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, 2023

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 — 17,796,741 shares outstanding as of July 28, 2023.

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	30
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	59
ITEM 4.	CONTROLS AND PROCEDURES	60
PART II—OTHER INFORMATION		61
ITEM 1.	LEGAL PROCEEDINGS	61
ITEM 1A.	RISK FACTORS	61
ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	61
ITEM 3.	DEFAULTS UPON SENIOR SECURITIES	61
ITEM 5.	OTHER INFORMATION	61
ITEM 6.	EXHIBITS	62
SIGNATURES		63

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, a division of Chesapeake Utilities

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: 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

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

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

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

GUARD: Gas Utility Access and Replacement Directive a program to enhance the safety, reliability and accessibility of portions of the Company’s natural gas distribution system in Florida

Guernsey Power Station: Guernsey Power Station, LLC, a power generation facility in Guernsey County Ohio

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: the 2013 and 2023 Stock and Incentive Compensation Plans

SOFR: Secured Overnight Financing Rate, a secured interbank overnight interest rate established as an alternative to LIBOR

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,
	2023		2022		2023		2022
(in thousands, except shares and per share data)
Operating Revenues
Regulated Energy	$	101,141	$	92,193	$	243,411	$	220,084
Unregulated Energy and other	34,452		47,277		110,311		142,266
Total Operating Revenues	135,593		139,470		353,722		362,350
Operating Expenses
Natural gas and electric costs	23,886		21,573		79,174		67,016
Propane and natural gas costs	11,907		25,543		45,208		77,279
Operations	42,163		38,002		86,930		80,796
Maintenance	5,258		4,507		10,362		8,772
Depreciation and amortization	17,303		17,216		34,486		34,193
Other taxes	6,730		6,160		14,301		12,960
Total Operating Expenses	107,247		113,001		270,461		281,016
Operating Income	28,346		26,469		83,261		81,334
Other income, net	831		2,584		1,107		3,498
Interest charges	6,964		5,825		14,196		11,164
Income Before Income Taxes	22,213		23,228		70,172		73,668
Income Taxes	6,080		6,177		17,695		19,683
Net Income	$	16,133	$	17,051	$	52,477	$	53,985
Weighted Average Common Shares Outstanding:
Basic	17,794,320		17,730,833		17,777,203		17,704,592
Diluted	17,852,024		17,809,871		17,841,954		17,785,629
Earnings Per Share of Common Stock:
Basic	$	0.91	$	0.96	$	2.95	$	3.05
Diluted	$	0.90	$	0.96	$	2.94	$	3.04

    

The accompanying notes are an integral part of these condensed consolidated 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,
	2023		2022		2023		2022
(in thousands)
Net Income	$	16,133	$	17,051	$	52,477	$	53,985
Other Comprehensive Income (Loss), net of tax:
Employee Benefits, net of tax:
Reclassifications of amortization of prior service credit and actuarial loss, net of tax of $3 and $6, $5 and $13, respectively	12		18		21		35
Cash Flow Hedges, net of tax:
Net (loss) gain on commodity contract cash flow hedges, net of tax of $(784), $(110), $(775) and $826, respectively	(2,065)		(293)		(2,045)		2,206
Reclassifications of net loss (gain) on commodity contract cash flow hedges, net of tax $119, $(78), $(48) and $(830), respectively	313		(205)		(126)		(2,174)
Net gain on interest rate swap cash flow hedges, net of tax of $267, $0, $213 and $0, respectively	758		—		612		—
Reclassifications of net (gain) on interest rate swap cash flow hedges, net of tax of $(33), $0, $(50) and $0, respectively	(94)		—		(142)		—
Total Other Comprehensive Income (Loss), net of tax	(1,076)		(480)		(1,680)		67
Comprehensive Income	$	15,057	$	16,571	$	50,797	$	54,052

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

2

Chesapeake Utilities Corporation and Subsidiaries

Condensed Consolidated Balance Sheets (Unaudited)

Assets	June 30, 2023		December 31, 2022
(in thousands, except shares and per share data)
Property, Plant and Equipment
Regulated Energy	$	1,868,763	$	1,802,999
Unregulated Energy	402,352		393,215
Other businesses and eliminations	29,213		29,890
Total property, plant and equipment	2,300,328		2,226,104
Less: Accumulated depreciation and amortization	(489,724)		(462,926)
Plus: Construction work in progress	60,578		47,295
Net property, plant and equipment	1,871,182		1,810,473
Current Assets
Cash and cash equivalents	4,169		6,204
Trade and other receivables	48,091		65,758
Less: Allowance for credit losses	(2,692)		(2,877)
Trade and other receivables, net	45,399		62,881
Accrued revenue	15,875		29,206
Propane inventory, at average cost	6,492		9,365
Other inventory, at average cost	17,873		16,896
Regulatory assets	26,343		41,439
Storage gas prepayments	3,208		6,364
Income taxes receivable	1,276		2,541
Prepaid expenses	12,496		15,865
Derivative assets, at fair value	1,704		2,787
Other current assets	1,934		428
Total current assets	136,769		193,976
Deferred Charges and Other Assets
Goodwill	46,213		46,213
Other intangible assets, net	16,965		17,859
Investments, at fair value	11,693		10,576
Derivative assets, at fair value	140		982
Operating lease right-of-use assets	13,432		14,421
Regulatory assets	95,985		108,214
Receivables and other deferred charges	12,111		12,323
Total deferred charges and other assets	196,539		210,588
Total Assets	$	2,204,490	$	2,215,037

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

3

Chesapeake Utilities Corporation and Subsidiaries

Condensed Consolidated Balance Sheets (Unaudited)

Capitalization and Liabilities	June 30, 2023		December 31, 2022
(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)	8,662		8,635
Additional paid-in capital	380,830		380,036
Retained earnings	477,795		445,509
Accumulated other comprehensive income (loss)	(3,059)		(1,379)
Deferred compensation obligation	9,001		7,060
Treasury stock	(9,001)		(7,060)
Total stockholders’ equity	864,228		832,801
Long-term debt, net of current maturities	645,742		578,388
Total capitalization	1,509,970		1,411,189
Current Liabilities
Current portion of long-term debt	19,994		21,483
Short-term borrowing	95,807		202,157
Accounts payable	44,173		61,496
Customer deposits and refunds	38,468		37,152
Accrued interest	3,429		3,349
Dividends payable	10,500		9,492
Accrued compensation	9,772		14,660
Regulatory liabilities	12,894		5,031
Derivative liabilities, at fair value	2,178		585
Other accrued liabilities	17,942		13,618
Total current liabilities	255,157		369,023
Deferred Credits and Other Liabilities
Deferred income taxes	261,215		256,167
Regulatory liabilities	144,275		142,989
Environmental liabilities	2,512		3,272
Other pension and benefit costs	17,890		16,965
Derivative liabilities, at fair value	474		1,630
Operating lease - liabilities	11,585		12,392
Deferred investment tax credits and other liabilities	1,412		1,410
Total deferred credits and other liabilities	439,363		434,825
Environmental and other commitments and contingencies (Notes 6 and 7)
Total Capitalization and Liabilities	$	2,204,490	$	2,215,037

    

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

4

Chesapeake Utilities Corporation and Subsidiaries

Condensed Consolidated Statements of Cash Flows (Unaudited)

	Six Months Ended
	June 30,
	2023		2022
(in thousands)
Operating Activities
Net income	$	52,477	$	53,985
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	34,486		34,193
Depreciation and accretion included in other costs	5,714		5,781
Deferred income taxes	5,695		11,434
Realized gain on commodity contracts and sale of assets	(1,032)		(6,980)
Unrealized (gain) loss on investments/commodity contracts	(1,131)		1,956
Employee benefits and compensation	218		(520)
Share-based compensation	2,919		3,555
Changes in assets and liabilities:
Accounts receivable and accrued revenue	30,812		24,766
Propane inventory, storage gas and other inventory	5,052		270
Regulatory assets/liabilities, net	28,796		(6,405)
Prepaid expenses and other current assets	2,953		10,326
Accounts payable and other accrued liabilities	(18,273)		(2,274)
Income taxes receivable/payable	1,265		5,107
Customer deposits and refunds	1,316		(1,999)
Accrued compensation	(5,061)		(6,266)
Other assets and liabilities, net	2,777		(3,134)
Net cash provided by operating activities	148,983		123,795
Investing Activities
Property, plant and equipment expenditures	(90,265)		(65,087)
Proceeds from sale of assets	2,034		3,367
Acquisitions, net of cash acquired	—		(2,006)
Environmental expenditures	(760)		(441)
Net cash used in investing activities	(88,991)		(64,167)
Financing Activities
Common stock dividends	(19,009)		(16,575)
Issuance of stock under the Dividend Reinvestment Plan, net of offering fees	(14)		4,259
Tax withholding payments related to net settled stock compensation	(2,455)		(2,838)
Change in cash overdrafts due to outstanding checks	(2,157)		(1,202)
Net repayments under line of credit agreements	(104,194)		(83,424)
Proceeds from long-term debt, net of offering fees	79,840		49,890
Repayment of long-term debt	(14,038)		(10,528)
Net cash used in financing activities	(62,027)		(60,418)
Net Increase (Decrease) in Cash and Cash Equivalents	(2,035)		(790)
Cash and Cash Equivalents—Beginning of Period	6,204		4,976
Cash and Cash Equivalents—End of Period	$	4,169	$	4,186

The accompanying notes are an integral part of these condensed consolidated 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, 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 (3)	8,886	5		1,203		—		—		—		—		1,208
Share-based compensation and tax benefit (4) (5)	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 (3)	33,846	17		4,613		—		—		—		—		4,630
Share-based compensation and tax benefit (4) (5)	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
Balance at March 31, 2023	17,789,856	$	8,659	$	379,703	$	472,209	$	(1,983)	$	8,816	$	(8,816)	$	858,588
Net income	—	—		—		16,133		—		—		—		16,133
Other comprehensive loss	—	—		—		—		(1,076)		—		—		(1,076)
Dividend declared ($0.590 per share)	—	—		—		(10,547)		—		—		—		(10,547)
Issuance under various plans (3)	—	—		(8)		—		—		—		—		(8)
Share-based compensation and tax benefit (4) (5)	6,885	3		1,135		—		—		—		—		1,138
Treasury stock activities	—	—		—		—		—		185		(185)		—
Balance at June 30, 2023	17,796,741	$	8,662	$	380,830	$	477,795	$	(3,059)	$	9,001	$	(9,001)	$	864,228
Balance at December 31, 2022	17,741,418	$	8,635	$	380,036	$	445,509	$	(1,379)	$	7,060	$	(7,060)	$	832,801
Net income	—	—		—		52,477		—		—		—		52,477
Other comprehensive loss	—	—		—		—		(1,680)		—		—		(1,680)
Dividends declared ($1.125 per share)	—	—		—		(20,191)		—		—		—		(20,191)
Issuance under various plans (3)	—	—		(19)		—		—		—		—		(19)
Share-based compensation and tax benefit (4) (5)	55,323	27		813		—		—		—		—		840
Treasury stock activities	—	—		—		—		—		1,941		(1,941)		—
Balance at June 30, 2023	17,796,741	$	8,662	$	380,830	$	477,795	$	(3,059)	$	9,001	$	(9,001)	$	864,228

(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 110,277, 108,143, 110,835, and 116,238 shares at June 30, 2023, December 31, 2022, June 30, 2022 and December 31, 2021, respectively, held in a Rabbi Trust related to our Non-Qualified Deferred Compensation Plan.

(3)Can include shares issued under the Retirement Savings Plan, DRIP and ATM equity issuances.

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

(5)The shares issued under the SICP are net of shares withheld for employee taxes. For the six months ended June 30, 2023 and 2022, we withheld 19,859 and 21,832 shares, respectively, for employee taxes.

The accompanying notes are an integral part of these condensed consolidated 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, 2022. 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

There are no pending or recently effective accounting standards which have had, or are expected to have, a material impact to our consolidated financial statements or disclosures.

2.    Calculation of Earnings Per Share

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
(in thousands, except shares and per share data)
Calculation of Basic Earnings Per Share:
Net Income	$	16,133	$	17,051	$	52,477	$	53,985
Weighted average shares outstanding	17,794,320		17,730,833		17,777,203		17,704,592
Basic Earnings Per Share	$	0.91	$	0.96	$	2.95	$	3.05
Calculation of Diluted Earnings Per Share:
Net Income	$	16,133	$	17,051	$	52,477	$	53,985
Reconciliation of Denominator:
Weighted shares outstanding—Basic	17,794,320		17,730,833		17,777,203		17,704,592
Effect of dilutive securities—Share-based compensation	57,704		79,038		64,751		81,037
Adjusted denominator—Diluted	17,852,024		17,809,871		17,841,954		17,785,629
Diluted Earnings Per Share	$	0.90	$	0.96	$	2.94	$	3.04

3.     Acquisitions

Acquisition of Davenport Energy

In June 2022, Sharp acquired the propane operating assets of Davenport Energy's Siler City, North Carolina propane division for approximately $2.0 million. Through this acquisition, we expanded our operating footprint further into

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North Carolina, where customers are served by Sharp Energy’s Diversified Energy division. Sharp added approximately 850 customers, along with 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. All amounts initially recorded in connection with this acquisition are now final as a result of the conclusion of the measurement period; no further adjustments were necessary. The financial results associated with this acquisition are included within our propane distribution operations within our Unregulated Energy segment.

Acquisition of Planet Found Energy Development

In October 2022, we acquired Planet Found Energy Development, LLC ("Planet Found") for $9.5 million. In connection with this acquisition, we recorded a $0.9 million liability which is subject to the seller's adherence to various provisions contained in the purchase agreement through the first anniversary of the transaction closing. We accounted for this acquisition as a business combination within our Unregulated Energy segment beginning in the fourth quarter of 2022. Planet Found's farm scale anaerobic digestion pilot system and technology produces biogas from 1,200 tons of poultry litter annually, which can be used to create renewable energy in the form of electricity or upgraded to renewable natural gas. The transaction will accelerate our efforts in converting poultry waste to renewable, sustainable energy while simultaneously improving the local environments in our service territories. The operating revenues and operating income of Planet Found were not material to our consolidated results for the three and six months ended June 30, 2023.

In connection with this acquisition, we recorded $4.4 million in intangible assets associated primarily with intellectual property and non-compete agreements, $4.0 million in property plant and equipment, $1.1 million in goodwill, and less than $0.1 million in working capital, 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.

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, 2023 and 2022:

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	Three Months Ended June 30, 2023								Three Months Ended June 30, 2022
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total		Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Energy distribution
Delaware natural gas division	$	14,109	$	—	$	—	$	14,109	$	13,086	$	—	$	—	$	13,086
Florida natural gas distribution (1)	40,766		—		—		40,766		35,436		—		—		35,436
FPU electric distribution	23,034		—		—		23,034		20,305		—		—		20,305
Maryland natural gas division	4,622		—		—		4,622		4,372		—		—		4,372
Sandpiper natural gas/propane operations	4,079		—		—		4,079		4,248		—		—		4,248
Elkton Gas	1,303		—		—		1,303		1,705		—		—		1,705
Total energy distribution	87,913		—		—		87,913		79,152		—		—		79,152
Energy transmission
Aspire Energy	—		5,726		—		5,726		—		10,808		—		10,808
Aspire Energy Express	369		—		—		369		369		—		—		369
Eastern Shore	19,632		—		—		19,632		18,875		—		—		18,875
Peninsula Pipeline	7,593		—		—		7,593		6,777		—		—		6,777
Total energy transmission	27,594		5,726		—		33,320		26,021		10,808		—		36,829
Energy generation
Eight Flags	—		4,532		—		4,532		—		5,916		—		5,916
Propane operations
Propane delivery operations	—		27,315		—		27,315		—		34,469		—		34,469
Compressed Natural Gas Services
Marlin Gas Services	—		3,238		—		3,238		—		2,380		—		2,380
Other and eliminations
Eliminations	(14,366)		(60)		(6,344)		(20,770)		(12,980)		(110)		(6,271)		(19,361)
Other	—		—		45		45		—		—		85		85
Total other and eliminations	(14,366)		(60)		(6,299)		(20,725)		(12,980)		(110)		(6,186)		(19,276)
Total operating revenues (2)	$	101,141	$	40,751	$	(6,299)	$	135,593	$	92,193	$	53,463	$	(6,186)	$	139,470

(1) In accordance with the Florida PSC approval of our natural gas base rate proceeding, effective March 1, 2023, 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”) have been consolidated for rate-making purposes and amounts above are now being presented on a consolidated basis consistent with the final rate order.

(2) Total operating revenues for the three months ended June 30, 2023 include other revenue (revenues from sources other than contracts with customers) of $0.2 million and $0.1 million for our Regulated and Unregulated Energy segments, respectively and $(0.1) million and $0.1 million for our Regulated and Unregulated Energy segments, respectively, for the three months ended June 30, 2022. 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, 2023 and 2022:

	Six Months Ended June 30, 2023								Six Months Ended June 30, 2022
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total		Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Energy distribution
Delaware natural gas division	$	51,016	$	—	$	—	$	51,016	$	47,568	$	—	$	—	$	47,568
Florida natural gas distribution (1)	87,124		—		—		87,124		75,722		—		—		75,722
FPU electric distribution	45,771		—		—		45,771		39,394		—		—		39,394
Maryland natural gas division	16,884		—		—		16,884		14,836		—		—		14,836
Sandpiper natural gas/propane operations	11,161		—		—		11,161		11,885		—		—		11,885
Elkton Gas	5,444		—		—		5,444		5,071		—		—		5,071
Total energy distribution	217,400		—		—		217,400		194,476		—		—		194,476
Energy transmission
Aspire Energy	—		19,680		—		19,680		—		28,844		—		28,844
Aspire Energy Express	733		—		—		733		632		—		—		632
Eastern Shore	40,302		—		—		40,302		39,196		—		—		39,196
Peninsula Pipeline	14,504		—		—		14,504		13,549		—		—		13,549
Total energy transmission	55,539		19,680		—		75,219		53,377		28,844		—		82,221
Energy generation
Eight Flags	—		9,832		—		9,832		—		11,455		—		11,455
Propane operations
Propane delivery operations	—		87,295		—		87,295		—		110,075		—		110,075
Compressed Natural Gas Services
Marlin Gas Services	—		7,238		—		7,238		—		4,589		—		4,589
Other and eliminations
Eliminations	(29,528)		(129)		(13,696)		(43,353)		(27,769)		(207)		(12,706)		(40,682)
Other	—		—		91		91		—		—		216		216
Total other and eliminations	(29,528)		(129)		(13,605)		(43,262)		(27,769)		(207)		(12,490)		(40,466)
Total operating revenues (2)	$	243,411	$	123,916	$	(13,605)	$	353,722	$	220,084	$	154,756	$	(12,490)	$	362,350

(1) In accordance with the Florida PSC approval of our natural gas base rate proceeding, effective March 1, 2023, 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”) have been consolidated for rate-making purposes and amounts above are now being presented on a consolidated basis consistent with the final rate order.

(2) Total operating revenues for the six months ended June 30, 2023 include other revenue (revenues from sources other than contracts with customers) of $0.8 million and $0.2 million for our Regulated and Unregulated Energy segments, respectively and $0.1 million and $0.2 million for our Regulated and Unregulated Energy segments, respectively, for the six months ended June 30, 2022. 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, 2023 and December 31, 2022 were as follows:

	Trade Receivables		Contract Assets (Current)		Contract Assets (Non-current)		Contract Liabilities (Current)
(in thousands)
Balance at 12/31/2022	$	61,687	$	18	$	4,321	$	983
Balance at 6/30/2023	41,140		18		3,787		594
Decrease	$	(20,547)	$	—	$	(534)	$	(389)

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 and North Carolina 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, 2023 and 2022, we recognized revenue of $0.2 million and $0.3 million, respectively. For the six months ended June 30, 2023 and 2022, we recognized revenue of $0.4 million and $0.7 million, respectively.

Remaining Performance Obligations

Our businesses have long-term fixed fee contracts with customers in which revenues are recognized when performance obligations are satisfied over the contract term. Revenue for these businesses for the remaining performance obligations, at June 30, 2023, are expected to be recognized as follows:

(in thousands)	2023		2024		2025		2026		2027		2028		2029 and thereafter
Eastern Shore and Peninsula Pipeline	$	19,613	$	37,006	$	30,613	$	27,138	$	24,163	$	23,398	$	188,498
Natural gas distribution operations	3,967		7,744		7,297		7,066		6,470		5,154		28,371
FPU electric distribution	326		652		275		275		275		275		—
Total revenue contracts with remaining performance obligations	$	23,906	$	45,402	$	38,185	$	34,479	$	30,908	$	28,827	$	216,869

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

Refer to the additional details below pertaining to the Customer Information System Regulatory Asset Petition and COVID-19 impact.

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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 FERC approved the Section 7(f) request on August 29, 2022. The project will increase the reliability of the existing distribution system in those areas while also expanding infrastructure to serve new customers. Construction was completed during the second quarter of 2023.

Florida

Wildlight Expansion: In August 2022, Peninsula Pipeline and FPU filed a joint petition with the Florida PSC for approval of its Transportation Service Agreement associated with the Wildlight planned community located in Nassau County, Florida. The project enables us to meet the significant growing demand for service in Yulee, Florida. The agreement will enable us to construct the project during the build-out of the community, and charge the reservation rate as each phase of the project goes into service. Construction of the pipeline facilities will occur in two separate phases. Phase one consists of three extensions with associated facilities, and a gas injection interconnect with associated facilities. Phase two will consist of two additional pipeline extensions. The various phases of the project commenced in the first quarter of 2023, with construction on the overall project continuing through 2025. The petition was approved by the Florida PSC in November 2022.

Natural Gas Rate Case: In May 2022, our natural gas distribution businesses in Florida filed a consolidated natural gas rate case with the Florida PSC. The application included a request for the following: (i) permanent rate relief of approximately $24.1 million, effective January 1, 2023, (ii) a depreciation study also submitted with filing; (iii) authorization to make certain changes to tariffs to include the consolidation of rates and rate structure across the businesses and to unify the Florida natural gas distribution businesses under FPU; (iv) authorization to retain the acquisition adjustment recorded at the time of the FPU merger in our revenue requirement; and (v) authorization to establish an environmental remediation surcharge for the purposes of addressing future expected remediation costs for FPU MGP sites. In August 2022, interim rates were approved by the Florida PSC in the amount of approximately $7.7 million on an annualized basis, effective for all meter readings in September 2022. The discovery process and subsequent hearings were concluded during the fourth quarter of 2022 and briefs were submitted during the same quarter of 2022. In January 2023, the Florida PSC approved the application for consolidation and permanent rate relief of approximately $17.2 million on an annual basis. Actual rates in connection with the rate relief were approved by the Florida PSC in February 2023 with an effective date of March 1, 2023.

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 constructed 11.3 miles of pipeline from its existing pipeline in the Sebastian, Florida area, traveling east under the Intercoastal Waterway and southward on the barrier island. The project was placed in-service during April 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 FPU, for an additional 2,400 Dt/d of firm service in the St. Cloud, Florida area. As part of this agreement, Peninsula Pipeline will construct a pipeline extension and regulator station for FPU. The extension will be used to support new incremental load due to growth in the area, including providing service, most immediately, to the residential development, Twin Lakes. The expansion will also improve reliability and provide operational benefits to FPU's existing distribution system in the area, supporting future growth. The petition was approved by the Florida PSC in October 2022. We expect this expansion to be placed into service during the third quarter of 2023.

Storm Protection Plan: In 2020, the Florida PSC implemented the Storm Protection Plan ("SPP") and Storm Protection Plan Cost Recovery Clause ("SPPCRC") rules, which require electric utilities to petition the Florida PSC for approval of a Transmission and Distribution Storm Protection Plan that covers the utility’s immediate 10-year planning period with updates to the plan at least every 3 years. The SPPCRC rules allow the utility to file for recovery of associated costs for the SPP. Our Florida electric distribution operation’s SPP plan was filed during the first quarter of 2022 and approved in the fourth quarter of 2022 with modifications, by the Florida PSC. Rates associated with this initiative were effective in January 2023.

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Lake Wales Pipeline Acquisition: In February 2023, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with FPU for an additional 9,000 Dt/d of firm service in the Lake Wales, Florida area. The Commission approved the petition in April 2023. Approval of the agreement allowed Peninsula Pipeline to complete the acquisition of the existing pipeline in May 2023 which is being utilized to serve our current natural gas customers as well as enable us to serve new customers.

GUARD: In February 2023, FPU filed a petition with the Florida PSC for approval of the GUARD program. GUARD is a ten-year program to enhance the safety, reliability, and accessibility of portions of our natural gas distribution system. We have identified various categories of projects to be included in GUARD, which include the relocation of mains and service lines located in rear easements and other difficult to access areas to the front of the street, the replacement of problematic distribution mains, service lines, and M&R equipment and system reliability projects. In August 2023, the Florida PSC approved the GUARD program, with the exception of reliability projects with an approximate value of $10 million. The remainder of the program was approved as filed, which included $205 million of capital expenditures projected to be spent over a 10-year period.

Newberry Expansion: In April 2023, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with FPU for an additional 8,000 Dt/d of firm service in the Newberry, Florida area. In July 2023, the Florida PSC approved the company's recommendation to proceed with this project. Peninsula Pipeline will construct a pipeline extension which will be used by FPU to support the development of a natural gas distribution system to provide gas service to the City of Newberry.

Amendment to Escambia County Agreement: In April of 2023, Peninsula Pipeline filed a petition with the Florida PSC for approval of an amendment to an existing contract with FPU. This amendment will allow Peninsula Pipeline to construct an additional delivery point on a pipeline located in Escambia County. The additional delivery point comes at the request of an FPU customer and will be used to enhance natural gas service in the area. Currently, the petition is under review by the Florida PSC. A decision is expected in the third quarter of 2023.

Florida Electric Depreciation Study: The Florida PSC requires electric utilities to file a depreciation study every four years to reevaluate and set depreciation rates for the utility's plant assets. In June 2023, FPU filed a petition with the Florida PSC for approval of it’s proposed depreciation rates. If approved, new rates will become effective retroactively on January 1, 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 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 its pipeline system. The project obtained FERC approval in December 2022, and is under construction, estimated to go into service in the fourth quarter of 2023.

