Chesapeake Utilities - 10-Q quarterly report FY2019 Q3

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Table of Contents

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: September 30, 2019



☐	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.)

909 Silver Lake Boulevard, Dover, Delaware 19904

(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.

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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 — 16,403,776 shares outstanding as of October 31, 2019.

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PART I—FINANCIAL INFORMATION		1

ITEM 1.	FINANCIAL STATEMENTS	1

ITEM 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	36

ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	59

ITEM 4.	CONTROLS AND PROCEDURES	61

PART II—OTHER INFORMATION		62

ITEM 1.	LEGAL PROCEEDINGS	62

ITEM 1A.	RISK FACTORS	62

ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	62

ITEM 3.	DEFAULTS UPON SENIOR SECURITIES	62

ITEM 5.	OTHER INFORMATION	62

ITEM 6.	EXHIBITS	63

SIGNATURES		64

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GLOSSARY OF DEFINITIONS

ASC: Accounting Standards Codification issued by the FASB

Aspire Energy: Aspire Energy of Ohio, LLC

ASU: Accounting Standards Update issued by the FASB

CDD: Cooling Degree-Day

CGS: Community Gas Systems

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

CHP: Combined heat and power plant

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

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

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

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 subsidiary of Chesapeake OnSight Services, LLC

FASB: Financial Accounting Standards Board

FERC: Federal Energy Regulatory Commission

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

Gas South: Gas South, LLC, a subsidiary of Cobb Electric Membership Corporation

GAAP: Accounting principles generally accepted in the United States of America

GRIP: Gas Reliability Infrastructure Program

Gross Margin: a non-GAAP measure defined as operating revenues less the cost of sales. The Company's cost of sales includes purchased fuel cost for natural gas, electricity and propane and the cost of labor spent on direct revenue-producing activities and excludes depreciation, amortization and accretion

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

HDD: Heating Degree-Day

LIBOR: The London Inter-Bank Offered Rate

Marlin Gas Services: Marlin Gas Services, LLC, a wholly-owned subsidiary of Chesapeake Utilities that acquired certain operating assets of Marlin Gas Transport, Inc.

Marlin Gas Transport: Marlin Gas Transport, Inc., a former supplier of mobile compressed natural gas distribution and pipeline solutions

MetLife: MetLife Investment Advisors, an institutional debt investment management firm, with which we entered into the MetLife Shelf Agreement

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

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MTM: Mark-to-Market (fair value accounting)

NJRES: New Jersey Resource Energy Services Company a subsidiary of New Jersey Resources Inc.

NYL: New York Life Investors LLC, an institutional debt investment management firm, with which Chesapeake Utilities entered into a Shelf Agreement and issued Shelf Notes

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

PESCO: Peninsula Energy Services Company, Inc., a wholly-owned subsidiary of Chesapeake Utilities

Prudential: Prudential Investment Management Inc., an institutional investment management firm, with which Chesapeake Utilities has entered into a 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

Retirement Savings Plan: A qualified 401(k) retirement savings plan sponsored by Chesapeake Utilities

Revolver: Our unsecured revolving credit facility with certain lenders

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

SEC: U.S. Securities and Exchange Commission

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

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

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

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

SICP: 2013 Stock and Incentive Compensation Plan

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

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

UET: United Energy Trading, LLC a subsidiary of United Energy Corporation

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PART I—FINANCIAL INFORMATION

Item 1. Financial Statements

Chesapeake Utilities Corporation and Subsidiaries

Condensed Consolidated Statements of Income (Unaudited)



	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
(in thousands, except shares and per share data)
Operating Revenues
Regulated Energy	$	74,580		$	72,770		$	251,601		$	252,667
Unregulated Energy and other	18,046			20,630			96,029			103,435
Total Operating Revenues	92,626			93,400			347,630			356,102
Operating Expenses
Regulated Energy cost of sales	19,619			21,501			74,452			89,741
Unregulated Energy and other cost of sales	5,709			9,512			36,975			49,196
Operations	32,623			31,449			99,596			97,723
Maintenance	3,920			3,208			11,199			10,419
Gain from a settlement	—			—			(130		)	(130		)
Depreciation and amortization	11,219			10,487			33,612			29,739
Other taxes	5,178			4,364			15,282			13,446
Total Operating Expenses	78,268			80,521			270,986			290,134
Operating Income	14,358			12,879			76,644			65,968
Other expense, net	(350		)	(4		)	(729		)	(168		)
Interest charges	5,403			4,357			16,583			11,764
Income from Continuing Operations Before Income Taxes	8,605			8,518			59,332			54,036
Income Taxes on Continuing Operations	2,360			2,428			15,355			14,918
Income from Continuing Operations	6,245			6,090			43,977			39,118
Loss from Discontinued Operations, Net of Tax	(624		)	(552		)	(1,388		)	(339		)
Net Income	$	5,621		$	5,538		$	42,589		$	38,779
Weighted Average Common Shares Outstanding:
Basic	16,403,776			16,378,545			16,396,646			16,366,608
Diluted	16,453,867			16,428,439			16,444,231			16,416,255
Basic Earnings Per Share of Common Stock:
Earnings from Continuing Operations	$	0.38		$	0.37		$	2.68		$	2.39
Earnings from Discontinued Operations	(0.04		)	(0.03		)	(0.08		)	(0.02		)
Basic Earnings Per Share of Common Stock	$	0.34		$	0.34		$	2.60		$	2.37

Diluted Earnings Per Share of Common Stock:
Earnings from Continuing Operations	$	0.38		$	0.37		$	2.67		$	2.38
Earnings from Discontinued Operations	(0.04		)	(0.03		)	(0.08		)	(0.02		)
Diluted Earnings Per Share of Common Stock	$	0.34		$	0.34		$	2.59		$	2.36

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

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Chesapeake Utilities Corporation and Subsidiaries

Condensed Consolidated Statements of Comprehensive Income (Unaudited)



	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
(in thousands)
Net Income	$	5,621		$	5,538		$	42,589		$	38,779
Other Comprehensive Income (Loss), net of tax:
Employee Benefits, net of tax:
Amortization of prior service cost, net of tax of $(5), $(5), $(15) and $(16), respectively	(14		)	(14		)	(43		)	(42		)
Net gain, net of tax of $39, $38, $125 and $118, respectively	114			100			355			317
Cash Flow Hedges, net of tax:
Unrealized gain (loss) on commodity contract cash flow hedges, net of tax of $152, $257, $496 and $(70), respectively	324			644			1,193			(83		)
Total Other Comprehensive Income, net of tax	424			730			1,505			192
Comprehensive Income	$	6,045		$	6,268		$	44,094		$	38,971

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

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Chesapeake Utilities Corporation and Subsidiaries

Condensed Consolidated Balance Sheets (Unaudited)



Assets	September 30, 2019			December 31, 2018
(in thousands, except shares and per share data)
Property, Plant and Equipment
Regulated Energy	$	1,407,371		$	1,297,416
Unregulated Energy	250,826			236,440
Other businesses and eliminations	30,596			34,585
Total property, plant and equipment	1,688,793			1,568,441
Less: Accumulated depreciation and amortization	(330,479		)	(294,089		)
Plus: Construction work in progress	102,640			108,584
Net property, plant and equipment	1,460,954			1,382,936
Current Assets
Cash and cash equivalents	4,320			6,089
Trade and other receivables (less allowance for uncollectible accounts of $1,350 and $1,058, respectively)	34,504			53,837
Accrued revenue	11,538			22,640
Propane inventory, at average cost	4,370			9,791
Other inventory, at average cost	6,037			7,127
Regulatory assets	6,633			4,796
Storage gas prepayments	2,158			3,433
Income taxes receivable	11,100			15,300
Prepaid expenses	10,571			10,079
Derivative assets, at fair value	—			82
Other current assets	2,489			5,682
Current assets held for sale	21,155			52,681
Total current assets	114,875			191,537
Deferred Charges and Other Assets
Goodwill	21,516			21,568
Other intangible assets, net	3,272			3,850
Investments, at fair value	8,536			6,711
Operating lease right-of-use assets (refer to Note 16)	12,004			—
Regulatory assets	77,030			72,422
Other assets	8,874			6,985
Noncurrent assets held for sale	7,179			7,662
Total deferred charges and other assets	138,411			119,198
Total Assets	$	1,714,240		$	1,693,671

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

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Chesapeake Utilities Corporation and Subsidiaries

