of June 30, 2022, we are in compliance with this covenant.

The 364-day tranche of the Revolver expires in August 2022 and the five-year tranche expires in August 2026 both are available to fund for our short-term cash needs to meet seasonal working capital requirements and to temporarily fund portions of our capital expenditures. Borrowings under both tranches of the Revolver are subject to a pricing grid, including the commitment fee and the interest rate charged. Our pricing is adjusted each quarter based upon a total indebtedness to total capitalization ratio. As of June 30, 2022, the pricing under the 364-day tranche of the Revolver does not include an unused commitment fee and maintains an interest rate of 0.70 percent over LIBOR. As of June 30, 2022, the pricing under the five-year tranche of the Revolver included an unused commitment fee of 0.09 percent and an interest rate of 0.95 percent over LIBOR.

We are currently in discussions with the various lending institutions regarding the renewal of the 364-day tranche. At that time, the reference interest rate for the 364-day and five-year tranche will transition from LIBOR which is being retired by financial institutions to the Standard Overnight Financing Rate ("SOFR"). We do not expect this transition to have a material impact on our financial condition.

Our total available credit under the Revolver at June 30, 2022 was $257.7 million. As of June 30, 2022, we had issued $5.3 million in letters of credit to various counterparties under the syndicated Revolvers. These letters of credit are not included in the outstanding short-term borrowings and we do not anticipate that they will be drawn upon by the counterparties. The letters of credit reduce the available borrowings under our syndicated Revolver.

In the fourth quarter of 2020, we entered into two $30.0 million interest rate swaps with a notional amount of $60.0 million through September and December 2021 at a pricing of 0.205 and 0.20 percent, respectively. In February 2021, we entered into an additional interest rate swap with a notional amount of $40.0 million through December 2021 with pricing of 0.17 percent. Our short-term borrowing is based on the 30-day LIBOR rate. At December 31, 2021, all of our interest rate swaps had expired and we have not entered into any new derivative contracts associated with our outstanding short-term borrowings.

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Leases Leases

6 Months Ended

Jun. 30, 2022

Lease Disclosure [Abstract]

Lessee, Operating Leases [Text Block]

Leases

    We have entered into lease arrangements for office space, land, equipment, pipeline facilities and warehouses. These lease arrangements enable us to better conduct business operations in the regions in which we operate. Office space is leased to provide adequate workspace for our employees in several locations throughout our service territories. We lease land at various locations throughout our service territories to enable us to inject natural gas into underground storage and distribution systems, for bulk storage capacity, for our propane operations and for storage of equipment used in repairs and maintenance of our infrastructure. We lease natural gas compressors to ensure timely and reliable transportation of natural gas to our customers. Additionally, we lease a pipeline to deliver natural gas to an industrial customer in Polk County, Florida. We also lease warehouses to store equipment and materials used in repairs and maintenance for our businesses.

Some of our leases are subject to annual changes in the Consumer Price Index (“CPI”). While lease liabilities are not re-measured as a result of changes to the CPI, changes to the CPI are treated as variable lease payments and recognized in the period in which the obligation for those payments was incurred. A 100-basis-point increase in CPI would not have resulted in material additional annual lease costs. Most of our leases include options to renew, with renewal terms that can extend the lease term from one to 25 years or more. The exercise of lease renewal options is at our sole discretion. The amounts disclosed in our consolidated balance sheet at June 30, 2022, pertaining to the right-of-use assets and lease liabilities, are measured based on our current expectations of exercising our available renewal options. Our existing leases are not subject to any restrictions or covenants that would preclude our ability to pay dividends, obtain financing or enter into additional leases. As of June 30, 2022, we have not entered into any leases, which have not yet commenced, that would entitle us to significant rights or create additional obligations. The following table presents information related to our total lease cost included in our consolidated statements of income:

		Three Months Ended		Six Months Ended
		June 30,		June 30,
( in thousands)	Classification	2022	2021	2022	2021
Operating lease cost (1)	Operations expense	$726	$515	$1,377	$1,038

(1) Includes short-term leases and variable lease costs, which are immaterial.

The following table presents the balance and classifications of our right of use assets and lease liabilities included in our condensed consolidated balance sheet at June 30, 2022 and December 31, 2021:

(in thousands)	Balance sheet classification	June 30, 2022		December 31, 2021
Assets
Operating lease assets	Operating lease right-of-use assets	$	15,767	$	10,139
Liabilities
Current
Operating lease liabilities	Other accrued liabilities	$	2,501	$	1,996
Noncurrent
Operating lease liabilities	Operating lease - liabilities	13,807		8,571
Total lease liabilities		$	16,308	$	10,567

The following table presents our weighted-average remaining lease terms and weighted-average discount rates for our operating and financing leases at June 30, 2022 and December 31, 2021:

	June 30, 2022		December 31, 2021
Weighted-average remaining lease term (in years)
Operating leases	8.32		8.10
Weighted-average discount rate
Operating leases	3.3	%	3.6	%

The following table presents additional information related to cash paid for amounts included in the measurement of lease liabilities included in our condensed consolidated statements of cash flows as of June 30, 2022 and 2021:

	Six Months Ended
	June 30,
(in thousands)	2022		2021
Operating cash flows from operating leases	$	1,428	$	936

The following table presents the future undiscounted maturities of our operating and financing leases at June 30, 2022 and for each of the next five years and thereafter:

(in thousands)	Operating  Leases (1)
Remainder of 2022	$	1,392
2023	2,844
2024	2,629
2025	2,260
2026	1,746
2027	1,501
Thereafter	5,994
Total lease payments	18,366
Less: Interest	(2,058)
Present value of lease liabilities	$	16,308

    (1) Operating lease payments include $2.1 million related to options to extend lease terms that are reasonably certain of being exercised.

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Summary of Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2022

Accounting Policies [Abstract]

COVID-19 Effect [Policy Text Block]

Effects of COVID-19

In March 2020, the CDC declared a national emergency due to the rapidly growing outbreak of COVID-19. In response to this declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the country imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to slow the spread of the illness. These restrictions significantly impacted economic conditions in the United States beginning in 2020 and to a lesser extent have continued into 2022. Chesapeake Utilities is considered an “essential business,” which allowed us to continue operational activities and construction projects while social distancing restrictions were in place. At this time, restrictions have predominantly been lifted as vaccines have become widely available in the United States. Previously existing states of emergency in all of our service territories expired during the second and third quarters of 2021 eliminating a majority of restrictions initially implemented to slow the spread of the virus. The expiration of the states of emergency along with the settlement of our limited proceeding in Florida concluded our ability to defer incremental pandemic related costs for consideration through the applicable regulatory process. We adjusted our operating practices accordingly to ensure the safety of our operations and will take the necessary actions to comply with the CDC, and the Occupational and Safety and Health Administration, as new developments occur.

Refer to Note 5, Rates and Other Regulatory Activities, for further information on the regulated assets established as a result of the incremental expenses associated with COVID-19.

Basis of Presentation

Basis of Presentation

References in this document to the “Company,” “Chesapeake Utilities,” “we,” “us” and “our” are intended to mean Chesapeake Utilities Corporation, its divisions and/or its subsidiaries, as appropriate in the context of the disclosure.

The accompanying unaudited condensed consolidated financial statements have been prepared in compliance with the rules and regulations of the SEC and GAAP. In accordance with these rules and regulations, certain information and disclosures normally required for audited financial statements have been condensed or omitted. These financial statements should be read in conjunction with the consolidated financial statements and notes thereto, included in our latest Annual Report on Form 10-K for the year ended December 31, 2021. In the opinion of management, these financial statements reflect all adjustments that are necessary for a fair presentation of our results of operations, financial position and cash flows for the interim periods presented.

Where necessary to improve comparability, prior period amounts have been changed to conform to current period presentation.

Due to the seasonality of our business, results for interim periods are not necessarily indicative of results for the entire fiscal year. Revenue and earnings are typically greater during the first and fourth quarters, when consumption of energy is highest due to colder temperatures.

FASB Statements and Other Authoritative Pronouncements

Recent Accounting Standards Yet to be Adopted

Reference Rate Reform - (ASC 848) - In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting, which was subsequently amended by ASU 2021-01. The standard provides relief for companies preparing for the discontinuation of interest rates, such as LIBOR, and allows optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions affected by reference rate reform. The amendments included in this ASU are to be applied prospectively, and are not expected to have a material impact on our financial position or results of operations. Refer to Note 16, Short-Term Borrowings, for further information regarding the expected timing of implementing this update.

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Calculation of Earnings Per Share (Tables)

6 Months Ended

Jun. 30, 2022

Earnings Per Share [Abstract]

Calculation of Basic and Diluted Earnings Per Share

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
(in thousands, except shares and per share data)
Calculation of Basic Earnings Per Share:
Net Income	$	17,051	$	13,813	$	53,985	$	48,279
Weighted average shares outstanding	17,730,833		17,546,346		17,704,592		17,516,273
Basic Earnings Per Share	$	0.96	$	0.79	$	3.05	$	2.76
Calculation of Diluted Earnings Per Share:
Net Income	$	17,051	$	13,813	$	53,985	$	48,279
Reconciliation of Denominator:
Weighted shares outstanding—Basic	17,730,833		17,546,346		17,704,592		17,516,273
Effect of dilutive securities—Share-based compensation	79,038		70,150		81,037		68,733
Adjusted denominator—Diluted	17,809,871		17,616,496		17,785,629		17,585,006
Diluted Earnings Per Share	$	0.96	$	0.78	$	3.04	$	2.75

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Revenue Recognition (Tables)

6 Months Ended

Jun. 30, 2022

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 June 30, 2022 and 2021:

	Three months ended June 30, 2022								Three months ended June 30, 2021
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total		Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Energy distribution
Delaware natural gas division	$	13,086	$	—	$	—	$	13,086	$	10,068	$	—	$	—	$	10,068
Florida natural gas division	9,619		—		—		9,619		8,446		—		—		8,446
FPU electric distribution	20,305		—		—		20,305		18,898		—		—		18,898
FPU natural gas distribution	25,817		—		—		25,817		23,159		—		—		23,159
Maryland natural gas division	4,372		—		—		4,372		3,224		—		—		3,224
Sandpiper natural gas/propane operations	4,248		—		—		4,248		3,814		—		—		3,814
Elkton Gas	1,705		—		—		1,705		1,195		—		—		1,195
Total energy distribution	79,152		—		—		79,152		68,804		—		—		68,804
Energy transmission
Aspire Energy	—		10,808		—		10,808		—		5,578		—		5,578
Aspire Energy Express	369		—		—		369		47		—		—		47
Eastern Shore	18,875		—		—		18,875		18,617		—		—		18,617
Peninsula Pipeline	6,777		—		—		6,777		6,610		—		—		6,610
Total energy transmission	26,021		10,808		—		36,829		25,274		5,578		—		30,852
Energy generation
Eight Flags	—		5,916		—		5,916		—		4,173		—		4,173
Propane operations
Propane delivery operations	—		34,469		—		34,469		—		23,098		—		23,098
Compressed Natural Gas Services
Marlin Gas Services	—		2,380		—		2,380		—		1,989		—		1,989
Other and eliminations
Eliminations	(12,980)		(110)		(6,271)		(19,361)		(13,168)		(65)		(4,734)		(17,967)
Other	—		—		85		85		—		—		133		133
Total other and eliminations	(12,980)		(110)		(6,186)		(19,276)		(13,168)		(65)		(4,601)		(17,834)
Total operating revenues (1)	$	92,193	$	53,463	$	(6,186)	$	139,470	$	80,910	$	34,773	$	(4,601)	$	111,082

(1) Total operating revenues for the three months ended June 30, 2022, include other revenue (revenues from sources other than contracts with customers) of $(0.1) million for Regulated and $0.1 million Unregulated Energy segments, respectively, and $0.1 million for both our Regulated and Unregulated Energy segments, respectively, for the three months ended June 30, 2021. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the Maryland division and Sandpiper Energy and late fees.