Capital Cost Surcharge: In December 2022, Eastern Shore submitted a filing with the FERC regarding a capital cost surcharge to recover capital costs associated with the replacement of existing Eastern Shore facilities as a result of mandated highway relocation projects as well as compliance with a Pipeline and Hazardous Materials Safety Administration ("PHMSA") regulation. The capital cost surcharge mechanism was approved in Eastern Shore’s last rate case. In conjunction with the filing of this surcharge, a cumulative adjustment to the existing surcharge to reflect additional depreciation was included. The FERC issued an order approving the surcharge as filed on December 19, 2022. The combined revised surcharge became effective January 1, 2023.

Various Jurisdictional Activity Related to the Joint Customer Information System Project

In July 2022, we filed a joint petition for our natural gas divisions in Maryland (Maryland Division, Sandpiper, and Elkton Gas) for the approval to establish a regulatory asset for non-capitalizable expenses related to the initial development and implementation of our new Customer Information System ("CIS") system. The petition was approved by the Maryland PSC in August 2022. A similar petition for our Florida Regulated Energy businesses was filed during the same time frame and was initially denied. The Florida PSC subsequently approved capitalization of these expenses. Additionally, our Delaware Division has the ability to defer these costs as a regulatory asset. We have completed the system selection process and the CIS implementation began during the first quarter of 2023.

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COVID-19 Impact

In March 2020, the CDC declared a national emergency due to the rapidly growing outbreak of COVID-19. In response to this declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the country imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to slow the spread of the illness. These restrictions significantly impacted economic conditions in the United States in 2020 and continued to impact economic conditions, to a lesser extent, through 2021 and 2022. Chesapeake Utilities is considered an “essential business,” which allowed us to continue operational activities and construction projects with appropriate safety precautions and personal protective equipment, while being mindful of the social distancing restrictions that were in place.

In response to the COVID-19 pandemic and related restrictions, we experienced reduced consumption of energy largely in the commercial and industrial sectors, higher bad debt expenses and incremental expenses associated with COVID-19, including expenditures associated with personal protective equipment and premium pay for field personnel. The additional operating expenses we incurred supported the ongoing delivery of our essential services during the height of the pandemic. In April and May 2020, we were authorized by the Maryland and Delaware PSCs, respectively, to record regulatory assets for COVID-19 related costs which offered us the ability to seek recovery of those costs. In July 2021, the Florida PSC issued an order that approved incremental expenses we incurred due to COVID-19. The order allowed us to establish a regulatory asset in a total amount of $2.1 million as of June 30, 2021 for natural gas and electric distribution operations. The regulatory asset is being amortized over two years and is recovered through the Purchased Gas Adjustment and Swing Service mechanisms for our natural gas distribution businesses and through the Fuel Purchased Power Cost Recovery clause for our electric division. As of June 30, 2023 and December 31, 2022, our total COVID-19 regulatory asset balance was $0.7 million and $1.2 million, respectively.

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, 2023 and December 31, 2022:

	Amount (in thousands)
Operation and Regulatory Jurisdiction	June 30, 2023	December 31, 2022	Status
Eastern Shore (FERC)	$34,190	$34,190	Will be addressed in Eastern Shore's next rate case filing.
Chesapeake Delaware natural gas division (Delaware PSC)	$12,134	$12,230	PSC approved amortization of ADIT in January 2019.
Chesapeake Maryland natural gas division (Maryland PSC)	$3,644	$3,703	PSC approved amortization of ADIT in May 2018.
Sandpiper Energy (Maryland PSC)	$3,542	$3,597	PSC approved amortization of ADIT in May 2018.
Florida natural gas distribution (Florida PSC) (1)	$26,894	$27,179	PSC issued order authorizing amortization and retention of net ADIT liability by the Company in February 2019.
FPU electric division (Florida PSC)	$4,876	$4,993	In January 2019, PSC issued order approving amortization of ADIT through purchased power cost recovery, storm reserve and rates.
Elkton Gas (Maryland PSC)	$1,043	$1,059	PSC approved amortization of ADIT in March 2018.

(1) In accordance with the Florida PSC approval of our natural gas base rate proceeding, effective March 1, 2023, our natural gas distribution businesses in Florida have been consolidated for rate-making purposes and amounts above are now being presented on a consolidated basis consistent with the final rate order.

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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, 2023 and December 31, 2022, we had approximately $3.4 million and $4.3 million, respectively, in environmental liabilities related to the former MGP sites. As of June 30, 2023 and December 31, 2022, we have cumulative regulatory assets of $0.5 million and $0.8 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 for and has recovered, through a combination of insurance and customer rates, $14.0 million of its environmental costs related to its MGP sites as of June 30, 2023.

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 later in 2023.

7.     Other Commitments and Contingencies

Natural Gas, Electric and Propane Supply

In March 2023, 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, 2023 and expire in March 2026.

Our Florida natural gas distribution operations and Eight Flags generation facility 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.

Additionally, our Florida natural gas distribution operations have 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

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in the Gulf Power agreement could also result in FPU having to provide an irrevocable letter of credit. As of June 30, 2023, 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, 2023 was $20.0 million. The aggregate amount guaranteed related to our subsidiaries at June 30, 2023 was approximately $14.2 million with the guarantees expiring on various dates through May 2024. In addition, the Board has authorized us to issue specific purpose corporate guarantees. The amount of specific purpose guarantees outstanding at June 30, 2023 was $4.0 million.

As of June 30, 2023, we have issued letters of credit totaling approximately $5.9 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 April 2024 and to date, none have been used. 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 distribution operations, mobile compressed natural gas distribution and pipeline solutions operations, and project development activities related to our sustainable energy initiatives. Also included in this segment are other unregulated energy services, such as energy-related merchandise sales and heating, ventilation and air conditioning, plumbing and electrical services. These operations are unregulated as to their rates and services.

The remainder of our operations are presented as “Other businesses and eliminations,” which consists of unregulated subsidiaries that own real estate leased to Chesapeake Utilities, as well as certain corporate costs not allocated to other operations.

16

The following table presents financial information about our reportable segments:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
(in thousands)
Operating Revenues, Unaffiliated Customers
Regulated Energy	$	100,657	$	91,830	$	242,279	$	215,888
Unregulated Energy	34,936		47,640		111,443		146,462
Total operating revenues, unaffiliated customers	$	135,593	$	139,470	$	353,722	$	362,350
Intersegment Revenues (1)
Regulated Energy	$	484	$	363	$	1,132	$	4,196
Unregulated Energy	5,816		5,823		12,473		7,819
Other businesses	45		85		91		691
Total intersegment revenues	$	6,345	$	6,271	$	13,696	$	12,706
Operating Income
Regulated Energy	$	29,291	$	25,841	$	66,916	$	60,539
Unregulated Energy	(993)		560		16,252		20,613
Other businesses and eliminations	48		68		93		182
Operating income	28,346		26,469		83,261		81,334
Other income, net	831		2,584		1,107		3,498
Interest charges	6,964		5,825		14,196		11,164
Income Before Income Taxes	22,213		23,228		70,172		73,668
Income Taxes	6,080		6,177		17,695		19,683
Net Income	$	16,133	$	17,051	$	52,477	$	53,985

    

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

(in thousands)	June 30, 2023		December 31, 2022
Identifiable Assets
Regulated Energy segment	$	1,707,605	$	1,716,255
Unregulated Energy segment	448,217		463,239
Other businesses and eliminations	48,668		35,543
Total Identifiable Assets	$	2,204,490	$	2,215,037

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9.    Stockholders' Equity

Common Stock Issuances

We maintain an effective shelf registration statement with the SEC for the issuance of shares under our DRIP and ATM programs. 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 2022, we issued less than 0.1 million shares at an average price per share of $136.26 and received net proceeds of $4.5 million under the DRIP. In the first six months of 2023, there were no issuances under the DRIP. Our most recent ATM equity program, which allowed us to issue and sell shares of our common stock up to an aggregate offering price of $75.0 million, expired in June 2023. We expect to execute a new ATM during the third quarter of 2023.

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

Accumulated Other Comprehensive Income (Loss)

Defined benefit pension and postretirement plan items, unrealized gains (losses) of our propane swap agreements 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 income (loss) components as of June 30, 2023 and 2022. 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		Total
(in thousands)
As of December 31, 2022	$	(2,506)	$	1,092	$	35	$	(1,379)
Other comprehensive income (loss) before reclassifications	—		(2,045)		612		(1,433)
Amounts reclassified from accumulated other comprehensive income (loss)	21		(126)		(142)		(247)
Net current-period other comprehensive income (loss)	21		(2,171)		470		(1,680)
As of June 30, 2023	$	(2,485)	$	(1,079)	$	505	$	(3,059)

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 prior-period other comprehensive income	35		32		—		67
As of June 30, 2022	$	(3,233)	$	4,603	$	—	$	1,370

Deferred gains or losses for our commodity contracts and interest rate swap cash flow hedges are recognized in earnings upon settlement. Amortization of the net loss related to the defined benefit pension plan and postretirement plans is included in the computation of net periodic costs (benefits). See Note 10, Employee Benefit Plans, for additional details. Gains on commodity contracts classified as cash flow hedges related to our propane swaps are included in the effects of gains and losses from derivative instruments. See Note 12, Derivative Instruments, for additional details.

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Amortization of defined benefit pension and postretirement plan items are included in other expense, net, gains and losses on propane swap agreement contracts are included in revenue and unregulated propane and natural gas costs, and 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 the FPU Pension Plan for the three and six months ended June 30, 2023 and 2022 is set forth in the following table:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
FPU Pension Plan	2023		2022		2023		2022
(in thousands)
Interest cost	$	633	$	449	$	1,266	$	898
Expected return on plan assets	(668)		(857)		(1,336)		(1,714)
Amortization of net (gain) loss	110		124		220		248
Total periodic cost (benefit)	$	75	$	(284)	$	150	$	(568)

The following table presents the amounts included in the regulatory asset and accumulated other comprehensive income (loss) that were recognized as components of the FPU Pension Plan's net periodic benefit cost during the three and six months ended June 30, 2023 and 2022: 

	Three Months Ended				Six Months Ended
	June 30,				June 30,
FPU Pension Plan	2023		2022		2023		2022
(in thousands)
Recognized from accumulated other comprehensive (income) loss (1)	$	21	$	24	$	42	$	48
Recognized from regulatory asset	89		100		178		200
Total net loss in net periodic benefit cost	$	110	$	124	$	220	$	248

(1) See Note 9, Stockholders' Equity.

Net periodic benefit cost for our other pension and post-retirement benefit plans were not material for the three and six months ended June 30, 2023 and 2022.

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 (loss).

During the three and six months ended June 30, 2023, there were no contributions to the FPU Pension Plan and we do not expect to contribute to the FPU Pension Plan during 2023. 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 these other post retirement benefit plans for the three and six months ended June 30, 2023 were approximately $0.2 million and $0.3 million, respectively. We expect to pay total cash benefits of approximately $0.4 million for these other post retirement benefit plans in 2023.

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Non-Qualified Deferred Compensation Plan

Members of our Board of Directors and officers of the Company are eligible to participate in the Non-Qualified Deferred Compensation Plan. Directors can elect to defer any portion of their cash or stock compensation and officers can defer up to 80 percent of their base compensation, cash bonuses or any amount of their stock bonuses (net of required withholdings). Officers may receive a matching contribution on their cash compensation deferrals up to 6 percent of their compensation, provided it does not duplicate a match they receive in the Retirement Savings Plan.

All obligations arising under the Non-Qualified Deferred Compensation Plan are payable from our general assets, although we have established a Rabbi Trust to informally fund the plan. Deferrals of cash compensation may be invested by the participants in various mutual funds (the same options that are available in the Retirement Savings Plan). The participants are credited with gains or losses on those investments. Assets held in the Rabbi Trust, recorded as Investments on the condensed consolidated balance sheet, had a fair value of $11.7 million at June 30, 2023 and $10.6 million at December 31, 2022. The assets of the Rabbi Trust are at all times subject to the claims of our general creditors.

11.    Share-Based Compensation

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

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, 2023 and 2022:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
(in thousands)
Awards to key employees	$	284	$	1,122	$	2,440	$	3,101
Awards to non-employee directors	227		220		479		454
Total compensation expense	511		1,342		2,919		3,555
Less: tax benefit	(132)		(346)		(754)		(917)
Share-based compensation amounts included in net income	$	379	$	996	$	2,165	$	2,638

Officers and Key Employees

Our Compensation Committee is authorized to grant our key employees the right to receive awards of shares of our common stock, contingent upon the achievement of established performance goals and subject to SEC transfer restrictions once awarded. Our President and CEO has the right to issue awards of shares of our common stock, to other officers of the Company, contingent upon various performance goals and subject to SEC transfer restrictions.

We currently have several outstanding multi-year performance plans, which are based upon the successful achievement of long-term goals, growth and financial results and comprise both market-based and performance-based conditions and targets. The fair value per share, tied to a performance-based condition or target, is equal to the market price per share on the grant date. For the market-based conditions, we used the Monte Carlo valuation to estimate the fair value of each share granted.

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The table below presents the summary of the stock activity for awards to key employees for the six months ended June 30, 2023: 

	Number of Shares	Weighted Average Fair Value
Outstanding—December 31, 2022	204,149	$	103.17
Granted	80,752	$	128.01
Vested	(68,302)	$	91.59
Expired	(2,053)	$	94.64
Outstanding—June 30, 2023	214,546	$	116.04

During the six months ended June 30, 2023, we granted awards of 80,752 shares of common stock to key employees under the SICP, including awards granted in February 2023 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, 2025. 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 2023, 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 March 2023 for the performance period ended December 31, 2022. We paid the balance of such awarded shares to each such executive officer and remitted cash equivalent to the withheld shares to the appropriate taxing authorities. We withheld 19,859 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 $2.5 million.

At June 30, 2023, the aggregate intrinsic value of the SICP awards granted to key employees was approximately $25.5 million. At June 30, 2023, there was approximately $8.7 million of unrecognized compensation cost related to these awards, which will be recognized through 2025.

Non-employee Directors

Shares granted to non-employee directors are issued in advance of the directors’ service periods and are fully vested as of the grant date. We record a deferred expense equal to the fair value of the shares issued and amortize the expense equally over a service period of one year or less.

Our directors receive an annual retainer of shares of common stock under the SICP for services rendered through the subsequent Annual Meeting of Shareholders. Accordingly, our directors that served on the Board as of May 2023 each received 765 shares of common stock, respectively, with a weighted average fair value of $124.12 per share.

At June 30, 2023, there was approximately $0.8 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 2024.

12.    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, 2023, our natural gas and electric distribution operations did not have any outstanding derivative contracts.

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Volume of Derivative Activity

As of June 30, 2023, 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	21.3	Cash flow hedges	June 2026
Sharp	Propane (gallons)	Sales	3.2	Cash flow hedges	December 2023

Sharp entered into futures and swap agreements to mitigate the risk of fluctuations in wholesale propane index prices associated with the propane volumes 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 2023 through June 2026) 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 flow 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 unrealized losses of approximately $1.1 million from accumulated other comprehensive income (loss) related to our commodity cash flow hedges to earnings during the next 12-month period ended June 30, 2024.

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 September 2022, we entered into an interest rate swap with a notional amount of $50.0 million through September 2025, with pricing of 3.98 percent.

Prior to August 2022, our short-term borrowing was based on the 30-day LIBOR rate. In August 2022, we amended and restated our revolver and transitioned the benchmark interest rate to the 30-day SOFR as a result of the expiration of LIBOR. Our prior interest rate swaps were cash settled monthly as the counter-party paid us the 30-day LIBOR rate less the fixed rate. Our interest rate swap is cash settled monthly as the counter-party pays us the 30-day SOFR rate less the fixed rate.

We designate and account for interest rate swaps as cash flow hedges. Accordingly, unrealized gains and losses associated with the interest rate swap are recorded as a component of accumulated other comprehensive income (loss). When the interest rate swap settles, the realized gain or loss is recorded in the income statement and is recognized as a component of interest charges.

Broker Margin

Futures exchanges have contract specific margin requirements that require the posting of cash or cash equivalents relating to traded contracts. Margin requirements consist of initial margin that is posted upon the initiation of a position, maintenance margin that is usually expressed as a percent of initial margin, and variation margin that fluctuates based on the daily mark-to-market relative to maintenance margin requirements. We currently maintain a broker margin account for Sharp which was classified within our Other Current Assets on the consolidated balance sheet with a balance of $1.4 million as of June 30, 2023. At December 31, 2022, $0.1 million was classified in Other Current Liabilities on the consolidated balance sheet.

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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, 2023 and December 31, 2022, are as follows: 

	Derivative Assets
		Fair Value As Of
(in thousands)	Balance Sheet Location	June 30, 2023		December 31, 2022
Derivatives designated as cash flow hedges
Propane swap agreements	Derivative assets, at fair value	$	1,068	$	3,317
Interest rate swap agreements	Derivative assets, at fair value	776		452
Total Derivative Assets (1)		$	1,844	$	3,769

 (1) Derivative assets, at fair value include $1.7 million and $2.8 million in current assets in the condensed consolidated balance sheet at June 30, 2023 and December 31, 2022, respectively, with the remainder of the balance classified as long-term.

	Derivative Liabilities
		Fair Value As Of
(in thousands)	Balance Sheet Location	June 30, 2023		December 31, 2022
Derivatives designated as cash flow hedges
Propane swap agreements	Derivative liabilities, at fair value	$	2,556	$	1,810
Interest rate swap agreements	Derivative liabilities, at fair value	96		405
Total Derivative Liabilities (1)		$	2,652	$	2,215

(1) Derivative liabilities, at fair value include $2.2 million and $0.6 million in current liabilities in the condensed consolidated balance sheet at June 30, 2023 and December 31, 2022, respectively, with the remainder of the balance classified as long-term.

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	2023		2022		2023		2022
Derivatives not designated as hedging instruments
Propane swap agreements	Unregulated propane and natural gas costs	$	—	$	—	$	—	$	56
Derivatives designated as cash flow hedges
Propane swap agreements	Revenues	—		—		733		(826)
Propane swap agreements	Unregulated propane and natural gas costs	(432)		283		(559)		3,830
Propane swap agreements	Other comprehensive income (loss)	(2,417)		(686)		(2,994)		28
Interest rate swap agreements	Interest expense	127		—		192		—
Interest rate swap agreements	Other comprehensive income (loss)	898		—		633		—
Total		$	(1,824)	$	(403)	$	(1,995)	$	3,088

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13.    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, 2023 and December 31, 2022:

			Fair Value Measurements Using:
As of June 30, 2023	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	$	23	$	23	$	—	$	—
Investments—guaranteed income fund	1,756		—		—		1,756
Investments—mutual funds and other	9,914		9,914		—		—
Total investments	11,693		9,937		—		1,756
Derivative assets	1,844		—		1,844		—
Total assets	$	13,537	$	9,937	$	1,844	$	1,756
Liabilities:
Derivative liabilities	$	2,652	$	—	$	2,652	$	—

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			Fair Value Measurements Using:
As of December 31, 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	1,853		—		—		1,853
Investments—mutual funds and other	8,699		8,699		—		—
Total investments	10,576		8,723		—		1,853
Derivative assets	3,769		—		3,769		—
Total assets	$	14,345	$	8,723	$	3,769	$	1,853
Liabilities:
Derivative liabilities	$	2,215	$	—	$	2,215	$	—

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, 2023 and 2022:     

	Six months ended June 30,
	2023		2022
(in thousands)
Beginning Balance	$	1,853	$	2,036
Purchases and adjustments	—		132
Transfers	—		—
Distribution	(114)		(83)
Investment income	17		17
Ending Balance	$	1,756	$	2,102

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

At June 30, 2023, 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 2 measurement).

At June 30, 2023, long-term debt, which includes current maturities but excludes debt issuance costs, had a carrying value of approximately $666.8 million, compared to the estimated fair value of $573.3 million. At December 31, 2022, long-term debt, which includes the current maturities but excludes debt issuance costs, had a carrying value of approximately $600.8 million, compared to a fair value of approximately $505.0 million. The fair value was calculated using a discounted cash flow methodology that incorporates a market interest rate based on published corporate borrowing rates for debt instruments with similar terms and average maturities, and with adjustments for duration, optionality, and risk profile. The valuation technique used to estimate the fair value of long-term debt would be considered a Level 2 measurement.

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14.    Long-Term Debt

Our outstanding long-term debt is shown below: 

	June 30,		December 31,
(in thousands)	2023		2022
Uncollateralized senior notes:
5.93% note, due October 31, 2023	$	1,500	$	3,000
5.68% note, due June 30, 2026	8,700		11,600
6.43% note, due May 2, 2028	3,500		4,200
3.73% note, due December 16, 2028	12,000		12,000
3.88% note, due May 15, 2029	30,000		35,000
3.25% note, due April 30, 2032	63,000		66,500
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		50,000
5.43% notes Due March 14, 2038	80,000		—
Equipment security note
2.46% note, due September 24, 2031	8,078		8,517
Less: debt issuance costs	(1,042)		(946)
Total long-term debt	665,736		599,871
Less: current maturities	(19,994)		(21,483)
Total long-term debt, net of current maturities	$	645,742	$	578,388

    

Note Purchase Agreements

On March 14, 2023 we issued 5.43 percent Senior Notes due March 14, 2038 in the aggregate principal amount of $80.0 million and used the proceeds received from the issuances of the Senior Notes to reduce short-term borrowings under our Revolver credit facility and to fund capital expenditures. These Senior Notes have similar covenants and default provisions as our other Senior Notes, and have an annual principal payment beginning in the sixth year after the issuance.

Shelf Agreements

We have entered into Shelf Agreements with Prudential and MetLife, whom are under no obligation to purchase any unsecured debt. In February 2023, we amended our Shelf Agreements with Prudential and MetLife. The amended agreements expand the total borrowing capacity and extend the term of the agreements for an additional three years from the effective dates. The following table summarizes the current available capacity under our Shelf Agreements at June 30, 2023:

(in thousands)	Total Borrowing Capacity		Less: Amount of Debt Issued		Less: Unfunded Commitments		Remaining Borrowing Capacity
Shelf Agreements (1)
Prudential Shelf Agreement	$	405,000	$	(300,000)	$	—	$	105,000
MetLife Shelf Agreement	200,000		(50,000)		—		150,000
Total Shelf Agreements as of June 30, 2023	$	605,000	$	(350,000)	$	—	$	255,000

(1) The Prudential and MetLife Shelf Agreements both expire in February 2026.

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The Uncollateralized Senior 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.

15.    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, 2023 and December 31, 2022, we had $95.8 million and $202.2 million, respectively, of short-term borrowings outstanding at a weighted average interest rate of 5.33 percent and 5.04 percent, respectively.

In August 2022, we amended both tranches of our Revolver, which now bear interest using SOFR as the benchmark interest rate, plus a 10-basis point SOFR adjustment. In addition, the 364-day tranche was extended through August 2023. We expect to renew the 364-day tranche of the Revolver upon its current expiration. As part of these amendments, the parties agreed to eliminate the previous covenant capping the aggregate investments limit at $150.0 million where we maintain an ownership interest less than 50 percent. Additionally the 364-day tranche of the facility now offers a reduced interest margin similar to the five-year tranche for amounts borrowed in connection with new sustainable investments. All other terms and conditions remain unchanged. Borrowings outstanding under the sustainable investment sublimit of the 364-day tranche amounted to $9.4 million at June 30, 2023.

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, 2023, we are in compliance with this covenant.

The 364-day tranche of the Revolver expires in August 2023 and the five-year tranche expires in August 2026, both of which are available to fund our short-term cash needs to meet seasonal working capital requirements and to temporarily fund portions of our capital expenditures. Borrowings under both tranches of the Revolver are subject to a pricing grid, including the commitment fee and the interest rate charged based upon our total indebtedness to total capitalization ratio for the prior quarter. As of June 30, 2023, the pricing under the 364-day tranche of the Revolver included an unused commitment fee of 9 basis points and maintains an interest rate of 70 basis points over SOFR plus a 10 basis point SOFR adjustment. As of June 30, 2023, the pricing under the five-year tranche of the Revolver included an unused commitment fee of 9 basis points and an interest rate of 95 basis points over SOFR plus a 10 basis point SOFR adjustment.

Our total available credit under the Revolver at June 30, 2023 was $298.3 million. As of June 30, 2023, we had issued $5.9 million in letters of credit to various counterparties under the Revolver. These letters of credit are not included in the outstanding short-term borrowings and we do not anticipate that they will be drawn upon by the counterparties. The letters of credit reduce the available borrowings under the Revolver.

For additional information on interest rate swaps related to our short-term borrowings, see Note 12, Derivative Instruments.

16.    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. 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

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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, 2023, 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, 2023, 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	2023	2022	2023	2022
Operating lease cost (1)	Operations expense	$780	$726	$1,568	$1,377

(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, 2023 and December 31, 2022:

(in thousands)	Balance sheet classification	June 30, 2023		December 31, 2022
Assets
Operating lease assets	Operating lease right-of-use assets	$	13,432	$	14,421
Liabilities
Current
Operating lease liabilities	Other accrued liabilities	$	2,373	$	2,552
Noncurrent
Operating lease liabilities	Operating lease - liabilities	11,585		12,392
Total lease liabilities		$	13,958	$	14,944

The following table presents our weighted-average remaining lease terms and weighted-average discount rates for our operating leases at June 30, 2023 and December 31, 2022:

	June 30, 2023		December 31, 2022
Weighted-average remaining lease term (in years)
Operating leases	8.37		8.54
Weighted-average discount rate
Operating leases	3.5	%	3.4	%

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, 2023 and 2022:

	Six Months Ended
	June 30,
(in thousands)	2023		2022
Operating cash flows from operating leases	$	1,465	$	1,428

The following table presents the future undiscounted maturities of our operating and financing leases at June 30, 2023 and for each of the next five years and thereafter:

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(in thousands)	Operating Leases (1)
Remainder of 2023	$	1,419
2024	2,629
2025	2,263
2026	1,734
2027	1,571
2028	1,192
Thereafter	5,243
Total lease payments	16,051
Less: Interest	(2,093)
Present value of lease liabilities	$	13,958

    (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, 2022, 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 2022 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 availability and reliability of adequate technology, including our ability to adapt to technological advances, effectively implement new technologies and manage the related costs;

•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;

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

•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 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. Our growth strategy includes the continued investment and expansion of our regulated operations that provide a stable base of earnings, as well as investments in other related non-regulated businesses and services including sustainable energy initiatives. By investing in these related business and services, we create opportunities to sustain our track record of higher returns, as compared to a traditional utility.