Condensed Consolidated Balance Sheets (Unaudited)



Capitalization and Liabilities	September 30, 2019			December 31, 2018
(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)	7,984			7,971
Additional paid-in capital	257,436			255,651
Retained earnings	284,694			261,530
Accumulated other comprehensive loss	(5,403		)	(6,713		)
Deferred compensation obligation	4,505			3,854
Treasury stock	(4,505		)	(3,854		)
Total stockholders’ equity	544,711			518,439
Long-term debt, net of current maturities	375,810			316,020
Total capitalization	920,521			834,459
Current Liabilities
Current portion of long-term debt	75,600			11,935
Short-term borrowing	224,744			294,458
Accounts payable	53,150			98,681
Customer deposits and refunds	29,629			32,620
Accrued interest	4,891			2,317
Dividends payable	6,644			6,060
Accrued compensation	10,362			13,923
Regulatory liabilities	5,691			7,883
Derivative liabilities, at fair value	2,216			1,604
Other accrued liabilities	15,210			10,081
Current liabilities held for sale	18,110			48,672
Total current liabilities	446,247			528,234
Deferred Credits and Other Liabilities
Deferred income taxes	165,492			156,820
Regulatory liabilities	133,966			135,039
Environmental liabilities	6,713			7,638
Other pension and benefit costs	27,890			28,513
Operating lease - liabilities (refer to Note 16)	10,392			—
Deferred investment tax credits and other liabilities	3,019			2,968
Total deferred credits and other liabilities	347,472			330,978
Environmental and other commitments and contingencies (Notes 6 and 7)
Total Capitalization and Liabilities	$	1,714,240		$	1,693,671

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

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Chesapeake Utilities Corporation and Subsidiaries

Condensed Consolidated Statements of Cash Flows (Unaudited)



	Nine Months Ended
	September 30,
	2019			2018
(in thousands)
Operating Activities
Net income	$	42,589		$	38,779
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	34,049			30,176
Depreciation and accretion included in other costs	6,380			6,464
Deferred income taxes	8,789			11,047
Realized (gain) loss on commodity contracts/sale of assets/investments	(1,087		)	4,015
Unrealized gain on investments/commodity contracts	(1,025		)	(427		)
Employee benefits and compensation	1,163			456
Share-based compensation	2,305			2,535
Other, net	—			(35		)
Changes in assets and liabilities:
Accounts receivable and accrued revenue	51,997			32,988
Propane inventory, storage gas and other inventory	7,996			6,379
Regulatory assets/liabilities, net	(7,160		)	3,899
Prepaid expenses and other current assets	13,959			(1,533		)
Accounts payable and other accrued liabilities	(51,550		)	(9,590		)
Income taxes receivable	4,200			6,053
Customer deposits and refunds	(2,992		)	136
Accrued compensation	(3,747		)	(2,804		)
Other assets and liabilities, net	(1,927		)	(542		)
Net cash provided by operating activities	103,939			127,996
Investing Activities
Property, plant and equipment expenditures	(139,315		)	(171,410		)
Proceeds from sale of assets	327			565
Environmental expenditures	(925		)	(322		)
Net cash used in investing activities	(139,913		)	(171,167		)
Financing Activities
Common stock dividends	(18,235		)	(16,171		)
Issuance of stock under the Dividend Reinvestment Plan	(536		)	(518		)
Tax withholding payments related to net settled stock compensation	(692		)	(1,210		)
Change in cash overdrafts due to outstanding checks	(2,855		)	712
Net borrowings (repayments) under line of credit agreements	(66,859		)	16,612
Proceeds from long-term debt	129,817			74,901
Repayment of long-term debt, long-term borrowing under the Revolver and capital lease obligation	(6,435		)	(30,554		)
Net cash provided by financing activities	34,205			43,772
Net Increase (Decrease) in Cash and Cash Equivalents	(1,769		)	601
Cash and Cash Equivalents—Beginning of Period	6,089			5,614
Cash and Cash Equivalents—End of Period	$	4,320		$	6,215

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

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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 Loss			Deferred Compensation			Treasury Stock			Total
Balance at June 30, 2018	16,378,545	$	7,971	$	255,356		$	250,377		$	(5,717	)	$	3,782		$	(3,782	)	$	507,987
Net income	—	—		—			5,538			—			—			—			5,538
Other comprehensive income	—	—		—			—			730			—			—			730
Dividend declared ($0.3700 per share)	—	—		—			(6,110		)	—			—			—			(6,110		)
Dividend reinvestment plan	—	—		—			—			—			—			—			—
Share-based compensation and tax benefit ⁽³⁾⁽⁴⁾	—	—		153			—			—			—			—			153
Treasury stock activities	—	—		—			—			—			36			(36		)	—
Balance at September 30, 2018	16,378,545	$	7,971	$	255,509		$	249,805		$	(4,987	)	$	3,818		$	(3,818	)	$	508,298

Balance at December 31, 2017	16,344,442	$	7,955	$	253,470		$	229,141		$	(4,272	)	$	3,395		$	(3,395	)	$	486,294
Net income	—	—		—			38,779			—			—			—			38,779
Cumulative effect of the adoption of ASU 2014-09	—	—		—			(1,498		)	—			—			—			(1,498		)
Reclassification upon the adoption of ASU 2018-02	—	—		—			907			(907		)	—			—			—
Other comprehensive loss	—	—		—			—			192			—			—			192
Dividend declared ($1.065 per share)	—	—		—			(17,524		)	—			—			—			(17,524		)
Dividend reinvestment plan	—	—		(2		)	—			—			—			—			(2		)
Share-based compensation and tax benefit ⁽³⁾⁽⁴⁾	34,103	16		2,041			—			—			—			—			2,057
Treasury stock activities	—	—		—			—			—			423			(423		)	—
Balance at September 30, 2018	16,378,545	$	7,971	$	255,509		$	249,805		$	(4,987	)	$	3,818		$	(3,818	)	$	508,298

Balance at June 30, 2019	16,403,776	$	7,984	$	256,385		$	285,762		$	(5,747	)	$	4,694		$	(4,694	)	544,384
Net income	—	—		—			5,621			—			—			—			5,621
Other comprehensive loss	—	—		—			—			344			—			—			344
Dividend declared ($0.4050 per share)	—	—		—			(6,689		)	—			—			—			(6,689		)
Dividend reinvestment plan	—	—		(1		)	—			—			—			—			(1		)
Share-based compensation and tax benefit ⁽³⁾ ⁽⁴⁾		—		1,052			—			—			—			—			1,052
Treasury stock activities	—	—		—			—			—			(189		)	189			—
Balance at September 30, 2019	16,403,776	$	7,984	$	257,436		$	284,694		$	(5,403	)	$	4,505		$	(4,505	)	$	544,711

Balance at December 31, 2018	16,378,545	$	7,971	$	255,651		$	261,530		$	(6,713	)	$	3,854		$	(3,854	)	$	518,439
Net income	—	—		—			42,589			—			—			—			42,589
Prior period reclassification	—	—		—			115			(115		)	—			—			—
Other comprehensive income	—	—		—			—			1,425			—			—			1,425
Dividend declared ($1.1800 per share)	—	—		—			(19,540		)	—			—			—			(19,540		)
Dividend reinvestment plan	—	—		(3		)	—			—			—			—			(3		)
Share-based compensation and tax benefit ⁽³⁾ ⁽⁴⁾	25,231	13		1,788			—			—			—			—			1,801
Treasury stock activities	—	—		—			—			—			651			(651		)	—
Balance at September 30, 2019	16,403,776	$	7,984	$	257,436		$	284,694		$	(5,403	)	$	4,505		$	(4,505	)	$	544,711


(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 94,923 shares at September 30, 2019, 97,053 shares at December 31, 2018, 96,622 shares at September 30, 2018 and 90,961 shares at December 31, 2017, respectively, held in a Rabbi Trust related to our Non-Qualified Deferred Compensation Plan.


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


(4)	The shares issued under the SICP are net of shares withheld for employee taxes. For the nine months ended September 30, 2019 and 2018, we withheld 7,635 and 16,918 shares, respectively, for employee taxes.

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

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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, 2018. 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.