The following table displays our revenue by major source based on product and service type for the six months ended June 30, 2022 and 2021:

	Six Months Ended June 30, 2022								Six Months Ended June 30, 2021
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total		Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Energy distribution
Delaware natural gas division	$	47,568	$	—	$	—	$	47,568	$	43,340	$	—	$	—	$	43,340
Florida natural gas division	19,885		—		—		19,885		17,402		—		—		17,402
FPU electric distribution	39,394		—		—		39,394		37,449		—		—		37,449
FPU natural gas distribution	55,837		—		—		55,837		50,020		—		—		50,020
Maryland natural gas division	14,836		—		—		14,836		13,690		—		—		13,690
Sandpiper natural gas/propane operations	11,885		—		—		11,885		11,885		—		—		11,885
Elkton Gas	5,071		—		—		5,071		3,830		—		—		3,830
Total energy distribution	194,476		—		—		194,476		177,616		—		—		177,616
Energy transmission
Aspire Energy	—		28,844		—		28,844		—		18,484		—		18,484
Aspire Energy Express	632		—		—		632		93		—		—		93
Eastern Shore	39,196		—		—		39,196		38,589		—		—		38,589
Peninsula Pipeline	13,549		—		—		13,549		13,077		—		—		13,077
Total energy transmission	53,377		28,844		—		82,221		51,759		18,484		—		70,243
Energy generation
Eight Flags	—		11,455		—		11,455		—		8,502		—		8,502
Propane operations
Propane delivery operations	—		110,075		—		110,075		—		78,361		—		78,361
Compressed Natural Gas Services
Marlin Gas Services	—		4,589		—		4,589		—		4,340		—		4,340
Other and eliminations
Eliminations	(27,769)		(207)		(12,706)		(40,682)		(27,268)		(156)		(9,635)		(37,059)
Other	—		—		216		216		—		—		265		265
Total other and eliminations	(27,769)		(207)		(12,490)		(40,466)		(27,268)		(156)		(9,370)		(36,794)
Total operating revenues (1)	$	220,084	$	154,756	$	(12,490)	$	362,350	$	202,107	$	109,531	$	(9,370)	$	302,268

(1) Total operating revenues for the six months ended June 30, 2022, include other revenue (revenues from sources other than contracts with customers) of $0.1 million for Regulated and $0.2 million Unregulated Energy segments, respectively, and $(0.2) million and $0.2 million for our Regulated and Unregulated Energy segments, respectively, for the six months ended June 30, 2021. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the Maryland division and Sandpiper Energy and late fees.

Contract with Customer, Asset and Liability [Table Text Block]

The balances of our trade receivables, contract assets, and contract liabilities as of June 30, 2022 and December 31, 2021 were as follows:

	Trade Receivables		Contract Assets (Current)		Contract Assets (Non-current)		Contract Liabilities (Current)
(in thousands)
Balance at 12/31/2021	$	56,277	$	18	$	4,806	$	747
Balance at 6/30/2022	38,778		18		4,607		724
Decrease	$	(17,499)	$	—	$	(199)	$	(23)

Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block]

Revenue for these businesses for the remaining performance obligations, at June 30, 2022, are expected to be recognized as follows:

(in thousands)	2022		2023		2024		2025		2026		2027		2028 and thereafter
Eastern Shore and Peninsula Pipeline	$	24,379	$	45,426	$	40,431	$	33,804	$	29,294	$	25,096	$	179,259
Natural gas distribution operations	3,433		6,238		6,050		5,698		5,515		5,100		33,113
FPU electric distribution	326		652		652		275		275		275		275
Total revenue contracts with remaining performance obligations	$	28,138	$	52,316	$	47,133	$	39,777	$	35,084	$	30,471	$	212,647

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Rates and Other Regulatory Activities Rates and Regulatory Activities (Tables)

6 Months Ended

Jun. 30, 2022

Rates and Regulatory Activities [Abstract]

Summary of Effects of Federal Tax Reform on Regulated Businesses [Table Text Block]

The following table summarizes the regulatory liabilities related to accumulated deferred taxes ("ADIT") associated with TCJA for our regulated businesses as of June 30, 2022 and December 31, 2021:

	Amount (in thousands)
Operation and Regulatory Jurisdiction	June 30, 2022	December 31, 2021	Status
Eastern Shore (FERC)	$34,190	$34,190	Will be addressed in Eastern Shore's next rate case filing.
Delaware natural gas division (Delaware PSC)	$12,510	$12,591	PSC approved amortization of ADIT in January 2019.
Maryland natural gas division (Maryland PSC)	$3,772	$3,840	PSC approved amortization of ADIT in May 2018.
Sandpiper Energy (Maryland PSC)	$3,626	$3,656	PSC approved amortization of ADIT in May 2018.
Chesapeake Florida natural gas division/CFG (Florida PSC)	$7,939	$8,032	PSC issued order authorizing amortization and retention of net ADIT liability by the Company in February 2019.
FPU natural gas (excludes Fort Meade and Indiantown) (Florida PSC)	$19,058	$19,189	Same treatment on a net basis as Chesapeake Florida Gas Division (above).
FPU Fort Meade and Indiantown natural gas divisions (Florida PSC)	$265	$271	Same treatment on a net basis as Chesapeake Florida Gas Division (above).
FPU electric division (Florida PSC)	$5,115	$5,237	In January 2019, PSC issued order approving amortization of ADIT through purchased power cost recovery, storm reserve and rates.
Elkton Gas (Maryland PSC)	$1,074	$1,091	PSC approved amortization of ADIT in March 2018.

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Segment Information (Tables)

6 Months Ended

Jun. 30, 2022

Segment Reporting [Abstract]

Schedule of Segment Reporting Information by Segment

The following table presents financial information about our reportable segments:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
(in thousands)
Operating Revenues, Unaffiliated Customers
Regulated Energy	$	91,830	$	80,374	$	215,888	$	201,095
Unregulated Energy	47,640		30,708		146,462		101,173
Total operating revenues, unaffiliated customers	$	139,470	$	111,082	$	362,350	$	302,268
Intersegment Revenues (1)
Regulated Energy	$	363	$	536	$	4,196	$	1,012
Unregulated Energy	5,823		4,065		7,819		8,358
Other businesses	85		133		691		265
Total intersegment revenues	$	6,271	$	4,734	$	12,706	$	9,635
Operating Income
Regulated Energy	$	25,841	$	22,760	$	60,539	$	55,466
Unregulated Energy	560		(465)		20,613		18,575
Other businesses and eliminations	68		283		182		134
Operating income	26,469		22,578		81,334		74,175
Other income, net	2,584		1,453		3,498		1,828
Interest charges	5,825		5,054		11,164		10,159
Income before Income Taxes	23,228		18,977		73,668		65,844
Income Taxes	6,177		5,164		19,683		17,565
Net Income	$	17,051	$	13,813	$	53,985	$	48,279

    

(1) All significant intersegment revenues are billed at market rates and have been eliminated from consolidated operating revenues.

(in thousands)	June 30, 2022		December 31, 2021
Identifiable Assets
Regulated Energy segment	$	1,637,003	$	1,629,191
Unregulated Energy segment	447,209		439,114
Other businesses and eliminations	33,130		46,564
Total identifiable assets	$	2,117,342	$	2,114,869

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Stockholder's Equity - Accumulated Other Comprehensive Income (Loss) (Tables)

6 Months Ended

Jun. 30, 2022

Equity [Abstract]

Changes in Accumulated Other Comprehensive Loss

	Defined Benefit		Commodity		Interest Rate
	Pension and		Contracts		Swap
	Postretirement		Cash Flow		Cash Flow
	Plan Items		Hedges		Hedges (1)		Total
(in thousands)
As of December 31, 2021	$	(3,268)	$	4,571	$	—	$	1,303
Other comprehensive income before reclassifications	—		2,206		—		2,206
Amounts reclassified from accumulated other comprehensive income/(loss)	35		(2,174)		—		(2,139)
Net current-period other comprehensive income	35		32		—		67
As of June 30, 2022	$	(3,233)	$	4,603	$	—	$	1,370

(in thousands)
As of December 31, 2020	$	(5,146)	$	2,309	$	(28)	$	(2,865)
Other comprehensive income before reclassifications	—		5,825		23		5,848
Amounts reclassified from accumulated other comprehensive income/(loss)	128		(2,534)		(19)		(2,425)
Net prior-period other comprehensive income	128		3,291		4		3,423
As of June 30, 2021	$	(5,018)	$	5,600	$	(24)	$	558

Reclassifications out of Accumulated Other Comprehensive Income (Loss)

The following table presents amounts reclassified out of accumulated other comprehensive income (loss) for the three and six months ended June 30, 2022 and 2021. Deferred gains or losses for our commodity contracts and interest rate swap cash flow hedges are recognized in earnings upon settlement.

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
(in thousands)
Amortization of defined benefit pension and postretirement plan items:
Prior service credit (1)	$	19	$	19	$	38	$	38
Net loss(1)	(43)		(106)		(86)		(209)
Total before income taxes	(24)		(87)		(48)		(171)
Income tax benefit	6		23		13		43
Net of tax	$	(18)	$	(64)	$	(35)	$	(128)
Gains on commodity contracts cash flow hedges:
Propane swap agreements (2)	$	283	$	455	$	3,004	$	3,502
Income tax expense	(78)		(126)		(830)		(968)
Net of tax	$	205	$	329	$	2,174	$	2,534
Gains on interest rate swap cash flow hedges:
Interest rate swap agreements	$	—	$	22	$	—	$	26
Income tax expense	—		(6)		—		(7)
Net of tax	$	—	$	16	$	—	$	19
Total reclassifications for the period	$	187	$	281	$	2,139	$	2,425

(1) These amounts are included in the computation of net periodic costs (benefits). See Note 10, Employee Benefit Plans, for additional details.

(2) These amounts are included in the effects of gains and losses from derivative instruments. See Note 13, Derivative Instruments, for additional details.