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, 2023 and 2022:

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	For the Three Months Ended June 30, 2023
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Operating Revenues	$	101,141	$	40,751	$	(6,299)	$	135,593
Cost of Sales:
Natural gas, propane and electric costs	(23,886)		(18,116)		6,209		(35,793)
Depreciation & amortization	(13,035)		(4,269)		1		(17,303)
Operations & maintenance expense (1)	(9,240)		(7,520)		(2)		(16,762)
Gross Margin (GAAP)	54,980		10,846		(91)		65,735
Operations & maintenance expense (1)	9,240		7,520		2		16,762
Depreciation & amortization	13,035		4,269		(1)		17,303
Adjusted Gross Margin (Non-GAAP)	$	77,255	$	22,635	$	(90)	$	99,800

	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 Six months ended June 30, 2023
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Operating Revenues	$	243,411	$	123,916	$	(13,605)	$	353,722
Cost of Sales:
Natural gas, propane and electric costs	(79,174)		(58,687)		13,479		(124,382)
Depreciation & amortization	(25,987)		(8,503)		4		(34,486)
Operations & maintenance expense (1)	(18,527)		(15,996)		3		(34,520)
Gross Margin (GAAP)	119,723		40,730		(119)		160,334
Operations & maintenance expense (1)	18,527		15,996		(3)		34,520
Depreciation & amortization	25,987		8,503		(4)		34,486
Adjusted Gross Margin (Non-GAAP)	$	164,237	$	65,229	$	(126)	$	229,340

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	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

(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.

2023 to 2022 Gross Margin (GAAP) Variance – Regulated Energy

Gross Margin (GAAP) for the Regulated Energy segment for the quarter ended June 30, 2023 was $55.0 million, an increase of $5.8 million, or 11.8 percent, compared to the same period in 2022. Higher gross margin reflects contributions from our Florida natural gas base rate proceeding, organic growth in our natural gas distribution businesses, continued pipeline expansion projects and incremental contributions associated with regulated infrastructure programs. These increases were partially offset by changes in customer consumption largely related to continued warmer weather during the quarter, increased employee costs driven by growth initiatives, the ongoing competitive labor market and higher benefits costs compared to the prior-year period, higher property taxes, and increased facilities, maintenance and outside services costs.

Gross Margin (GAAP) for the Regulated Energy segment for the six months ended June 30, 2023 was $119.7 million, an increase of $9.4 million, or 8.5 percent, compared to the same period in 2022. The increase in gross margin for the period reflects contributions from our Florida natural gas base rate proceeding, organic growth in our natural gas distribution businesses, continued pipeline expansion projects and incremental contributions associated with regulated infrastructure programs. These increases were partially offset by changes in customer consumption due to significantly warmer weather experienced in the first half of 2023. Higher operating expenses also contributed to the offset driven by increased employee costs driven by growth initiatives, the ongoing competitive labor market and higher benefits costs, increased facilities, maintenance and outside services costs, and higher property taxes compared to the prior-year period.

2023 to 2022 Gross Margin (GAAP) Variance – Unregulated Energy

Gross Margin (GAAP) for the Unregulated Energy segment for the quarter ended June 30, 2023 was $10.8 million, compared to $11.0 million for the same period in 2022. Gross margin was impacted by reduced customer consumption due in part to the conversion of propane customers to our natural gas distribution service and to a lesser extent, continued warmer weather in our Mid-Atlantic service territories. Additionally, we experienced increased operating expenses associated with employee costs driven by the ongoing competitive labor market and higher benefits costs, increased property taxes and higher facilities, maintenance and outside services costs. These factors were partially offset by higher propane margins and fees and increased demand for CNG, RNG and LNG services.

Gross Margin (GAAP) for the Unregulated Energy segment for the six months ended June 30, 2023 was $40.7 million, compared to $43.3 million for the same period in 2022. Gross margin during the first half of 2023 was impacted by changes in customer consumption due to significantly warmer weather in our Mid-Atlantic service territories primarily during the first quarter, as well as the ongoing conversion of propane customers to our natural gas distribution service. Additionally, we experienced increased operating expenses associated with employee costs driven by the ongoing competitive labor market and higher benefits costs, increased property taxes and higher facilities, maintenance and outside services costs. These factors were partially offset by expanded propane margins and fees and increased demand for CNG, RNG and LNG services.

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Results of Operations for the Three and Six Months Ended June 30, 2023

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.

Sustainability Initiatives

In May 2023, we published our most recent annual sustainability report, and continue to remain steadfast in regards to our commitments, including the following:

•Maintaining a leading role in the journey to a lower carbon future in our service areas.

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

•Operating our businesses 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 the relationships we have with our stakeholders. We encourage our investors to review the report, which can be accessed on our website, and welcome feedback as we continue to enhance our sustainability disclosures.

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Operational Highlights

Our net income for the three months ended June 30, 2023 was $16.1 million, or $0.90 per share, compared to $17.1 million, or $0.96 per share, for the same quarter of 2022. Net income for the second quarter of 2022 included a non-recurring after-tax gain of $1.4 million related to a building sale. Operating income for the second quarter of 2023 was $28.3 million, an increase of $1.9 million or 7.1 percent compared to the same period in 2022. Adjusted gross margin in the second quarter of 2023 was positively impacted by contributions from the Florida natural gas base rate proceeding, organic growth in our natural gas distribution businesses, increased propane margins and fees, continued pipeline expansion projects, increased demand for CNG, RNG and LNG services and incremental contributions associated with regulated infrastructure programs. These increases in adjusted gross margin were partially offset by reduced consumption, including the continued effects of warmer temperatures experienced during the second quarter of 2023, and higher operating expenses which were largely associated with increased employee costs driven by growth initiatives, the ongoing competitive labor market and higher benefits costs compared to the prior-year period. Operating income was also impacted by higher property taxes during the second quarter of 2023.

	Three Months Ended
	June 30,				Increase
	2023		2022		(Decrease)
(in thousands, except per share data)
Adjusted Gross Margin
Regulated Energy segment	$	77,255	$	70,620	$	6,635
Unregulated Energy segment	22,635		21,762		873
Other businesses and eliminations	(90)		(28)		(62)
Total Adjusted Gross Margin	$	99,800	$	92,354	$	7,446
Operating Income (Loss)
Regulated Energy segment	$	29,291	$	25,841	$	3,450
Unregulated Energy segment	(993)		560		(1,553)
Other businesses and eliminations	48		68		(20)
Total Operating Income	28,346		26,469		1,877
Other income, net	831		2,584		(1,753)
Interest charges	6,964		5,825		1,139
Income from Before Income Taxes	22,213		23,228		(1,015)
Income Taxes	6,080		6,177		(97)
Net Income	$	16,133	$	17,051	$	(918)
Basic Earnings Per Share of Common Stock	$	0.91	$	0.96	$	(0.05)
Diluted Earnings Per Share of Common Stock	$	0.90	$	0.96	$	(0.06)

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Key variances between the second quarter of 2022 and the second quarter of 2023 included: 

(in thousands, except per share data)	Pre-tax Income		Net Income		Earnings Per Share
Second Quarter of 2022 Reported Results	$	23,228	$	17,051	$	0.96
Adjusting for Non-recurring Items:
Absence of gain from sales of assets	(1,902)		(1,382)		(0.08)
	(1,902)		(1,382)		(0.08)
Increased (Decreased) Adjusted Gross Margins:
Contribution from rates associated with Florida natural gas base rate proceeding*	3,873		2,813		0.16
Natural gas growth including conversions (excluding service expansions)	1,844		1,339		0.08
Increased propane margins and service fees	1,512		1,098		0.06
Natural gas transmission service expansions*	1,113		809		0.05
Increased adjusted gross margin from off-system natural gas capacity sales	637		463		0.03
Increased margins related to demand for CNG/RNG/LNG services*	478		347		0.02
Contributions from regulated infrastructure programs*	395		287		0.02
Customer consumption - primarily resulting from weather	(2,165)		(1,572)		(0.09)
	7,687		5,584		0.33
Increased Operating Expenses (Excluding Natural Gas, Propane, and Electric Costs):
Increased payroll, benefits and other employee-related expenses	(3,124)		(2,269)		(0.13)
Increased facilities expenses, maintenance costs and outside services	(1,008)		(732)		(0.04)
Depreciation, amortization and property taxes	(774)		(562)		(0.03)
	(4,906)		(3,563)		(0.20)
Interest charges	(1,139)		(827)		(0.05)
Net other changes	(755)		(730)		(0.06)
	(1,894)		(1,557)		(0.11)
Second Quarter of 2023 Reported Results	$	22,213	$	16,133	$	0.90

*See the Major Projects and Initiatives table.

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Our net income for the six months ended June 30, 2023 was $52.5 million, or $2.94 per share, compared to $54.0 million, or $3.04 per share, for the same period of 2022. Net income for the six months ended June 30, 2023 included a one-time tax benefit of $1.3 million associated with a reduction in state tax rate, while the prior-year included a non-recurring after-tax gain of $1.4 million related to a building sale. Operating income for the six months ended June 30, 2023 was $83.3 million, an increase of $1.9 million or 2.4 percent compared to the same period in 2022, despite significantly warmer temperatures in our northern service territories during the first half of 2023. Adjusted gross margin for the first half of 2023 was positively impacted by contributions from the Florida natural gas base rate proceeding, increased propane margins and fees, organic growth in our natural gas distribution businesses, increased demand for CNG, RNG and LNG services, continued pipeline expansion projects and incremental contributions associated with regulated infrastructure programs. These increases in adjusted gross margin were significantly offset by reduced consumption experienced during the first half of 2023 from warmer weather in our northern service territories. We recorded higher employee costs driven by growth initiatives, the ongoing competitive labor market and higher benefits costs compared to the prior-year period, increased costs related to our facilities, maintenance and outside services, and higher property taxes.

	Six Months Ended
	June 30,				Increase
	2023		2022		(Decrease)
(in thousands, except per share data)
Adjusted Gross Margin
Regulated Energy segment	$	164,237	$	153,068	$	11,169
Unregulated Energy segment	65,229		65,046		183
Other businesses and eliminations	(126)		(61)		(65)
Total Adjusted Gross Margin	$	229,340	$	218,053	$	11,287
Operating Income
Regulated Energy segment	$	66,916	$	60,539	$	6,377
Unregulated Energy segment	16,252		20,613		(4,361)
Other businesses and eliminations	93		182		(89)
Total Operating Income	83,261		81,334		1,927
Other income, net	1,107		3,498		(2,391)
Interest charges	14,196		11,164		3,032
Income from Before Income Taxes	70,172		73,668		(3,496)
Income Taxes	17,695		19,683		(1,988)
Net Income	$	52,477	$	53,985	$	(1,508)
Basic Earnings Per Share of Common Stock	$	2.95	$	3.05	$	(0.10)
Diluted Earnings Per Share of Common Stock	$	2.94	$	3.04	$	(0.10)

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Key variances between the six months ended June 30, 2022 and the six months ended June 30, 2023 included:

(in thousands, except per share data)	Pre-tax Income		Net Income		Earnings Per Share
Six months ended June 30, 2022 Reported Results	$	73,668	$	53,985	$	3.04
Adjusting for Non-recurring Items:
Absence of gain from sales of assets	(1,902)		(1,423)		(0.08)
One-time benefit associated with reduction in state tax rate	—		1,284		0.07
	(1,902)		(139)		(0.01)
Increased (Decreased) Adjusted Gross Margins:
Customer consumption - primarily resulting from weather	(9,081)		(6,792)		(0.38)
Contribution from rates associated with Florida natural gas base rate proceeding*	7,970		5,962		0.33
Increased propane margins and service fees	4,576		3,423		0.19
Natural gas growth including conversions (excluding service expansions)	3,366		2,518		0.14
Increased margins related to demand for CNG/RNG/LNG services*	1,766		1,321		0.07
Natural gas transmission service expansions*	1,594		1,192		0.07
Contributions from regulated infrastructure programs*	1,193		892		0.05
Eastern Shore contracted rate adjustments	(285)		(213)		(0.01)
	11,099		8,303		0.46
Increased Operating Expenses (Excluding Natural Gas, Propane, and Electric Costs):
Increased payroll, benefits and other employee-related expenses	(4,267)		(3,191)		(0.18)
Increased facilities expenses, maintenance costs and outside services	(2,069)		(1,548)		(0.09)
Depreciation, amortization and property taxes	(1,700)		(1,272)		(0.07)
	(8,036)		(6,011)		(0.34)
Interest charges	(3,032)		(2,268)		(0.13)
Changes in Other income, net	(489)		(366)		(0.02)
Net other changes	(1,136)		(1,027)		(0.06)
	(4,657)		(3,661)		(0.21)
Six months ended June 30, 2023 Reported Results	$	70,172	$	52,477	$	2.94

*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, further grow our businesses and earnings, and 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 at the beginning of the next calendar year. Our practice is to add new projects and initiatives to this table once negotiations or details are substantially final and/or 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)	2023		2022		2023		2022		2022		2023		2024
Pipeline Expansions:
Guernsey Power Station	$	369	$	368	$	734	$	631	$	1,377	$	1,486	$	1,482
Southern Expansion	—		—		—		—		—		586		2,344
Winter Haven Expansion	163		28		302		61		260		576		626
Beachside Pipeline Expansion	603		—		603		—		—		1,825		2,451
North Ocean City Connector	—		—		—		—		—		—		200
St. Cloud / Twin Lakes Expansion	—		—		—		—		—		268		584
Clean Energy (1)	269		—		516		—		126		1,009		1,009
Wildlight	67		—		93		—		—		528		2,000
Lake Wales	38		—		38		—		—		265		454
Newberry	—		—		—		—		—		TBD		TBD
Total Pipeline Expansions	1,509		396		2,286		692		1,763		6,543		11,150
CNG/RNG/LNG Transportation and Infrastructure	2,905		2,427		6,426		4,660		11,100		12,558		12,280
Regulatory Initiatives:
Florida GUARD program	—		—		—		—		—		37		1,412
Capital Cost Surcharge Programs	703		497		1,423		1,014		2,001		2,811		3,558
Florida Rate Case Proceeding (2)	3,873		—		7,970		—		2,474		16,289		17,153
Electric Storm Protection Plan	436		—		642		—		486		960		2,433
Total Regulatory Initiatives	5,012		497		10,035		1,014		4,961		20,097		24,556
Total	$	9,426	$	3,320	$	18,747	$	6,366	$	17,824	$	39,198	$	47,986

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

(2) Includes adjusted gross margin during 2023 comprised of both interim rates and permanent base rates which became effective in March 2023.

Detailed Discussion of Major Projects and Initiatives

Pipeline Expansions

Guernsey Power Station

Guernsey Power Station and our affiliate, Aspire Energy Express, are engaged in a firm transportation capacity agreement whereby Guernsey Power Station has constructed a power generation facility and Aspire Energy Express provides 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, and the facility went into service during the first quarter of 2023. The project generated additional adjusted gross margin of $0.1 million for the six months ended June 30, 2023, and is expected to produce adjusted gross margin of approximately $1.5 million in 2023 and beyond.

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Southern Expansion

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 obtained FERC approval in December 2022 and 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 $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 Florida Natural Gas Distribution for an incremental 6,800 Dts/d of firm service in the Winter Haven, Florida area. As part of this agreement, Peninsula Pipeline constructed a new interconnect with FGT and a new regulator station for Florida Natural Gas Distribution. Florida Natural Gas Distribution is using the additional firm service 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 Florida Natural Gas Distribution’s existing distribution system in the area. In connection with Peninsula Pipeline’s new regulator station, Florida Natural Gas Distribution also extended its distribution system to connect to the new station. This expansion was placed in service in the third quarter of 2022. The project generated additional adjusted gross margin of $0.1 million and $0.2 million for the three and six months ended June 30, 2023, respectively, and is expected to produce adjusted gross margin of approximately $0.6 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 constructed 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 was completed and the project went into service in April 2023. The project generated additional adjusted gross margin of $0.6 million for the three and six months ended June 30, 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 of 2022, we began construction of an extension of service into North Ocean City, Maryland. Our Delaware natural gas division and Sandpiper installed approximately 5.7 miles of pipeline across southern Sussex County, Delaware to Fenwick Island, Delaware and Worcester County, Maryland. The project reinforces our existing system in Ocean City, Maryland and enables incremental growth along the pipeline. Construction of this project was completed in the second quarter 2023. Adjusted gross margin in connection with this project is expected to be recognized contingent upon the completion and approval of our next rate case in Maryland. As a result, we expect this expansion to generate annual adjusted gross margin of approximately $0.2 million beginning in 2024, 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 provide operational benefits to FPU’s existing distribution system in the area, supporting future growth. We expect this expansion to be placed in service during the third quarter of 2023 and generate adjusted gross margin of $0.3 million in 2023 and $0.6 million thereafter.

Clean Energy Expansion

During the fourth quarter of 2022, Clean Energy Fuels ("Clean Energy") and Florida Natural Gas Distribution entered into a precedent agreement for firm transportation services associated with a CNG fueling station Clean Energy is constructing. We plan to install approximately 2.2 miles of main extension in Davenport, Florida to support the filling station. Construction is underway and is expected to be complete in the third quarter of 2023. Our subsidiary, Marlin Gas Services, is providing interim services to Clean Energy during the construction phase of the project. The project generated additional adjusted gross margin of $0.3 million and $0.5 million for the three and six months ended June 30, 2023, respectively, and is expected to produce adjusted gross margin of approximately $1.0 million in 2023 and beyond.

Wildlight Expansion

In August 2022, Peninsula Pipeline and FPU filed a joint petition with the Florida PSC for approval of its Transportation Service Agreement associated with the Wildlight planned community located in Nassau County, Florida. The project enables us

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to meet the significant growing demand for service in Yulee, Florida. The agreement will enable us to build the project during the construction and build-out of the community, and charge the reservation rate as each phase of the project goes into service. Construction of the pipeline facilities will occur in two separate phases. Phase one consists of three extensions with associated facilities, and a gas injection interconnect with associated facilities. Phase two will consist of two additional pipeline extensions. Various phases of the project commenced in the first quarter of 2023, with construction on the overall project continuing through 2025. The project generated adjusted gross margin of less than $0.1 million for both the three and six months ended June 30, 2023. We expect this project to contribute adjusted gross margin of approximately $0.5 million in 2023 and $2.0 million in 2024 and beyond.

Lake Wales Expansion

In February 2023, 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 9,000 Dt/d of firm service in the Lake Wales, Florida area. The PSC approved the petition in April 2023. Approval of the agreement enabled Peninsula Pipeline to complete the acquisition of an existing pipeline in May 2023 that is being utilized to serve our current natural gas customers as well as enable us to serve new customers. During the three and six months ended June 30, 2023 the project generated adjusted gross margin of less than $0.1 million. The project is expected to contribute adjusted gross margin of approximately $0.3 million in 2023 and $0.5 million in 2024 and beyond.

Newberry Expansion

In April 2023, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with FPU for an additional 8,000 Dt/d of firm service in the Newberry, Florida area. In July 2023, the Florida PSC approved the Company's recommendation to proceed with this project. Peninsula Pipeline will construct a pipeline extension which will be used by FPU to support the development of a natural gas distribution system to provide gas service to the City of Newberry.

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.

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. We include our RNG transportation services and infrastructure related adjusted gross margin from across the organization in combination with our CNG and LNG projects.

For the three and six months ended June 30, 2023, we generated $0.5 million and $1.8 million, respectively, 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. We estimate annual adjusted gross margin of approximately $12.6 million in 2023, and $12.3 million in 2024 for these transportation related services, with potential for additional growth in future years.

Full Circle Dairy

In February 2023, we announced plans to construct, own and operate a dairy manure RNG facility at Full Circle Dairy in Madison County, Florida. The project consists of a facility converting dairy manure to RNG and transportation assets to bring the gas to market. The first injection of RNG is projected to occur in the first half of 2024.

Planet Found Development

In late October 2022, we consummated the acquisition of Planet Found. Planet Found's farm scale anaerobic digestion pilot system and technology produces biogas from 1,200 tons of poultry litter annually, which can be used to create renewable energy in the form of electricity or upgraded to renewable natural gas. In addition to generating biogas, Planet Found’s nutrient capture system converts digestate into a nutrient-rich soil conditioner, which is distributed to bulk and retail markets under the brand Element Soil. The transaction accelerated our access to renewable, sustainable energy generated from poultry waste while continuing to enhance the local environments in our service territories.

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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.

Regulatory Initiatives

Florida GUARD Program

In February 2023, FPU filed a petition with the Florida PSC for approval of the GUARD program. GUARD is a ten-year program to enhance the safety, reliability, and accessibility of portions of our natural gas distribution system. We have identified various categories of projects to be included in GUARD, which include the relocation of mains and service lines located in rear easements and other difficult to access areas to the front of the street, the replacement of problematic distribution mains, service lines, and M&R equipment and system reliability projects. In August 2023, the Florida PSC approved the GUARD program, with the exception of reliability projects with an approximate value of $10 million. The remainder of the program was approved as filed, which included $205 million of capital expenditures projected to be spent over a 10-year period. The program is expected to generate less than $0.1 million of additional adjusted gross margin in 2023 and $1.4 million in 2024.

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, 2023, there was $0.2 million and $0.4 million, respectively, of incremental adjusted gross margin generated pursuant to the program. Eastern Shore expects to produce adjusted gross margin of approximately $2.8 million in 2023 and $3.6 million in 2024 from relocation projects, which is ultimately dependent upon the timing of filings and the completion of construction.

Florida Natural Gas Base Rate Proceeding

In May 2022, our natural gas distribution businesses in Florida filed a consolidated natural gas rate case with the Florida PSC. The application included a request for the following: (i) permanent rate relief of approximately $24.1 million, effective January 1, 2023, (ii) a depreciation study also submitted with the filing; (iii) authorization to make certain changes to tariffs to include the consolidation of rates and rate structure across the businesses and to unify the Florida natural gas distribution businesses under FPU; (iv) authorization to retain the acquisition adjustment recorded at the time of the FPU merger in our revenue requirement; and (v) authorization to establish an environmental remediation surcharge for the purposes of addressing future expected remediation costs for FPU MGP sites. In August 2022, interim rates were approved by the Florida PSC in the amount of approximately $7.7 million on an annualized basis, effective for all meter readings in September 2022. The discovery process and related hearings were concluded during the fourth quarter of 2022 and briefs were submitted in the same quarter of 2022. In January 2023, the Florida PSC approved the application for consolidation and permanent rate relief of approximately $17.2 million on an annual basis. Actual rates in connection with the rate relief were approved by the Florida PSC in February 2023 with an effective date of March 1, 2023. For the three and six months ended June 30, 2023, this proceeding generated adjusted gross margin of approximately $3.9 million and $8.0 million, respectively, and is expected to generate $16.3 million of additional adjusted gross margin in 2023 and $17.2 million in 2024.

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. Our Florida electric distribution operation's SPP and SPPCRC were filed during the first quarter of 2022 and approved in the fourth quarter of 2022 with modifications, by the Florida PSC. For the three and six months ended June 30, 2023, this initiative generated adjusted gross margin of approximately $0.4 million and $0.6 million and is expected to generate $1.0 million of additional adjusted gross margin in 2023 and $2.4 million in 2024. We expect continued investment under the SPP going forward.

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 obtain recovery of these costs in the next base rate proceedings. Our Florida regulated business units reached a settlement with the

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Florida OPC in June 2021, enabling 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 currently amortizing the amount over two years effective January 1, 2022 and recovering 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 additional adjusted gross margin of $1.0 million annually that is being offset by a corresponding amortization of regulatory asset expense, for both 2022 and 2023.

Other Major Factors Influencing Adjusted Gross Margin

Weather Impact

For the first half of 2023, lower consumption driven by weather experienced primarily during the first quarter resulted in a $9.1 million decrease in adjusted gross margin compared to the same period in 2022. The impact to adjusted gross margin was largely the result of unprecedented temperatures in the Company's northern service territories that were more than 20 percent higher than historical averages. Assuming normal temperatures, as detailed below, adjusted gross margin would have been higher by $10.3 million. 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, 2023 and 2022.

	Three Months Ended			Six Months Ended
	June 30,			June 30,
	2023	2022	Variance	2023	2022	Variance
Delmarva Peninsula
Actual HDD	276	394	(118)	2,050	2,575	(525)
10-Year Average HDD ("Normal")	408	412	(4)	2,693	2,667	26
Variance from Normal	(132)	(18)		(643)	(92)
Florida
Actual HDD	26	37	(11)	370	534	(164)
10-Year Average HDD ("Normal")	44	45	(1)	549	542	7
Variance from Normal	(18)	(8)		(179)	(8)
Ohio
Actual HDD	678	604	74	3,062	3,530	(468)
10-Year Average HDD ("Normal")	631	630	1	3,596	3,542	54
Variance from Normal	47	(26)		(534)	(12)
Florida
Actual CDD	937	988	(51)	1,260	1,183	77
10-Year Average CDD ("Normal")	952	945	7	1,144	1,142	2
Variance from Normal	(15)	43		116	41

Natural Gas Distribution Adjusted Gross Margin Growth

The average number of residential customers served on the Delmarva Peninsula increased by approximately 5.5 percent and 5.7 percent, respectively, for the three and six months ended June 30, 2023, while Florida customers increased by 4.0 percent and 4.2 percent, respectively, for the three and six month periods. On the Delmarva Peninsula, a larger percentage of the adjusted gross margin growth was generated from residential growth given the expansion of gas into new housing communities and conversions to natural gas as our distribution infrastructure continues to build out. In Florida, as new communities continue to build out due to population growth and infrastructure is added to support the growth, there is increased load from both residential customers as well as new commercial and industrial customers. The details are provided in the following table:

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	Three Months Ended				Six Months Ended
	June 30, 2023				June 30, 2023
(in thousands)	Delmarva Peninsula		Florida		Delmarva Peninsula		Florida
Customer Growth:
Residential	$	476	$	347	$	1,086	$	663
Commercial and industrial	241		780		453		1,164
Total Customer Growth (1)	$	717	$	1,127	$	1,539	$	1,827

(1) Customer growth amounts for Florida include the effects of revised rates associated with our natural gas base rate proceeding.