Beginning in the third quarter of 2019, management began executing a strategy to sell the operating assets of PESCO. In connection with this strategy, during the third quarter of 2019, we reached agreements with three entities to sell PESCO's assets and contracts. Two transactions closed in October 2019 and one transaction closed in November 2019 with subsequent closings scheduled for December 2019 and January 2020. As a result of the sale, we are fully exiting the natural gas marketing business. Accordingly, PESCO’s historical financial results are reflected in our condensed consolidated financial statements as discontinued operations, which required retrospective application to financial information for all periods presented. Refer to Note 3, Discontinued Operations for further information.

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.

Except for the completion of the sale of certain PESCO's assets and contracts on October 1, 2019, as discussed in Note 3, Discontinued Operations and the settlement of Chesapeake Pension Plan obligations, see Note 10, Employee Benefit Plans, no events have occurred subsequent to the balance sheet date that would require recognition or disclosure in the condensed consolidated financial statements. We have evaluated subsequent events for recognition or disclosure through November 6, 2019, the date the financial statements were available to be issued.

Marlin Gas Transport and Ohl Fuel Oil Acquisitions

In December 2018, Marlin Gas Services acquired certain operating assets of Marlin Gas Transport. The acquisition allows us to offer solutions to supply interruption scenarios and other situations where pipeline supplies are unavailable or inadequate to meet customer requirements.

In December 2018, Sharp acquired certain propane operating assets and customers of R. F. Ohl Fuel Oil, Inc. ("Ohl"), which provides propane distribution service to approximately 2,500 residential and commercial customers in Pennsylvania.

We accounted for the purchases of the operating assets of Marlin Gas Transport and Ohl, which totaled approximately $18.4 million, as business combinations within our Unregulated Energy segment. Goodwill of $4.8 million, related to the Marlin Gas Transport acquisition, and $1.5 million, associated with the Ohl acquisition, were initially recorded at the close of these transactions. In 2019, we recorded a reduction to the purchase price for Ohl of $0.2 million upon completing our inspection of the assets purchased. The purchase price adjustment was recorded as a reduction in our property, plant and equipment balance. The amounts recorded in conjunction with these acquisitions are preliminary and subject to adjustment based on additional valuations performed during the measurement period. Due to the timing of these acquisitions, the revenue and operating income from these acquisitions in 2018 were immaterial. For the quarter and nine months ended September 30, 2019, these acquisitions generated the following operating revenue and income:

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	Three Months Ended September 30, 2019					Nine Months Ended September 30, 2019
	Operating Revenue		Operating Income			Operating Revenue		Operating Income
(in thousands)
Marlin Gas Services	$	1,059	$	68		$	4,601	$	1,491
Ohl propane acquisition	$	149	$	(35	)	$	1,146	$	177

FASB Statements and Other Authoritative Pronouncements

Recently Adopted Accounting Standards

Leases (ASC 842) - In February 2016, the FASB issued ASU 2016-02, Leases, which requires lessees to recognize leases on the balance sheet and disclose key information about leasing arrangements. The standard establishes a right of use model that requires a lessee to recognize a right of use asset and lease liability for all leases with a term greater than 12 months. The update also expands the required quantitative and qualitative disclosures surrounding leases. ASC 842 was subsequently amended by ASU No. 2018-01, Land Easement Practical Expedient for Transition to Topic 842; ASU No. 2018-10, Codification Improvements to Topic 842, Leases; ASU No. 2018-11, Targeted Improvements; and ASU No. 2019-01, Codification Improvements. We adopted ASU 2016-02 and the related amendments on January 1, 2019, and used the optional transition method for all existing leases. The optional transition method enabled us to adopt the new standard as of the beginning of the period of adoption and did not require restatement of prior period financial information. As a result, prior period financial information was not recast and continues to be reported under the accounting guidance effective during those periods.

At adoption, we elected the following practical expedients: (1) the ‘package of practical expedients,’ pursuant to which we did not need to reassess our prior conclusions about lease identification, lease classification and initial direct costs, (2) the ‘use-of-hindsight’ practical expedient, which allowed us to use hindsight in assessing impairment of our existing land easements, (3) the creation of an accounting policy for short-term leases resulting in lease payments being recorded as an expense on a straight-line basis over the lease term, and (4) the aggregation, rather than separation, of the lease and non-lease components for all leases.

See Note 16, Leases, for additional information with respect to the impact of the adoption of the lease accounting guidance and the disclosures required by ASU 2016-02 and the related amendments.

Compensation - Stock Compensation (ASC 718) - In June 2018, the FASB issued ASU 2018-07, Improvements to Nonemployee Share-Based Payment Accounting, which expands the scope of Topic 718 to include share-based payment transactions for acquiring goods and services from nonemployees. We adopted ASU 2018-07 on January 1, 2019. Implementation of this new standard did not have a material impact on our financial position or results of operations.

Recent Accounting Standards Yet to be Adopted

Financial Instruments - Credit Losses (ASC 326) - In June 2016, the FASB issued ASU 2016-13, Measurement of Credit Losses on Financial Instruments, which changes how entities account for credit losses for most financial assets and certain other instruments, and subsequent guidance which served to clarify or amend the original standard. ASU 2016-13 and the related amendments require entities to estimate lifetime expected credit losses for trade receivables and to provide additional disclosure related to credit losses. ASU 2016-13 will be effective for our annual and interim financial statements beginning in January 1, 2020 and is not expected to have a material impact on our financial position or results of operations.

Intangibles - Goodwill (ASC 350) - In January 2017, the FASB issued ASU 2017-04, Simplifying the Test for Goodwill Impairment, which simplifies how an entity is required to test goodwill for impairment by eliminating Step 2 from the goodwill impairment test. ASU 2017-04 will be effective for our annual and interim financial statements beginning January 1, 2020, although early adoption is permitted. The amendments included in this ASU are to be applied prospectively, and is not expected to have a material impact on our financial position or results of operations.

Fair Value Measurement (ASC 820) - In August 2018, the FASB issued ASU 2018-13, Disclosure Framework - Changes to the Disclosure Requirements for Fair Value Measurement, which removes, modifies and adds certain disclosure requirements on fair value measurements in ASC 820. ASU 2018-13 will be effective for our annual and interim financial statements beginning January 1, 2020 and, since the changes only impact disclosures, will not have a material impact on our financial position or results of operations.

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2.	Calculation of Earnings Per Share



	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
(in thousands, except shares and per share data)
Calculation of Basic Earnings Per Share:
Income from Continuing Operations	$	6,245		$	6,090		$	43,977		$	39,118
Loss from Discontinued Operations	(624		)	(552		)	(1,388		)	(339		)
Net Income	$	5,621		$	5,538		$	42,589		$	38,779

Weighted average shares outstanding	16,403,776			16,378,545			16,396,646			16,366,608
Earnings from Continuing Operations	$	0.38		$	0.37		$	2.68		$	2.39
Earnings from Discontinued Operations	(0.04		)	(0.03		)	(0.08		)	(0.02		)
Basic Earnings Per Share	$	0.34		$	0.34		$	2.60		$	2.37


Calculation of Diluted Earnings Per Share:
Reconciliation of Numerator:
Income from Continuing Operations	$	6,245		$	6,090		$	43,977		$	39,118
Loss from Discontinued Operations	(624		)	(552		)	(1,388		)	(339		)
Net Income	$	5,621		$	5,538		$	42,589		$	38,779

Reconciliation of Denominator:
Weighted shares outstanding—Basic	16,403,776			16,378,545			16,396,646			16,366,608
Effect of dilutive securities—Share-based compensation	50,091			49,894			47,585			49,647
Adjusted denominator—Diluted	16,453,867			16,428,439			16,444,231			16,416,255
Diluted Earnings Per Share from Continuing Operations	$	0.38		$	0.37		$	2.67		$	2.38
Diluted Earnings Per Share from Discontinued Operations	(0.04		)	(0.03		)	(0.08		)	(0.02		)
Diluted Earnings Per Share	$	0.34		$	0.34		$	2.59		$	2.36


3.	Discontinued Operations

In September of 2019, we initiated a plan to sell a majority of the assets of PESCO, our natural gas marketing subsidiary. This was done in an effort to enable us to focus on the strategies that support our core energy delivery business. To date, we have executed the following three separate transactions to sell PESCO’s assets and contracts:


•	PESCO’s Florida retail operations were sold to Gas South. The initial closing for the transaction was completed in November 2019 with subsequent closings expected for December 2019 and January 2020.


•	PESCO’s other non-Florida retail operations and contracts were sold to UET in October 2019.


•	PESCO’s Mid-Atlantic wholesale contracts and Chesapeake Utilities’ Delaware division, Maryland division and Sandpiper Energy asset management agreements were sold to NJRES in October 2019.