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Employee Benefit Plans (Tables)

6 Months Ended

Jun. 30, 2022

Retirement Benefits [Abstract]

Schedule of Net Benefit Costs [Table Text Block]

Net periodic benefit costs for our pension and post-retirement benefits plans for the three and six months ended June 30, 2022 and 2021 are set forth in the following tables:

	Chesapeake Pension Plan				FPU Pension Plan				Chesapeake SERP				Chesapeake Postretirement Plan				FPU Medical Plan
For the Three Months Ended June 30,	2022		2021		2022		2021		2022		2021		2022		2021		2022		2021
(in thousands)
Interest cost	$	—	$	34	$	449	$	429	$	13	$	12	$	6	$	6	$	6	$	6
Expected return on plan assets	—		(40)		(857)		(830)		—		—		—		—		—		—
Amortization of prior service credit	—		—		—		—		—		—		(19)		(19)		—		—
Amortization of net (gain) loss	—		60		124		155		7		7		12		10		—		(2)
Total periodic cost (benefit)	$	—	$	54	$	(284)	$	(246)	$	20	$	19	$	(1)	$	(3)	$	6	$	4

	Chesapeake Pension Plan				FPU Pension Plan				Chesapeake SERP				Chesapeake Postretirement Plan				FPU Medical Plan
For the Six Months Ended June 30,	2022		2021		2022		2021		2022		2021		2022		2021		2022		2021
(in thousands)
Interest cost	$	—	$	68	$	898	$	858	$	26	$	24	$	12	$	12	$	12	$	12
Expected return on plan assets	—		(80)		(1,714)		(1,660)		—		—		—		—		—		—
Amortization of prior service credit	—		—		—		—		—		—		(38)		(38)		—		—
Amortization of net (gain) loss	—		120		248		310		14		14		24		18		—		(4)
Total periodic cost (benefit)	$	—	$	108	$	(568)	$	(492)	$	40	$	38	$	(2)	$	(8)	$	12	$	8

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 income that were recognized as components of net periodic benefit cost during the three and six months ended June 30, 2022 and 2021: 

For the Three Months Ended June 30, 2022	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan		FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(19)	$	—	$	(19)
Net loss	—		124		7		12		—		143
Total recognized in net periodic benefit cost	—		124		7		(7)		—		124
Recognized from accumulated other comprehensive (income)/loss (1)	—		24		7		(7)		—		24
Recognized from regulatory asset	—		100		—		—		—		100
Total	$	—	$	124	$	7	$	(7)	$	—	$	124

For the Three Months Ended June 30, 2021	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan		FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(19)	$	—	$	(19)
Net loss	60		155		7		10		(2)		230
Total recognized in net periodic benefit cost	60		155		7		(9)		(2)		211
Recognized from accumulated other comprehensive (income)/loss (1)	60		29		7		(9)		—		87
Recognized from regulatory asset	—		126		—		—		(2)		124
Total	$	60	$	155	$	7	$	(9)	$	(2)	$	211

.

For the Six months ended June 30, 2022	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan		FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(38)	$	—	$	(38)
Net loss	—		248		14		24		—		286
Total recognized in net periodic benefit cost	—		248		14		(14)		—		248
Recognized from accumulated other comprehensive (income)/loss (1)	—		48		14		(14)		—		48
Recognized from regulatory asset	—		200		—		—		—		200
Total	$	—	$	248	$	14	$	(14)	$	—	$	248

For the Six months ended June 30, 2021	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan		FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(38)	$	—	$	(38)
Net loss	120		310		14		18		(4)		458
Total recognized in net periodic benefit cost	120		310		14		(20)		(4)		420
Recognized from accumulated other comprehensive (income)/loss (1)	120		58		14		(20)		(1)		171
Recognized from regulatory asset	—		252		—		—		(3)		249
Total	$	120	$	310	$	14	$	(20)	$	(4)	$	420

(1) See Note 9, Stockholders' Equity.

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Investments (Tables)

6 Months Ended

Jun. 30, 2022

Investments, Debt and Equity Securities [Abstract]

Investments schedule [Table Text Block]

The investment balances at June 30, 2022 and December 31, 2021, consisted of the following:

(in thousands)	June 30, 2022		December 31, 2021
Rabbi trust (associated with the Non-Qualified Deferred Compensation Plan)	$	10,499	$	12,069
Investments in equity securities	24		26
Total	$	10,523	$	12,095

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Share-Based Compensation (Tables)

6 Months Ended

Jun. 30, 2022

Shares awarded to non-employee directors [Line Items]

Schedule of Compensation Cost for Share-based Payment Arrangements, Allocation of Share-based Compensation Costs by Plan

The table below presents the amounts included in net income related to share-based compensation expense for the three and six months ended June 30, 2022 and 2021:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
(in thousands)
Awards to non-employee directors	$	220	$	192	$	454	$	380
Awards to key employees	1,122		1,247		3,101		2,935
Total compensation expense	1,342		1,439		3,555		3,315
Less: tax benefit	(346)		(384)		(917)		(885)
Share-based compensation amounts included in net income	$	996	$	1,055	$	2,638	$	2,430

Award to key employees [Member]

Shares awarded to non-employee directors [Line Items]

Schedule of Share-based Compensation, Activity

The table below presents the summary of the stock activity for awards to key employees for the six months ended June 30, 2022: 

	Number of Shares	Weighted Average Fair Value
Outstanding—December 31, 2021	197,398	$	94.15
Granted	66,942	$	119.77
Vested	(60,850)	$	90.60
Expired	557	$	91.42
Outstanding—June 30, 2022	204,047	$	102.91

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Derivative Instruments (Tables)

6 Months Ended

Jun. 30, 2022

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Derivative Instruments [Table Text Block]

As of June 30, 2022, the volume of our commodity derivative contracts were as follows:

Business unit	Commodity	Contract Type	Quantity hedged (in millions)	Designation	Longest Expiration date of hedge
Sharp	Propane (gallons)	Purchases	16.0	Cash flows hedges	June 2024
Sharp	Propane (gallons)	Sales	3.8	Cash flows hedges	March 2023

Schedule of Due to (from) Broker-Dealers and Clearing Organizations [Table Text Block]

(in thousands)	Balance Sheet Location	June 30, 2022		December 31, 2021
Sharp	Other Accrued Liabilities	$	4,418	$	4,081

Fair Values of Derivative Contracts Recorded in Condensed Consolidated Balance Sheet

June 30, 2022 and December 31, 2021, are as follows: 

	Derivative Assets
		Fair Value As Of
(in thousands)	Balance Sheet Location	June 30, 2022		December 31, 2021
Derivatives not designated as hedging instruments
Propane swap agreements	Derivative assets, at fair value	$	—	$	16
Derivatives designated as cash flow hedges
Propane swap agreements	Derivative assets, at fair value	6,772		7,060
Total Derivative Assets		$	6,772	$	7,076

	Derivative Liabilities
		Fair Value As Of
(in thousands)	Balance Sheet Location	June 30, 2022		December 31, 2021
Derivatives designated as cash flow hedges
Propane swap agreements	Derivative liabilities, at fair value	$	427	$	743

Effects of Gains and Losses from Derivative Instruments on Condensed Consolidated Financial Statements

The effects of gains and losses from derivative instruments on the condensed consolidated financial statements are as follows:

		Amount of Gain (Loss) on Derivatives:
	Location of Gain	For the Three Months Ended June 30,				For the Six Months Ended June 30,
(in thousands)	(Loss) on Derivatives	2022		2021		2022		2021
Derivatives not designated as hedging instruments
Propane swap agreements	Unregulated propane and natural gas costs	$	—	$	—	$	56	$	—
Derivatives designated as fair value hedges
Propane put options	Unregulated propane and natural gas costs	—		—		—		(24)
Derivatives designated as cash flow hedges
Propane swap agreements	Revenues	—		—		(826)		—
Propane swap agreements	Unregulated propane and natural gas costs	283		455		3,830		3,502
Propane swap agreements	Other comprehensive income (loss)	(686)		4,319		28		4,548
Interest rate swap agreements	Interest expense	—		22		—		26
Interest rate swap agreements	Other comprehensive income	—		8		—		5
Total		$	(403)	$	4,804	$	3,088	$	8,057

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Fair Value of Financial Instruments (Tables)

6 Months Ended

Jun. 30, 2022

Fair Value Disclosures [Abstract]

Financial Assets and Liabilities Measured at Fair Value on Recurring Basis

The following tables summarize our financial assets and liabilities that are measured at fair value on a recurring basis and the fair value measurements, by level, within the fair value hierarchy as of June 30, 2022 and December 31, 2021:

			Fair Value Measurements Using:
As of June 30, 2022	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	$	24	$	24	$	—	$	—
Investments—guaranteed income fund	2,102		—		—		2,102
Investments—mutual funds and other	8,397		8,397		—		—
Total investments	10,523		8,421		—		2,102
Derivative assets	6,772		—		6,772		—
Total assets	$	17,295	$	8,421	$	6,772	$	2,102
Liabilities:
Derivative liabilities	$	427	$	—	$	427	$	—

			Fair Value Measurements Using:
As of December 31, 2021	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	$	26	$	26	$	—	$	—
Investments—guaranteed income fund	2,036		—		—		2,036
Investments—mutual funds and other	10,033		10,033		—		—
Total investments	12,095		10,059		—		2,036
Derivative assets	7,076		—		7,076		—
Total assets	$	19,171	$	10,059	$	7,076	$	2,036
Liabilities:
Derivative liabilities	$	743	$	—	$	743	$	—

Summary of Changes in Fair Value of Investments

The following table sets forth the summary of the changes in the fair value of Level 3 investments for the six months ended June 30, 2022 and 2021:

	Six months ended June 30,
	2022		2021
(in thousands)
Beginning Balance	$	2,036	$	2,156
Purchases and adjustments	132		70
Transfers	—		—
Distribution	(83)		(51)
Investment income	17		16
Ending Balance	$	2,102	$	2,191

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Long-Term Debt (Tables)

6 Months Ended

Jun. 30, 2022

Debt Disclosure [Abstract]

Outstanding Long-Term Debt

Our outstanding long-term debt is shown below: 

	June 30,		December 31,
(in thousands)	2022		2021
Uncollateralized senior notes:
5.93% note, due October 31, 2023	$	4,500	$	6,000
5.68% note, due June 30, 2026	11,600		14,500
6.43% note, due May 2, 2028	4,200		4,900
3.73% note, due December 16, 2028	14,000		14,000
3.88% note, due May 15, 2029	35,000		40,000
3.25% note, due April 30, 2032	70,000		70,000
3.48% note, due May 31, 2038	50,000		50,000
3.58% note, due November 30, 2038	50,000		50,000
3.98% note, due August 20, 2039	100,000		100,000
2.98% note, due December 20, 2034	70,000		70,000
3.00% note, due July 15, 2035	50,000		50,000
2.96% note, due August 15, 2035	40,000		40,000
2.49% notes Due January 25, 2037	50,000		50,000
2.95% notes Due March 15, 2042	50,000		—
Equipment security note
2.46% note, due September 24, 2031	8,950		9,378
Less: debt issuance costs	(973)		(913)
Total long-term debt	607,277		567,865
Less: current maturities	(21,472)		(17,962)
Total long-term debt, net of current maturities	$	585,805	$	549,903

Schedule of Line of Credit Facilities [Line Items]

Schedule of Line of Credit Facilities [Table Text Block]