Regulated Energy Segment

For the quarter ended June 30, 2023, compared to the quarter ended June 30, 2022:

	Three Months Ended
	June 30,				Increase
	2023		2022		(Decrease)
(in thousands)
Revenue	$	101,141	$	92,193	$	8,948
Regulated natural gas and electric costs	23,886		21,573		2,313
Adjusted gross margin (1)	77,255		70,620		6,635
Operations & maintenance	29,362		26,489		2,873
Depreciation & amortization	13,035		13,140		(105)
Other taxes	5,567		5,150		417
Total operating expenses	47,964		44,779		3,185
Operating income	$	29,291	$	25,841	$	3,450

(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 2023 was $29.3 million, an increase of $3.5 million, or 13.4 percent, over the same period in 2022. Higher operating income reflects contributions from our Florida natural gas base rate proceeding, organic growth in our natural gas distribution businesses, incremental contributions associated with regulated infrastructure programs, and continued pipeline expansion projects. These increases were partially offset by changes in customer consumption due to the continued effects of warmer weather during the quarter. Operating expenses increased by $3.2 million compared to the prior year quarter related to employee costs driven by growth initiatives, the ongoing competitive labor market and higher benefits costs, higher facilities, maintenance and outside services costs and increased property taxes.

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

(in thousands)
Rate changes associated with the Florida natural gas base rate proceeding (1)	$	3,873
Natural gas growth including conversions (excluding service expansions)	1,844
Natural gas transmission service expansions	1,113
Increased adjusted gross margin from off-system natural gas capacity sales	637
Contributions from regulated infrastructure programs	395
Changes in customer consumption - primarily related to weather	(1,148)
Other variances	(79)
Quarter-over-quarter increase in adjusted gross margin**	$	6,635

(1) Includes adjusted gross margin contributions from permanent base rates that became effective in March 2023.

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

Rate Changes Associated with the Florida Natural Gas Base Rate Proceeding

In March 2023, we obtained a final rate order in connection with the Florida natural gas base rate proceeding with permanent rates effective on March 1, 2023. These permanent rates contributed additional adjusted gross margin of $3.9 million for the three months ended June 30, 2023. Please 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 $1.8 million from natural gas customer growth. Adjusted gross margin increased by $1.1 million in Florida and $0.7 million on the Delmarva Peninsula for the three months ended June 30, 2023, as compared to the same period in 2022, due primarily to residential customer growth of 4.0 percent and 5.5 percent in Florida and on the Delmarva Peninsula, respectively.

Natural Gas Transmission Service Expansions

We generated increased adjusted gross margin of $1.1 million for the three months ended June 30, 2023 from natural gas transmission service expansions including, Peninsula Pipeline's Wildlight, Lake Wales, Winter Haven, and Beachside projects, FPU natural gas' Clean Energy project and Aspire Energy Express' Guernsey pipeline expansion.

Contributions from Off-System Natural Gas Sales

We generated additional adjusted gross margin of $0.6 million related to off-system natural gas capacity sales for the three months ended June 30, 2023.

Contributions from Regulated Infrastructure Programs

Contributions from regulated infrastructure programs generated incremental adjusted gross margin of $0.4 million in the second quarter of 2023. The increase in adjusted gross margin was primarily related to continued investment in the Eastern Shore's capital surcharge program and FPU Electric's storm protection plan. Refer to Note 5, Rates and Other Regulatory Activities, in the condensed consolidated financial statements for additional information.

Changes in Customer Consumption

The continued effects of warmer weather in the second quarter of 2023 contributed to changes in weather-related consumption resulting in reduced adjusted gross margin of $1.1 million.

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Operating Expenses

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

(in thousands)
Increased payroll, benefits and other employee-related expenses	$	1,305
Increased facilities expenses, maintenance costs and outside services	682
Depreciation, amortization and property taxes	474
Increased costs related to credit and collections	345
Other variances	379
Quarter-over-quarter increase in operating expenses	$	3,185

For the six months ended June 30, 2023, compared to the six months ended June 30, 2022:

	Six Months Ended
	June 30,				Increase
	2023		2022		(Decrease)
(in thousands)
Revenue	$	243,411	$	220,084	$	23,327
Regulated natural gas and electric costs	79,174		67,016		12,158
Adjusted gross margin (1)	164,237		153,068		11,169
Operations & maintenance	59,698		55,621		4,077
Depreciation & amortization	25,987		26,225		(238)
Other taxes	11,636		10,683		953
Total operating expenses	97,321		92,529		4,792
Operating income	$	66,916	$	60,539	$	6,377

(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, 2023 was $66.9 million, an increase of $6.4 million, or 10.5 percent, over the same period in 2022. Higher operating income reflects contributions from our Florida natural gas base rate proceeding, organic growth in our natural gas distribution businesses, continued pipeline expansion projects and incremental contributions associated with regulated infrastructure programs. These increases were partially offset by changes in customer consumption due to significantly warmer weather during the first half of 2023. Operating expenses increased by $4.8 million compared to the prior year related to employee costs driven by growth initiatives, the ongoing competitive labor market and higher benefits costs, higher facilities, maintenance and outside services costs and increased property taxes.

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

(in thousands)
Rate changes associated with the Florida natural gas base rate proceeding (1)	$	7,970
Natural gas growth including conversions (excluding service expansions)	3,366
Natural gas transmission service expansions	1,594
Contributions from regulated infrastructure programs	1,193
Changes in customer consumption - primarily related to weather	(3,013)
Eastern Shore contracted rate adjustments	(285)
Other variances	344
Period-over-period increase in adjusted gross margin**	$	11,169

(1) Includes adjusted gross margin comprised of both interim rates and permanent base rates that became effective in March 2023.

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

Rate Changes Associated with the Florida Natural Gas Base Rate Proceeding

In August 2022, the Florida PSC approved interim rates starting in September 2022. In March 2023, we obtained a final rate order in connection with the Florida natural gas base rate proceeding with permanent rates effective on March 1, 2023. These interim and permanent rates contributed additional adjusted gross margin of $8.0 million. Please 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 $3.4 million from natural gas customer growth. Adjusted gross margin increased by $1.8 million in Florida and $1.6 million on the Delmarva Peninsula for the six months ended June 30, 2023, as compared to the same period in 2022, due primarily to residential customer growth of 4.2 percent and 5.7 percent in Florida and on the Delmarva Peninsula, respectively.

Natural Gas Transmission Service Expansions

We generated increased adjusted gross margin of $1.6 million for the six months ended June 30, 2023 from natural gas transmission service expansions including, Peninsula Pipeline's Wildlight, Lake Wales, Winter Haven, and Beachside projects, FPU natural gas' Clean Energy project and Aspire Energy Express' Guernsey pipeline expansion.

Contributions from Regulated Infrastructure Programs

Contributions from regulated infrastructure programs generated incremental adjusted gross margin of $1.2 million for the six months ended June 30, 2023. The increase in adjusted gross margin was primarily related to Eastern Shore's capital surcharge program, and FPU Electric's storm protection plan. Refer to Note 5, Rates and Other Regulatory Activities, in the condensed consolidated financial statements for additional information.

Changes in Customer Consumption

Significantly warmer weather experienced during the first half of 2023 contributed to changes in weather-related consumption resulting in reduced adjusted gross margin of $3.0 million for the six months ended June 30, 2023. The Delmarva Peninsula and Florida were warmer by approximately 20 percent and 31 percent, respectively, for the six months ended June 30, 2023 compared to the same period in 2022.

Eastern Shore Contracted Rate Adjustments

Adjustments to contracted rates charged to various Eastern Shore customers resulted in reduced adjusted gross margin of $0.3 million for the six months ended June 30, 2023 compared to the same period in 2022.

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)
Payroll, benefits and other employee-related expenses	$	1,598
Increased facilities expenses, maintenance costs and outside services	1,064
Depreciation, amortization and property tax costs due to new capital investments	893
Increased costs related to credit and collections	426
Other variances	811
Period-over-period increase in operating expenses	$	4,792

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Unregulated Energy Segment

For the quarter ended June 30, 2023, compared to the quarter ended June 30, 2022:

	Three Months Ended
	June 30,				Increase
	2023		2022		(Decrease)
(in thousands)
Revenue	$	40,751	$	53,463	$	(12,712)
Unregulated propane and natural gas costs	18,116		31,701		(13,585)
Adjusted gross margin (1)	22,635		21,762		873
Operations & maintenance	18,196		16,127		2,069
Depreciation & amortization	4,269		4,074		195
Other taxes	1,163		1,001		162
Total operating expenses	23,628		21,202		2,426
Operating Income (Loss)	$	(993)	$	560	$	(1,553)

(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 2023 experienced a reduction of $1.6 million compared to the same period in 2022. Adjusted gross margin in the Unregulated Energy segment during the second quarter was impacted by changes in customer consumption due to continued warmer weather in our Mid-Atlantic service territories and the conversion of propane customers to our natural gas distribution service. Additionally, we experienced increased operating expenses associated with higher employee costs driven by the continued competition in the current labor market and increased benefit costs, increased property taxes and higher costs related to facilities, maintenance, and outside services. These factors were partially offset by increased propane margins and fees and continued demand for CNG, RNG and LNG services.

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

(in thousands)
Propane Operations
Increased propane margins and service fees	$	1,512
Reduced customer consumption due to conversion of customers to our natural gas system	(591)
Propane customer consumption - primarily weather related	(381)
CNG/RNG/LNG Transportation and Infrastructure
Increased demand for CNG/RNG/LNG Services	478
Aspire Energy
Reduced customer consumption - primarily weather related	(45)
Other variances	(100)
Quarter-over-quarter increase in adjusted gross margin	$	873

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

Propane Operations

•Increased Propane Margins and Service Fees - Adjusted gross margin increased by $1.5 million for the three months ended June 30, 2023, mainly due to increased margins and customer service fees. 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.

•Reduced customer consumption due to conversion of customers to our natural gas system - Adjusted gross margin decreased by $0.6 million as more customers converted from propane to our natural gas distribution service.

•Propane customer consumption - Adjusted gross margin decreased by $0.4 million due to reduced customer consumption as weather mainly on the Delmarva Peninsula continued to remain significantly warmer relative to the

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prior year.

CNG/RNG/LNG Transportation and Infrastructure

•Increased demand for CNG/RNG/LNG services - Adjusted gross margin increased by $0.5 million during the second quarter of 2023 as compared to the same period in the prior year due to higher demand for CNG hold services and contributions from the Aspire Noble Road RNG project .

Aspire Energy

•Reduced Customer Consumption - Adjusted gross margin was reduced by less than $0.1 million due to reduced demand as weather in Ohio remained warmer compared to the same period in the prior year.

Operating Expenses

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

(in thousands)
Increased payroll, benefits and other employee-related expenses	$	1,908
Increased depreciation, amortization and property tax costs	311
Increased facilities expenses, maintenance costs and outside services	291
Other variances	(84)
Quarter-over-quarter increase in operating expenses	$	2,426

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For the six months ended June 30, 2023, compared to the six months ended June 30, 2022:

	Six Months Ended
	June 30,				Increase
	2023		2022		(Decrease)
(in thousands)
Revenue	$	123,916	$	154,754	$	(30,838)
Unregulated propane and natural gas costs	58,687		89,708		(31,021)
Adjusted gross margin (1)	65,229		65,046		183
Operations & maintenance	37,810		34,211		3,599
Depreciation & amortization	8,503		7,954		549
Other taxes	2,664		2,268		396
Total operating expenses	48,977		44,433		4,544
Operating Income	$	16,252	$	20,613	$	(4,361)

Operating results for the Unregulated Energy segment for the six months ended June 30, 2023 decreased by $4.4 million compared to the same period in 2022. Operating results during the first half of 2023 were impacted by changes in customer consumption due to significantly warmer weather in our Mid-Atlantic service territories as well as the conversion of propane customers to our natural gas distribution service. Additionally, we experienced increased operating expenses associated with higher employee related expenses driven by the continued competition in the current labor market and higher benefit costs, increased costs for facilities, maintenance, and outside services and higher property taxes. These factors were partially offset by increased propane margins and fees and continued demand for CNG, RNG and LNG services.

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

(in thousands)
Propane Operations
Propane customer consumption - primarily weather related	$	(4,924)
Increased propane margins and service fees	4,576
Decreased customer consumption due to conversion of customers to our natural gas system	(591)
CNG/RNG/LNG Transportation and Infrastructure
Increased demand for CNG/RNG/LNG Services	1,766
Aspire Energy
Reduced customer consumption - primarily weather related	(553)
Other variances	(91)
Period-over-period increase in adjusted gross margin	$	183

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

Propane Operations

•Propane customer consumption - Adjusted gross margin fell by $4.9 million as a result of reduced customer consumption driven by significantly warmer weather in our Mid-Atlantic and North Carolina service areas experienced primarily during the first quarter which continued to a lesser extent through the second quarter.

•Increased Propane Margins and Service Fees - Adjusted gross margin increased by $4.6 million for the six months ended June 30, 2023, mainly due to increased margins and customer service fees. Propane margins also increased due to gains associated 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.

•Reduced customer consumption due to conversion of customers to our natural gas system - Adjusted gross margin fell by $0.6 million as more customers converted from propane to our natural gas distribution service.

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CNG/RNG/LNG Transportation and Infrastructure

•Increased demand for CNG/RNG/LNG services - Adjusted gross margin increased by $1.8 million during the first half of the year as compared to the same period in the prior year due to higher demand for CNG hold services and contributions from the Aspire Noble Road RNG project.

Aspire Energy

•Reduced Customer Consumption - Adjusted gross margin was reduced by $0.6 million due to reduced demand as weather in Ohio was approximately 13 percent warmer over the same period in the prior year.

Operating Expenses

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

(in thousands)
Increased payroll, benefits and other employee-related expenses	$	2,733
Increased facilities expenses, maintenance costs and outside services	889
Increased depreciation, amortization and property tax costs	836
Other variances	86
Period-over-period increase in operating expenses	$	4,544

OTHER INCOME, NET

For the quarter ended June 30, 2023 compared to the quarter ended June 30, 2022

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, decreased by $1.8 million in the second quarter of 2023. This was primarily attributable to lower gains on asset sales, including the absence of a one-time gain of $1.9 million related to a building sale during the second quarter of 2022, and higher pension related expenses compared to the same period in 2022.

For the six months ended June 30, 2023 compared to the six months ended June 30, 2022

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, decreased by $2.4 million in the six months ended June 30, 2023. This was primarily attributable to lower gains on asset sales, including the absence of a one-time gain referred to above, and higher pension related expenses compared to the same period in 2022.

INTEREST CHARGES

For the quarter ended June 30, 2023 compared to the quarter ended June 30, 2022

Interest charges for the three months ended June 30, 2023 increased by $1.1 million, compared to the same period in 2022, attributable primarily to $0.9 million in interest expense as a result of a long-term debt placement in 2023 and $0.7 million in higher interest rates on outstanding borrowings under our Revolver. These factors were partially offset by higher capitalized interest of $0.4 million associated with growth projects. The weighted-average interest rate on our Revolver borrowings was 5.25 percent during the second quarter of 2023 compared to 1.52 percent during the prior-year period as a result of the Federal Reserve raising interest rates throughout 2022 and through the second quarter of 2023. 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, 2023 compared to the six months ended June 30, 2022

Interest charges for the six months ended June 30, 2023 increased by $3.0 million, compared to the same period in 2022, attributable to $2.6 million primarily related to higher interest rates on outstanding borrowings under our Revolver and $1.1 million in interest expense as a result of a long-term debt placement in 2022 and 2023. These factors were partially offset by higher capitalized interest of $0.8 million associated with growth projects. The weighted-average interest rate on our Revolver borrowings was 5.18 percent during the six months ended June 30, 2023 compared to 1.12 percent during the prior-year period as a result of the Federal Reserve raising interest rates throughout 2022 and during the six months ended June 30, 2023. Any additional increases in interest rates by the Federal Reserve would have a corresponding increase in the interest rates charged under our Revolver.

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INCOME TAXES

For the quarter ended June 30, 2023 compared to the quarter ended June 30, 2022

Income tax expense was $6.1 million for the quarter ended June 30, 2023, compared to $6.2 million for the quarter ended June 30, 2022. Our effective income tax rate was 27.4 percent and 26.6 percent, for the three months ended June 30, 2023 and 2022, respectively.

For the six months ended June 30, 2023 compared to the six months ended June 30, 2022

Income tax expense was $17.7 million for the six months ended June 30, 2023, compared to $19.7 million for the six months ended June 30, 2022. Our effective income tax rate was 25.2 percent and 26.7 percent, for the six months ended June 30, 2023 and 2022, respectively. Income tax expense for the six months ended June 30, 2023 includes a $1.3 million benefit in deferred tax expense resulting from a reduction in the Pennsylvania state income tax rate. Excluding this change, our effective income tax rate was 27.0 percent for the six months ended June 30, 2023.

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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 an 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 an 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 $91.9 million for the six months ended June 30, 2023. In the table below, we have provided the range of our forecasted capital expenditures for 2023:

	2023
(in thousands)	Low		High
Regulated Energy:
Natural gas distribution	$	89,000	$	100,000
Natural gas transmission	50,000		60,000
Electric distribution	13,000		15,000
Total Regulated Energy	152,000		175,000
Unregulated Energy:
Propane distribution	15,000		16,000
Energy transmission	8,000		9,000
Other unregulated energy	23,000		27,000
Total Unregulated Energy	46,000		52,000
Other:
Corporate and other businesses	2,000		3,000
Total Other	2,000		3,000
Total 2023 Forecasted Capital Expenditures	$	200,000	$	230,000

The 2023 forecast, excluding acquisitions, includes capital expenditures associated with the following: Pipeline expansions related to the Eastern Shore Southern Expansion project, the Florida Beachside Pipeline, the Wildlight pipeline expansion, other small pipeline expansion opportunities and continued distribution system expansions including the Wildlight development in Florida. Furthermore, the 2023 forecast includes continued expenditures under, the capital cost surcharge program as well as information technology system enhancements, and other strategic initiatives and investments.

The capital expenditure projection is subject to continuous review and modification. 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 and other factors discussed in Item 1A. Risk Factors in our 2022 Annual Report on Form 10-K. 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, 2023 and December 31, 2022:

	June 30, 2023				December 31, 2022
(in thousands)
Long-term debt, net of current maturities	$	645,742	43	%	$	578,388	41	%
Stockholders’ equity	864,228		57	%	832,801		59	%
Total capitalization, excluding short-term debt	$	1,509,970	100	%	$	1,411,189	100	%
	June 30, 2023				December 31, 2022
(in thousands)
Short-term debt	$	95,807	6	%	$	202,157	12	%
Long-term debt, including current maturities	665,736		41	%	599,871		37	%
Stockholders’ equity	864,228		53	%	832,801		51	%
Total capitalization, including short-term debt	$	1,625,771	100	%	$	1,634,829	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 53 percent as of June 30, 2023. 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.

During the first half of 2023, there were no issuances under the DRIP. In 2022, we issued less than 0.1 million shares at an average price per share of $136.26 and received net proceeds of $4.5 million under the DRIP. 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. In February 2023, we amended our Shelf Agreements with Prudential and MetLife. The amended agreements expanded the total borrowing capacity and extended the term of the agreements for an additional three years from the effective date. The following table summarizes our Shelf Agreements at June 30, 2023:

(in thousands)	Total Borrowing Capacity		Less: Amount of Debt Issued		Less: Unfunded Commitments		Remaining Borrowing Capacity
Shelf Agreement (1)
Prudential Shelf Agreement	$	405,000	$	(300,000)	$	—	$	105,000
MetLife Shelf Agreement	200,000		(50,000)		—		150,000
Total Shelf Agreements as of June 30, 2023	$	605,000	$	(350,000)	$	—	$	255,000

(1) The Prudential and MetLife Shelf Agreements both expire in February 2026.

The Uncollateralized Senior 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, 2023 and December 31, 2022, we had $95.8 million and $202.2 million, respectively, of short-term borrowings outstanding at a weighted average interest rate of 5.33 percent and 5.04 percent respectively.

In August 2022, we amended both tranches of the Revolver, which now bear interest using SOFR as the benchmark interest rate, plus a 10-basis point SOFR adjustment. In addition, the 364-day tranche was extended through August 2023. We expect to renew the 364-day tranche of the Revolver upon its current expiration. As part of these amendments, the parties agreed to eliminate the previous covenant capping the aggregate investments limit at $150.0 million where we maintain an ownership interest less than 50 percent. Additionally, the 364 day tranche of the facility now offers a reduced interest margin similar to the five-year tranche for amounts borrowed in connection with new sustainable investments. All other terms and conditions remained unchanged. Borrowings outstanding under the sustainable investment sublimit of the 364-day tranche amounted to $9.4 million at June 30, 2023.

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, 2023, we are in compliance with this covenant.

The 364-day tranche of the Revolver expires in August 2023 and the five-year tranche expires in August 2026, both of which are available to fund our short-term cash needs to meet seasonal working capital requirements and to temporarily fund portions of our capital expenditures. Borrowings under both tranches of the Revolver are subject to a pricing grid, including the commitment fee and the interest rate charged based upon our total indebtedness to total capitalization ratio for the prior quarter. As of June 30, 2023, the pricing under the 364-day tranche of the Revolver included an unused commitment fee of 9 basis points and maintains an interest rate of 70 basis points over SOFR plus a 10 basis point SOFR adjustment. As of June 30, 2023, the pricing under the five-year tranche of the Revolver included an unused commitment fee of 9 basis points and an interest rate of 95 basis points over SOFR plus a 10 basis point SOFR adjustment.

Our total available credit under the Revolver at June 30, 2023 was $298.3 million. As of June 30, 2023, we had issued $5.9 million in letters of credit to various counterparties under the Revolver. These letters of credit are not included in the outstanding short-term borrowings and we do not anticipate that they will be drawn upon by the counterparties. The letters of credit reduce the available borrowings under the Revolver.

For additional information on interest rate swaps related to our short-term borrowings, see Note 12, Derivative Instruments.

Long-Term Debt

On March 14, 2023 we issued 5.43 percent Senior Notes due March 14, 2038 in the aggregate principal amount of $80.0 million. We used the proceeds received from the issuances of the Senior Notes to reduce short-term borrowings under our Revolver credit facility and to fund capital expenditures. These Senior Notes have similar covenants and default provisions as our other Senior Notes, and have an annual principal payment beginning in the sixth year after the issuance.

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Cash Flows

The following table provides a summary of our operating, investing and financing cash flows for the six months ended June 30, 2023 and 2022:

	Six Months Ended
	June 30,
(in thousands)	2023		2022
Net cash provided by (used in):
Operating activities	$	148,983	$	123,795
Investing activities	(88,991)		(64,167)
Financing activities	(62,027)		(60,418)
Net (decrease) increase in cash and cash equivalents	(2,035)		(790)
Cash and cash equivalents—beginning of period	6,204		4,976
Cash and cash equivalents—end of period	$	4,169	$	4,186

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 amortization, changes in deferred income taxes, share-based compensation expense 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, 2023, net cash provided by operating activities was $149.0 million. Operating cash flows were primarily impacted by the following:

•Net income, adjusted for non-cash adjustments, provided a $93.7 million source of cash;

•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 $28.8 million source of cash;

•Other working capital changes, impacted primarily by a reduction in net receivables and propane inventory levels, resulted in a $19.6 million source of cash; and

•An increased level of deferred taxes associated with incremental tax depreciation from growth investments resulted in a source of cash of $5.7 million.

Cash Flows Used in Investing Activities

Net cash used in investing activities totaled $89.0 million during the six months ended June 30, 2023, largely driven by $90.3 million for new capital expenditures.

Cash Flows Used in Financing Activities

Net cash used in financing activities totaled $62.0 million during the six months ended June 30, 2023 and included the following:

•Net repayments under the Revolver of $104.2 million;

•A use of cash of $19.0 million for dividend payments in 2023; partially offset by

•A net increase in long-term debt borrowings of $65.8 million to permanently finance investment in growth initiatives.

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, 2023 was $20.0 million. The aggregate amount guaranteed related to our subsidiaries at June 30, 2023 was $14.2 million, with the guarantees expiring on various dates through May 2024. In addition, the Board has authorized us to issue specific purpose corporate guarantees. The amount of specific purpose guarantees outstanding at June 30, 2023 was $4.0 million.

As of June 30, 2023, we have issued letters of credit totaling approximately $5.9 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 April

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2024. We have not drawn upon these letters of credit as of June 30, 2023 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 2022 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, 2023:

	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)	$	47,157	$	—	$	—	$	—	$	47,157
Total	$	47,157	$	—	$	—	$	—	$	47,157

(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.

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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 14, Long-Term Debt, and Note 15, 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 8.7 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, 2022 to June 30, 2023:

(in thousands)	Balance at December 31, 2022		(Decrease) in Fair Market Value		Less Amounts Settled		Balance at June 30, 2023
Sharp	$	1,507	$	(3,169)	$	174	$	(1,488)

There were no changes in methods of valuations during the six months ended June 30, 2023.

The following is a summary of fair market value of financial derivatives as of June 30, 2023, by method of valuation and by maturity for each fiscal year period.

(in thousands)	2023		2024		2025		2026		Total Fair Value
Price based on Mont Belvieu - Sharp	$	(491)	$	(847)	$	(133)	$	(17)	$	(1,488)

59

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 12, 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, 2023. 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, 2023.

Changes in Internal Control over Financial Reporting

During the quarter ended June 30, 2023, 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.

60

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, 2022, 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 

Company Purchases of Equity Securities

Share repurchases during the three months ended June 30, 2023 were as follows:

	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, 2023 through April 30, 2023 (1)	450	$	130.12	—	—
May 1, 2023 through May 31, 2023	—	—		—	—
June 1, 2023 through June 30, 2023	—	—		—	—
Total	450	$	130.12	—	—

(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 16, Employee Benefit Plans,” in our latest Annual Report on Form 10-K for the year ended December 31, 2022.

(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

During the three months ended June 30, 2023, no director or officer of the Company adopted or terminated a "Rule 10b5-1 trading arrangement" or "non-Rule 10b5-1 trading arrangement," as each term is defined in Item 408(a) of Regulation S-K.

61

Item 6.     Exhibits

3.1	Amended and Restated Bylaws of Chesapeake Utilities Corporation, effective May 3, 2023, are incorporated herein by reference to Exhibit 3.1 of our Current Report on Form 8-K, filed May 3, 2023, File No. 001-11590.
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

62

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, 2023

63

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, 2023 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, 2023

/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, 2023 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, 2023

/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, 2023, 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, 2023

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, 2023, 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, 2023

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.