In addition to these transactions, we are actively marketing PESCO’s producer services portfolio and are targeting a sale by the end of 2019. We expect to recognize a pre-tax gain ranging from $5.0 million to $7.0 million in connection with the closing of the three transactions during the fourth quarter of 2019.

As a result of the sales agreements, we began to report PESCO as discontinued operations during the third quarter of 2019, we began to exclude PESCO's performance from continuing operations and segment results for all periods presented

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and classified its assets and liabilities as held for sale. The assets and liabilities of PESCO are presented as current and noncurrent assets and liabilities of a business held for sale in the condensed consolidated balance sheets.

Additionally, amounts for operating revenues and costs of sales which had previously been eliminated in consolidation related to intercompany sales and purchases have been grossed up and are now reflected as a component of operating revenues and costs of sales for all periods presented. We have recast these amounts because upon completion of the sales transactions, we will continue to provide and receive services from the buyers.

A summary of discontinued operations presented in the condensed consolidated statements of income includes the following:



	Three Months Ended						Nine Months Ended
	September 30,						September 30,
(in thousands)	2019 ⁽¹⁾			2018 ⁽²⁾			2019 ⁽¹⁾			2018 ⁽²⁾
Operating revenues	$	34,271		$	51,619		$	152,573		$	181,976
Cost of sales	33,763			50,888			149,464			177,463
Other operating expenses	1,361			1,574			4,818			4,791
Operating loss	(853		)	(843		)	(1,709		)	(278		)
Interest and other expense	75			80			243			248
Loss from Discontinued Operations before income taxes	(928		)	(923		)	(1,952		)	(526		)
Income tax benefit	(304		)	(371		)	(564		)	(187		)
Loss from Discontinued Operations, net of tax	$	(624	)	$	(552	)	$	(1,388	)	$	(339	)

⁽¹⁾ Included in operating revenues and cost of sales for the three and nine months ended September 30, 2019, is $4.3 million and $19.1 million respectively, representing amounts which had been previously eliminated in consolidation related to intercompany activity that will continue with the buyers after the disposition of the assets of PESCO.

⁽²⁾Included in operating revenues and cost of sales for the three and nine months ended September 30, 2018 is $4.7 million and $22.1 million respectively, representing amounts which had been previously eliminated in consolidation related to intercompany activity that will continue with the buyers after the disposition of the assets of PESCO.

The assets and liabilities of the discontinued operations classified as held for sale in the condensed consolidated balance sheet include the following:



	September 30,			December 31,
(in thousands)	2019			2018
Property, plant and equipment	$	1,203		$	1,242
Less: accumulated depreciation	(334		)	(206		)
Net property, plant and equipment ⁽¹⁾	869			1,036
Current assets	21,155			52,681
Deferred charges and other assets ⁽¹⁾	6,310			6,626
Assets of Discontinued Operations held for sale	$	28,334		$	60,343

Current liabilities	$	18,110		$	48,672
Liabilities of Discontinued Operations held for sale	$	18,110		$	48,672
Net assets	$	10,224		$	11,671

⁽¹⁾ These balances have been combined within the condensed consolidated balance sheets to arrive at non-current assets held for sale.

We have elected not to separately disclose discontinued operations on the condensed consolidated statement of cash flows. The following table summarizes significant statement of cash flow data related to the discontinued operations of PESCO:

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	Nine Months Ended
	September 30,
(in thousands)	2019		2018
Depreciation and amortization	$	437	$	437
Property, plant and equipment expenditures	$	—	$	72
Deferred income taxes	$	513	$	403
Realized gain on commodity contracts	$	623	$	3,295

Our Delmarva Peninsula natural gas distribution operations had asset management agreements with PESCO to manage their natural gas transportation and storage capacity. The agreements were effective as of April 1, 2017, and each expire on March 31, 2020. As a result of the sale of the assets of PESCO, effective October 1, 2019, these agreements are now managed by NJRES through the remainder of the contract term. In addition to the asset management agreements, our Eastern Shore subsidiary had several firm transportation and capacity arrangements with PESCO which were included in the assets sold to UET. Eastern Shore will continue to fulfill these arrangements throughout the remainder of their contractual term. These agreements currently have expiration dates of March 31, 2020 and November 30, 2021.

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 revenues in the following tables exclude operating revenues from PESCO that are now reflected as discontinued operations. The following table displays our revenue from continuing operations by major source based on product and service type for the three months ended September 30, 2019 and 2018:

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	Three months ended September 30, 2019												Three Months Ended September 30, 2018
(in thousands)	Regulated Energy			Unregulated Energy			Other and Eliminations			Total			Regulated Energy			Unregulated Energy			Other and Eliminations			Total
Energy distribution
Delaware natural gas division	$	6,953		$	—		$	—		$	6,953		$	7,010		$	—		$	—		$	7,010
Florida natural gas division	6,710			—			—			6,710			6,282			—			—			6,282
FPU electric distribution	24,174			—			—			24,174			23,830			—			—			23,830
FPU natural gas distribution	17,908			—			—			17,908			17,390			—			—			17,390
Maryland natural gas division	2,634			—			—			2,634			2,463			—			—			2,463
Sandpiper natural gas/propane operations	3,673			—			—			3,673			3,561			—			—			3,561
Total energy distribution	62,052			—			—			62,052			60,536			—			—			60,536

Energy transmission
Aspire Energy	—			4,247			—			4,247			—			5,750			—			5,750
Eastern Shore	17,573			—			—			17,573			16,189			—			—			16,189
Peninsula Pipeline	4,442			—			—			4,442			3,404			—			—			3,404
Total energy transmission	22,015			4,247			—			26,262			19,593			5,750			—			25,343

Energy generation
Eight Flags	—			4,027			—			4,027			—			4,044			—			4,044

Propane operations
Propane delivery operations	—			13,805			—			13,805			—			17,338			—			17,338

Energy delivery services
Marlin Gas Services	—			1,059			—			1,059			—			—			—			—

Other and eliminations
Eliminations	(9,487		)	(1,254		)	(4,367		)	(15,108		)	(7,359		)	(3,185		)	(3,928		)	(14,472		)
Other	—			395			134			529			—			476			135			611
Total other and eliminations	(9,487		)	(859		)	(4,233		)	(14,579		)	(7,359		)	(2,709		)	(3,793		)	(13,861		)

Total operating revenues⁽¹⁾	$	74,580		$	22,279		$	(4,233	)	$	92,626		$	72,770		$	24,423		$	(3,793	)	$	93,400

⁽¹⁾ Total operating revenues for the three months ended September 30, 2019, include other revenue (revenues from sources other than contracts with customers) of $0.1 million and $0.1 million for our Regulated and Unregulated Energy segments, respectively, and $0.5 million and $0.1 million for our Regulated and Unregulated Energy segments, respectively, for the three months ended September 30, 2018. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the Maryland division and Sandpiper and late fees.

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The following table displays our revenue from continuing operations by major source based on product and service type for the nine months ended September 30, 2019 and 2018:



	Nine months ended September 30, 2019												Nine months ended September 30, 2018
(in thousands)	Regulated Energy			Unregulated Energy			Other and Eliminations			Total			Regulated Energy			Unregulated Energy			Other and Eliminations			Total
Energy distribution
Delaware natural gas division	$	42,758		$	—		$	—		$	42,758		$	50,963		$	—		$	—		$	50,963
Florida natural gas division	21,625			—			—			21,625			18,462			—			—			18,462
FPU electric distribution	59,016			—			—			59,016			60,933			—			—			60,933
FPU natural gas distribution	60,357			—			—			60,357			58,885			—			—			58,885
Maryland natural gas division	15,867			—			—			15,867			17,136			—			—			17,136
Sandpiper natural gas/propane operations	14,237			—			—			14,237			16,892			—			—			16,892
Total energy distribution	213,860			—			—			213,860			223,271			—			—			223,271

Energy transmission
Aspire Energy	—			23,139			—			23,139			—			23,682			—			23,682
Eastern Shore	54,368			—			—			54,368			46,289			—			—			46,289
Peninsula Pipeline	11,573			—			—			11,573			8,469			—			—			8,469
Total energy transmission	65,941			23,139			—			89,080			54,758			23,682			—			78,440

Energy generation
Eight Flags	—			12,405			—			12,405			—			12,652			—			12,652

Propane operations
Propane delivery operations	—			76,947			—			76,947			—			89,648			—			89,648

Energy delivery services
Marlin Gas Services	—			4,601			—			4,601			—			—			—			—

Other and eliminations
Eliminations	(28,200		)	(9,377		)	(13,351		)	(50,928		)	(25,362		)	(11,679		)	(12,864		)	(49,905		)
Other	—			1,270			395			1,665			—			1,475			521			1,996
Total other and eliminations	(28,200		)	(8,107		)	(12,956		)	(49,263		)	(25,362		)	(10,204		)	(12,343		)	(47,909		)

Total operating revenues⁽¹⁾	$	251,601		$	108,985		$	(12,956	)	$	347,630		$	252,667		$	115,778		$	(12,343	)	$	356,102

⁽¹⁾ Total operating revenues for the nine months ended September 30, 2019, include other revenue (revenues from sources other than contracts with customers) of $(0.1) million and $0.3 million for our Regulated and Unregulated Energy segments, respectively, and $(0.4) million and $0.2 million for our Regulated and Unregulated Energy segments, respectively, for the nine months ended September 30, 2018. The sources of other revenues include revenue from alternative revenue programs related to revenue normalization for the Maryland division and Sandpiper and late fees.