(in thousands)	Total Borrowing Capacity		Less: Amount of Debt Issued		Less: Unfunded Commitments		Remaining Borrowing Capacity
Shelf Agreement
Prudential Shelf Agreement (1)	$	370,000	$	(220,000)	$	—	$	150,000
MetLife Shelf Agreement (1)	150,000		(50,000)		—		100,000
Total Shelf Agreements as of June 30, 2022	$	520,000	$	(270,000)	$	—	$	250,000

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Leases Leases (Tables)

6 Months Ended

Jun. 30, 2022

Lease Disclosure [Abstract]

Lease, Cost [Table Text Block]

		Three Months Ended		Six Months Ended
		June 30,		June 30,
( in thousands)	Classification	2022	2021	2022	2021
Operating lease cost (1)	Operations expense	$726	$515	$1,377	$1,038

(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 condensed consolidated balance sheet at June 30, 2022 and December 31, 2021:

(in thousands)	Balance sheet classification	June 30, 2022		December 31, 2021
Assets
Operating lease assets	Operating lease right-of-use assets	$	15,767	$	10,139
Liabilities
Current
Operating lease liabilities	Other accrued liabilities	$	2,501	$	1,996
Noncurrent
Operating lease liabilities	Operating lease - liabilities	13,807		8,571
Total lease liabilities		$	16,308	$	10,567

Leases, Weighted Average Remaining Lease Term [Table Text Block]

The following table presents our weighted-average remaining lease terms and weighted-average discount rates for our operating and financing leases at June 30, 2022 and December 31, 2021:

	June 30, 2022		December 31, 2021
Weighted-average remaining lease term (in years)
Operating leases	8.32		8.10
Weighted-average discount rate
Operating leases	3.3	%	3.6	%

Lease, Cash Flow [Table Text Block]

The following table presents additional information related to cash paid for amounts included in the measurement of lease liabilities included in our condensed consolidated statements of cash flows as of June 30, 2022 and 2021:

	Six Months Ended
	June 30,
(in thousands)	2022		2021
Operating cash flows from operating leases	$	1,428	$	936

Schedule of Maturities of Leases [Table Text Block]

The following table presents the future undiscounted maturities of our operating and financing leases at June 30, 2022 and for each of the next five years and thereafter:

(in thousands)	Operating  Leases (1)
Remainder of 2022	$	1,392
2023	2,844
2024	2,629
2025	2,260
2026	1,746
2027	1,501
Thereafter	5,994
Total lease payments	18,366
Less: Interest	(2,058)
Present value of lease liabilities	$	16,308

    (1) Operating lease payments include $2.1 million related to options to extend lease terms that are reasonably certain of being exercised.

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Calculation of Earnings Per Share - Calculation of Basic and Diluted Earnings Per Share (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Earnings Per Share [Abstract]
Income (Loss) from Continuing Operations, Per Basic Share	$ 0.96	$ 0.79	$ 3.05	$ 2.76
Calculation of Basic Earnings Per Share:
Net Income	$ 17,051	$ 13,813	$ 53,985	$ 48,279
Weighted shares outstanding (shares)	17,730,833	17,546,346	17,704,592	17,516,273
Basic Earnings Per Share (in dollars per share)	$ 0.96	$ 0.79	$ 3.05	$ 2.76
Reconciliation of Numerator:
Net Income	$ 17,051	$ 13,813	$ 53,985	$ 48,279
Reconciliation of Denominator:
Weighted shares outstanding - Basic (shares)	17,730,833	17,546,346	17,704,592	17,516,273
Effect of dilutive securities:
Share-based compensation (shares)	79,038	70,150	81,037	68,733
Adjusted denominator-Diluted (shares)	17,809,871	17,616,496	17,785,629	17,585,006
Income (Loss) from Continuing Operations, Per Diluted Share	$ 0.96	$ 0.78	$ 3.04	$ 2.75
Diluted Earnings Per Share (in dollars per share)	$ 0.96	$ 0.78	$ 3.04	$ 2.75
Net Income	$ 17,051	$ 13,813	$ 53,985	$ 48,279
Basic (shares)	17,730,833	17,546,346	17,704,592	17,516,273
Income (Loss) from Continuing Operations, Per Basic Share	$ 0.96	$ 0.79	$ 3.05	$ 2.76
Basic (in dollars per share)	$ 0.96	$ 0.79	$ 3.05	$ 2.76
Share-based compensation (shares)	79,038	70,150	81,037	68,733
Diluted (shares)	17,809,871	17,616,496	17,785,629	17,585,006
Income (Loss) from Continuing Operations, Per Diluted Share	$ 0.96	$ 0.78	$ 3.04	$ 2.75
Diluted (in dollars per share)	$ 0.96	$ 0.78	$ 3.04	$ 2.75
Retained Earnings [Member]
Earnings Per Share [Abstract]
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent	$ 17,051	$ 13,813	$ 53,985	$ 48,279
Calculation of Basic Earnings Per Share:
Net Income	17,051	13,813	53,985	48,279
Reconciliation of Numerator:
Net Income	17,051	13,813	53,985	48,279
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent	17,051	13,813	53,985	48,279
Net Income	$ 17,051	$ 13,813	$ 53,985	$ 48,279

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Acquisitions and Divestitures (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues	$ 139,470	$ 111,082	$ 362,350	$ 302,268
Operating Income (Loss)	26,469	22,578	81,334	74,175
Unregulated Energy [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Operating Income (Loss)	560	(465)	20,613	18,575
Regulated Energy [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Operating Income (Loss)	25,841	$ 22,760	60,539	$ 55,466
Diversified Energy | Unregulated Energy [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	23,100		23,100
Revenues	4,000		14,300
Operating Income (Loss)	(800)		$ 700
Number of customers acquired through acquisition			19,000
Business Combination, Consideration Transferred			$ 37,500
Business Combination, Working Capital	1,700		1,700
Business Combination, Contingent Consideration, Liability	2,100		2,100
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net	5,900		5,900
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Indefinite-Lived Intangible Assets	6,200		$ 6,200
Gallons acquired through acquisition			10,000,000
Business Acquisition, Preacquisition Contingency, Amount of Settlement	800		$ 800
Davenport Energy | Unregulated Energy [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	1,500		$ 1,500
Number of customers acquired through acquisition			850
Business Combination, Consideration Transferred			$ 2,000
Business Combination, Working Capital	100		100
Business Combination, Contingent Consideration, Liability	100		100
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net	$ 500		$ 500
Gallons acquired through acquisition			400,000

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Revenue Recognition Additional Information (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Revenue from Contract with Customer [Abstract]
Contract with Customer, Liability, Revenue Recognized	$ 0.3	$ 0.2	$ 0.7	$ 0.6

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Revenue Recognition Disegragation of Revenue (Details) - USD ($)	3 Months Ended				6 Months Ended
	Jun. 30, 2022		Jun. 30, 2021		Jun. 30, 2022		Jun. 30, 2021
Disaggregation of Revenue [Line Items]
Revenues	$ 139,470,000		$ 111,082,000		$ 362,350,000		$ 302,268,000
Revenue from Contract with Customer, Excluding Assessed Tax	139,470,000	[1]	111,082,000	[1]	362,350,000	[2]	302,268,000	[2]
Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	92,193,000	[1]	80,910,000	[1]	220,084,000	[2]	202,107,000	[2]
Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	53,463,000	[1]	34,773,000	[1]	154,756,000	[2]	109,531,000	[2]
Other Segments And Intersegments Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(6,186,000)		(4,601,000)		(12,490,000)		(9,370,000)
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(6,186,000)	[1]	(4,601,000)	[1]	(12,490,000)	[2]	(9,370,000)	[2]
Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(19,276,000)		(17,834,000)		(40,466,000)		(36,794,000)
Eliminations [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(12,980,000)		(13,168,000)		(27,769,000)		(27,268,000)
Other [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenues	(100,000)		100,000		100,000		(200,000)
Other [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenues	100,000				200,000		200,000
Revenue from Contract with Customer, Excluding Assessed Tax	(110,000)		(65,000)		(207,000)		(156,000)
Energy Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	79,152,000		68,804,000		194,476,000		177,616,000
Energy Distribution [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	79,152,000		68,804,000		194,476,000		177,616,000
Energy Distribution [Member] | Delaware natural gas division [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	13,086,000		10,068,000		47,568,000		43,340,000
Energy Distribution [Member] | Delaware natural gas division [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	13,086,000		10,068,000		47,568,000		43,340,000
Energy Distribution [Member] | Central Florida Gas Division [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	9,619,000		8,446,000		19,885,000		17,402,000
Energy Distribution [Member] | Central Florida Gas Division [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	9,619,000		8,446,000		19,885,000		17,402,000
Energy Distribution [Member] | FPU Electric Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	20,305,000		18,898,000		39,394,000		37,449,000
Energy Distribution [Member] | FPU Electric Distribution [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	20,305,000		18,898,000		39,394,000		37,449,000
Energy Distribution [Member] | Florida Public Utilities Company [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	25,817,000		23,159,000		55,837,000		50,020,000
Energy Distribution [Member] | Florida Public Utilities Company [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	25,817,000		23,159,000		55,837,000		50,020,000
Energy Distribution [Member] | Maryland Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,372,000		3,224,000		14,836,000		13,690,000
Energy Distribution [Member] | Maryland Natural Gas [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,372,000		3,224,000		14,836,000		13,690,000
Energy Distribution [Member] | Sandpiper [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,248,000		3,814,000		11,885,000		11,885,000
Energy Distribution [Member] | Sandpiper [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,248,000		3,814,000		11,885,000		11,885,000
Energy Distribution [Member] | Elkton Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,705,000				5,071,000
Energy Distribution [Member] | Elkton Gas [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,705,000		1,195,000		5,071,000		3,830,000
Energy Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	36,829,000		30,852,000		82,221,000		70,243,000
Energy Transmission [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	26,021,000		25,274,000		53,377,000		51,759,000
Energy Transmission [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	10,808,000		5,578,000		28,844,000		18,484,000
Energy Transmission [Member] | Aspire [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	10,808,000		5,578,000		28,844,000		18,484,000
Energy Transmission [Member] | Aspire [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	10,808,000		5,578,000		28,844,000		18,484,000
Energy Transmission [Member] | Eastern Shore Gas Company [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	18,875,000		18,617,000		39,196,000		38,589,000
Energy Transmission [Member] | Eastern Shore Gas Company [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	18,875,000		18,617,000		39,196,000		38,589,000
Energy Transmission [Member] | Peninsula Pipeline [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	6,777,000		6,610,000		13,549,000		13,077,000
Energy Transmission [Member] | Peninsula Pipeline [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	6,777,000		6,610,000		13,549,000		13,077,000
Energy Transmission [Member] | Aspire Energy Express | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	369,000		47,000		632,000		93,000
Energy Generation [Member] | Eight Flags [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5,916,000		4,173,000		11,455,000		8,502,000
Energy Generation [Member] | Eight Flags [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5,916,000		4,173,000		11,455,000		8,502,000
Propane Delivery [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	34,469,000		23,098,000		110,075,000		78,361,000
Propane Delivery [Member] | Florida Propane | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	34,469,000		23,098,000		110,075,000		78,361,000
Energy Services [Member] | Marlin Gas Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,380,000				4,589,000
Energy Services [Member] | Marlin Gas Services [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,380,000		1,989,000		4,589,000		4,340,000
Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(19,361,000)		(17,967,000)		(40,682,000)		(37,059,000)
Eliminations [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(12,980,000)		(13,168,000)		(27,769,000)		(27,268,000)
Eliminations [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(110,000)		(65,000)		(207,000)		(156,000)
Eliminations [Member] | Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(6,271,000)		(4,734,000)		(12,706,000)		(9,635,000)
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	85,000		133,000		216,000		265,000
Other [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax					0		0
Other [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 85,000		$ 133,000		$ 216,000		$ 265,000

[1] (1) Total operating revenues for the three months ended June 30, 2022, include other revenue (revenues from sources other than contracts with customers) of $(0.1) million for Regulated and $0.1 million Unregulated Energy segments, respectively, and $0.1 million for both our Regulated and Unregulated Energy segments, respectively, for the three months ended June 30, 2021. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the Maryland division and Sandpiper Energy and late fees.