XML

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2023	Jul. 28, 2023
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2023
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		17,796,741
Entity Central Index Key	0000019745
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q2
Amendment Flag	false

XML

Condensed Consolidated Statements of Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Operating Revenues
Regulated Energy	$ 101,141	$ 92,193	$ 243,411	$ 220,084
Unregulated Energy and other	34,452	47,277	110,311	142,266
Total Operating Revenues	135,593	139,470	353,722	362,350
Operating Expenses
Natural gas and electric costs	23,886	21,573	79,174	67,016
Propane and natural gas costs	11,907	25,543	45,208	77,279
Operations	42,163	38,002	86,930	80,796
Maintenance	5,258	4,507	10,362	8,772
Depreciation and amortization	17,303	17,216	34,486	34,193
Other taxes	6,730	6,160	14,301	12,960
Total Operating Expenses	107,247	113,001	270,461	281,016
Total operating income	28,346	26,469	83,261	81,334
Other income, net	831	2,584	1,107	3,498
Interest charges	6,964	5,825	14,196	11,164
Income Before Income Taxes	22,213	23,228	70,172	73,668
Income Taxes	6,080	6,177	17,695	19,683
Net Income	$ 16,133	$ 17,051	$ 52,477	$ 53,985
Weighted Average Common Shares Outstanding:
Basic (shares)	17,794,320	17,730,833	17,777,203	17,704,592
Diluted (shares)	17,852,024	17,809,871	17,841,954	17,785,629
Earnings Per Share of Common Stock:
Income (Loss) from Continuing Operations, Per Basic Share	$ 0.91	$ 0.96	$ 2.95	$ 3.05
Basic (in dollars per share)	0.91	0.96	2.95	3.05
Earnings Per Share, Diluted [Abstract]
Income (Loss) from Continuing Operations, Per Diluted Share	0.90	0.96	2.94	3.04
Diluted (in dollars per share)	$ 0.90	$ 0.96	$ 2.94	$ 3.04

XML

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Statement of Comprehensive Income [Abstract]
Net Income	$ 16,133	$ 17,051	$ 52,477	$ 53,985
Reclassifications of amortization of prior service credit and actuarial loss, net of tax of $3 and $6, $5 and $13, respectively	12	18	21	35
Other comprehensive income (loss)	(1,076)	(480)	(1,680)	67
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	15,057	16,571	50,797	54,052
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax			(247)	(2,139)
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax			247	2,139
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax			(1,433)	2,206
Reclassifications of amortization of prior service credit and actuarial loss, net of tax of $3 and $6, $5 and $13, respectively	12	18	21	35
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent
Statement of Comprehensive Income [Abstract]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(94)	0	(142)	0
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	94	0	142	0
Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Statement of Comprehensive Income [Abstract]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	313	(205)	(126)	(2,174)
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(313)	205	126	2,174
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(2,065)	(293)	(2,045)	2,206
Accumulated (Gain) Loss from Interest Rate Swap Cash Flows Hedges [Member]
Statement of Comprehensive Income [Abstract]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax			(142)	0
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax			142	0
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	$ 758	$ 0	$ 612	$ 0

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Condensed Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Statement of Other Comprehensive Income [Abstract]
Amortization of prior service cost, tax	$ 3	$ 6	$ 5	$ 13
Net gain, tax	0	0	0	0
Unrealized (loss)/gain on commodity contract cash flow hedges, tax	(784)	(110)	(775)	826
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Interest Rate Swaps During Period, Tax	267	0	213	0
Accumulated Other Comprehensive Income (Loss) [Line Items]
Amortization of prior service cost, tax	3	6	5	13
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, Tax	0	0	0	0
Unrealized (loss)/gain on commodity contract cash flow hedges, tax	(784)	(110)	(775)	826
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Interest Rate Swaps During Period, Tax	267	0	213	0
Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Statement of Other Comprehensive Income [Abstract]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	119	(78)	(48)	(830)
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	119	(78)	(48)	(830)
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent
Statement of Other Comprehensive Income [Abstract]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	(33)	0	(50)	0
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	$ (33)	$ 0	$ (50)	$ 0

XML

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2023		Dec. 31, 2022
Property, Plant and Equipment
Regulated Energy	$ 1,868,763		$ 1,802,999
Unregulated Energy	402,352		393,215
Other businesses and eliminations	29,213		29,890
Total property, plant and equipment	2,300,328		2,226,104
Less: Accumulated depreciation and amortization	(489,724)		(462,926)
Property, Plant and Equipment, Net	1,871,182		1,810,473
Current Assets
Cash and cash equivalents	4,169		6,204
Trade and other receivables	45,399		62,881
Accounts Receivable, Allowance for Credit Loss, Current	(2,692)		(2,877)
Accounts Receivable, before Allowance for Credit Loss, Current	48,091		65,758
Accrued revenue	15,875		29,206
Propane inventory, at average cost	6,492		9,365
Other inventory, at average cost	17,873		16,896
Regulatory assets	26,343		41,439
Storage gas prepayments	3,208		6,364
Income taxes receivable	1,276		2,541
Prepaid expenses	12,496		15,865
Derivative assets, at fair value	1,704		2,787
Other current assets	1,934		428
Total current assets	136,769		193,976
Deferred Charges and Other Assets
Goodwill	46,213		46,213
Other intangible assets, net	16,965		17,859
Investments, at fair value	11,693		10,576
Operating Lease, Right-of-Use Asset	13,432		14,421
Regulatory assets	95,985		108,214
Receivables and other deferred charges	12,111		12,323
Total deferred charges and other assets	196,539		210,588
Total Assets	2,204,490		2,215,037
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)	8,662		8,635
Additional paid-in capital	380,830		380,036
Retained earnings	477,795		445,509
Accumulated other comprehensive income (loss)	(3,059)		(1,379)
Deferred compensation obligation	9,001		7,060
Treasury stock	(9,001)		(7,060)
Total stockholders’ equity	864,228	[1]	832,801
Total capitalization	1,509,970		1,411,189
Current Liabilities
Less: current maturities	19,994		21,483
Short-term borrowing	95,807		202,157
Accounts payable	44,173		61,496
Customer deposits and refunds	38,468		37,152
Accrued interest	3,429		3,349
Dividends payable	10,500		9,492
Accrued compensation	9,772		14,660
Regulatory liabilities	12,894		5,031
Derivative liabilities, at fair value	2,178		585
Other accrued liabilities	17,942		13,618
Total current liabilities	255,157		369,023
Deferred Credits and Other Liabilities
Deferred income taxes	261,215		256,167
Regulatory liabilities	144,275		142,989
Environmental liabilities	2,512		3,272
Other pension and benefit costs	17,890		16,965
Operating Lease, Liability, Noncurrent	11,585		12,392
Deferred investment tax credits and other liabilities	1,412		1,410
Total deferred credits and other liabilities	439,363		434,825
Environmental and other commitments and contingencies (Notes 5 and 6)
Total Capitalization and Liabilities	2,204,490		2,215,037
Other businesses and eliminations	29,213		29,890
Property, Plant and Equipment, Gross	2,300,328		2,226,104
Construction Work in Progress	60,578		47,295
Property, Plant and Equipment, Net	1,871,182		1,810,473
Trade and other receivables	45,399		62,881
Income taxes receivable	1,276		2,541
Other current assets	1,934		428
Assets, Current	136,769		193,976
Receivables and other deferred charges	12,111		12,323
Deferred Charges And Other Assets	196,539		210,588
Total identifiable assets	2,204,490		2,215,037
Regulated Energy	1,868,763		1,802,999
Unregulated Energy	402,352		393,215
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	489,724		462,926
Cash and cash equivalents	4,169		6,204
Accounts Receivable, before Allowance for Credit Loss, Current	48,091		65,758
Allowance for uncollectible accounts	2,692		2,877
Accrued revenue	15,875		29,206
Propane inventory, at average cost	6,492		9,365
Other inventory, at average cost	17,873		16,896
Regulatory assets	26,343		41,439
Storage gas prepayments	3,208		6,364
Prepaid expenses	12,496		15,865
Derivative assets, at fair value	1,704		2,787
Goodwill	46,213		46,213
Other intangible assets, net	16,965		17,859
Investments, at fair value	11,693		10,576
Operating Lease, Right-of-Use Asset	13,432		14,421
Regulatory assets	95,985		108,214
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	864,228	[1]	832,801
Capitalization, Long-term Debt and Equity	1,509,970		1,411,189
Accounts payable	44,173		61,496
Other accrued liabilities	17,942		13,618
Liabilities, Current	255,157		369,023
Regulatory liabilities	144,275		142,989
Operating Lease, Liability, Noncurrent	11,585		12,392
Deferred investment tax credits and other liabilities	1,412		1,410
Deferred Credits and Other Liabilities	439,363		434,825
Environmental and other commitments and contingencies (Notes 5 and 6)
Liabilities and Equity	2,204,490		2,215,037
Common stock, par value $0.4867 per share (authorized 50,000,000 shares)	8,662		8,635
Additional paid-in capital	380,830		380,036
Retained earnings	477,795		445,509
Accumulated other comprehensive income (loss)	(3,059)		(1,379)
Deferred compensation obligation	9,001		7,060
Treasury Stock, Value	9,001		7,060
Long-term Debt and Capital Lease Obligations, Net of Current Maturities	645,742		578,388
Less: current maturities	19,994		21,483
Short-term borrowing	95,807		202,157
Customer deposits and refunds	38,468		37,152
Accrued interest	3,429		3,349
Dividends payable	10,500		9,492
Accrued compensation	9,772		14,660
Regulatory liabilities	12,894		5,031
Energy Marketing Contract Liabilities, Current	2,178		585
Deferred income taxes	261,215		256,167
Environmental liabilities	2,512		3,272
Other pension and benefit costs	17,890		16,965
Energy Marketing Contracts Assets, Noncurrent	140		982
Energy Marketing Contract Liabilities, Noncurrent	$ 474		$ 1,630

[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, 2023	Dec. 31, 2022
Statement of Financial Position [Abstract]
Allowance for uncollectible accounts	$ 2,692	$ 2,877
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, 2023	Jun. 30, 2022
Operating Activities
Net Income	$ 52,477	$ 53,985
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	34,486	34,193
Depreciation and accretion included in other costs	5,714	5,781
Deferred income taxes	5,695	11,434
Realized gain on commodity contracts and sale of assets	(1,032)	(6,980)
Unrealized (gain) loss on investments/commodity contracts	(1,131)	1,956
Employee benefits and compensation	218	(520)
Share-based compensation	2,919	3,555
Changes in assets and liabilities:
Accounts receivable and accrued revenue	30,812	24,766
Propane inventory, storage gas and other inventory	5,052	270
Regulatory assets/liabilities, net	28,796	(6,405)
Prepaid expenses and other current assets	2,953	10,326
Accounts payable and other accrued liabilities	(18,273)	(2,274)
Income taxes receivable/payable	1,265	5,107
Customer deposits and refunds	1,316	(1,999)
Accrued compensation	(5,061)	(6,266)
Other assets and liabilities, net	2,777	(3,134)
Net cash provided by operating activities	148,983	123,795
Investing Activities
Property, plant and equipment expenditures	(90,265)	(65,087)
Proceeds from sale of assets	2,034	3,367
Environmental expenditures	760	441
Net cash used in investing activities	(88,991)	(64,167)
Financing Activities
Common stock dividends	(19,009)	(16,575)
Issuance of stock under the Dividend Reinvestment Plan, net of offering fees	(14)	4,259
Tax withholding payments related to net settled stock compensation	(2,455)	(2,838)
Change in cash overdrafts due to outstanding checks	(2,157)	(1,202)
Net repayments under line of credit agreements	(104,194)	(83,424)
Proceeds from long-term debt, net of offering fees	79,840	49,890
Repayment of long-term debt	(14,038)	(10,528)
Net cash used in financing activities	(62,027)	(60,418)
Net Increase (Decrease) in Cash and Cash Equivalents	(2,035)	(790)
Cash and Cash Equivalents—Beginning of Period	6,204	4,976
Cash and Cash Equivalents—End of Period	4,169	4,186
Payments to Acquire Businesses, Gross	$ 0	$ (2,006)

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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, Preferred	Treasury Stock, Common
Increase (Decrease) in Stockholders' Equity [Roll Forward]
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				17,655,410
Beginning Balances at Dec. 31, 2021		$ 774,130		$ 8,593		$ 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
Stock Issued During The Period Value Retirement Savings Plan And Dividend Reinvestment Plan				$ 17		4,613
Share-based compensation (shares)				45,538
Share-based compensation and tax benefit		4,630		$ 22		1,091
Treasury stock activities		1,113					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
Stock Issued During The Period Value Retirement Savings Plan And 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)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares Held In Trust For Deferred Compensation Plan		110,835
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		108,143
Common Stock, Dividends, Per Share, Declared		$ 1.125
Beginning Balances (shares) at Dec. 31, 2022	[1],[2]			17,741,418
Beginning Balances at Dec. 31, 2022		$ 832,801		$ 8,635	[1],[2]	380,036	445,509	(1,379)	7,060		(7,060)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		52,477					52,477
Other comprehensive income (loss)		(1,680)						(1,680)
Other Comprehensive Income (Loss), Net of Tax		(1,680)
Dividend declared		(20,191)					(20,191)
Retirement savings plan and dividend reinvestment plan (shares)				0
Stock Issued During The Period Value Retirement Savings Plan And Dividend Reinvestment Plan		(19)		$ 0		(19)
Share-based compensation (shares)	[3],[4]			55,323
Share-based compensation and tax benefit	[3],[4]	840		$ 27		813
Treasury stock activities							0		1,941		(1,941)
Ending Balances (shares) at Jun. 30, 2023	[1]			17,796,741
Ending Balances at Jun. 30, 2023		$ 864,228	[1]	$ 8,662	[1]	380,830	477,795	(3,059)	9,001		(9,001)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation		19,859
Common Stock, Dividends, Per Share, Declared		$ 0.5900
Beginning Balances (shares) at Mar. 31, 2023				17,789,856
Beginning Balances at Mar. 31, 2023		$ 858,588		$ 8,659		379,703	472,209	(1,983)	8,816		(8,816)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		16,133					16,133
Other comprehensive income (loss)		(1,076)						(1,076)
Other Comprehensive Income (Loss), Net of Tax		(1,076)
Dividend declared		(10,547)					(10,547)
Retirement savings plan and dividend reinvestment plan (shares)				0
Stock Issued During The Period Value Retirement Savings Plan And Dividend Reinvestment Plan		(8)		$ 0		(8)
Share-based compensation (shares)				6,885
Share-based compensation and tax benefit		1,138		$ 3		1,135
Treasury stock activities							0		185		(185)
Ending Balances (shares) at Jun. 30, 2023	[1]			17,796,741
Ending Balances at Jun. 30, 2023		$ 864,228	[1]	$ 8,662	[1]	$ 380,830	$ 477,795	$ (3,059)	$ 9,001		$ (9,001)
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		110,277

[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 110,277, 108,143, 110,835, and 116,238 shares at June 30, 2023, December 31, 2022, June 30, 2022 and December 31, 2021, respectively, held in a Rabbi Trust related to our Non-Qualified Deferred Compensation Plan.(3)Can include shares issued under the Retirement Savings Plan, DRIP and ATM equity issuances.

[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, 2023 and 2022, we withheld 19,859 and 21,832 shares, respectively, for employee taxes.

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Condensed Consolidated Statements of Stockholders' Equity (Parenthetical) (Unaudited) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022	Dec. 31, 2021
Statement of Stockholders' Equity [Abstract]
Dividend declared (in dollars per share)	$ 0.5900	$ 0.5350	$ 1.125	$ 1.015
Deferred compensation plan held Rabbi Trust (shares)	110,277	110,835	110,277	110,835	108,143	116,238
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)			19,859	21,832

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Summary of Accounting Policies

6 Months Ended

Jun. 30, 2023

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, 2022. 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

There are no pending or recently effective accounting standards which have had, or are expected to have, a material impact to our consolidated financial statements or disclosures.

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Calculation of Earnings Per Share

6 Months Ended

Jun. 30, 2023

Earnings Per Share [Abstract]

Calculation of Earnings Per Share

Calculation of Earnings Per Share

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
(in thousands, except shares and per share data)
Calculation of Basic Earnings Per Share:
Net Income	$	16,133	$	17,051	$	52,477	$	53,985
Weighted average shares outstanding	17,794,320		17,730,833		17,777,203		17,704,592
Basic Earnings Per Share	$	0.91	$	0.96	$	2.95	$	3.05
Calculation of Diluted Earnings Per Share:
Net Income	$	16,133	$	17,051	$	52,477	$	53,985
Reconciliation of Denominator:
Weighted shares outstanding—Basic	17,794,320		17,730,833		17,777,203		17,704,592
Effect of dilutive securities—Share-based compensation	57,704		79,038		64,751		81,037
Adjusted denominator—Diluted	17,852,024		17,809,871		17,841,954		17,785,629
Diluted Earnings Per Share	$	0.90	$	0.96	$	2.94	$	3.04

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Acquisitions and Divestitures (Notes)

6 Months Ended

Jun. 30, 2023

Discontinued Operations and Disposal Groups [Abstract]

Business Combination Disclosure [Text Block]

3.     Acquisitions

Acquisition of Davenport Energy

In June 2022, Sharp acquired the propane operating assets of Davenport Energy's Siler City, North Carolina propane division for approximately $2.0 million. Through this acquisition, we expanded our operating footprint further into

North Carolina, where customers are served by Sharp Energy’s Diversified Energy division. Sharp added approximately 850 customers, along with 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. All amounts initially recorded in connection with this acquisition are now final as a result of the conclusion of the measurement period; no further adjustments were necessary. The financial results associated with this acquisition are included within our propane distribution operations within our Unregulated Energy segment.

Acquisition of Planet Found Energy Development

In October 2022, we acquired Planet Found Energy Development, LLC ("Planet Found") for $9.5 million. In connection with this acquisition, we recorded a $0.9 million liability which is subject to the seller's adherence to various provisions contained in the purchase agreement through the first anniversary of the transaction closing. We accounted for this acquisition as a business combination within our Unregulated Energy segment beginning in the fourth quarter of 2022. Planet Found's farm scale anaerobic digestion pilot system and technology produces biogas from 1,200 tons of poultry litter annually, which can be used to create renewable energy in the form of electricity or upgraded to renewable natural gas. The transaction will accelerate our efforts in converting poultry waste to renewable, sustainable energy while simultaneously improving the local environments in our service territories. The operating revenues and operating income of Planet Found were not material to our consolidated results for the three and six months ended June 30, 2023.

In connection with this acquisition, we recorded $4.4 million in intangible assets associated primarily with intellectual property and non-compete agreements, $4.0 million in property plant and equipment, $1.1 million in goodwill, and less than $0.1 million in working capital, 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.

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Rates and Other Regulatory Activities

6 Months Ended

Jun. 30, 2023

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

Refer to the additional details below pertaining to the Customer Information System Regulatory Asset Petition and 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 FERC approved the Section 7(f) request on August 29, 2022. The project will increase the reliability of the existing distribution system in those areas while also expanding infrastructure to serve new customers. Construction was completed during the second quarter of 2023.

Florida

Wildlight Expansion: In August 2022, Peninsula Pipeline and FPU filed a joint petition with the Florida PSC for approval of its Transportation Service Agreement associated with the Wildlight planned community located in Nassau County, Florida. The project enables us to meet the significant growing demand for service in Yulee, Florida. The agreement will enable us to construct the project during the build-out of the community, and charge the reservation rate as each phase of the project goes into service. Construction of the pipeline facilities will occur in two separate phases. Phase one consists of three extensions with associated facilities, and a gas injection interconnect with associated facilities. Phase two will consist of two additional pipeline extensions. The various phases of the project commenced in the first quarter of 2023, with construction on the overall project continuing through 2025. The petition was approved by the Florida PSC in November 2022.

Natural Gas Rate Case: In May 2022, our natural gas distribution businesses in Florida filed a consolidated natural gas rate case with the Florida PSC. The application included a request for the following: (i) permanent rate relief of approximately $24.1 million, effective January 1, 2023, (ii) a depreciation study also submitted with filing; (iii) authorization to make certain changes to tariffs to include the consolidation of rates and rate structure across the businesses and to unify the Florida natural gas distribution businesses under FPU; (iv) authorization to retain the acquisition adjustment recorded at the time of the FPU merger in our revenue requirement; and (v) authorization to establish an environmental remediation surcharge for the purposes of addressing future expected remediation costs for FPU MGP sites. In August 2022, interim rates were approved by the Florida PSC in the amount of approximately $7.7 million on an annualized basis, effective for all meter readings in September 2022. The discovery process and subsequent hearings were concluded during the fourth quarter of 2022 and briefs were submitted during the same quarter of 2022. In January 2023, the Florida PSC approved the application for consolidation and permanent rate relief of approximately $17.2 million on an annual basis. Actual rates in connection with the rate relief were approved by the Florida PSC in February 2023 with an effective date of March 1, 2023.

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 constructed 11.3 miles of pipeline from its existing pipeline in the Sebastian, Florida area, traveling east under the Intercoastal Waterway and southward on the barrier island. The project was placed in-service during April 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 FPU, for an additional 2,400 Dt/d of firm service in the St. Cloud, Florida area. As part of this agreement, Peninsula Pipeline will construct a pipeline extension and regulator station for FPU. The extension will be used to support new incremental load due to growth in the area, including providing service, most immediately, to the residential development, Twin Lakes. The expansion will also improve reliability and provide operational benefits to FPU's existing distribution system in the area, supporting future growth. The petition was approved by the Florida PSC in October 2022. We expect this expansion to be placed into service during the third quarter of 2023.

Storm Protection Plan: In 2020, the Florida PSC implemented the Storm Protection Plan ("SPP") and Storm Protection Plan Cost Recovery Clause ("SPPCRC") rules, which require electric utilities to petition the Florida PSC for approval of a Transmission and Distribution Storm Protection Plan that covers the utility’s immediate 10-year planning period with updates to the plan at least every 3 years. The SPPCRC rules allow the utility to file for recovery of associated costs for the SPP. Our Florida electric distribution operation’s SPP plan was filed during the first quarter of 2022 and approved in the fourth quarter of 2022 with modifications, by the Florida PSC. Rates associated with this initiative were effective in January 2023.

Lake Wales Pipeline Acquisition: In February 2023, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with FPU for an additional 9,000 Dt/d of firm service in the Lake Wales, Florida area. The Commission approved the petition in April 2023. Approval of the agreement allowed Peninsula Pipeline to complete the acquisition of the existing pipeline in May 2023 which is being utilized to serve our current natural gas customers as well as enable us to serve new customers.

GUARD: In February 2023, FPU filed a petition with the Florida PSC for approval of the GUARD program. GUARD is a ten-year program to enhance the safety, reliability, and accessibility of portions of our natural gas distribution system. We have identified various categories of projects to be included in GUARD, which include the relocation of mains and service lines located in rear easements and other difficult to access areas to the front of the street, the replacement of problematic distribution mains, service lines, and M&R equipment and system reliability projects. In August 2023, the Florida PSC approved the GUARD program, with the exception of reliability projects with an approximate value of $10 million. The remainder of the program was approved as filed, which included $205 million of capital expenditures projected to be spent over a 10-year period.

Newberry Expansion: In April 2023, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with FPU for an additional 8,000 Dt/d of firm service in the Newberry, Florida area. In July 2023, the Florida PSC approved the company's recommendation to proceed with this project. Peninsula Pipeline will construct a pipeline extension which will be used by FPU to support the development of a natural gas distribution system to provide gas service to the City of Newberry.

Amendment to Escambia County Agreement: In April of 2023, Peninsula Pipeline filed a petition with the Florida PSC for approval of an amendment to an existing contract with FPU. This amendment will allow Peninsula Pipeline to construct an additional delivery point on a pipeline located in Escambia County. The additional delivery point comes at the request of an FPU customer and will be used to enhance natural gas service in the area. Currently, the petition is under review by the Florida PSC. A decision is expected in the third quarter of 2023.

Florida Electric Depreciation Study: The Florida PSC requires electric utilities to file a depreciation study every four years to reevaluate and set depreciation rates for the utility's plant assets. In June 2023, FPU filed a petition with the Florida PSC for approval of it’s proposed depreciation rates. If approved, new rates will become effective retroactively on January 1, 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 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 its pipeline system. The project obtained FERC approval in December 2022, and is under construction, estimated to go into service in the fourth quarter of 2023.

Capital Cost Surcharge: In December 2022, Eastern Shore submitted a filing with the FERC regarding a capital cost surcharge to recover capital costs associated with the replacement of existing Eastern Shore facilities as a result of mandated highway relocation projects as well as compliance with a Pipeline and Hazardous Materials Safety Administration ("PHMSA") regulation. The capital cost surcharge mechanism was approved in Eastern Shore’s last rate case. In conjunction with the filing of this surcharge, a cumulative adjustment to the existing surcharge to reflect additional depreciation was included. The FERC issued an order approving the surcharge as filed on December 19, 2022. The combined revised surcharge became effective January 1, 2023.

Various Jurisdictional Activity Related to the Joint Customer Information System Project

In July 2022, we filed a joint petition for our natural gas divisions in Maryland (Maryland Division, Sandpiper, and Elkton Gas) for the approval to establish a regulatory asset for non-capitalizable expenses related to the initial development and implementation of our new Customer Information System ("CIS") system. The petition was approved by the Maryland PSC in August 2022. A similar petition for our Florida Regulated Energy businesses was filed during the same time frame and was initially denied. The Florida PSC subsequently approved capitalization of these expenses. Additionally, our Delaware Division has the ability to defer these costs as a regulatory asset. We have completed the system selection process and the CIS implementation began during the first quarter of 2023.

COVID-19 Impact

In March 2020, the CDC declared a national emergency due to the rapidly growing outbreak of COVID-19. In response to this declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the country imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to slow the spread of the illness. These restrictions significantly impacted economic conditions in the United States in 2020 and continued to impact economic conditions, to a lesser extent, through 2021 and 2022. Chesapeake Utilities is considered an “essential business,” which allowed us to continue operational activities and construction projects with appropriate safety precautions and personal protective equipment, while being mindful of the social distancing restrictions that were in place.