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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 September 30, 2019 and December 31, 2018 were as follows:



	Trade Receivables			Contract Assets (Current)		Contract Assets (Non-current)		Contract Liabilities (Current)
(in thousands)
Balance at 12/31/2018	$	52,140		$	—	$	2,614	$	480
Balance at 9/30/2019	33,205			18		3,255		774
Increase (decrease)	$	(18,935	)	$	18	$	641	$	294

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

At times, we receive advances or deposits from our customers before we satisfy our performance obligation, resulting in contract liabilities. Contract liabilities are included in other accrued liabilities in the condensed consolidated balance sheets and relate to non-refundable prepaid fixed fees for our Mid-Atlantic propane delivery operation's retail offerings. Our performance obligation is satisfied over the term of the respective retail offering plan on a ratable basis. For the three months ended September 30, 2019 and 2018, we recognized revenue of $0.2 million and $0.1 million, respectively. For the nine months ended September 30, 2019 and 2018, we recognized revenue of $0.7 million and $0.4 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 September 30, 2019, are expected to be recognized as follows:



(in thousands)	2019		2020		2021		2022		2023		2024		2025 and thereafter
Eastern Shore and Peninsula Pipeline	$	9,603	$	36,628	$	33,293	$	26,349	$	20,923	$	18,744	$	192,842
Natural gas distribution operations	1,009		3,646		3,964		5,007		4,609		4,587		31,172
FPU electric distribution	74		297		297		109		—		—		—
Total revenue contracts with remaining performance obligations	$	10,686	$	40,571	$	37,554	$	31,465	$	25,532	$	23,331	$	224,014


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, our intrastate pipeline subsidiary, is subject to regulation (excluding cost of service) by the Florida PSC.

Delaware

Effect of the TCJA on Customers: On January 31, 2019, the Delaware PSC approved the as-filed Delaware Division Delivery Service Rates reflecting the impact of the TCJA. The new rates went into effect March 1, 2019. The refunds, which were retroactive to February 2018, were completed prior to the mandated deadline of June 30, 2019. The order also provided for a line item billing credit that went into effect on April 1, 2019, for the return of the excess accumulated

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deferred income taxes ("ADIT"). Additional information on the TCJA impact is included in the table at the end of this Note 5, Rates and Other Regulatory Activities.

CGS: In August 2019, we filed with the Delaware PSC an application seeking an order that will establish the regulatory accounting treatment and valuation methodology for the acquisition of propane CGS owned by our affiliate, Sharp and the conversion of the CGS to natural gas service. We propose to acquire each CGS one at a time and to pay replacement cost for each CGS system. In addition, we are requesting authorization to pay for and capitalize the CGS residents’ behind-the-meter conversion costs. Our existing natural gas customers will be protected against subsidizing the acquisitions and conversions of the CGS systems because we will complete only those systems that meet our economic test. On September 26, 2019, the Delaware PSC issued an order to open a docket for the purpose of reviewing our application and to conduct evidentiary hearings on the matter.

Florida

Electric Limited Proceeding-Storm Recovery (Pre-Hurricane Michael): In February 2018, FPU filed a petition with the Florida PSC, requesting recovery of incremental storm restoration costs related to several hurricanes and tropical storms, along with the replenishment of the storm reserve to its pre-storm level of $1.5 million. As a result of these hurricanes and tropical storms, FPU’s storm reserve was depleted and, at the time of this filing, had a deficit of $0.8 million. This matter went to hearing in December 2018 and was subsequently approved at the March 5, 2019 Agenda with the Final Order issued on March 25, 2019. FPU received approval to begin a surcharge of $1.54 per 1,000-kilowatt hour on customer bills for two years beginning in April 2019, to recover storm-related costs and replenish the storm reserve.

Hurricane Michael: In October 2018, Hurricane Michael passed through FPU's electric distribution operation's service territory in Northwest Florida. The hurricane caused widespread and severe damage to FPU's infrastructure resulting in 100 percent of its customers in the Northwest Florida service territory losing electrical service. FPU, after exerting extraordinary hurricane restoration efforts, restored service to those customers who were able to accept it. FPU expended more than $65.0 million to restore service, which has been recorded as new plant and equipment, charged against FPU’s accumulated depreciation or charged against FPU’s storm reserve. In conjunction with the hurricane-related expenditures, we executed two 13-month unsecured term loans as temporary financing, each in the amount of $30 million. The interest cost associated with these loans is the one-month LIBOR rate plus 75 points. One of the term loans was executed in December 2018; the other was executed in January 2019.

In August 2019, FPU filed a limited proceeding requesting recovery of storm-related costs associated with Hurricane Michael (capital and expenses) through a change in base rates. FPU also requested treatment and recovery of certain storm-related costs as regulatory asset for items currently not allowed to be recovered through the storm reserve as well as the recovery of capital replaced as a result of the storm. Recovery of these costs includes a component of an overall return on capital additions and regulatory assets. In the fourth quarter of 2019, FPU along with the Office of Public Counsel in Florida, filed a joint motion with the Florida PSC to approve an interim rate increase, subject to refund, pending the final ruling on the recovery of the restoration costs incurred. The petition was approved by the Florida PSC on November 5, 2019 and interim rate increases will be effective January 2, 2020. While there is a short-term negative impact, the storm is not expected to have a significant impact on our financial results going forward, assuming permanent recovery is granted through the regulatory process.

Effect of the TCJA on Customers: In February 2018, the Florida PSC opened dockets to consider the impacts associated with the TCJA. In May 2018, FPU’s natural gas divisions filed petitions and supporting testimony regarding the disposition of the related impacts of the TCJA. Hearings on this matter took place in November 2018, and the staff's recommendation was approved by the Florida PSC at the February 5, 2019 Agenda. Final orders were issued on February 25, 2019. Staff’s recommendations are summarized in the table at the end of this Note 5, Rates and Other Regulatory Activities.

Imbalance Petition: In February 2019, FPU filed a petition, with the Florida PSC, to modify the pool manager cash out tiers and respective cash out rates. With this petition, FPU further facilitates consistency across the Florida business units and eliminates the unintentional arbitrage opportunity created by the tariff. The petition does not have a financial impact for FPU, and it will benefit customers by lowering costs. This petition was approved by the Florida PSC at the April 2, 2019 Agenda.

Electric Depreciation Study: In September 2019, FPU filed a petition, with the Florida PSC, for approval of its consolidated electric depreciation rates. The new rates will be effective January 1, 2020. The petition is currently scheduled for review for approval at the Florida PSC February 2020 Agenda.

Natural Gas Depreciation Study: In March 2019, FPU filed a petition, with the Florida PSC, for approval of its consolidated natural gas depreciation rates. The petition was approved by the Florida PSC at Agenda on October 3, 2019. The new

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rates were effective retroactive to January 1, 2019, and are expected to decrease depreciation expense by approximately $0.9 million annually.

Auburndale Project: In June 2019, Peninsula Pipeline filed with the Florida PSC for approval of its Transportation Service Agreement with the Florida Division of Chesapeake Utilities. Peninsula Pipeline will purchase existing pipeline owned by the Florida Division of Chesapeake Utilities and Calpine and construct pipeline facilities in Polk County, Florida. Peninsula Pipeline will provide transportation service to the Florida Division of Chesapeake Utilities increasing both delivery capacity and downstream pressure as well as introducing a secondary source of natural gas for the Florida Division of Chesapeake Utilities' distribution system. The petition was approved by the Florida PSC at the August 6, 2019 Agenda. The project was placed in service in the third quarter of 2019.