[2] 1) Total operating revenues for the six months ended June 30, 2022, include other revenue (revenues from sources other than contracts with customers) of $0.1 million for Regulated and $0.2 million Unregulated Energy segments, respectively, and $(0.2) million and $0.2 million for our Regulated and Unregulated Energy segments, respectively, for the six months ended June 30, 2021. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the Maryland division and Sandpiper Energy and late fees

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Revenue Recognition Contract Balances with Customers (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Receivables from Customers					$ 56,277
Contract with Customer, Asset, Net, Current	$ 18		$ 18		18
Contract with Customer, Asset, Net, Noncurrent	4,607		4,607		4,806
Customer deposits and refunds	724		724		$ 747
Increase (Decrease) in Receivables			(17,499)
Increase (Decrease) in Other Current Assets			0
Increase (Decrease) in Other Noncurrent Assets			(199)
Increase (Decrease) in Other Current Liabilities			(23)
Contract with Customer, Liability, Revenue Recognized	$ 300	$ 200	$ 700	$ 600

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Revenue Recognition Remaining Performance Obligations (Details) $ in Thousands	Jun. 30, 2022 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 326
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	652
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	652
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	275
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	275
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	275
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	275
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	3,433
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	6,238
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	6,050
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	5,698
Natural gas distribution operations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	5,515
Natural gas distribution operations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	5,100
Natural gas distribution operations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	33,113
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	24,379
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	45,426
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	40,431
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	33,804
Eastern Shore and Peninsula Pipeline [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	29,294
Eastern Shore and Peninsula Pipeline [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	25,096
Eastern Shore and Peninsula Pipeline [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	179,259
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	28,138
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	52,316
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	47,133
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	39,777
Total for Segments [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	35,084
Total for Segments [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	30,471
Total for Segments [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 212,647

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Rates and Other Regulatory Activities - Additional Information (Detail) $ in Thousands	6 Months Ended
	Jun. 30, 2022 USD ($) Dekatherm mi	Dec. 31, 2021 USD ($)
Rates and Other Regulatory Activities [Line Items]
COVID-19 Regulatory Asset	$ 1,800	$ 2,300
Interim Rates	7,700
Permanent Rates	24,100
Requested Interim Rates	7,200
Florida Public Utilities Company [Member]
Rates and Other Regulatory Activities [Line Items]
COVID-19 Settlement Amount	2,100
Delaware natural gas division [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	12,510	12,591
Maryland Division [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	3,772	3,840
Sandpiper [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	3,626	3,656
Central Florida Gas Division [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	7,939	8,032
Florida Public Utilities Company [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	19,058	19,189
Fort Meade and Indiantown Divisions [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	265	271
FPU electric division [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	5,115	5,237
Eastern Shore Gas Company [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	34,190	34,190
Elkton Gas [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	$ 1,074	$ 1,091
Beachside Expansion | Peninsula Pipeline Company [Member]
Rates and Other Regulatory Activities [Line Items]
Number of Mainline Pipeline Miles | mi	11.3
Additional Firm Natural Gas Transportation Deliverability | Dekatherm	10,176
Winter Haven Expansion | Peninsula Pipeline Company [Member]
Rates and Other Regulatory Activities [Line Items]
Additional Firm Natural Gas Transportation Deliverability | Dekatherm	6,800
Twin Lakes Expansion | Peninsula Pipeline Company [Member]
Rates and Other Regulatory Activities [Line Items]
Additional Firm Natural Gas Transportation Deliverability | Dekatherm	2,400

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Environmental Commitments and Contingencies - Additional Information (Detail)	6 Months Ended	12 Months Ended
	Jun. 30, 2022 USD ($) site	Dec. 31, 2021 USD ($)
Environmental Commitments And Contingencies [Line Items]
Company's exposure in number of former Manufactured Gas Plant Sites | site	7
Environmental liabilities	$ 3,097,000	$ 3,538,000
West Palm Beach Florida [Member] | Minimum [Member]
Environmental Commitments And Contingencies [Line Items]
Estimated costs of remediation range, minimum	3,300,000
West Palm Beach Florida [Member] | Maximum [Member]
Environmental Commitments And Contingencies [Line Items]
Estimated costs of remediation range, minimum	14,200,000
Seaford [Member] | Minimum [Member]
Environmental Commitments And Contingencies [Line Items]
Estimated costs of remediation range, minimum	300,000
Seaford [Member] | Maximum [Member]
Environmental Commitments And Contingencies [Line Items]
Estimated costs of remediation range, minimum	900,000
Manufactured Gas Plant [Member]
Environmental Commitments And Contingencies [Line Items]
Regulatory Assets for future recovery of environmental costs	1,000,000	1,300,000
FPU [Member]
Environmental Commitments And Contingencies [Line Items]
Environmental liabilities	4,800,000	5,200,000
Approval of recovery of environmental costs	14,000,000
Environmental costs recovered	13,100,000	12,900,000
FPU [Member] | Manufactured Gas Plant [Member]
Environmental Commitments And Contingencies [Line Items]
Regulatory Assets for future recovery of environmental costs	$ 900,000	$ 1,100,000

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Other Commitments and Contingencies - Additional Information (Detail) $ in Millions	6 Months Ended
	Jun. 30, 2022 USD ($)
Other Commitments [Line Items]
Debt Service Coverage Ratio	1.25
Debt Service Coverage Ratio Measurement Period	12
Maximum Days To Make Default Good	5 days
Ratio based on average number of prior quarters	6
Ratios based on average of the prior quarters	1 year 6 months
Funds from operations interest coverage ratio minimum times	2
Total debt to capital maximum	0.65
Number Of Years For Power Purchase Agreement	20 years
Contract Duration	20 years
Aggregate guaranteed amount	$ 20.0
Guarantor Obligations, Current Carrying Value	11.4
Draws on letters of credit	5.3
Specific Purpose
Other Commitments [Line Items]
Guarantor Obligations, Current Carrying Value	2.0
Rate Case
Other Commitments [Line Items]
Guarantor Obligations, Current Carrying Value	$ 7.1
Florida Natural Gas Distribution and Eight Flags [Member]
Other Commitments [Line Items]
Number of Years for Asset Management Agreement	10 years
Delmarva [Member]
Other Commitments [Line Items]
Number of Years for Asset Management Agreement	3 years

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Segment Information - Schedule of Segment Reporting Information by Segment (Detail) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Dec. 31, 2021 USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments				2
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers		$ 139,470	$ 111,082	$ 362,350	$ 302,268
Operating Income
Total operating income		26,469	22,578	81,334	74,175
Other expense, net		2,584	1,453	3,498	1,828
Interest		5,825	5,054	11,164	10,159
Income Before Income Taxes		23,228	18,977	73,668	65,844
Income Taxes		6,177	5,164	19,683	17,565
Net Income		17,051	13,813	53,985	48,279
Identifiable Assets
Total identifiable assets		2,117,342		2,117,342		$ 2,114,869
Regulated Energy [Member]
Operating Income
Total operating income		25,841	22,760	60,539	55,466
Identifiable Assets
Total identifiable assets		1,637,003		1,637,003		1,629,191
Unregulated Energy [Member]
Operating Income
Total operating income		560	(465)	20,613	18,575
Identifiable Assets
Total identifiable assets		447,209		447,209		439,114
Other [Member]
Identifiable Assets
Total identifiable assets		33,130		33,130		$ 46,564
Other and eliminations [Member]
Operating Income
Total operating income		68	283	182	134
Operating Revenues, Unaffiliated Customers [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers		139,470	111,082	362,350	302,268
Operating Revenues, Unaffiliated Customers [Member] | Regulated Energy [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers		91,830	80,374	215,888	201,095
Operating Revenues, Unaffiliated Customers [Member] | Unregulated Energy [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers		47,640	30,708	146,462	101,173
Intersegment Revenues [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	[1]	6,271	4,734	12,706	9,635
Intersegment Revenues [Member] | Regulated Energy [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	[1]	363	536	4,196	1,012
Intersegment Revenues [Member] | Unregulated Energy [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	[1]	5,823	4,065	7,819	8,358
Intersegment Revenues [Member] | Other [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	[1]	85	133	691	265
Retained Earnings [Member]
Operating Income
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent		17,051	13,813	53,985	48,279
Net Income		$ 17,051	$ 13,813	$ 53,985	$ 48,279

[1] All significant intersegment revenues are billed at market rates and have been eliminated from consolidated operating revenues.