In response to the COVID-19 pandemic and related restrictions, we experienced reduced consumption of energy largely in the commercial and industrial sectors, higher bad debt expenses and incremental expenses associated with COVID-19, including expenditures associated with personal protective equipment and premium pay for field personnel. The additional operating expenses we incurred supported the ongoing delivery of our essential services during the height of the pandemic. In April and May 2020, we were authorized by the Maryland and Delaware PSCs, respectively, to record regulatory assets for COVID-19 related costs which offered us the ability to seek recovery of those costs. In July 2021, the Florida PSC issued an order that approved incremental expenses we incurred due to COVID-19. The order allowed us to establish a regulatory asset in a total amount of $2.1 million as of June 30, 2021 for natural gas and electric distribution operations. The regulatory asset is being amortized over two years and is recovered through the Purchased Gas Adjustment and Swing Service mechanisms for our natural gas distribution businesses and through the Fuel Purchased Power Cost Recovery clause for our electric division. As of June 30, 2023 and December 31, 2022, our total COVID-19 regulatory asset balance was $0.7 million and $1.2 million, respectively.

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, 2023 and December 31, 2022:

	Amount (in thousands)
Operation and Regulatory Jurisdiction	June 30, 2023	December 31, 2022	Status
Eastern Shore (FERC)	$34,190	$34,190	Will be addressed in Eastern Shore's next rate case filing.
Chesapeake Delaware natural gas division (Delaware PSC)	$12,134	$12,230	PSC approved amortization of ADIT in January 2019.
Chesapeake Maryland natural gas division (Maryland PSC)	$3,644	$3,703	PSC approved amortization of ADIT in May 2018.
Sandpiper Energy (Maryland PSC)	$3,542	$3,597	PSC approved amortization of ADIT in May 2018.
Florida natural gas distribution (Florida PSC) (1)	$26,894	$27,179	PSC issued order authorizing amortization and retention of net ADIT liability by the Company in February 2019.
FPU electric division (Florida PSC)	$4,876	$4,993	In January 2019, PSC issued order approving amortization of ADIT through purchased power cost recovery, storm reserve and rates.
Elkton Gas (Maryland PSC)	$1,043	$1,059	PSC approved amortization of ADIT in March 2018.

(1) In accordance with the Florida PSC approval of our natural gas base rate proceeding, effective March 1, 2023, our natural gas distribution businesses in Florida have been consolidated for rate-making purposes and amounts above are now being presented on a consolidated basis consistent with the final rate order.

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Environmental Commitments and Contingencies

6 Months Ended

Jun. 30, 2023

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, 2023 and December 31, 2022, we had approximately $3.4 million and $4.3 million, respectively, in environmental liabilities related to the former MGP sites. As of June 30, 2023 and December 31, 2022, we have cumulative regulatory assets of $0.5 million and $0.8 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 for and has recovered, through a combination of insurance and customer rates, $14.0 million of its environmental costs related to its MGP sites as of June 30, 2023.

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 later in 2023.

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Other Commitments and Contingencies

6 Months Ended

Jun. 30, 2023

Commitments and Contingencies Disclosure [Abstract]

Other Commitments and Contingencies

Other Commitments and Contingencies

Natural Gas, Electric and Propane Supply

In March 2023, 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, 2023 and expire in March 2026.

Our Florida natural gas distribution operations and Eight Flags generation facility 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.

Additionally, our Florida natural gas distribution operations have 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, 2023, 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, 2023 was $20.0 million. The aggregate amount guaranteed related to our subsidiaries at June 30, 2023 was approximately $14.2 million with the guarantees expiring on various dates through May 2024. In addition, the Board has authorized us to issue specific purpose corporate guarantees. The amount of specific purpose guarantees outstanding at June 30, 2023 was $4.0 million.

As of June 30, 2023, we have issued letters of credit totaling approximately $5.9 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 April 2024 and to date, none have been used. 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, 2023

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 distribution operations, mobile compressed natural gas distribution and pipeline solutions operations, and project development activities related to our sustainable energy initiatives. Also included in this segment are other unregulated energy services, such as energy-related merchandise sales and heating, ventilation and air conditioning, plumbing and electrical services. These operations are unregulated as to their rates and services.

The remainder of our operations are presented as “Other businesses and eliminations,” which consists of unregulated subsidiaries that own real estate leased to Chesapeake Utilities, as well as certain corporate costs not allocated to other operations.

The following table presents financial information about our reportable segments:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
(in thousands)
Operating Revenues, Unaffiliated Customers
Regulated Energy	$	100,657	$	91,830	$	242,279	$	215,888
Unregulated Energy	34,936		47,640		111,443		146,462
Total operating revenues, unaffiliated customers	$	135,593	$	139,470	$	353,722	$	362,350
Intersegment Revenues (1)
Regulated Energy	$	484	$	363	$	1,132	$	4,196
Unregulated Energy	5,816		5,823		12,473		7,819
Other businesses	45		85		91		691
Total intersegment revenues	$	6,345	$	6,271	$	13,696	$	12,706
Operating Income
Regulated Energy	$	29,291	$	25,841	$	66,916	$	60,539
Unregulated Energy	(993)		560		16,252		20,613
Other businesses and eliminations	48		68		93		182
Operating income	28,346		26,469		83,261		81,334
Other income, net	831		2,584		1,107		3,498
Interest charges	6,964		5,825		14,196		11,164
Income Before Income Taxes	22,213		23,228		70,172		73,668
Income Taxes	6,080		6,177		17,695		19,683
Net Income	$	16,133	$	17,051	$	52,477	$	53,985

    

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

(in thousands)	June 30, 2023		December 31, 2022
Identifiable Assets
Regulated Energy segment	$	1,707,605	$	1,716,255
Unregulated Energy segment	448,217		463,239
Other businesses and eliminations	48,668		35,543
Total Identifiable Assets	$	2,204,490	$	2,215,037

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

6 Months Ended

Jun. 30, 2023

Equity [Abstract]

Accumulated Other Comprehensive Income (Loss)

Stockholders' Equity

Common Stock Issuances

We maintain an effective shelf registration statement with the SEC for the issuance of shares under our DRIP and ATM programs. 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 2022, we issued less than 0.1 million shares at an average price per share of $136.26 and received net proceeds of $4.5 million under the DRIP. In the first six months of 2023, there were no issuances under the DRIP. Our most recent ATM equity program, which allowed us to issue and sell shares of our common stock up to an aggregate offering price of $75.0 million, expired in June 2023. We expect to execute a new ATM during the third quarter of 2023.

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

Accumulated Other Comprehensive Income (Loss)

Defined benefit pension and postretirement plan items, unrealized gains (losses) of our propane swap agreements 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 income (loss) components as of June 30, 2023 and 2022. 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		Total
(in thousands)
As of December 31, 2022	$	(2,506)	$	1,092	$	35	$	(1,379)
Other comprehensive income (loss) before reclassifications	—		(2,045)		612		(1,433)
Amounts reclassified from accumulated other comprehensive income (loss)	21		(126)		(142)		(247)
Net current-period other comprehensive income (loss)	21		(2,171)		470		(1,680)
As of June 30, 2023	$	(2,485)	$	(1,079)	$	505	$	(3,059)

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 prior-period other comprehensive income	35		32		—		67
As of June 30, 2022	$	(3,233)	$	4,603	$	—	$	1,370

Deferred gains or losses for our commodity contracts and interest rate swap cash flow hedges are recognized in earnings upon settlement. Amortization of the net loss related to the defined benefit pension plan and postretirement plans is included in the computation of net periodic costs (benefits). See Note 10, Employee Benefit Plans, for additional details. Gains on commodity contracts classified as cash flow hedges related to our propane swaps are included in the effects of gains and losses from derivative instruments. See Note 12, Derivative Instruments, for additional details.

Amortization of defined benefit pension and postretirement plan items are included in other expense, net, gains and losses on propane swap agreement contracts are included in revenue and unregulated propane and natural gas costs, and 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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Share-Based Compensation

6 Months Ended

Jun. 30, 2023

Share-Based Payment Arrangement [Abstract]

Share-Based Compensation

Share-Based Compensation

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

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, 2023 and 2022:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
(in thousands)
Awards to key employees	$	284	$	1,122	$	2,440	$	3,101
Awards to non-employee directors	227		220		479		454
Total compensation expense	511		1,342		2,919		3,555
Less: tax benefit	(132)		(346)		(754)		(917)
Share-based compensation amounts included in net income	$	379	$	996	$	2,165	$	2,638

Officers and Key Employees

Our Compensation Committee is authorized to grant our key employees the right to receive awards of shares of our common stock, contingent upon the achievement of established performance goals and subject to SEC transfer restrictions once awarded. Our President and CEO has the right to issue awards of shares of our common stock, to other officers of the Company, contingent upon various performance goals and subject to SEC transfer restrictions.

We currently have several outstanding multi-year performance plans, which are based upon the successful achievement of long-term goals, growth and financial results and comprise both market-based and performance-based conditions and targets. The fair value per share, tied to a performance-based condition or target, is equal to the market price per share on the grant date. For the market-based conditions, we used the Monte Carlo valuation to estimate the fair value of each share granted.

The table below presents the summary of the stock activity for awards to key employees for the six months ended June 30, 2023: 

	Number of Shares	Weighted Average Fair Value
Outstanding—December 31, 2022	204,149	$	103.17
Granted	80,752	$	128.01
Vested	(68,302)	$	91.59
Expired	(2,053)	$	94.64
Outstanding—June 30, 2023	214,546	$	116.04

During the six months ended June 30, 2023, we granted awards of 80,752 shares of common stock to key employees under the SICP, including awards granted in February 2023 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, 2025. 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 2023, 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 March 2023 for the performance period ended December 31, 2022. We paid the balance of such awarded shares to each such executive officer and remitted cash equivalent to the withheld shares to the appropriate taxing authorities. We withheld 19,859 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 $2.5 million.

At June 30, 2023, the aggregate intrinsic value of the SICP awards granted to key employees was approximately $25.5 million. At June 30, 2023, there was approximately $8.7 million of unrecognized compensation cost related to these awards, which will be recognized through 2025.

Non-employee Directors

Shares granted to non-employee directors are issued in advance of the directors’ service periods and are fully vested as of the grant date. We record a deferred expense equal to the fair value of the shares issued and amortize the expense equally over a service period of one year or less.

Our directors receive an annual retainer of shares of common stock under the SICP for services rendered through the subsequent Annual Meeting of Shareholders. Accordingly, our directors that served on the Board as of May 2023 each received 765 shares of common stock, respectively, with a weighted average fair value of $124.12 per share.

At June 30, 2023, there was approximately $0.8 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 2024.

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Derivative Instruments

6 Months Ended

Jun. 30, 2023

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, 2023, our natural gas and electric distribution operations did not have any outstanding derivative contracts.

Volume of Derivative Activity

As of June 30, 2023, 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	21.3	Cash flow hedges	June 2026
Sharp	Propane (gallons)	Sales	3.2	Cash flow hedges	December 2023

Sharp entered into futures and swap agreements to mitigate the risk of fluctuations in wholesale propane index prices associated with the propane volumes 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 2023 through June 2026) 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 flow 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 unrealized losses of approximately $1.1 million from accumulated other comprehensive income (loss) related to our commodity cash flow hedges to earnings during the next 12-month period ended June 30, 2024.

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 September 2022, we entered into an interest rate swap with a notional amount of $50.0 million through September 2025, with pricing of 3.98 percent.

Prior to August 2022, our short-term borrowing was based on the 30-day LIBOR rate. In August 2022, we amended and restated our revolver and transitioned the benchmark interest rate to the 30-day SOFR as a result of the expiration of LIBOR. Our prior interest rate swaps were cash settled monthly as the counter-party paid us the 30-day LIBOR rate less the fixed rate. Our interest rate swap is cash settled monthly as the counter-party pays us the 30-day SOFR rate less the fixed rate.

We designate and account for interest rate swaps as cash flow hedges. Accordingly, unrealized gains and losses associated with the interest rate swap are recorded as a component of accumulated other comprehensive income (loss). When the interest rate swap settles, the realized gain or loss is recorded in the income statement and is recognized as a component of interest charges.

Broker Margin

Futures exchanges have contract specific margin requirements that require the posting of cash or cash equivalents relating to traded contracts. Margin requirements consist of initial margin that is posted upon the initiation of a position, maintenance margin that is usually expressed as a percent of initial margin, and variation margin that fluctuates based on the daily mark-to-market relative to maintenance margin requirements. We currently maintain a broker margin account for Sharp which was classified within our Other Current Assets on the consolidated balance sheet with a balance of $1.4 million as of June 30, 2023. At December 31, 2022, $0.1 million was classified in Other Current Liabilities on the consolidated balance sheet.

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, 2023 and December 31, 2022, are as follows: 

	Derivative Assets
		Fair Value As Of
(in thousands)	Balance Sheet Location	June 30, 2023		December 31, 2022
Derivatives designated as cash flow hedges
Propane swap agreements	Derivative assets, at fair value	$	1,068	$	3,317
Interest rate swap agreements	Derivative assets, at fair value	776		452
Total Derivative Assets (1)		$	1,844	$	3,769

 (1) Derivative assets, at fair value include $1.7 million and $2.8 million in current assets in the condensed consolidated balance sheet at June 30, 2023 and December 31, 2022, respectively, with the remainder of the balance classified as long-term.

	Derivative Liabilities
		Fair Value As Of
(in thousands)	Balance Sheet Location	June 30, 2023		December 31, 2022
Derivatives designated as cash flow hedges
Propane swap agreements	Derivative liabilities, at fair value	$	2,556	$	1,810
Interest rate swap agreements	Derivative liabilities, at fair value	96		405
Total Derivative Liabilities (1)		$	2,652	$	2,215

(1) Derivative liabilities, at fair value include $2.2 million and $0.6 million in current liabilities in the condensed consolidated balance sheet at June 30, 2023 and December 31, 2022, respectively, with the remainder of the balance classified as long-term.

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	2023		2022		2023		2022
Derivatives not designated as hedging instruments
Propane swap agreements	Unregulated propane and natural gas costs	$	—	$	—	$	—	$	56
Derivatives designated as cash flow hedges
Propane swap agreements	Revenues	—		—		733		(826)
Propane swap agreements	Unregulated propane and natural gas costs	(432)		283		(559)		3,830
Propane swap agreements	Other comprehensive income (loss)	(2,417)		(686)		(2,994)		28
Interest rate swap agreements	Interest expense	127		—		192		—
Interest rate swap agreements	Other comprehensive income (loss)	898		—		633		—
Total		$	(1,824)	$	(403)	$	(1,995)	$	3,088

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Fair Value of Financial Instruments

6 Months Ended

Jun. 30, 2023

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, 2023 and December 31, 2022:

			Fair Value Measurements Using:
As of June 30, 2023	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	$	23	$	23	$	—	$	—
Investments—guaranteed income fund	1,756		—		—		1,756
Investments—mutual funds and other	9,914		9,914		—		—
Total investments	11,693		9,937		—		1,756
Derivative assets	1,844		—		1,844		—
Total assets	$	13,537	$	9,937	$	1,844	$	1,756
Liabilities:
Derivative liabilities	$	2,652	$	—	$	2,652	$	—

			Fair Value Measurements Using:
As of December 31, 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	1,853		—		—		1,853
Investments—mutual funds and other	8,699		8,699		—		—
Total investments	10,576		8,723		—		1,853
Derivative assets	3,769		—		3,769		—
Total assets	$	14,345	$	8,723	$	3,769	$	1,853
Liabilities:
Derivative liabilities	$	2,215	$	—	$	2,215	$	—

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, 2023 and 2022:     

	Six months ended June 30,
	2023		2022
(in thousands)
Beginning Balance	$	1,853	$	2,036
Purchases and adjustments	—		132
Transfers	—		—
Distribution	(114)		(83)
Investment income	17		17
Ending Balance	$	1,756	$	2,102

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

At June 30, 2023, 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 2 measurement).

At June 30, 2023, long-term debt, which includes current maturities but excludes debt issuance costs, had a carrying value of approximately $666.8 million, compared to the estimated fair value of $573.3 million. At December 31, 2022, long-term debt, which includes the current maturities but excludes debt issuance costs, had a carrying value of approximately $600.8 million, compared to a fair value of approximately $505.0 million. The fair value was calculated using a discounted cash flow methodology that incorporates a market interest rate based on published corporate borrowing rates for debt instruments with similar terms and average maturities, and with adjustments for duration, optionality, and risk profile. The valuation technique used to estimate the fair value of long-term debt would be considered a Level 2 measurement.

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Long-Term Debt

6 Months Ended

Jun. 30, 2023

Debt Disclosure [Abstract]

Long-Term Debt

Long-Term Debt

Our outstanding long-term debt is shown below: 

	June 30,		December 31,
(in thousands)	2023		2022
Uncollateralized senior notes:
5.93% note, due October 31, 2023	$	1,500	$	3,000
5.68% note, due June 30, 2026	8,700		11,600
6.43% note, due May 2, 2028	3,500		4,200
3.73% note, due December 16, 2028	12,000		12,000
3.88% note, due May 15, 2029	30,000		35,000
3.25% note, due April 30, 2032	63,000		66,500
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		50,000
5.43% notes Due March 14, 2038	80,000		—
Equipment security note
2.46% note, due September 24, 2031	8,078		8,517
Less: debt issuance costs	(1,042)		(946)
Total long-term debt	665,736		599,871
Less: current maturities	(19,994)		(21,483)
Total long-term debt, net of current maturities	$	645,742	$	578,388

    

Note Purchase Agreements

On March 14, 2023 we issued 5.43 percent Senior Notes due March 14, 2038 in the aggregate principal amount of $80.0 million and used the proceeds received from the issuances of the Senior Notes to reduce short-term borrowings under our Revolver credit facility and to fund capital expenditures. These Senior Notes have similar covenants and default provisions as our other Senior Notes, and have an annual principal payment beginning in the sixth year after the issuance.

Shelf Agreements

We have entered into Shelf Agreements with Prudential and MetLife, whom are under no obligation to purchase any unsecured debt. In February 2023, we amended our Shelf Agreements with Prudential and MetLife. The amended agreements expand the total borrowing capacity and extend the term of the agreements for an additional three years from the effective dates. The following table summarizes the current available capacity under our Shelf Agreements at June 30, 2023:

(in thousands)	Total Borrowing Capacity		Less: Amount of Debt Issued		Less: Unfunded Commitments		Remaining Borrowing Capacity
Shelf Agreements (1)
Prudential Shelf Agreement	$	405,000	$	(300,000)	$	—	$	105,000
MetLife Shelf Agreement	200,000		(50,000)		—		150,000
Total Shelf Agreements as of June 30, 2023	$	605,000	$	(350,000)	$	—	$	255,000

(1) The Prudential and MetLife Shelf Agreements both expire in February 2026.

The Uncollateralized Senior 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, 2023

Short-Term Borrowing [Abstract]

Short-term Debt [Text Block]

15.    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, 2023 and December 31, 2022, we had $95.8 million and $202.2 million, respectively, of short-term borrowings outstanding at a weighted average interest rate of 5.33 percent and 5.04 percent, respectively.

In August 2022, we amended both tranches of our Revolver, which now bear interest using SOFR as the benchmark interest rate, plus a 10-basis point SOFR adjustment. In addition, the 364-day tranche was extended through August 2023. We expect to renew the 364-day tranche of the Revolver upon its current expiration. As part of these amendments, the parties agreed to eliminate the previous covenant capping the aggregate investments limit at $150.0 million where we maintain an ownership interest less than 50 percent. Additionally the 364-day tranche of the facility now offers a reduced interest margin similar to the five-year tranche for amounts borrowed in connection with new sustainable investments. All other terms and conditions remain unchanged. Borrowings outstanding under the sustainable investment sublimit of the 364-day tranche amounted to $9.4 million at June 30, 2023.

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, 2023, we are in compliance with this covenant.

The 364-day tranche of the Revolver expires in August 2023 and the five-year tranche expires in August 2026, both of which are available to fund our short-term cash needs to meet seasonal working capital requirements and to temporarily fund portions of our capital expenditures. Borrowings under both tranches of the Revolver are subject to a pricing grid, including the commitment fee and the interest rate charged based upon our total indebtedness to total capitalization ratio for the prior quarter. As of June 30, 2023, the pricing under the 364-day tranche of the Revolver included an unused commitment fee of 9 basis points and maintains an interest rate of 70 basis points over SOFR plus a 10 basis point SOFR adjustment. As of June 30, 2023, the pricing under the five-year tranche of the Revolver included an unused commitment fee of 9 basis points and an interest rate of 95 basis points over SOFR plus a 10 basis point SOFR adjustment.

Our total available credit under the Revolver at June 30, 2023 was $298.3 million. As of June 30, 2023, we had issued $5.9 million in letters of credit to various counterparties under the Revolver. These letters of credit are not included in the outstanding short-term borrowings and we do not anticipate that they will be drawn upon by the counterparties. The letters of credit reduce the available borrowings under the Revolver.

For additional information on interest rate swaps related to our short-term borrowings, see Note 12, Derivative Instruments.

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Leases Leases

6 Months Ended

Jun. 30, 2023

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. 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, 2023, 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, 2023, 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	2023	2022	2023	2022
Operating lease cost (1)	Operations expense	$780	$726	$1,568	$1,377

(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, 2023 and December 31, 2022:

(in thousands)	Balance sheet classification	June 30, 2023		December 31, 2022
Assets
Operating lease assets	Operating lease right-of-use assets	$	13,432	$	14,421
Liabilities
Current
Operating lease liabilities	Other accrued liabilities	$	2,373	$	2,552
Noncurrent
Operating lease liabilities	Operating lease - liabilities	11,585		12,392
Total lease liabilities		$	13,958	$	14,944

The following table presents our weighted-average remaining lease terms and weighted-average discount rates for our operating leases at June 30, 2023 and December 31, 2022:

	June 30, 2023		December 31, 2022
Weighted-average remaining lease term (in years)
Operating leases	8.37		8.54
Weighted-average discount rate
Operating leases	3.5	%	3.4	%

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, 2023 and 2022:

	Six Months Ended
	June 30,
(in thousands)	2023		2022
Operating cash flows from operating leases	$	1,465	$	1,428

The following table presents the future undiscounted maturities of our operating and financing leases at June 30, 2023 and for each of the next five years and thereafter:

(in thousands)	Operating Leases (1)
Remainder of 2023	$	1,419
2024	2,629
2025	2,263
2026	1,734
2027	1,571
2028	1,192
Thereafter	5,243
Total lease payments	16,051
Less: Interest	(2,093)
Present value of lease liabilities	$	13,958

    (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, 2023

Accounting Policies [Abstract]

Basis of Presentation

Basis of Presentation

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

The accompanying unaudited condensed consolidated financial statements have been prepared in compliance with the rules and regulations of the SEC and GAAP. In accordance with these rules and regulations, certain information and disclosures normally required for audited financial statements have been condensed or omitted. These financial statements should be read in conjunction with the consolidated financial statements and notes thereto, included in our latest Annual Report on Form 10-K for the year ended December 31, 2022. 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

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Calculation of Earnings Per Share (Tables)

6 Months Ended

Jun. 30, 2023

Earnings Per Share [Abstract]

Calculation of Basic and Diluted Earnings Per Share

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
(in thousands, except shares and per share data)
Calculation of Basic Earnings Per Share:
Net Income	$	16,133	$	17,051	$	52,477	$	53,985
Weighted average shares outstanding	17,794,320		17,730,833		17,777,203		17,704,592
Basic Earnings Per Share	$	0.91	$	0.96	$	2.95	$	3.05
Calculation of Diluted Earnings Per Share:
Net Income	$	16,133	$	17,051	$	52,477	$	53,985
Reconciliation of Denominator:
Weighted shares outstanding—Basic	17,794,320		17,730,833		17,777,203		17,704,592
Effect of dilutive securities—Share-based compensation	57,704		79,038		64,751		81,037
Adjusted denominator—Diluted	17,852,024		17,809,871		17,841,954		17,785,629
Diluted Earnings Per Share	$	0.90	$	0.96	$	2.94	$	3.04

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Revenue Recognition (Tables)

6 Months Ended

Jun. 30, 2023

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, 2023 and 2022:

	Three Months Ended June 30, 2023								Three Months Ended June 30, 2022
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total		Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Energy distribution
Delaware natural gas division	$	14,109	$	—	$	—	$	14,109	$	13,086	$	—	$	—	$	13,086
Florida natural gas distribution (1)	40,766		—		—		40,766		35,436		—		—		35,436
FPU electric distribution	23,034		—		—		23,034		20,305		—		—		20,305
Maryland natural gas division	4,622		—		—		4,622		4,372		—		—		4,372
Sandpiper natural gas/propane operations	4,079		—		—		4,079		4,248		—		—		4,248
Elkton Gas	1,303		—		—		1,303		1,705		—		—		1,705
Total energy distribution	87,913		—		—		87,913		79,152		—		—		79,152
Energy transmission
Aspire Energy	—		5,726		—		5,726		—		10,808		—		10,808
Aspire Energy Express	369		—		—		369		369		—		—		369
Eastern Shore	19,632		—		—		19,632		18,875		—		—		18,875
Peninsula Pipeline	7,593		—		—		7,593		6,777		—		—		6,777
Total energy transmission	27,594		5,726		—		33,320		26,021		10,808		—		36,829
Energy generation
Eight Flags	—		4,532		—		4,532		—		5,916		—		5,916
Propane operations
Propane delivery operations	—		27,315		—		27,315		—		34,469		—		34,469
Compressed Natural Gas Services
Marlin Gas Services	—		3,238		—		3,238		—		2,380		—		2,380
Other and eliminations
Eliminations	(14,366)		(60)		(6,344)		(20,770)		(12,980)		(110)		(6,271)		(19,361)
Other	—		—		45		45		—		—		85		85
Total other and eliminations	(14,366)		(60)		(6,299)		(20,725)		(12,980)		(110)		(6,186)		(19,276)
Total operating revenues (2)	$	101,141	$	40,751	$	(6,299)	$	135,593	$	92,193	$	53,463	$	(6,186)	$	139,470

(1) In accordance with the Florida PSC approval of our natural gas base rate proceeding, effective March 1, 2023, 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”) have been consolidated for rate-making purposes and amounts above are now being presented on a consolidated basis consistent with the final rate order.