Palm Beach Expansion Project: In June 2019, Peninsula Pipeline filed with the Florida PSC for approval of its Transportation Service Agreement with FPU. Peninsula Pipeline will construct several new interconnection points and pipeline expansions in Palm Beach County, Florida, which will enable FPU to serve an industrial research park and several new residential developments. Peninsula Pipeline will provide transportation service to FPU, increasing reliability, system pressure as well as introducing diversity in fuel source for natural gas to serve the increased demand in these areas. The petition was approved by the Florida PSC at the August 6, 2019 Agenda. Interim services were offered beginning in the third quarter of 2019.

Callahan Pipeline, Nassau County: On July 19, 2019, Peninsula Pipeline filed a petition for approval of the firm transportation service agreement with FPU as well as the restructuring of the business and operational agreements between Peoples Gas ("PGS"), FPU and Seacoast Gas Transmission. Peninsula Pipeline will construct and jointly own 26 miles of 16 inch steel pipeline with Seacoast Gas Transmission and interconnect to the Cypress Pipeline interstate system in western Nassau County. The Callahan pipeline will terminate into the existing Peninsula Pipeline-PGS jointly owned pipeline, which serves Amelia Island and the PGS distribution system. Callahan pipeline will enhance FPU’s ability to expand service into Nassau County and will enable PGS to enhance its system pressure and reliability of its service in Duval County. This petition is currently scheduled for review for approval by the Florida PSC at the December 3, 2019 Agenda.

Maryland Division and Sandpiper

There were no material regulatory matters during the quarter.

Eastern Shore

Del-Mar Energy Pathway Project: In September 2018, Eastern Shore filed a Certificate Application with the FERC, requesting authorization to construct and operate the Del-Mar Energy Pathway project, which will provide an additional 14,300 Dts/d of firm service to four customers. Facilities to be constructed include six miles of pipeline looping in Delaware; 13 miles of new mainline extension in Sussex County, Delaware and Somerset County, Maryland; and new pressure control and delivery stations in these counties. The benefits of this project include: (i) additional natural gas transmission pipeline infrastructure in eastern Sussex County, Delaware, and (ii) extension of Eastern Shore’s pipeline system, for the first time, into Somerset County, Maryland. During the fourth quarter of 2018, the FERC held a full project area scoping meeting in Sussex County, Delaware and issued a Notice of Schedule for Environmental Review. The Environmental Assessment for the Del-Mar Energy Pathway project was issued on April 1, 2019. As of the date of this filing, final FERC authorization is still pending.

Renewable Natural Gas Tariff: On October 16, 2019, Eastern Shore filed an application with the FERC to include renewable natural gas (biogas) utilization and standards in its tariff with a proposed effective date of November 1, 2019. Eastern Shore is proposing changes to its gas quality specifications that will enable it to accommodate renewable natural gas at various receipt points on its system. Changes to the gas quality specifications will ensure interchangeability of renewable natural gas with the natural gas currently delivered to Eastern Shore. This application is expected to be approved by the FERC in 30 days absent opposing comments.

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Summary TCJA Table

The following table summarizes the TCJA impact on our regulated businesses:



	Regulatory Liabilities related to ADIT
Operation and Regulatory Jurisdiction	Amount (in thousands)	Status	Status of Customer Rate impact related to lower federal corporate income tax rate
Eastern Shore (FERC)	$34,190	Will be addressed in Eastern Shore's next rate case filing.	Implemented one-time bill credit (totaling $0.9 million) in April 2018. Customer rates were adjusted in April 2018.
Delaware Division (Delaware PSC)	$12,877	PSC approved amortization of ADIT in January 2019.	Implemented one-time bill credit (totaling $1.5 million) in April 2019. Customer rates were adjusted in March 2019.
Maryland Division (Maryland PSC)	$4,115	PSC approved amortization of ADIT in May 2018.	Implemented one-time bill credit (totaling $0.4 million) in July 2018. Customer rates were adjusted in May 2018.
Sandpiper Energy (Maryland PSC)	$3,778	PSC approved amortization of ADIT in May 2018.	Implemented one-time bill credit (totaling $0.6 million) in July 2018. Customer rates were adjusted in May 2018.
Chesapeake Florida Gas Division/Central Florida Gas (Florida PSC)	$8,289	PSC issued order authorizing amortization and retention of net ADIT liability by the Company in February 2019.	Florida PSC's final order was issued in February 2019. Excluding GRIP, tax savings arising from the TCJA rate reduction will be retained by the Company. GRIP: Tax savings for 2018 will be refunded to customers in 2020 through the annual GRIP cost recovery mechanism. Future customer GRIP surcharges will be adjusted to reflect tax savings associated with TCJA.
FPU Natural Gas (excludes Fort Meade and Indiantown) (Florida PSC)	$19,168	Same treatment on a net basis as Chesapeake Florida Gas Division (above).	Same treatment on a net basis as Chesapeake Florida Gas Division (above).
FPU Fort Meade and Indiantown Divisions	$295	Same treatment on a net basis as Chesapeake Florida Gas Division (above).	Tax rate reduction: The impact was immaterial for the divisions. GRIP (Applicable to Fort Meade division only): Same treatment as Chesapeake Florida Gas Division (above).
FPU Electric (Florida PSC)	$5,789	In January 2019, PSC issued order approving amortization of ADIT through purchased power cost recovery, storm reserve and rates.	TCJA benefit will flow back to its customers through a combination of reductions to the fuel cost recovery rate, base rates, as well as application to the storm reserve over the next several years.

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. We are also in discussions with the Maryland Department of Environment ("MDE") regarding another former MGP site located in Cambridge, Maryland.

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As of September 30, 2019 and December 31, 2018, we had approximately $8.3 million and $9.1 million, respectively, in environmental liabilities related to FPU’s MGP sites in Key West, Pensacola, Sanford and West Palm Beach. FPU has approval to recover, from insurance and through customer rates, up to $14.0 million of its environmental costs related to its MGP sites. As of September 30, 2019 and December 31, 2018, we had recovered approximately $11.8 million and $11.5 million, respectively, leaving approximately $2.2 million and $2.5 million, respectively, in regulatory assets for future recovery of environmental costs from FPU’s customers.

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

The following is a summary of our remediation status and estimated costs to implement clean-up of our key MGP sites:



MGP Site (Jurisdiction)	Status	Estimated Cost to Clean up (Expect to Recover through Rates with Customers)
West Palm Beach (Florida)	Remedial actions approved by the Florida Department of Environmental Protection have been implemented on the east parcel of the site. We expect to implement similar remedial actions on the site's west parcel in 2019.	Between $4.5 million to $15.4 million, including costs associated with the relocation of FPU’s operations at this site, and any potential costs associated with future redevelopment of the properties.
Sanford (Florida)	In March 2018, the United States Environmental Protection Agency ("EPA") approved a "site-wide ready for anticipated use" status, which is the final step before delisting a site. Construction has been completed and restrictive covenants are in place to ensure protection of human health. The only remaining activity is long-term groundwater monitoring.	FPU's remaining remediation expenses, including attorneys' fees and costs, are anticipated to be immaterial.
Winter Haven (Florida)	Remediation is ongoing.	Not expected to exceed $0.4 million.
Seaford (Delaware)	Conducted investigations of on-site and off-site impacts in the vicinity of the site, from 2014 through 2018, and submitted the findings to Delaware Department of Natural Resources and Environmental Control ("DNREC") in a March 2019 report. An interim action involving air-sparging/vapor extraction is being implemented, in accordance with the DNREC-approved Work Plan.	Between $0.2 million and $0.5 million.
Cambridge (Maryland)	Currently in discussions with the MDE.	Unable to estimate.


7.	Other Commitments and Contingencies

Natural Gas and Electric

In May 2019, FPU natural gas distribution operations and Eight Flags entered into separate asset management agreements with Emera Energy Services, Inc. to manage their natural gas transportation capacity. Long-term agreements will

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commence on or about July 2020, and each has a 10-year term. Short-term agreements were entered for a one year term beginning July 2019 through July 2020.