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Stockholder's Equity - Accumulated Other Comprehensive Income (Loss) - Changes in Accumulated Other Comprehensive Loss (Detail) - USD ($) shares in Millions		3 Months Ended			6 Months Ended		12 Months Ended
		Jun. 30, 2022	Dec. 31, 2021	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance					$ 1,303,000	$ (2,865,000)	$ (2,865,000)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax					2,206,000	5,848,000
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax					(2,139,000)	(2,425,000)
Net current-period other comprehensive income (loss)		$ (480,000)		$ 3,196,000	67,000	3,423,000
Ending balance		1,370,000	$ 1,303,000	558,000	$ 1,370,000	558,000	$ 1,303,000
Stock Issued During Period, Shares, Dividend Reinvestment Plan					0.1		0.1
Stock Issued During Period, Value, Dividend Reinvestment Plan					$ 137.24		$ 125.71
Proceeds from Issuance of Common Stock, Dividend Reinvestment Plan					$ 4,300,000		$ 15,200,000
Stock Issued During Period, Shares, Dividend Reinvestment Plan					0.1		0.1
Stock Issued During Period, Value, Dividend Reinvestment Plan					$ 137.24		$ 125.71
Proceeds from Issuance of Common Stock, Dividend Reinvestment Plan					4,300,000		15,200,000
Maximum [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Proceeds from Stock Plans			75,000,000
Proceeds from Stock Plans			75,000,000
UnrealizedGainsLossesFromDefinedBenefitPensionAndPostretirementPlanItems [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance					(3,268,000)	(5,146,000)	(5,146,000)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax					0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax					35,000	128,000
Net current-period other comprehensive income (loss)					35,000	128,000
Ending balance		(3,233,000)	(3,268,000)	(5,018,000)	(3,233,000)	(5,018,000)	(3,268,000)
Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance					4,571,000	2,309,000	2,309,000
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax					2,206,000	5,825,000
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax					(2,174,000)	(2,534,000)
Net current-period other comprehensive income (loss)					32,000	3,291,000
Ending balance		4,603,000	4,571,000	5,600,000	4,603,000	5,600,000	4,571,000
Accumulated (Gain) Loss from Interest Rate Swap Cash Flows Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance	[1]				0	(28,000)	(28,000)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	[1]				0	23,000
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	[1]				0	(19,000)
Net current-period other comprehensive income (loss)	[1]				0	4,000
Ending balance	[1]	$ 0	$ 0	$ (24,000)	$ 0	$ (24,000)	$ 0

[1] 1) All of our interest rate swaps expired at December 31, 2021

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Stockholder's Equity - Accumulated Other Comprehensive Income (Loss) - Reclassifications of Accumulated Other Comprehensive Loss (Detail) - USD ($) shares in Millions		3 Months Ended		6 Months Ended		12 Months Ended
		Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Amortization of pension and postretirement items:
Tax benefit		$ (6,177,000)	$ (5,164,000)	$ (19,683,000)	$ (17,565,000)
Derivative, Gain (Loss) on Derivative, Net		(403,000)	4,804,000	$ 3,088,000	8,057,000
Stock Issued During Period, Shares, Dividend Reinvestment Plan				0.1		0.1
Stock Issued During Period, Value, Dividend Reinvestment Plan				$ 137.24		$ 125.71
Proceeds from Issuance of Common Stock, Dividend Reinvestment Plan				4,300,000		$ 15,200,000
Reclassification out of Accumulated Other Comprehensive Income [Member]
Amortization of pension and postretirement items:
Net of tax		187,000	281,000	2,139,000	2,425,000
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment [Member]
Amortization of pension and postretirement items:
Prior service cost	[1]	19,000	19,000	38,000	38,000
Net loss	[1]	(43,000)	(106,000)	(86,000)	(209,000)
Total before tax		(24,000)	(87,000)	(48,000)	(171,000)
Tax benefit		6,000	23,000	13,000	43,000
Net of tax		(18,000)	(64,000)	(35,000)	(128,000)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Amortization of pension and postretirement items:
Tax benefit		(78,000)	(126,000)	(830,000)	(968,000)
Net of tax		205,000	329,000	2,174,000	2,534,000
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated (Gain) Loss from Interest Rate Swap Cash Flows Hedges [Member]
Amortization of pension and postretirement items:
Other Comprehensive Income Loss Adjustments AOCI Swap Agreements			22,000		26,000
Tax benefit		0	(6,000)	0	(7,000)
Net of tax		0	16,000	0	19,000
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]	283,000	455,000	3,004,000	3,502,000
Interest Rate Swap [Member] | Derivatives designated as hedging instrument [Member] | Interest Expense [Member]
Amortization of pension and postretirement items:
Derivative, Gain (Loss) on Derivative, Net		$ 0	$ 22,000	$ 0	$ 26,000

[1] These amounts are included in the computation of net periodic costs (benefits). See Note 10, Employee Benefit Plans, for additional details.

[2] These amounts are included in the effects of gains and losses from derivative instruments. See Note 13, Derivative Instruments, for additional details.

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Employee Benefit Plans (Detail) - USD ($) $ in Thousands		3 Months Ended				6 Months Ended
		Jun. 30, 2022		Jun. 30, 2021		Jun. 30, 2022		Jun. 30, 2021
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost		$ (19)		$ (19)		$ (38)		$ (38)
Defined Benefit Plan Actuarial Gain Loss, Net Settlement				211				420
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		143		230		286		458
Defined Benefit Plan Amounts Recognized Gain (Loss)		124		211		248		420
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax		24	[1]	87	[1]	48	[2]	171	[2]
Defined Benefit Plan Amounts Recognized From Regulatory Asset		100		124		200		249
Deferred Pension Settlement Expense						600
Chesapeake Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost		0		34		0		68
Expected return on plan assets		0		(40)		0		(80)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		0		60		0		120
Total periodic cost		0		54		0		108
Defined Benefit Plan Amounts Recognized Gain (Loss)		0		60		0		120
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax		0	[1]	60	[1]	0	[2]	120	[2]
Florida Public Utilities Company Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Contributions by Employer						100
Interest cost		449		429		898		858
Expected return on plan assets		(857)		(830)		(1,714)		(1,660)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		124		155		248		310
Total periodic cost		(284)		(246)		(568)		(492)
Defined Benefit Plan Amounts Recognized Gain (Loss)		124		155		248		310
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax		24	[1]	29	[1]	48	[2]	58	[2]
Defined Benefit Plan Amounts Recognized From Regulatory Asset		100		126		200		252
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		300				300
Chesapeake Pension SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Contributions by Employer						100
Interest cost		13		12		26		24
Defined Benefit Plan Actuarial Gain Loss, Net Settlement				7				14
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		7		7		14		14
Total periodic cost		20		19		40		38
Defined Benefit Plan Amounts Recognized Gain (Loss)		7		7		14		14
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax		7	[1]	7	[1]	14	[2]	14	[2]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		200				200
Chesapeake Postretirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Contributions by Employer						100
Interest cost		6		6		12		12
Amortization of prior service cost		(19)		(19)		(38)		(38)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		12		10		24		18
Total periodic cost		(1)		(3)		(2)		(8)
Defined Benefit Plan Amounts Recognized Gain (Loss)		(7)		(9)		(14)		(20)
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax		(7)	[1]	(9)	[1]	(14)	[2]	(20)	[2]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		100				100
Florida Public Utilities Company Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost		6		6		12		12
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)				(2)				(4)
Total periodic cost		6		4		12		8
Defined Benefit Plan Amounts Recognized Gain (Loss)				(2)				(4)
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax	[2]							(1)
Defined Benefit Plan Amounts Recognized From Regulatory Asset				$ (2)				$ (3)
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		$ 100				$ 100

[1] .

[2] 1) See Note 9, Stockholders' Equity.

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Employee Benefit Plans - Additional Information (Detail) - USD ($) $ in Thousands		3 Months Ended				6 Months Ended
		Jun. 30, 2022		Jun. 30, 2021		Jun. 30, 2022		Jun. 30, 2021
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost		$ (19)		$ (19)		$ (38)		$ (38)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		143		230		286		458
Defined Benefit Plan Amounts Recognized Gain (Loss)		124		211		248		420
Recognized from accumulated other comprehensive loss		24	[1]	87	[1]	48	[2]	171	[2]
Recognized from regulatory asset		100		124		200		249
Defined Benefit Plan Actuarial Gain Loss, Net Settlement				211				420
Florida Public Utilities Company Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Contribution to pension plan						100
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		300				300
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		124		155		248		310
Defined Benefit Plan Amounts Recognized Gain (Loss)		124		155		248		310
Recognized from accumulated other comprehensive loss		24	[1]	29	[1]	48	[2]	58	[2]
Recognized from regulatory asset		100		126		200		252
Chesapeake Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		0		60		0		120
Defined Benefit Plan Amounts Recognized Gain (Loss)		0		60		0		120
Recognized from accumulated other comprehensive loss		0	[1]	60	[1]	0	[2]	120	[2]
Chesapeake Pension SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Contribution to pension plan						100
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		200				200
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		7		7		14		14
Defined Benefit Plan Amounts Recognized Gain (Loss)		7		7		14		14
Recognized from accumulated other comprehensive loss		7	[1]	7	[1]	14	[2]	14	[2]
Defined Benefit Plan Actuarial Gain Loss, Net Settlement				7				14
Chesapeake Postretirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Contribution to pension plan						100
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		100				100
Amortization of prior service cost		(19)		(19)		(38)		(38)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		12		10		24		18
Defined Benefit Plan Amounts Recognized Gain (Loss)		(7)		(9)		(14)		(20)
Recognized from accumulated other comprehensive loss		(7)	[1]	(9)	[1]	(14)	[2]	(20)	[2]
Florida Public Utilities Company Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		$ 100				$ 100
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)				(2)				(4)
Defined Benefit Plan Amounts Recognized Gain (Loss)				(2)				(4)
Recognized from accumulated other comprehensive loss	[2]							(1)
Recognized from regulatory asset				$ (2)				$ (3)

[1] .

[2] 1) See Note 9, Stockholders' Equity.

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Employee Benefit Plans - Amounts Included in Regulatory Asset and Accumulated Other Comprehensive Income/Loss Recognized as Net Periodic Benefit Cost (Detail) - USD ($) $ in Thousands		3 Months Ended				6 Months Ended
		Jun. 30, 2022		Jun. 30, 2021		Jun. 30, 2022		Jun. 30, 2021
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Prior service cost (credit)		$ (19)		$ (19)		$ (38)		$ (38)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		143		230		286		458
Recognized from accumulated other comprehensive loss		24	[1]	87	[1]	48	[2]	171	[2]
Recognized from regulatory asset		100		124		200		249
Defined Benefit Plan Actuarial Gain Loss, Net Settlement				211				420
Total recognized in net periodic benefit cost		124		211		248		420
Chesapeake Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		0		60		0		120
Recognized from accumulated other comprehensive loss		0	[1]	60	[1]	0	[2]	120	[2]
Total recognized in net periodic benefit cost		0		60		0		120
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)		124		155		248		310
Recognized from accumulated other comprehensive loss		24	[1]	29	[1]	48	[2]	58	[2]
Recognized from regulatory asset		100		126		200		252
Total recognized in net periodic benefit cost		124		155		248		310
Chesapeake Pension SERP [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		7		7		14		14
Recognized from accumulated other comprehensive loss		7	[1]	7	[1]	14	[2]	14	[2]
Defined Benefit Plan Actuarial Gain Loss, Net Settlement				7				14
Total recognized in net periodic benefit cost		7		7		14		14
Chesapeake Postretirement Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Prior service cost (credit)		(19)		(19)		(38)		(38)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)		12		10		24		18
Recognized from accumulated other comprehensive loss		(7)	[1]	(9)	[1]	(14)	[2]	(20)	[2]
Total recognized in net periodic benefit cost		$ (7)		(9)		$ (14)		(20)
Florida Public Utilities Company Medical Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)				(2)				(4)
Recognized from accumulated other comprehensive loss	[2]							(1)
Recognized from regulatory asset				(2)				(3)
Total recognized in net periodic benefit cost				$ (2)				$ (4)

[1] .

[2] 1) See Note 9, Stockholders' Equity.