(2) Total operating revenues for the three months ended June 30, 2023 include other revenue (revenues from sources other than contracts with customers) of $0.2 million and $0.1 million for our Regulated and Unregulated Energy segments, respectively and $(0.1) million and $0.1 million for our Regulated and Unregulated Energy segments, respectively, for the three months ended June 30, 2022. 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, 2023 and 2022:

	Six Months Ended June 30, 2023								Six Months Ended June 30, 2022
(in thousands)	Regulated Energy		Unregulated Energy		Other and Eliminations		Total		Regulated Energy		Unregulated Energy		Other and Eliminations		Total
Energy distribution
Delaware natural gas division	$	51,016	$	—	$	—	$	51,016	$	47,568	$	—	$	—	$	47,568
Florida natural gas distribution (1)	87,124		—		—		87,124		75,722		—		—		75,722
FPU electric distribution	45,771		—		—		45,771		39,394		—		—		39,394
Maryland natural gas division	16,884		—		—		16,884		14,836		—		—		14,836
Sandpiper natural gas/propane operations	11,161		—		—		11,161		11,885		—		—		11,885
Elkton Gas	5,444		—		—		5,444		5,071		—		—		5,071
Total energy distribution	217,400		—		—		217,400		194,476		—		—		194,476
Energy transmission
Aspire Energy	—		19,680		—		19,680		—		28,844		—		28,844
Aspire Energy Express	733		—		—		733		632		—		—		632
Eastern Shore	40,302		—		—		40,302		39,196		—		—		39,196
Peninsula Pipeline	14,504		—		—		14,504		13,549		—		—		13,549
Total energy transmission	55,539		19,680		—		75,219		53,377		28,844		—		82,221
Energy generation
Eight Flags	—		9,832		—		9,832		—		11,455		—		11,455
Propane operations
Propane delivery operations	—		87,295		—		87,295		—		110,075		—		110,075
Compressed Natural Gas Services
Marlin Gas Services	—		7,238		—		7,238		—		4,589		—		4,589
Other and eliminations
Eliminations	(29,528)		(129)		(13,696)		(43,353)		(27,769)		(207)		(12,706)		(40,682)
Other	—		—		91		91		—		—		216		216
Total other and eliminations	(29,528)		(129)		(13,605)		(43,262)		(27,769)		(207)		(12,490)		(40,466)
Total operating revenues (2)	$	243,411	$	123,916	$	(13,605)	$	353,722	$	220,084	$	154,756	$	(12,490)	$	362,350

(1) In accordance with the Florida PSC approval of our natural gas base rate proceeding, effective March 1, 2023, 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”) have been consolidated for rate-making purposes and amounts above are now being presented on a consolidated basis consistent with the final rate order.

(2) Total operating revenues for the six months ended June 30, 2023 include other revenue (revenues from sources other than contracts with customers) of $0.8 million and $0.2 million for our Regulated and Unregulated Energy segments, respectively and $0.1 million and $0.2 million for our Regulated and Unregulated Energy segments, respectively, for the six months ended June 30, 2022. 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, 2023 and December 31, 2022 were as follows:

	Trade Receivables		Contract Assets (Current)		Contract Assets (Non-current)		Contract Liabilities (Current)
(in thousands)
Balance at 12/31/2022	$	61,687	$	18	$	4,321	$	983
Balance at 6/30/2023	41,140		18		3,787		594
Decrease	$	(20,547)	$	—	$	(534)	$	(389)

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

Revenue for these businesses for the remaining performance obligations, at June 30, 2023, are expected to be recognized as follows:

(in thousands)	2023		2024		2025		2026		2027		2028		2029 and thereafter
Eastern Shore and Peninsula Pipeline	$	19,613	$	37,006	$	30,613	$	27,138	$	24,163	$	23,398	$	188,498
Natural gas distribution operations	3,967		7,744		7,297		7,066		6,470		5,154		28,371
FPU electric distribution	326		652		275		275		275		275		—
Total revenue contracts with remaining performance obligations	$	23,906	$	45,402	$	38,185	$	34,479	$	30,908	$	28,827	$	216,869

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

6 Months Ended

Jun. 30, 2023

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, 2023 and December 31, 2022:

	Amount (in thousands)
Operation and Regulatory Jurisdiction	June 30, 2023	December 31, 2022	Status
Eastern Shore (FERC)	$34,190	$34,190	Will be addressed in Eastern Shore's next rate case filing.
Chesapeake Delaware natural gas division (Delaware PSC)	$12,134	$12,230	PSC approved amortization of ADIT in January 2019.
Chesapeake Maryland natural gas division (Maryland PSC)	$3,644	$3,703	PSC approved amortization of ADIT in May 2018.
Sandpiper Energy (Maryland PSC)	$3,542	$3,597	PSC approved amortization of ADIT in May 2018.
Florida natural gas distribution (Florida PSC) (1)	$26,894	$27,179	PSC issued order authorizing amortization and retention of net ADIT liability by the Company in February 2019.
FPU electric division (Florida PSC)	$4,876	$4,993	In January 2019, PSC issued order approving amortization of ADIT through purchased power cost recovery, storm reserve and rates.
Elkton Gas (Maryland PSC)	$1,043	$1,059	PSC approved amortization of ADIT in March 2018.

(1) In accordance with the Florida PSC approval of our natural gas base rate proceeding, effective March 1, 2023, our natural gas distribution businesses in Florida have been consolidated for rate-making purposes and amounts above are now being presented on a consolidated basis consistent with the final rate order.

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Segment Information (Tables)

6 Months Ended

Jun. 30, 2023

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,
	2023		2022		2023		2022
(in thousands)
Operating Revenues, Unaffiliated Customers
Regulated Energy	$	100,657	$	91,830	$	242,279	$	215,888
Unregulated Energy	34,936		47,640		111,443		146,462
Total operating revenues, unaffiliated customers	$	135,593	$	139,470	$	353,722	$	362,350
Intersegment Revenues (1)
Regulated Energy	$	484	$	363	$	1,132	$	4,196
Unregulated Energy	5,816		5,823		12,473		7,819
Other businesses	45		85		91		691
Total intersegment revenues	$	6,345	$	6,271	$	13,696	$	12,706
Operating Income
Regulated Energy	$	29,291	$	25,841	$	66,916	$	60,539
Unregulated Energy	(993)		560		16,252		20,613
Other businesses and eliminations	48		68		93		182
Operating income	28,346		26,469		83,261		81,334
Other income, net	831		2,584		1,107		3,498
Interest charges	6,964		5,825		14,196		11,164
Income Before Income Taxes	22,213		23,228		70,172		73,668
Income Taxes	6,080		6,177		17,695		19,683
Net Income	$	16,133	$	17,051	$	52,477	$	53,985

    

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

(in thousands)	June 30, 2023		December 31, 2022
Identifiable Assets
Regulated Energy segment	$	1,707,605	$	1,716,255
Unregulated Energy segment	448,217		463,239
Other businesses and eliminations	48,668		35,543
Total Identifiable Assets	$	2,204,490	$	2,215,037

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

6 Months Ended

Jun. 30, 2023

Equity [Abstract]

Changes in Accumulated Other Comprehensive Loss

	Defined Benefit		Commodity		Interest Rate
	Pension and		Contracts		Swap
	Postretirement		Cash Flow		Cash Flow
	Plan Items		Hedges		Hedges		Total
(in thousands)
As of December 31, 2022	$	(2,506)	$	1,092	$	35	$	(1,379)
Other comprehensive income (loss) before reclassifications	—		(2,045)		612		(1,433)
Amounts reclassified from accumulated other comprehensive income (loss)	21		(126)		(142)		(247)
Net current-period other comprehensive income (loss)	21		(2,171)		470		(1,680)
As of June 30, 2023	$	(2,485)	$	(1,079)	$	505	$	(3,059)

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 prior-period other comprehensive income	35		32		—		67
As of June 30, 2022	$	(3,233)	$	4,603	$	—	$	1,370

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Employee Benefit Plans (Tables)

6 Months Ended

Jun. 30, 2023

Retirement Benefits [Abstract]

Schedule of Net Benefit Costs [Table Text Block]

Net periodic benefit costs for the FPU Pension Plan for the three and six months ended June 30, 2023 and 2022 is set forth in the following table:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
FPU Pension Plan	2023		2022		2023		2022
(in thousands)
Interest cost	$	633	$	449	$	1,266	$	898
Expected return on plan assets	(668)		(857)		(1,336)		(1,714)
Amortization of net (gain) loss	110		124		220		248
Total periodic cost (benefit)	$	75	$	(284)	$	150	$	(568)

Amounts Included in Regulatory asset and AOCI [Table Text Block]

The following table presents the amounts included in the regulatory asset and accumulated other comprehensive income (loss) that were recognized as components of the FPU Pension Plan's net periodic benefit cost during the three and six months ended June 30, 2023 and 2022: 

	Three Months Ended				Six Months Ended
	June 30,				June 30,
FPU Pension Plan	2023		2022		2023		2022
(in thousands)
Recognized from accumulated other comprehensive (income) loss (1)	$	21	$	24	$	42	$	48
Recognized from regulatory asset	89		100		178		200
Total net loss in net periodic benefit cost	$	110	$	124	$	220	$	248

(1) See Note 9, Stockholders' Equity.

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Share-Based Compensation (Tables)

6 Months Ended

Jun. 30, 2023

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, 2023 and 2022:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
(in thousands)
Awards to key employees	$	284	$	1,122	$	2,440	$	3,101
Awards to non-employee directors	227		220		479		454
Total compensation expense	511		1,342		2,919		3,555
Less: tax benefit	(132)		(346)		(754)		(917)
Share-based compensation amounts included in net income	$	379	$	996	$	2,165	$	2,638

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, 2023: 

	Number of Shares	Weighted Average Fair Value
Outstanding—December 31, 2022	204,149	$	103.17
Granted	80,752	$	128.01
Vested	(68,302)	$	91.59
Expired	(2,053)	$	94.64
Outstanding—June 30, 2023	214,546	$	116.04

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Derivative Instruments (Tables)

6 Months Ended

Jun. 30, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Derivative Instruments [Table Text Block]

As of June 30, 2023, 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	21.3	Cash flow hedges	June 2026
Sharp	Propane (gallons)	Sales	3.2	Cash flow hedges	December 2023

Fair Values of Derivative Contracts Recorded in Condensed Consolidated Balance Sheet

June 30, 2023 and December 31, 2022, are as follows: 

	Derivative Assets
		Fair Value As Of
(in thousands)	Balance Sheet Location	June 30, 2023		December 31, 2022
Derivatives designated as cash flow hedges
Propane swap agreements	Derivative assets, at fair value	$	1,068	$	3,317
Interest rate swap agreements	Derivative assets, at fair value	776		452
Total Derivative Assets (1)		$	1,844	$	3,769

 (1) Derivative assets, at fair value include $1.7 million and $2.8 million in current assets in the condensed consolidated balance sheet at June 30, 2023 and December 31, 2022, respectively, with the remainder of the balance classified as long-term.

	Derivative Liabilities
		Fair Value As Of
(in thousands)	Balance Sheet Location	June 30, 2023		December 31, 2022
Derivatives designated as cash flow hedges
Propane swap agreements	Derivative liabilities, at fair value	$	2,556	$	1,810
Interest rate swap agreements	Derivative liabilities, at fair value	96		405
Total Derivative Liabilities (1)		$	2,652	$	2,215

(1) Derivative liabilities, at fair value include $2.2 million and $0.6 million in current liabilities in the condensed consolidated balance sheet at June 30, 2023 and December 31, 2022, respectively, with the remainder of the balance classified as long-term.

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	2023		2022		2023		2022
Derivatives not designated as hedging instruments
Propane swap agreements	Unregulated propane and natural gas costs	$	—	$	—	$	—	$	56
Derivatives designated as cash flow hedges
Propane swap agreements	Revenues	—		—		733		(826)
Propane swap agreements	Unregulated propane and natural gas costs	(432)		283		(559)		3,830
Propane swap agreements	Other comprehensive income (loss)	(2,417)		(686)		(2,994)		28
Interest rate swap agreements	Interest expense	127		—		192		—
Interest rate swap agreements	Other comprehensive income (loss)	898		—		633		—
Total		$	(1,824)	$	(403)	$	(1,995)	$	3,088

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Fair Value of Financial Instruments (Tables)

6 Months Ended

Jun. 30, 2023

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, 2023 and December 31, 2022:

			Fair Value Measurements Using:
As of June 30, 2023	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	$	23	$	23	$	—	$	—
Investments—guaranteed income fund	1,756		—		—		1,756
Investments—mutual funds and other	9,914		9,914		—		—
Total investments	11,693		9,937		—		1,756
Derivative assets	1,844		—		1,844		—
Total assets	$	13,537	$	9,937	$	1,844	$	1,756
Liabilities:
Derivative liabilities	$	2,652	$	—	$	2,652	$	—

			Fair Value Measurements Using:
As of December 31, 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	1,853		—		—		1,853
Investments—mutual funds and other	8,699		8,699		—		—
Total investments	10,576		8,723		—		1,853
Derivative assets	3,769		—		3,769		—
Total assets	$	14,345	$	8,723	$	3,769	$	1,853
Liabilities:
Derivative liabilities	$	2,215	$	—	$	2,215	$	—

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, 2023 and 2022:     

	Six months ended June 30,
	2023		2022
(in thousands)
Beginning Balance	$	1,853	$	2,036
Purchases and adjustments	—		132
Transfers	—		—
Distribution	(114)		(83)
Investment income	17		17
Ending Balance	$	1,756	$	2,102

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Long-Term Debt (Tables)

6 Months Ended

Jun. 30, 2023

Debt Disclosure [Abstract]

Outstanding Long-Term Debt

Our outstanding long-term debt is shown below: 

	June 30,		December 31,
(in thousands)	2023		2022
Uncollateralized senior notes:
5.93% note, due October 31, 2023	$	1,500	$	3,000
5.68% note, due June 30, 2026	8,700		11,600
6.43% note, due May 2, 2028	3,500		4,200
3.73% note, due December 16, 2028	12,000		12,000
3.88% note, due May 15, 2029	30,000		35,000
3.25% note, due April 30, 2032	63,000		66,500
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		50,000
5.43% notes Due March 14, 2038	80,000		—
Equipment security note
2.46% note, due September 24, 2031	8,078		8,517
Less: debt issuance costs	(1,042)		(946)
Total long-term debt	665,736		599,871
Less: current maturities	(19,994)		(21,483)
Total long-term debt, net of current maturities	$	645,742	$	578,388

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 Agreements (1)
Prudential Shelf Agreement	$	405,000	$	(300,000)	$	—	$	105,000
MetLife Shelf Agreement	200,000		(50,000)		—		150,000
Total Shelf Agreements as of June 30, 2023	$	605,000	$	(350,000)	$	—	$	255,000

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Leases Leases (Tables)

6 Months Ended

Jun. 30, 2023

Lease Disclosure [Abstract]

Lease, Cost [Table Text Block]

		Three Months Ended		Six Months Ended
		June 30,		June 30,
(in thousands)	Classification	2023	2022	2023	2022
Operating lease cost (1)	Operations expense	$780	$726	$1,568	$1,377

(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, 2023 and December 31, 2022:

(in thousands)	Balance sheet classification	June 30, 2023		December 31, 2022
Assets
Operating lease assets	Operating lease right-of-use assets	$	13,432	$	14,421
Liabilities
Current
Operating lease liabilities	Other accrued liabilities	$	2,373	$	2,552
Noncurrent
Operating lease liabilities	Operating lease - liabilities	11,585		12,392
Total lease liabilities		$	13,958	$	14,944

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 leases at June 30, 2023 and December 31, 2022:

	June 30, 2023		December 31, 2022
Weighted-average remaining lease term (in years)
Operating leases	8.37		8.54
Weighted-average discount rate
Operating leases	3.5	%	3.4	%

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, 2023 and 2022:

	Six Months Ended
	June 30,
(in thousands)	2023		2022
Operating cash flows from operating leases	$	1,465	$	1,428

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, 2023 and for each of the next five years and thereafter:

(in thousands)	Operating Leases (1)
Remainder of 2023	$	1,419
2024	2,629
2025	2,263
2026	1,734
2027	1,571
2028	1,192
Thereafter	5,243
Total lease payments	16,051
Less: Interest	(2,093)
Present value of lease liabilities	$	13,958

    (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, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Earnings Per Share [Abstract]
Income (Loss) from Continuing Operations, Per Basic Share	$ 0.91	$ 0.96	$ 2.95	$ 3.05
Calculation of Basic Earnings Per Share:
Net Income	$ 16,133	$ 17,051	$ 52,477	$ 53,985
Weighted shares outstanding (shares)	17,794,320	17,730,833	17,777,203	17,704,592
Basic Earnings Per Share (in dollars per share)	$ 0.91	$ 0.96	$ 2.95	$ 3.05
Reconciliation of Numerator:
Net Income	$ 16,133	$ 17,051	$ 52,477	$ 53,985
Reconciliation of Denominator:
Weighted shares outstanding - Basic (shares)	17,794,320	17,730,833	17,777,203	17,704,592
Effect of dilutive securities:
Share-based compensation (shares)	57,704	79,038	64,751	81,037
Adjusted denominator-Diluted (shares)	17,852,024	17,809,871	17,841,954	17,785,629
Income (Loss) from Continuing Operations, Per Diluted Share	$ 0.90	$ 0.96	$ 2.94	$ 3.04
Diluted Earnings Per Share (in dollars per share)	$ 0.90	$ 0.96	$ 2.94	$ 3.04
Net Income	$ 16,133	$ 17,051	$ 52,477	$ 53,985
Basic (shares)	17,794,320	17,730,833	17,777,203	17,704,592
Income (Loss) from Continuing Operations, Per Basic Share	$ 0.91	$ 0.96	$ 2.95	$ 3.05
Basic (in dollars per share)	$ 0.91	$ 0.96	$ 2.95	$ 3.05
Share-based compensation (shares)	57,704	79,038	64,751	81,037
Diluted (shares)	17,852,024	17,809,871	17,841,954	17,785,629
Income (Loss) from Continuing Operations, Per Diluted Share	$ 0.90	$ 0.96	$ 2.94	$ 3.04
Diluted (in dollars per share)	$ 0.90	$ 0.96	$ 2.94	$ 3.04
Retained Earnings [Member]
Earnings Per Share [Abstract]
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent	$ 16,133	$ 17,051	$ 52,477	$ 53,985
Calculation of Basic Earnings Per Share:
Net Income	16,133	17,051	52,477	53,985
Reconciliation of Numerator:
Net Income	16,133	17,051	52,477	53,985
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent	16,133	17,051	52,477	53,985
Net Income	$ 16,133	$ 17,051	$ 52,477	$ 53,985

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Acquisitions and Divestitures (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues	$ 135,593	$ 139,470	$ 353,722	$ 362,350
Operating Income (Loss)	28,346	26,469	83,261	81,334
Unregulated Energy [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Operating Income (Loss)	(993)	$ 560	16,252	$ 20,613
Davenport Energy
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, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net	500		$ 500
Gallons acquired through acquisition			400,000
Planet Found
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	4,000		$ 4,000
Business Combination, Consideration Transferred			9,500
Business Combination, Working Capital	100		100
Business Combination, Contingent Consideration, Liability	900		900
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net	1,100		1,100
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Indefinite-Lived Intangible Assets	$ 4,400		$ 4,400
Planet Found | Unregulated Energy [Member]
Acquisitions - Additional Information [Line Items]
Tons of Poultry Litter			1,200

XML

Revenue Recognition Additional Information (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Revenue from Contract with Customer [Abstract]
Contract with Customer, Liability, Revenue Recognized	$ 0.2	$ 0.3	$ 0.4	$ 0.7

XML

Revenue Recognition Disegragation of Revenue (Details) - USD ($)	3 Months Ended				6 Months Ended
	Jun. 30, 2023		Jun. 30, 2022		Jun. 30, 2023	Jun. 30, 2022
Disaggregation of Revenue [Line Items]
Revenues	$ 135,593,000		$ 139,470,000		$ 353,722,000	$ 362,350,000
Revenue from Contract with Customer, Excluding Assessed Tax	135,593,000	[1]	139,470,000	[1]	353,722,000	362,350,000
Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	101,141,000	[1]	92,193,000	[1]	243,411,000	220,084,000
Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	40,751,000	[1]	53,463,000	[1]	123,916,000	154,756,000
Other Segments And Intersegments Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(6,299,000)		(6,186,000)		(13,605,000)	(12,490,000)
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(6,299,000)	[1]	(6,186,000)	[1]	(13,605,000)	(12,490,000)
Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(20,725,000)		(19,276,000)		(43,262,000)	(40,466,000)
Eliminations [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(14,366,000)		(12,980,000)		(29,528,000)	(27,769,000)
Other [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenues	200,000		(100,000)		800,000	100,000
Other [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenues	100,000		100,000		200,000	200,000
Revenue from Contract with Customer, Excluding Assessed Tax	(60,000)		(110,000)		(129,000)	(207,000)
Energy Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	87,913,000		79,152,000		217,400,000	194,476,000
Energy Distribution [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	87,913,000		79,152,000		217,400,000	194,476,000
Energy Distribution [Member] | Delaware natural gas division [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	14,109,000		13,086,000		51,016,000	47,568,000
Energy Distribution [Member] | Delaware natural gas division [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	14,109,000		13,086,000		51,016,000	47,568,000
Energy Distribution [Member] | FPU Electric Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	23,034,000		20,305,000		45,771,000	39,394,000
Energy Distribution [Member] | FPU Electric Distribution [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	23,034,000		20,305,000		45,771,000	39,394,000
Energy Distribution [Member] | Florida Public Utilities Company [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	40,766,000		35,436,000		87,124,000	75,722,000
Energy Distribution [Member] | Florida Public Utilities Company [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	40,766,000		35,436,000		87,124,000	75,722,000
Energy Distribution [Member] | Maryland Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,622,000		4,372,000		16,884,000	14,836,000
Energy Distribution [Member] | Maryland Natural Gas [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,622,000		4,372,000		16,884,000	14,836,000
Energy Distribution [Member] | Sandpiper [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,079,000		4,248,000		11,161,000	11,885,000
Energy Distribution [Member] | Sandpiper [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,079,000		4,248,000		11,161,000	11,885,000
Energy Distribution [Member] | Elkton Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,303,000				5,444,000
Energy Distribution [Member] | Elkton Gas [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,303,000		1,705,000		5,444,000	5,071,000
Energy Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	33,320,000		36,829,000		75,219,000	82,221,000
Energy Transmission [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	27,594,000		26,021,000		55,539,000	53,377,000
Energy Transmission [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5,726,000		10,808,000		19,680,000	28,844,000
Energy Transmission [Member] | Aspire [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5,726,000		10,808,000		19,680,000	28,844,000
Energy Transmission [Member] | Aspire [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5,726,000		10,808,000		19,680,000	28,844,000
Energy Transmission [Member] | Eastern Shore Gas Company [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	19,632,000		18,875,000		40,302,000	39,196,000
Energy Transmission [Member] | Eastern Shore Gas Company [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	19,632,000		18,875,000		40,302,000	39,196,000
Energy Transmission [Member] | Peninsula Pipeline [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	7,593,000		6,777,000		14,504,000	13,549,000
Energy Transmission [Member] | Peninsula Pipeline [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	7,593,000		6,777,000		14,504,000	13,549,000
Energy Transmission [Member] | Aspire Energy Express | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	369,000		369,000		733,000	632,000
Energy Generation [Member] | Eight Flags [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,532,000		5,916,000		9,832,000	11,455,000
Energy Generation [Member] | Eight Flags [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,532,000		5,916,000		9,832,000	11,455,000
Propane Delivery [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	27,315,000		34,469,000		87,295,000	110,075,000
Propane Delivery [Member] | Florida Propane | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	27,315,000		34,469,000		87,295,000	110,075,000
Energy Services [Member] | Marlin Gas Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	3,238,000				7,238,000
Energy Services [Member] | Marlin Gas Services [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	3,238,000		2,380,000		7,238,000	4,589,000
Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(20,770,000)		(19,361,000)		(43,353,000)	(40,682,000)
Eliminations [Member] | Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(14,366,000)		(12,980,000)		(29,528,000)	(27,769,000)
Eliminations [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(60,000)		(110,000)		(129,000)	(207,000)
Eliminations [Member] | Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(6,344,000)		(6,271,000)		(13,696,000)	(12,706,000)
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	45,000		85,000		91,000	216,000
Other [Member] | Unregulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0		0		0	0
Other [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 45,000		$ 85,000		$ 91,000	$ 216,000

[1] 2) Total operating revenues for the three months ended June 30, 2023 include other revenue (revenues from sources other than contracts with customers) of $0.2 million and $0.1 million for our Regulated and Unregulated Energy segments, respectively and $(0.1) million and $0.1 million for our Regulated and Unregulated Energy segments, respectively, for the three months ended June 30, 2022. 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, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Revenue from Contract with Customer [Abstract]
Receivables from Customers	$ 41,140		$ 41,140		$ 61,687
Contract with Customer, Asset, Net, Current	18		18		18
Contract with Customer, Asset, Net, Noncurrent	3,787		3,787		4,321
Customer deposits and refunds	594		594		$ 983
Increase (Decrease) in Receivables			(20,547)
Increase (Decrease) in Other Current Assets			0
Increase (Decrease) in Other Noncurrent Assets			(534)
Increase (Decrease) in Other Current Liabilities			(389)
Contract with Customer, Liability, Revenue Recognized	$ 200	$ 300	$ 400	$ 700

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Revenue Recognition Remaining Performance Obligations (Details) $ in Thousands	Jun. 30, 2023 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]: 2023-01-01
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]: 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
FPU Electric Distribution [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	0
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	3,967
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	7,744
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	7,297
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	7,066
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	6,470
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	5,154
Natural gas distribution operations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	28,371
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	19,613
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	37,006
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	30,613
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	27,138
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	24,163
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	23,398
Eastern Shore and Peninsula Pipeline [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	188,498
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	23,906
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	45,402
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	38,185
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	34,479
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	30,908
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	28,827
Total for Segments [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 216,869

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Rates and Other Regulatory Activities - Additional Information (Detail) $ in Thousands	6 Months Ended
	Jun. 30, 2023 USD ($) Dekatherm mi	Dec. 31, 2022 USD ($)
Rates and Other Regulatory Activities [Line Items]
COVID-19 Regulatory Asset	$ 700	$ 1,200
Interim Rates	7,700
Permanent Rates	24,100
Annual Rate Case Recovery	17,200
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	12,134	12,230
Maryland Division [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	3,644	3,703
Sandpiper [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	3,542	3,597
Florida Public Utilities Company [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	26,894	27,179
FPU electric division [Member]
Rates and Other Regulatory Activities [Line Items]
Regulatory Liabilities	4,876	4,993
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	$ 1,043	$ 1,059
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
Twin Lakes Expansion | Peninsula Pipeline Company [Member]
Rates and Other Regulatory Activities [Line Items]
Additional Firm Natural Gas Transportation Deliverability | Dekatherm	2,400
Lake Wales Pipeline Acquisition | Peninsula Pipeline Company [Member]
Rates and Other Regulatory Activities [Line Items]
Additional Firm Natural Gas Transportation Deliverability | Dekatherm	9,000