Chesapeake Utilities' Florida Division has firm transportation service contracts with Florida Gas Transmission Company ("FGT") and Gulfstream. Pursuant to a capacity release program approved by the Florida PSC, all of the capacity under these agreements has been released to various third parties. 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 September 30, 2019, FPU was in compliance with all of the requirements of its fuel supply contracts.

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

Corporate Guarantees

We have issued corporate guarantees to certain vendors of our subsidiaries. As of September 30, 2019 the majority of our corporate guarantees were related to the operations of PESCO. These corporate guarantees provided for the payment of natural gas purchases in the event that PESCO defaults. PESCO has never defaulted on its obligations to pay its suppliers. The liabilities for these purchases are recorded when incurred. The aggregate amount guaranteed at September 30, 2019 was approximately $72.4 million, with the guarantees expiring on various dates through December 31, 2020.

As a result of the sale of assets and contracts for PESCO, corporate guarantees and letters of credit associated with PESCO totaling $69.0 million will be terminated or expire without being renewed. See Note 3, Discontinued Operations, for additional details on the sale of PESCO.

Chesapeake Utilities also guarantees the payment of FPU’s first mortgage bonds. The maximum exposure under this guarantee is the outstanding principal plus accrued interest balances. The outstanding principal balances of FPU’s first mortgage bonds approximate their carrying values (see Note 15, Long-Term Debt, for further details).


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.

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•

Unregulated Energy. Includes energy transmission, energy generation (the operations of our Eight Flags' CHP plant), propane operations, and the new mobile compressed natural gas distribution and pipeline solutions subsidiary. Also included in this segment are other unregulated energy services, such as energy-related merchandise sales and heating, ventilation and air conditioning, plumbing and electrical services. These operations are unregulated as to their rates and services. Effective in the third quarter of 2019, the natural gas marketing and related services subsidiary (PESCO), previously reported in the Unregulated Energy segment, are reflected in discontinued operations. See Note 3, Discontinued Operations for additional details of the sale of PESCO.

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

The following table presents financial information about our reportable segments:



	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
(in thousands)
Operating Revenues, Unaffiliated Customers
Regulated Energy	$	74,027		$	72,187		$	249,978		$	251,259
Unregulated Energy	18,599			21,213			97,652			104,843
Total operating revenues, unaffiliated customers	$	92,626		$	93,400		$	347,630		$	356,102
Intersegment Revenues ⁽¹⁾
Regulated Energy	$	553		$	583		$	1,623		$	1,408
Unregulated Energy	3,682			3,210			11,332			10,935
Other businesses	132			135			396			521
Total intersegment revenues	$	4,367		$	3,928		$	13,351		$	12,864
Operating Income
Regulated Energy	$	17,540		$	15,915		$	65,310		$	56,930
Unregulated Energy	(3,168		)	(3,090		)	11,316			10,519
Other businesses and eliminations	(14		)	54			18			(1,481		)
Operating income	14,358			12,879			76,644			65,968
Other expense, net	(350		)	(4		)	(729		)	(168		)
Interest charges	5,403			4,357			16,583			11,764
Income from Continuing Operations before Income Taxes	8,605			8,518			59,332			54,036
Income Taxes on Continuing Operations	2,360			2,428			15,355			14,918
Income from Continuing Operations	$	6,245		$	6,090		$	43,977		$	39,118
Loss from Discontinued Operations, net of tax	(624		)	(552		)	(1,388		)	(339		)
Net Income	$	5,621		$	5,538		$	42,589		$	38,779

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



(in thousands)	September 30, 2019		December 31, 2018
Identifiable Assets ⁽¹⁾
Regulated Energy segment	$	1,384,057	$	1,345,805
Unregulated Energy segment ⁽¹⁾	250,849		245,702
Other businesses and eliminations	51,000		41,821
Total identifiable assets ⁽¹⁾	$	1,685,906	$	1,633,328

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⁽¹⁾ Excludes assets held for sale related to the sale of assets and contracts for PESCO.


9.	Stockholder's Equity

Accumulated Other Comprehensive Loss

Defined benefit pension and postretirement plan items, unrealized gains (losses) of our propane swap agreements and natural gas swaps and futures contracts, designated as commodity contracts cash flow hedges, are the components of our accumulated other comprehensive loss. The following tables present the changes in the balance of accumulated other comprehensive (loss)/income as of September 30, 2019 and 2018. All amounts except the stranded tax reclassification are presented net of tax.



	Defined Benefit			Commodity
	Pension and			Contracts
	Postretirement			Cash Flow
	Plan Items			Hedges			Total
(in thousands)
As of December 31, 2018	$	(5,928	)	$	(785	)	$	(6,713	)
Other comprehensive income (loss) before reclassifications	(80		)	1,780			1,700
Amounts reclassified from accumulated other comprehensive income (loss)	312			(587		)	(275		)
Net current-period other comprehensive income	232			1,193			1,425
Prior-year reclassification	—			(115		)	(115		)
As of September 30, 2019	$	(5,696	)	$	293		$	(5,403	)



(in thousands)
As of December 31, 2017	$	(4,743	)	$	471		$	(4,272	)
Other comprehensive loss before reclassifications	—			(1,126		)	(1,126		)
Amounts reclassified from accumulated other comprehensive income	275			1,043			1,318
Net prior-period other comprehensive income/(loss)	275			(83		)	192
Stranded tax reclassification to retained earnings	(1,022		)	115			(907		)
As of September 30, 2018	$	(5,490	)	$	503		$	(4,987	)

The following table presents amounts reclassified out of accumulated other comprehensive loss for the three and nine months ended September 30, 2019 and 2018. Deferred gains or losses for our commodity contracts cash flow hedges are recognized in earnings upon settlement.

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	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
(in thousands)
Amortization of defined benefit pension and postretirement plan items:
Prior service credit ⁽¹⁾	$	19		$	19		$	58		$	58
Net loss⁽¹⁾	(153		)	(138		)	(480		)	(435		)
Total before income taxes	(134		)	(119		)	(422		)	(377		)
Income tax benefit	34			33			110			102
Net of tax	$	(100	)	$	(86	)	$	(312	)	$	(275	)
Gains and losses on commodity contracts cash flow hedges:
Propane swap agreements ⁽²⁾	$	290		$	(276	)	$	1,148		$	(921	)
Natural gas swaps ⁽²⁾⁽³⁾	(4		)	123			7			(358		)
Natural gas futures ⁽²⁾⁽³⁾	348			(308		)	(350		)	(171		)
Total before income taxes	634			(461		)	805			(1,450		)
Income tax benefit (expense)	(179		)	129			(218		)	407
Net of tax	455			(332		)	587			(1,043		)
Total reclassifications for the period	$	355		$	(418	)	$	275		$	(1,318	)

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

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

⁽³⁾ PESCO's results are reflected as discontinued operations in our condensed consolidated statements of income.

Amortization of defined benefit pension and postretirement plan items is included in other expense, net gains and losses on propane swap agreements, call options and natural gas futures contracts are included in cost of sales 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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10.	Employee Benefit Plans

Net periodic benefit costs for our pension and post-retirement benefits plans for the three and nine months ended September 30, 2019 and 2018 are set forth in the following tables:



	Chesapeake Pension Plan						FPU Pension Plan						Chesapeake SERP				Chesapeake Postretirement Plan						FPU Medical Plan
For the Three Months Ended September 30,	2019			2018			2019			2018			2019		2018		2019			2018			2019		2018
(in thousands)
Interest cost	$	104		$	94		$	614		$	570		$	16	$	21	$	10		$	10		$	12	$	12
Expected return on plan assets	(127		)	(131		)	(693		)	(770		)	—		—		—			—			—		—
Amortization of prior service credit	—			—			—			—			—		—		(19		)	(19		)	—		—
Amortization of net loss	101			82			128			86			17		25		11			15			—		—
Net periodic cost (benefit)	78			45			49			(114		)	33		46		2			6			12		12
Settlement expense	—			—			—			—			58		—		—			—			—		—
Amortization of pre-merger regulatory asset	—			—			162			191			—		—		—			—			2		2
Total periodic cost	$	78		$	45		$	211		$	77		$	91	$	46	$	2		$	6		$	14	$	14