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Investments - Schedule of Investments (Details) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
Investments schedule [Line Items]
Investments, at fair value	$ 10,523	$ 12,095
Rabbi Trust Associated With Deferred Compensation Plan [Member]
Investments schedule [Line Items]
Investments, at fair value	10,499	12,069
Equity Securities [Member]
Investments schedule [Line Items]
Investments, at fair value	$ 24	$ 26

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Investments - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Investments, Debt and Equity Securities [Abstract]
Unrealized gain (loss), net of other expenses	$ (1.4)	$ 0.6	$ (2.0)	$ 1.0

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Share-Based Compensation - Share-Based Compensation Amounts Included in Net Income (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	$ 1,342	$ 1,439	$ 3,555	$ 3,315
Less: tax benefit	(346)	(384)	(917)	(885)
Share-Based Compensation amounts included in net income	996	1,055	$ 2,638	2,430
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			652
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value			$ 130.36
Total compensation expense	$ 220	192	$ 454	380
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	204,047		204,047		197,398
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period			66,942
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period			60,850
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Expired In Period			557
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 102.91		$ 102.91		$ 94.15
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value			119.77
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value			90.60
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Expirations Weighted Average Grant Date Fair Value			$ 91.42
Total compensation expense	$ 1,122	$ 1,247	$ 3,101	$ 2,935

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Share-Based Compensation - Summary of Stock Activity under the SICP (Detail)	6 Months Ended
	Jun. 30, 2022 $ / shares shares
Award to key employees [Member]
Number of Shares
Outstanding - December 31, 2020 (shares) | shares	197,398
Granted awards (shares) | shares	66,942
Vested (shares) | shares	(60,850)
Expired (shares) | shares	(557)
Outstanding - June 30, 2021 (shares) | shares	204,047
Weighted Average Fair Value
Outstanding - December 31, 2020 (in dollars per share) | $ / shares	$ 94.15
Granted (in dollars per share) | $ / shares	119.77
Vested (in dollars per share) | $ / shares	90.60
Expired (in dollars per share) | $ / shares	91.42
Outstanding - June 30, 2021 (in dollars per share) | $ / shares	$ 102.91
Awards to non-employee directors [Member]
Number of Shares
Granted awards (shares) | shares	652
Weighted Average Fair Value
Granted (in dollars per share) | $ / shares	$ 130.36

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Share-Based Compensation - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Thousands	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation	21,832	14,020
Payment, Tax Withholding, Share-based Payment Arrangement	$ 2,838	$ 1,478
Unrecognized compensation cost	$ 8,800
Awards to non-employee directors [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 130.36
Granted awards (shares)	652
Unrecognized compensation expense related to the awards to non-employee directors	$ 700
Shares awarded to non-employee directors [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	$ 130.36
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	652
Total [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted awards (shares)	6,520
Shares awarded to non-employee directors [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	6,520
Award to key employees [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Expired In Period	557
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 119.77
Granted awards (shares)	66,942
Vesting period	3 years
Payment, Tax Withholding, Share-based Payment Arrangement	$ 2,800
Intrinsic value of the SICP awards	$ 26,400
Shares awarded to non-employee directors [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	$ 119.77
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	66,942
Accelerated Vested Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation	21,832

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Derivative Instruments Volume of Derivative Activity (Details) - Sharp Energy Inc [Member] gal in Millions, $ in Millions	6 Months Ended
	Jun. 30, 2022 USD ($) gal
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months | $	$ 3.8
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimate of Time to Transfer	12 months
Swap Purchases
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	16.0
Swap Sales
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	3.8

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Derivative Instruments - Additional Information (Detail) - USD ($) $ in Thousands	1 Months Ended	6 Months Ended
	Feb. 28, 2021	Jun. 30, 2022	Dec. 31, 2021
Derivative [Line Items]
Energy Marketing Contracts Assets, Current		$ 6,772	$ 7,076
Energy Marketing Contract Liabilities, Current		(427)	(743)
Notional Amount of Nonderivative Instruments	$ 40,000	30,000
Notional Amount Nonderivative Instruments, Total		60,000
Designated as Hedging Instrument [Member] | Mark To Market Energy Assets [Member] | Propane Swap Agreement [Member]
Derivative [Line Items]
Energy Marketing Contracts Assets, Current		6,772	7,060
Designated as Hedging Instrument [Member] | Mark-to-market energy liabilities [Member] | Propane Swap Agreement [Member]
Derivative [Line Items]
Energy Marketing Contract Liabilities, Current		(427)	(743)
Sharp Energy Inc [Member]
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months		$ 3,800
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimate of Time to Transfer		12 months
Other Payables to Broker-Dealers and Clearing Organizations		$ 4,418	$ 4,081
Interest Rate Swap Rate, High Range [Member]
Derivative [Line Items]
Fixed Swap Rate		0.17%	0.205%
Interest Rate Swap Rate, Low Range [Member]
Derivative [Line Items]
Fixed Swap Rate			0.20%

XML

Derivative Instruments - Fair Values of Derivative Contracts Recorded in Condensed Consolidated Balance Sheet (Detail) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
Derivatives, Fair Value [Line Items]
Energy Marketing Contracts Assets, Current	$ 6,772	$ 7,076
Energy Marketing Contract Liabilities, Current	427	743
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	6,772	7,060
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	16
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	$ 427	$ 743

XML

Derivative Instruments - Effects of Gains and Losses from Derivative Instruments on Condensed Consolidated Financial Statements (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ (403)	$ 4,804	$ 3,088	$ 8,057
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	283	455	3,830	3,502
Cost of Sales [Member] | Derivatives designated as hedging instrument [Member] | Put Or Call Option
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0	0	0	(24)
Cost of Sales [Member] | Not Designated as Hedging Instrument [Member] | Propane Swap Agreement [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0	0	56	0
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	(686)	4,319	28	4,548
Other Comprehensive Income (Loss) [Member] | Derivatives designated as hedging instrument [Member] | Interest Rate Swap [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, before Tax	0	8	0	5
Interest Expense [Member] | Derivatives designated as hedging instrument [Member] | Interest Rate Swap [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0	22	0	26
Revenues | Derivatives designated as hedging instrument [Member] | Propane Swap Agreement [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 0	$ 0	$ (826)	$ 0

XML

Fair Value of Financial Instruments - Financial Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
Assets:
Investments	$ 10,523	$ 12,095
Energy Marketing Contracts Assets, Current	6,772	7,076
Liabilities:
Energy Marketing Contract Liabilities, Current	427	743
Equity Securities [Member]
Assets:
Investments	24	26
Quoted Prices in Active Markets (Level 1) [Member]
Assets:
Assets, Fair Value Disclosure	8,421	10,059
Quoted Prices in Active Markets (Level 1) [Member] | Equity Securities [Member]
Assets:
Investments	24	26
Quoted Prices in Active Markets (Level 1) [Member] | Investments - Mutual funds and other [Member]
Assets:
Investments	8,397	10,033
Quoted Prices in Active Markets (Level 1) [Member] | Total Investments [Member]
Assets:
Investments	8,421	10,059
Significant Other Observable Inputs (Level 2) [Member]
Assets:
Assets, Fair Value Disclosure	6,772	7,076
Significant Unobservable Inputs (Level 3) [Member]
Assets:
Assets, Fair Value Disclosure	2,102	2,036
Significant Unobservable Inputs (Level 3) [Member] | Investments in guaranteed income fund [Member]
Assets:
Investments	2,102	2,036
Significant Unobservable Inputs (Level 3) [Member] | Total Investments [Member]
Assets:
Investments	2,102	2,036
Recurring [Member]
Assets:
Assets, Fair Value Disclosure	17,295	19,171
Liabilities:
Energy Marketing Contract Liabilities, Current		743
Recurring [Member] | Equity Securities [Member]
Assets:
Investments	24	26
Recurring [Member] | Investments in guaranteed income fund [Member]
Assets:
Investments	2,102	2,036
Recurring [Member] | Investments - Mutual funds and other [Member]
Assets:
Investments		10,033
Recurring [Member] | Total Investments [Member]
Assets:
Investments	$ 10,523	12,095
Recurring [Member] | Mark To Market Energy Assets incl. natural gas and swap agreements[Member]
Assets:
Derivative assets		$ 7,076

XML

Fair Value of Financial Instruments - Summary of Changes in Fair Value of Investments (Detail) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value	$ 10,523		$ 12,095
Derivative assets, at fair value	6,772		7,076
Energy Marketing Contract Liabilities, Current	427		743
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	(83)	$ (51)
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	2,036	2,156
Purchases and adjustments	132	70
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers out of Level 3	0	0
Investment Income	17	16
Ending Balance	2,102	$ 2,191
Quoted Prices in Active Markets (Level 1) [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	8,421		10,059
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	6,772		7,076
Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	2,102		2,036
Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	17,295		19,171
Energy Marketing Contract Liabilities, Current			743
Equity Securities [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value	24		26
Equity Securities [Member] | Quoted Prices in Active Markets (Level 1) [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value	24		26
Equity Securities [Member] | Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value	24		26
Investments in guaranteed income fund [Member] | Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value	2,102		2,036
Investments in guaranteed income fund [Member] | Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value	2,102		2,036
Investments - Mutual funds and other [Member] | Quoted Prices in Active Markets (Level 1) [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value	8,397		10,033
Investments - Mutual funds and other [Member] | Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value			10,033
Total Investments [Member] | Quoted Prices in Active Markets (Level 1) [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value	8,421		10,059
Total Investments [Member] | Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value	2,102		2,036
Total Investments [Member] | Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value	$ 10,523		12,095
Mark To Market Energy Assets Including Put Option [Member] | Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset			$ 7,076

XML

Fair Value of Financial Instruments - Additional Information (Detail) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Long-term debt including current maturities	$ 608.3	$ 568.8
Fair value of long-term debt	$ 540.6	$ 597.2

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Long-Term Debt - Outstanding Long-Term Debt (Detail) - USD ($) $ in Thousands		Jun. 30, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Total long-term debt		$ (608,300)	$ (568,800)
Debt Instrument, Unused Borrowing Capacity, Amount		250,000
Total Long-term debt		607,277	567,865
Less: current maturities		(21,472)	(17,962)
Less: debt issuance costs		973	913
Total long-term debt, net of current maturities		585,805	549,903
Aggregated Unfunded Commitments [Member]
Debt Instrument [Line Items]
Total long-term debt		0
5.93% note, due October 31, 2023 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (4,500)	(6,000)
Debt Instrument, Interest Rate, Stated Percentage		5.93%
5.68% note, due June 30, 2026 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (11,600)	(14,500)
Debt Instrument, Interest Rate, Stated Percentage		5.68%
6.43% note, due May 2, 2028 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (4,200)	(4,900)
Debt Instrument, Interest Rate, Stated Percentage		6.43%
3.73% note, due December 16, 2028 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (14,000)	(14,000)
Debt Instrument, Interest Rate, Stated Percentage		3.73%
3.88% note, due May 15, 2029 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (35,000)	(40,000)
Debt Instrument, Interest Rate, Stated Percentage		3.88%
3.25% note, due April 30, 2032 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (70,000)	(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)
Debt Instrument, Interest Rate, Stated Percentage		3.58%
Uncollateralized Senior Note Due July Two Thousand Thirty Five
Debt Instrument [Line Items]
Total long-term debt		$ (50,000)	(50,000)
Debt Instrument, Interest Rate, Stated Percentage		3.00%
Uncollateralized Senior Note Due August Two Thousand Thirty Five
Debt Instrument [Line Items]
Total long-term debt		$ (40,000)	(40,000)
Debt Instrument, Interest Rate, Stated Percentage		2.96%
Uncollateralized Senior Note Due November Two Thousand Thirty Nine
Debt Instrument [Line Items]
Total long-term debt		$ (100,000)	(100,000)
Equipment Security Note
Debt Instrument [Line Items]
Total long-term debt		$ (8,950)	(9,378)
Debt Instrument, Interest Rate, Stated Percentage		2.46%
Equipment Security Note | Marlin Gas Services [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (9,600)
Uncollateralized Senior Note Due January Two Thousand Thirty Seven
Debt Instrument [Line Items]
Total long-term debt		$ (50,000)	$ (50,000)
Debt Instrument, Interest Rate, Stated Percentage		2.49%
Uncollateralized Senior Note Due March 15, 2042
Debt Instrument [Line Items]
Total long-term debt		$ (50,000)
Debt Instrument, Interest Rate, Stated Percentage		2.95%
Aggregate Shelf Agreements [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (270,000)
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	[1]	(220,000)
Debt Instrument, Unused Borrowing Capacity, Amount	[1]	150,000
Prudential [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	[1]	370,000
MetLife [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	[1]	150,000
Total long-term debt	[1]	(50,000)
Debt Instrument, Unused Borrowing Capacity, Amount	[1]	100,000
MetLife [Member] | Uncollateralized Senior Note Due March 15, 2042
Debt Instrument [Line Items]
Total long-term debt		$ (50,000)

[1] (1) The Prudential and MetLife Shelf Agreements expire in April 2023 and May 2023, respectively.