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Environmental Commitments and Contingencies - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2023 USD ($) site	Dec. 31, 2022 USD ($)
Environmental Commitments And Contingencies [Line Items]
Company's exposure in number of former Manufactured Gas Plant Sites | site	7
Environmental liabilities	$ 2,512,000	$ 3,272,000
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	500,000	800,000
FPU [Member]
Environmental Commitments And Contingencies [Line Items]
Environmental liabilities	3,400,000	$ 4,300,000
Approval of recovery of environmental costs	$ 14,000,000

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Other Commitments and Contingencies - Additional Information (Detail) $ in Millions	6 Months Ended
	Jun. 30, 2023 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	14.2
Draws on letters of credit	5.9
Specific Purpose
Other Commitments [Line Items]
Guarantor Obligations, Current Carrying Value	$ 4.0
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, 2023 USD ($)		Jun. 30, 2022 USD ($)		Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments					2
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	$ 135,593		$ 139,470		$ 353,722	$ 362,350
Operating Income
Total operating income	28,346		26,469		83,261	81,334
Other expense, net	831		2,584		1,107	3,498
Interest	6,964		5,825		14,196	11,164
Income Before Income Taxes	22,213		23,228		70,172	73,668
Income Taxes	6,080		6,177		17,695	19,683
Net Income	16,133		17,051		52,477	53,985
Identifiable Assets
Total identifiable assets	2,204,490				2,204,490		$ 2,215,037
Intersegment Eliminations [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	6,345		6,271		13,696	12,706
Operating Revenues, Unaffiliated Customers [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	135,593		139,470		353,722	362,350
Regulated Energy [Member]
Operating Income
Total operating income	29,291		25,841		66,916	60,539
Identifiable Assets
Total identifiable assets	1,707,605				1,707,605		1,716,255
Regulated Energy [Member] | Intersegment Eliminations [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	484	[1]	363	[1]	1,132	4,196
Regulated Energy [Member] | Operating Revenues, Unaffiliated Customers [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	100,657		91,830		242,279	215,888
Unregulated Energy [Member]
Operating Income
Total operating income	(993)		560		16,252	20,613
Identifiable Assets
Total identifiable assets	448,217				448,217		463,239
Unregulated Energy [Member] | Intersegment Eliminations [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	5,816	[1]	5,823	[1]	12,473	7,819
Unregulated Energy [Member] | Operating Revenues, Unaffiliated Customers [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	34,936		47,640		111,443	146,462
Other [Member]
Identifiable Assets
Total identifiable assets	48,668				48,668		$ 35,543
Other [Member] | Intersegment Eliminations [Member]
Operating Revenues, Unaffiliated Customers
Total operating revenues, unaffiliated customers	45	[1]	85	[1]	91	691
Other and eliminations [Member]
Operating Income
Total operating income	48		68		93	182
Retained Earnings [Member]
Operating Income
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent	16,133		17,051		52,477	53,985
Net Income	$ 16,133		$ 17,051		$ 52,477	$ 53,985

[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
	Jun. 30, 2023	Mar. 31, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		$ (1,379,000)		$ (1,379,000)	$ 1,303,000
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax				(1,433,000)	2,206,000
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax				(247,000)	(2,139,000)
Net current-period other comprehensive income (loss)	$ (1,076,000)		$ (480,000)	(1,680,000)	67,000
Ending balance	(3,059,000)		1,370,000	(3,059,000)	1,370,000
Stock Issued During Period, Shares, Dividend Reinvestment Plan		0.1
Stock Issued During Period, Value, Dividend Reinvestment Plan		$ 136.26
Proceeds from Issuance of Common Stock, Dividend Reinvestment Plan		$ 4,500,000
Stock Issued During Period, Shares, Dividend Reinvestment Plan		0.1
Stock Issued During Period, Value, Dividend Reinvestment Plan		$ 136.26
Proceeds from Issuance of Common Stock, Dividend Reinvestment Plan		4,500,000
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		(2,506,000)		(2,506,000)	(3,268,000)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax				0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax				21,000	35,000
Net current-period other comprehensive income (loss)				21,000	35,000
Ending balance	(2,485,000)		(3,233,000)	(2,485,000)	(3,233,000)
Accumulated (Gain) Loss from Commodity Contracts Cash Flows Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		1,092,000		1,092,000	4,571,000
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(2,065,000)		(293,000)	(2,045,000)	2,206,000
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	313,000		(205,000)	(126,000)	(2,174,000)
Net current-period other comprehensive income (loss)				(2,171,000)	32,000
Ending balance	(1,079,000)		4,603,000	(1,079,000)	4,603,000
Accumulated (Gain) Loss from Interest Rate Swap Cash Flows Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		$ 35,000		35,000	0
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	758,000		0	612,000	0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax				(142,000)	0
Net current-period other comprehensive income (loss)				470,000	0
Ending balance	$ 505,000		$ 0	$ 505,000	$ 0

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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
	Jun. 30, 2023	Mar. 31, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Amortization of pension and postretirement items:
Tax benefit	$ (6,080,000)		$ (6,177,000)	$ (17,695,000)	$ (19,683,000)
Derivative, Gain (Loss) on Derivative, Net	(1,824,000)		(403,000)	(1,995,000)	3,088,000
Stock Issued During Period, Shares, Dividend Reinvestment Plan		0.1
Stock Issued During Period, Value, Dividend Reinvestment Plan		$ 136.26
Proceeds from Issuance of Common Stock, Dividend Reinvestment Plan		$ 4,500,000
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	$ 127,000		$ 0	$ 192,000	$ 0

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Employee Benefit Plans (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	$ 400		$ 400
Rabbi Trust Investments Assets	11,700		11,700		$ 10,600
Florida Public Utilities Company Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost	633	$ 449	1,266	$ 898
Expected return on plan assets	(668)	(857)	(1,336)	(1,714)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	110	124	220	248
Total periodic cost	75	(284)	150	(568)
Defined Benefit Plan Amounts Recognized Gain (Loss)	110		220
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax	21	24	42	48
Defined Benefit Plan Amounts Recognized From Regulatory Asset	89	$ 100	$ 178	200
Chesapeake Pension SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan Amounts Recognized Gain (Loss)	$ 124			$ 248

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Employee Benefit Plans - Additional Information (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	$ 400		$ 400
Investments, at fair value	11,693		11,693		$ 10,576
Deferred compensation obligation	9,001		9,001		7,060
Rabbi Trust Investments Assets	11,700		11,700		$ 10,600
Florida Public Utilities Company Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	110	$ 124	220	$ 248
Defined Benefit Plan Amounts Recognized Gain (Loss)	110		220
Recognized from accumulated other comprehensive loss	21	24	42	48
Recognized from regulatory asset	89	$ 100	178	200
Chesapeake Pension SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan Amounts Recognized Gain (Loss)	124			$ 248
Defined Benefit Plan, Plan Assets, Benefits Paid	$ 200		$ 300

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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, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
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)	$ 110	$ 124	$ 220	$ 248
Recognized from accumulated other comprehensive loss	21	24	42	48
Recognized from regulatory asset	89	$ 100	178	200
Total recognized in net periodic benefit cost	110		$ 220
Chesapeake Pension SERP [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Total recognized in net periodic benefit cost	$ 124			$ 248

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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		11 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Mar. 31, 2023	Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	$ 511	$ 1,342	$ 2,919	$ 3,555
Less: tax benefit	(132)	(346)	(754)	(917)
Share-Based Compensation amounts included in net income	379	996	$ 2,165	2,638
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					765
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value			$ 124.12
Total compensation expense	$ 227	220	$ 479	454
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	214,546		214,546			204,149
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period			80,752
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period			68,302
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Expired In Period			(2,053)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 116.04		$ 116.04			$ 103.17
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value			128.01
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value			91.59
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Expirations Weighted Average Grant Date Fair Value			$ 94.64
Total compensation expense	$ 284	$ 1,122	$ 2,440	$ 3,101

XML

Share-Based Compensation - Summary of Stock Activity under the SICP (Detail) - $ / shares	6 Months Ended	11 Months Ended
	Jun. 30, 2023	Mar. 31, 2023
Award to key employees [Member]
Number of Shares
Outstanding - December 31, 2020 (shares)	204,149
Granted awards (shares)	80,752
Vested (shares)	(68,302)
Expired (shares)	2,053
Outstanding - June 30, 2021 (shares)	214,546
Weighted Average Fair Value
Outstanding - December 31, 2020 (in dollars per share)	$ 103.17
Granted (in dollars per share)	128.01
Vested (in dollars per share)	91.59
Expired (in dollars per share)	94.64
Outstanding - June 30, 2021 (in dollars per share)	116.04
Awards to non-employee directors [Member]
Number of Shares
Granted awards (shares)		765
Weighted Average Fair Value
Granted (in dollars per share)	$ 124.12

XML

Share-Based Compensation - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Thousands	6 Months Ended		11 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Mar. 31, 2023
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Payment Arrangement, Shares Withheld for Tax Withholding Obligation	19,859	21,832
Payment, Tax Withholding, Share-based Payment Arrangement	$ 2,455	$ 2,838
Unrecognized compensation cost	$ 8,700
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	$ 124.12
Granted awards (shares)			765
Unrecognized compensation expense related to the awards to non-employee directors	$ 800
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	$ 124.12
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period			765
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	(2,053)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 128.01
Granted awards (shares)	80,752
Vesting period	3 years
Payment, Tax Withholding, Share-based Payment Arrangement	$ 2,500
Intrinsic value of the SICP awards	$ 25,500
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	$ 128.01
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	80,752
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	19,859

XML

Derivative Instruments Volume of Derivative Activity (Details) - Sharp Energy Inc [Member] gal in Millions, $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($) gal
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months | $	$ (1.1)
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	21.3
Swap Sales
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	3.2

XML

Derivative Instruments - Additional Information (Detail) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended	6 Months Ended
	Feb. 28, 2021	Sep. 30, 2021	Jun. 30, 2023	Dec. 31, 2022	Dec. 31, 2021
Derivative [Line Items]
Energy Marketing Contracts Assets, Current			$ 1,704	$ 2,787
Energy Marketing Contract Liabilities, Current			(2,178)	(585)
Notional Amount of Nonderivative Instruments	$ 40,000	$ 30,000	50,000
Notional Amount Nonderivative Instruments, Total		$ 60,000
Designated as Hedging Instrument [Member] | Mark To Market Energy Assets [Member] | Interest Rate Swap [Member]
Derivative [Line Items]
Energy Marketing Contracts Assets, Current			776	452
Designated as Hedging Instrument [Member] | Mark To Market Energy Assets [Member] | Propane Swap Agreement [Member]
Derivative [Line Items]
Energy Marketing Contracts Assets, Current			1,068	3,317
Designated as Hedging Instrument [Member] | Mark-to-market energy liabilities [Member] | Interest Rate Swap [Member]
Derivative [Line Items]
Energy Marketing Contract Liabilities, Current			(96)	(405)
Designated as Hedging Instrument [Member] | Mark-to-market energy liabilities [Member] | Propane Swap Agreement [Member]
Derivative [Line Items]
Energy Marketing Contract Liabilities, Current			(2,556)	(1,810)
Sharp Energy Inc [Member]
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months			$ (1,100)
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			$ 1,400	$ 100
Interest Rate Swap Rate, High Range [Member]
Derivative [Line Items]
Fixed Swap Rate			3.98%	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, 2023	Dec. 31, 2022
Derivatives, Fair Value [Line Items]
Energy Marketing Contracts Assets, Current	$ 1,704	$ 2,787
Energy Marketing Contract Liabilities, Current	2,178	585
Energy Marketing Contract Liabilities, Total	2,652	2,215
Energy Marketing Contracts Assets, Total	1,844	3,769
Mark To Market Energy Assets [Member] | Propane Swap Agreement [Member] | Derivatives designated as hedging instrument [Member]
Derivatives, Fair Value [Line Items]
Energy Marketing Contracts Assets, Current	1,068	3,317
Mark To Market Energy Assets [Member] | Interest Rate Swap [Member] | Derivatives designated as hedging instrument [Member]
Derivatives, Fair Value [Line Items]
Energy Marketing Contracts Assets, Current	776	452
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	2,556	1,810
Mark-to-market energy liabilities [Member] | Interest Rate Swap [Member] | Derivatives designated as hedging instrument [Member]
Derivatives, Fair Value [Line Items]
Energy Marketing Contract Liabilities, Current	$ 96	$ 405

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, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ (1,824)	$ (403)	$ (1,995)	$ 3,088
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	(432)	283	(559)	3,830
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	0	56
Other Comprehensive Income (Loss) [Member] | Derivatives designated as hedging instrument [Member] | Propane Swap Agreement [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, before Tax	(2,417)	(686)	(2,994)	28
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	898	0	633	0
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	127	0	192	0
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	$ 733	$ (826)

XML

Fair Value of Financial Instruments - Financial Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Assets:
Investments	$ 11,693	$ 10,576
Energy Marketing Contracts Assets, Current	1,704	2,787
Liabilities:
Energy Marketing Contract Liabilities, Current	2,178	585
Quoted Prices in Active Markets (Level 1) [Member]
Assets:
Assets, Fair Value Disclosure	9,937	8,723
Quoted Prices in Active Markets (Level 1) [Member] | Equity Securities [Member]
Assets:
Investments	23	24
Quoted Prices in Active Markets (Level 1) [Member] | Investments - Mutual funds and other [Member]
Assets:
Investments	9,914	8,699
Quoted Prices in Active Markets (Level 1) [Member] | Total Investments [Member]
Assets:
Investments	9,937	8,723
Significant Other Observable Inputs (Level 2) [Member]
Assets:
Assets, Fair Value Disclosure	1,844	3,769
Significant Unobservable Inputs (Level 3) [Member]
Assets:
Assets, Fair Value Disclosure	1,756	1,853
Significant Unobservable Inputs (Level 3) [Member] | Investments in guaranteed income fund [Member]
Assets:
Investments	1,756	1,853
Significant Unobservable Inputs (Level 3) [Member] | Total Investments [Member]
Assets:
Investments	1,756	1,853
Recurring [Member]
Assets:
Assets, Fair Value Disclosure	13,537	14,345
Liabilities:
Energy Marketing Contract Liabilities, Current		2,215
Recurring [Member] | Equity Securities [Member]
Assets:
Investments	23	24
Recurring [Member] | Investments in guaranteed income fund [Member]
Assets:
Investments	1,756	1,853
Recurring [Member] | Investments - Mutual funds and other [Member]
Assets:
Investments		8,699
Recurring [Member] | Total Investments [Member]
Assets:
Investments	11,693	10,576
Recurring [Member] | Mark To Market Energy Assets incl. natural gas and swap agreements[Member]
Assets:
Derivative assets	$ 1,844	$ 3,769

XML

Fair Value of Financial Instruments - Summary of Changes in Fair Value of Investments (Detail) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value	$ 11,693		$ 10,576
Energy Marketing Contract Liabilities, Current	2,178		585
Energy Marketing Contract Liabilities, Total	2,652		2,215
Energy Marketing Contracts Assets, Total	1,844		3,769
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	(114)	$ (83)
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	1,853	2,036
Purchases and adjustments	0	132
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers out of Level 3	0	0
Investment Income	17	17
Ending Balance	1,756	$ 2,102
Quoted Prices in Active Markets (Level 1) [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	9,937		8,723
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	1,844		3,769
Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	1,756		1,853
Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	13,537		14,345
Energy Marketing Contract Liabilities, Current			2,215
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	23		24
Equity Securities [Member] | Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value	23		24
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	1,756		1,853
Investments in guaranteed income fund [Member] | Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value	1,756		1,853
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	9,914		8,699
Investments - Mutual funds and other [Member] | Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value			8,699
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	9,937		8,723
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	1,756		1,853
Total Investments [Member] | Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Investments, at fair value	11,693		10,576
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	$ 1,844		$ 3,769

XML

Fair Value of Financial Instruments - Additional Information (Detail) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Fair Value Disclosures [Abstract]
Long-term debt including current maturities	$ 666.8	$ 600.8
Fair value of long-term debt	$ 573.3	$ 505.0

XML

Long-Term Debt - Outstanding Long-Term Debt (Detail) - USD ($) $ in Thousands		6 Months Ended
		Jun. 30, 2023	Dec. 31, 2022
Debt Instrument [Line Items]
Total long-term debt		$ (666,800)	$ (600,800)
Debt Instrument, Unused Borrowing Capacity, Amount		255,000
Total Long-term debt		665,736	599,871
Less: current maturities		(19,994)	(21,483)
Less: debt issuance costs		1,042	946
Total long-term debt, net of current maturities		645,742	578,388
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		$ (1,500)	(3,000)
Debt Instrument, Interest Rate, Stated Percentage		5.93%
Debt instrument, maturity date		Oct. 31, 2023
5.68% note, due June 30, 2026 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (8,700)	(11,600)
Debt Instrument, Interest Rate, Stated Percentage		5.68%
Debt instrument, maturity date		Jun. 30, 2026
6.43% note, due May 2, 2028 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (3,500)	(4,200)
Debt Instrument, Interest Rate, Stated Percentage		6.43%
Debt instrument, maturity date		May 02, 2028
3.73% note, due December 16, 2028 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (12,000)	(12,000)
Debt Instrument, Interest Rate, Stated Percentage		3.73%
Debt instrument, maturity date		Dec. 16, 2028
3.88% note, due May 15, 2029 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (30,000)	(35,000)
Debt Instrument, Interest Rate, Stated Percentage		3.88%
Debt instrument, maturity date		May 15, 2029
3.25% note, due April 30, 2032 [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (63,000)	(66,500)
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%
Debt instrument, maturity date		Nov. 30, 2038
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%
Debt instrument, maturity date		Jul. 15, 2035
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%
Debt instrument, maturity date		Aug. 15, 2035
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		$ (8,078)	(8,517)
Debt Instrument, Interest Rate, Stated Percentage		2.46%
Debt instrument, maturity date		Sep. 24, 2031
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%
Debt instrument, maturity date		Jan. 25, 2037
Uncollateralized Senior Note Due March 15, 2042
Debt Instrument [Line Items]
Total long-term debt		$ (50,000)	$ (50,000)
Debt Instrument, Interest Rate, Stated Percentage		2.95%
Debt instrument, maturity date		Mar. 15, 2042
Uncollateralized Senior Note Due March 14, 2038
Debt Instrument [Line Items]
Total long-term debt		$ (80,000)
Debt Instrument, Interest Rate, Stated Percentage		5.43%
Debt instrument, maturity date		Mar. 14, 2038
Aggregate Shelf Agreements [Member]
Debt Instrument [Line Items]
Total long-term debt		$ (350,000)
Aggregate Shelf Agreements [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		605,000
Prudential [Member]
Debt Instrument [Line Items]
Total long-term debt	[1]	(300,000)
Debt Instrument, Unused Borrowing Capacity, Amount	[1]	105,000
Prudential [Member] | Aggregated Unfunded Commitments [Member]
Debt Instrument [Line Items]
Total long-term debt	[1]	0
Prudential [Member] | Uncollateralized Senior Note Due March 14, 2038
Debt Instrument [Line Items]
Total long-term debt		(80,000)
Prudential [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	[1]	405,000
MetLife [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	[1]	200,000
Total long-term debt		(50,000)
Debt Instrument, Unused Borrowing Capacity, Amount	[1]	$ 150,000

[1] (1) The Prudential and MetLife Shelf Agreements both expire in February 2026.

XML

Long-Term Debt - Outstanding Long-Term Debt- Supplemental Information (Detail)	6 Months Ended
	Jun. 30, 2023
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%)
Uncollateralized Senior Note Due March 14, 2038
Debt Instrument [Line Items]
Debt instrument, maturity date	Mar. 14, 2038
Debt Instrument, Interest Rate, Stated Percentage	(5.43%)

XML

Long-Term Debt - Additional Information (Detail) - USD ($) $ in Thousands		6 Months Ended
		Jun. 30, 2023	Dec. 31, 2022
Debt Instrument [Line Items]
Document Period End Date		Jun. 30, 2023
Long-term debt including current maturities		$ 666,800	$ 600,800
Debt Instrument, Unused Borrowing Capacity, Amount		255,000
Short-term borrowing		$ 95,807	202,157
Uncollateralized Senior Note Due December Two Thousand Thirty Four [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		2.98%
Debt instrument, maturity date		Dec. 20, 2034
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		63,000	66,500
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		$ 8,078	8,517
Debt Instrument, Interest Rate, Stated Percentage		2.46%
Debt instrument, maturity date		Sep. 24, 2031
Uncollateralized Senior Note Due March 15, 2042
Debt Instrument [Line Items]
Long-term debt including current maturities		$ 50,000	50,000
Debt Instrument, Interest Rate, Stated Percentage		2.95%
Debt instrument, maturity date		Mar. 15, 2042
Uncollateralized Senior Note Due March 14, 2038
Debt Instrument [Line Items]
Long-term debt including current maturities		$ 80,000
Debt Instrument, Interest Rate, Stated Percentage		5.43%
Debt instrument, maturity date		Mar. 14, 2038
Uncollateralized Senior Note Due January Two Thousand Thirty Seven
Debt Instrument [Line Items]
Long-term debt including current maturities		$ 50,000	$ 50,000
Debt Instrument, Interest Rate, Stated Percentage		2.49%
Debt instrument, maturity date		Jan. 25, 2037
Aggregate Shelf Agreements [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities		$ 350,000
MetLife [Member]
Debt Instrument [Line Items]
Senior notes	[1]	200,000
Long-term debt including current maturities		50,000
Debt Instrument, Unused Borrowing Capacity, Amount	[1]	150,000
Prudential [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities	[1]	300,000
Debt Instrument, Unused Borrowing Capacity, Amount	[1]	105,000
Prudential [Member] | Aggregated Unfunded Commitments [Member]
Debt Instrument [Line Items]
Long-term debt including current maturities	[1]	0
Prudential [Member] | Uncollateralized Senior Note Due March 14, 2038
Debt Instrument [Line Items]
Long-term debt including current maturities		80,000
Maximum [Member] | Aggregate Shelf Agreements [Member]
Debt Instrument [Line Items]
Senior notes		605,000
Maximum [Member] | Prudential [Member]
Debt Instrument [Line Items]
Senior notes	[1]	$ 405,000

[1] (1) The Prudential and MetLife Shelf Agreements both expire in February 2026.

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Short-Term Borrowings (Details) - USD ($)	1 Months Ended	3 Months Ended	6 Months Ended
	Feb. 28, 2021	Sep. 30, 2021	Jun. 30, 2023	Dec. 31, 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	$ 50,000,000
Line of Credit Facility, Remaining Borrowing Capacity			298,300,000
Short-term borrowing			$ 95,807,000	$ 202,157,000
Short-term Debt, Weighted Average Interest Rate, at Point in Time			5.33%	5.04%
Draws on letters of credit			$ 5,900,000
Revolving Line of Credit, Short-term
Short-term Debt [Line Items]
Debt Instrument, Fee			9
Debt Instrument, Interest Rate, Stated Percentage			7000.00%
Aggregate Investment, Maximum				$ 150,000,000
Interest Rate Credit Adjustment			10
Borrowings Outstanding, Sustainable Investing			$ 9,400,000
Revolving Line of Credit, Long-term
Short-term Debt [Line Items]
Debt Instrument, Fee			9
Debt Instrument, Interest Rate, Stated Percentage			9500.00%
Interest Rate Credit Adjustment			10
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			3.98%	0.17%	0.205%

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Leases (Details) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Lease Disclosure [Abstract]
Operating Lease, Right-of-Use Asset	$ 13,432	$ 14,421
Operating Lease, Liability, Current	2,373	2,552
Operating Lease, Liability, Noncurrent	11,585	12,392
Total Operating and Finance Lease Liabilities	$ 13,958	$ 14,944

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Leases Leases - Lease Cost Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended				6 Months Ended
	Jun. 30, 2023		Jun. 30, 2022		Jun. 30, 2023	Jun. 30, 2022
Lease, Cost [Abstract]
Operating Lease, Cost	$ 780	[1]	$ 726	[1]	$ 1,568	$ 1,377

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

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Leases Leases - Right of Use Asset and Lease Liability Balance Sheet Classification Additional Information (Details) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Leases - Right of Use Asset and Lease Liability Balance Sheet Classification [Abstract]
Operating Lease, Right-of-Use Asset	$ 13,432	$ 14,421
Operating Lease, Liability, Current	2,373	2,552
Operating Lease, Liability, Noncurrent	11,585	12,392
Total Operating and Finance Lease Liabilities	$ 13,958	$ 14,944

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Leases Leases - Weighted Average Remaining Lease Term Additional Information (Details)	Jun. 30, 2023	Dec. 31, 2022
Leases - Weighted Average Remaining Lease term Additional Information [Abstract]
Operating Lease, Weighted Average Discount Rate, Percent	3.50%	3.40%
Operating Lease, Weighted Average Remaining Lease Term	8 years 4 months 13 days	8 years 6 months 14 days

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Leases Leases - Cash Flow Additional Information (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022
Leases - Cash Flow Additional Information [Abstract]
Operating Cash Flow from Operating Leases	$ 1,465	$ 1,428

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Leases Leases - Schedule of Future Maturities Additional Information (Details) $ in Thousands	Jun. 30, 2023 USD ($)
Leases - Schedule of Future Maturities Additional Information [Abstract]
Lessee, Operating Lease, Liability, Payments, Remainder of Fiscal Year	$ 1,419	[1]
Lessee, Operating Lease, Liability, to be Paid, Year One	2,629	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Two	2,263	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Three	1,734	[1]
Lessee, Operating Lease, Liability, Payments, Due	16,051	[1]
Lessee, Operating Lease, Liability, Undiscounted Excess Amount	(2,093)
Operating Lease, Liability	13,958	[1]
Lessee Future Operating Lease Option Payments	2,100
Lessee, Operating Lease, Liability, Payments, Due Year Four	1,571	[1]
Lessee, Operating Lease, Liability, Payments, Due Year Five	1,192	[1]
Lessee, Operating Lease, Liability, to be Paid, after Year Five	$ 5,243	[1]

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