XML

Long-Term Debt - Outstanding Long-Term Debt- Supplemental Information (Detail)	6 Months Ended
	Jun. 30, 2022
5.93% note, due October 31, 2023 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Oct. 31, 2023
Debt Instrument, Interest Rate, Stated Percentage	5.93%
5.68% note, due June 30, 2026 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Jun. 30, 2026
Debt Instrument, Interest Rate, Stated Percentage	5.68%
6.43% note, due May 2, 2028 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	May 02, 2028
Debt Instrument, Interest Rate, Stated Percentage	6.43%
3.73% note, due December 16, 2028 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Dec. 16, 2028
Debt Instrument, Interest Rate, Stated Percentage	3.73%
3.88% note, due May 15, 2029 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	May 15, 2029
Debt Instrument, Interest Rate, Stated Percentage	3.88%
3.25% due April 30, 2032 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Apr. 30, 2032
Debt Instrument, Interest Rate, Stated Percentage	3.25%
3.48% note, due May 31, 2038 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	May 31, 2038
Debt Instrument, Interest Rate, Stated Percentage	3.48%
Uncollateralized Senior Note Due November Two Thousand Thirty Eight [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Nov. 30, 2038
Debt Instrument, Interest Rate, Stated Percentage	3.58%
Uncollateralized Senior Note Due August Two Thousand Thirty Nine [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Aug. 20, 2039
Debt Instrument, Interest Rate, Stated Percentage	3.98%
Uncollateralized Senior Note Due December Two Thousand Thirty Four [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Dec. 20, 2034
Debt Instrument, Interest Rate, Stated Percentage	2.98%
Uncollateralized Senior Note Due July Two Thousand Thirty Five
Debt Instrument [Line Items]
Debt instrument, maturity date	Jul. 15, 2035
Debt Instrument, Interest Rate, Stated Percentage	3.00%
Uncollateralized Senior Note Due August Two Thousand Thirty Five
Debt Instrument [Line Items]
Debt instrument, maturity date	Aug. 15, 2035
Debt Instrument, Interest Rate, Stated Percentage	2.96%
Equipment Security Note
Debt Instrument [Line Items]
Debt instrument, maturity date	Sep. 24, 2031
Debt Instrument, Interest Rate, Stated Percentage	2.46%
Uncollateralized Senior Note Due January Two Thousand Thirty Seven
Debt Instrument [Line Items]
Debt instrument, maturity date	Jan. 25, 2037
Debt Instrument, Interest Rate, Stated Percentage	2.49%

XML

Long-Term Debt - Additional Information (Detail) - USD ($) $ in Thousands		6 Months Ended
		Jun. 30, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Document Period End Date		Jun. 30, 2022
Long-term debt including current maturities		$ 608,300	$ 568,800
Debt Instrument, Unused Borrowing Capacity, Amount		250,000
Short-term borrowing		$ 137,024	221,634
Uncollateralized Senior Note Due December Two Thousand Thirty Four [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		2.98%
Term Note Due January Two Thousand Twenty [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities		$ 70,000	70,000
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
Aggregated Unfunded Commitments [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities		0
Equipment Security Note
Debt Instrument [Line Items]
Long-term debt including current maturities		$ 8,950	$ 9,378
Debt Instrument, Interest Rate, Stated Percentage		2.46%
Equipment Security Note | Marlin Gas Services [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities		$ 9,600
Uncollateralized Senior Note Due March 15, 2042
Debt Instrument [Line Items]
Long-term debt including current maturities		$ 50,000
Debt Instrument, Interest Rate, Stated Percentage		2.95%
Aggregate Shelf Agreements [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities		$ 270,000
MetLife [Member]
Debt Instrument [Line Items]
Senior notes	[1]	150,000
Long-term debt including current maturities	[1]	50,000
Debt Instrument, Unused Borrowing Capacity, Amount	[1]	100,000
MetLife [Member] | Uncollateralized Senior Note Due March 15, 2042
Debt Instrument [Line Items]
Long-term debt including current maturities		50,000
Prudential [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities	[1]	220,000
Debt Instrument, Unused Borrowing Capacity, Amount	[1]	150,000
Maximum [Member] | Aggregate Shelf Agreements [Member]
Debt Instrument [Line Items]
Senior notes		520,000
Maximum [Member] | Prudential [Member]
Debt Instrument [Line Items]
Senior notes	[1]	$ 370,000

[1] (1) The Prudential and MetLife Shelf Agreements expire in April 2023 and May 2023, respectively.

XML

Short-Term Borrowings (Details) - USD ($)	1 Months Ended	6 Months Ended
	Feb. 28, 2021	Jun. 30, 2022	Dec. 31, 2021
Short-term Debt [Line Items]
Ratio of Indebtedness to Net Capital		0.65
Notional Amount of Nonderivative Instruments	$ 40,000,000	$ 30,000,000
Line of Credit Facility, Remaining Borrowing Capacity		257,700,000
Short-term borrowing		$ 137,024,000	$ 221,634,000
Short-term Debt, Weighted Average Interest Rate, at Point in Time		2.38%	0.83%
Draws on letters of credit		$ 5,300,000
Financing Receivable, Revolving		400,000,000
Revolving Line of Credit, Short-term
Short-term Debt [Line Items]
Financing Receivable, Revolving		$ 200,000,000
Debt Instrument, Interest Rate, Stated Percentage		70.00%
Revolving Line of Credit, Long-term
Short-term Debt [Line Items]
Financing Receivable, Revolving		$ 200,000,000
Debt Instrument, Fee		0.09
Debt Instrument, Interest Rate, Stated Percentage		95.00%
3.48% note, due May 31, 2038 [Member]
Short-term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		3.48%
Committed Line of Credit Facility Two [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis		LIBOR rate, plus 0.75 percent
Committed Line of Credit Facility Three [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis		Lender's base rate, plus 0.75 percent
Committed Line of Credit Facility Five [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis		Lender's base rate, plus 0.85 percent
Committed Line of Credit Facility Four [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis		LIBOR rate, plus 1.125 percent
Committed Line of Credit Facility Six [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis		LIBOR rate, plus 1.75 percent
Committed Line of Credit Facility Seven [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis		LIBOR rate, plus 1.75 percent
Committed Line of Credit Facility Eight [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis		LIBOR rate, plus 1.75 percent
Committed Line of Credit Facility Nine [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis		LIBOR rate, plus 1.75 percent
Committed Line of Credit Facility One [Member]
Short-term Debt [Line Items]
Debt Instrument, Description of Variable Rate Basis		LIBOR rate, plus 0.75 percent
Revolving Credit Facility
Short-term Debt [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 400,000,000
Interest Rate Swap Rate, Low Range [Member]
Short-term Debt [Line Items]
Fixed Swap Rate			0.20%
Interest Rate Swap Rate, High Range [Member]
Short-term Debt [Line Items]
Fixed Swap Rate		0.17%	0.205%

XML

Leases (Details) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
Lease Disclosure [Abstract]
Operating Lease, Right-of-Use Asset	$ 15,767	$ 10,139
Operating Lease, Liability, Current	2,501	1,996
Operating Lease, Liability, Noncurrent	13,807	8,571
Total Operating and Finance Lease Liabilities	$ 16,308	$ 10,567

XML

Leases Leases - Lease Cost Additional Information (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Lease, Cost [Abstract]
Operating Lease, Cost	[1]	$ 726	$ 515	$ 1,377	$ 1,038

[1] (1) Includes short-term leases and variable lease costs, which are immaterial

XML

Leases Leases - Right of Use Asset and Lease Liability Balance Sheet Classification Additional Information (Details) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
Leases - Right of Use Asset and Lease Liability Balance Sheet Classification [Abstract]
Operating Lease, Right-of-Use Asset	$ 15,767	$ 10,139
Operating Lease, Liability, Current	2,501	1,996
Operating Lease, Liability, Noncurrent	13,807	8,571
Total Operating and Finance Lease Liabilities	$ 16,308	$ 10,567

XML

Leases Leases - Weighted Average Remaining Lease Term Additional Information (Details)	Jun. 30, 2022	Dec. 31, 2021
Leases - Weighted Average Remaining Lease term Additional Information [Abstract]
Operating Lease, Weighted Average Discount Rate, Percent	3.30%	3.60%
Operating Lease, Weighted Average Remaining Lease Term	8 years 3 months 25 days	8 years 1 month 6 days

XML

Leases Leases - Cash Flow Additional Information (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Leases - Cash Flow Additional Information [Abstract]
Operating Cash Flow from Operating Leases	$ 1,428	$ 936

XML

Leases Leases - Schedule of Future Maturities Additional Information (Details) $ in Thousands	Jun. 30, 2022 USD ($)
Leases - Schedule of Future Maturities Additional Information [Abstract]
Lessee, Operating Lease, Liability, Payments, Remainder of Fiscal Year	$ 1,392	[1]
Lessee, Operating Lease, Liability, to be Paid, Year One	2,844	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Two	2,629	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Three	2,260	[1]
Lessee, Operating Lease, Liability, Payments, Due	18,366	[1]
Lessee, Operating Lease, Liability, Undiscounted Excess Amount	(2,058)
Operating Lease, Liability	16,308	[1]
Lessee Future Operating Lease Option Payments	2,100
Lessee, Operating Lease, Liability, Payments, Due Year Four	1,746	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Five	1,501	[1]
Lessee, Operating Lease, Liability, to be Paid, after Year Five	$ 5,994	[1]

[1] Operating lease payments include $2.1 million related to options to extend lease terms that are reasonably certain of being exercised.