	Chesapeake Pension Plan						FPU Pension Plan						Chesapeake SERP				Chesapeake Postretirement Plan						FPU Medical Plan
For the Nine Months Ended September 30,	2019			2018			2019			2018			2019		2018		2019			2018			2019		2018
(in thousands)
Interest cost	$	314		$	288		$	1,844		$	1,754		$	58	$	63	$	29		$	29		$	36	$	38
Expected return on plan assets	(381		)	(406		)	(2,079		)	(2,318		)	—		—		—			—			—		—
Amortization of prior service credit	—			—			—			—			—		—		(58		)	(58		)	—		—
Amortization of net loss	304			258			386			302			68		75		35			45			—		—
Net periodic cost (benefit)	237			140			151			(262		)	126		138		6			16			36		38
Settlement expense	—			—			—			—			58		—		—			—			—		—
Amortization of pre-merger regulatory asset	—			—			543			571			—		—		—			—			6		6
Total periodic cost	$	237		$	140		$	694		$	309		$	184	$	138	$	6		$	16		$	42	$	44

We expect to record pension and postretirement benefit costs of approximately $1.3 million for 2019. Included in these costs is approximately $0.6 million related to amortization of the FPU pension regulatory asset, which represents the portion attributable to FPU’s regulated energy operations for the changes in funded status that occurred, but were not recognized, as part of net periodic benefit costs prior to the FPU merger in 2009. This was deferred as a regulatory asset by FPU prior to the merger, to be recovered through rates pursuant to a previous order by the Florida PSC. As of September 30, 2019, a larger portion of the regulatory asset related primarily to the FPU Pension Plan was fully amortized. The unamortized balance of this regulatory asset was approximately $0.6 million at December 31, 2018. Excluding the service cost component, the other components of the net periodic costs have been recorded or reclassified to other expense, net in the condensed consolidated statements of income.

Pursuant to a Florida PSC order, FPU continues to record, as a regulatory asset, a portion of the unrecognized pension and postretirement benefit costs related to its regulated operations after the FPU merger. The portion of the unrecognized pension and postretirement benefit costs related to FPU’s unregulated operations and Chesapeake Utilities' operations is recorded to accumulated other comprehensive loss.

In connection with the lump sum distribution from the Chesapeake SERP in July 2019 and the related settlement accounting we re-measured the benefit obligation using a discount rate of three percent.

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We began executing a de-risking strategy for the Chesapeake Pension Plan. As a result, during the fourth quarter of 2019 we will purchase annuities for those retirees currently receiving monthly payments. We also offered lump-sum payments to our terminated vested employees. We will recognize the appropriate settlement accounting associated with retirees and terminated vested employees that are selecting lump sum payments in the fourth quarter of 2019.

The following tables present the amounts included in the regulatory asset and accumulated other comprehensive loss that were recognized as components of net periodic benefit cost during the three and nine months ended September 30, 2019 and 2018:



For the Three Months Ended September 30, 2019	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan			FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(19	)	$	—	$	(19	)
Net loss	101		128		17		11			—		257
Total recognized in net periodic benefit cost	101		128		17		(8		)	—		238
Recognized from accumulated other comprehensive loss/(gain) ⁽¹⁾	101		24		17		(8		)	—		134
Recognized from regulatory asset	—		104		—		—			—		104
Total	$	101	$	128	$	17	$	(8	)	$	—	$	238



For the Three Months Ended September 30, 2018	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan			FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(19	)	$	—	$	(19	)
Net loss	82		86		25		15			—		208
Total recognized in net periodic benefit cost	82		86		25		(4		)	—		189
Recognized from accumulated other comprehensive loss/(gain) ⁽¹⁾	82		16		25		(4		)	—		119
Recognized from regulatory asset	—		70		—		—			—		70
Total	$	82	$	86	$	25	$	(4	)	$	—	$	189



For the Nine Months Ended September 30, 2019	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan			FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(58	)	$	—	$	(58	)
Net loss	304		386		68		35			—		793
Total recognized in net periodic benefit cost	304		386		68		(23		)	—		735
Recognized from accumulated other comprehensive loss/(gain) ⁽¹⁾	304		73		68		(23		)	—		422
Recognized from regulatory asset	—		313		—		—			—		313
Total	$	304	$	386	$	68	$	(23	)	$	—	$	735

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For the Nine Months Ended September 30, 2018	Chesapeake Pension Plan		FPU Pension Plan		Chesapeake SERP		Chesapeake Postretirement Plan			FPU Medical Plan		Total
(in thousands)
Prior service credit	$	—	$	—	$	—	$	(58	)	$	—	$	(58	)
Net loss	258		302		75		45			—		680
Total recognized in net periodic benefit cost	258		302		75		(13		)	—		622
Recognized from accumulated other comprehensive loss/(gain) ⁽¹⁾	258		57		75		(13		)	—		377
Recognized from regulatory asset	—		245		—		—			—		245
Total	$	258	$	302	$	75	$	(13	)	$	—	$	622

⁽¹⁾See Note 9, Stockholder's Equity.

During the three and nine months ended September 30, 2019, we contributed approximately $1.0 million and $1.1 million, respectively, to the Chesapeake Pension Plan and approximately $0.3 million and $0.9 million, respectively, to the FPU Pension Plan. We expect to contribute a total of approximately $1.1 million and $1.2 million, respectively to the Chesapeake Pension Plan and FPU Pension Plans during 2019, which represents the minimum annual contribution payments required.

The Chesapeake SERP, the Chesapeake Postretirement Plan and the FPU Medical Plan are unfunded and are expected to be paid out of our general funds. Cash benefits paid under the Chesapeake SERP for the nine months ended September 30, 2019 were $0.1 million. There were immaterial cash benefits paid for the three months ended September 30, 2019. We expect to pay total cash benefits of approximately $0.4 million under the Chesapeake SERP in 2019. There were no cash benefits paid under the Chesapeake Postretirement Plan, for the three and nine months ended September 30, 2019. We estimate that approximately $0.1 million will be paid, primarily for medical claims under the Chesapeake Postretirement Plan in 2019. Cash benefits paid under the FPU Medical Plan, primarily for medical claims for the three and nine months ended September 30, 2019, were immaterial for each period. We estimate that approximately $0.1 million will be paid for such benefits under the FPU Medical Plan in 2019.


11.	Investments

The investment balances at September 30, 2019 and December 31, 2018, consisted of the following:



(in thousands)	September 30, 2019		December 31, 2018
Rabbi trust (associated with the Non-Qualified Deferred Compensation Plan)	$	8,509	$	6,689
Investments in equity securities	27		22
Total	$	8,536	$	6,711

We classify these investments as trading securities and report them at their fair value. For the three months ended September 30, 2019 and 2018, we recorded a net unrealized loss of approximately $0.1 million and a net unrealized gain of approximately $0.3 million, respectively, in other expense, net in the condensed consolidated statements of income related to these investments. For the nine months ended September 30, 2019 and 2018, we recorded a net unrealized gain of approximately $1.0 million and $0.4 million, respectively, in other expense, net in the condensed consolidated statements of income related to these investments. For the investment in the Rabbi Trust, we also have recorded an associated liability, which is included in other pension and benefit costs in the condensed consolidated balance sheets and is adjusted each period for the gains and losses incurred by the investments in the Rabbi Trust.


12.	Share-Based Compensation

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

The table below presents the amounts included in net income related to share-based compensation expense for the three and nine months ended September 30, 2019 and 2018:

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	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
(in thousands)
Awards to non-employee directors	$	158		$	135		$	463		$	404
Awards to key employees	1,052			153			1,842			2,728
Total compensation expense	1,210			288			2,305			3,132
Less: tax benefit	(315		)	(79		)	(600		)	(858		)
Share-based compensation amounts included in net income	$	895		$	209		$	1,705		$	2,274

Non-employee Directors

Shares granted to non-employee directors are issued in advance of the directors’ service periods and are fully vested as of the date of the grant. We record a deferred expense equal to the fair value of the shares issued and amortize the expense equally over a service period of one year. In May 2019, after the most recent election of directors, each of our continuing non-employee directors received an annual retainer of 751 shares of common stock under the SICP for service as a director through the 2020 Annual Meeting of Stockholders.



	Number of Shares		Weighted Average Fair Value
Outstanding—December 31, 2018	—		$	—
Granted	6,759		$	93.14
Vested	(6,759	)	$	93.14
Outstanding—September 30, 2019	—		$	—

At September 30, 2019, there was approximately $0.4 million of unrecognized compensation expense related to shares granted to non-employee directors. This expense will be recognized over the remaining service period ending April 30, 2020. See Note 1, Summary of Accounting Policies, for additional information regarding ASU 2018-07 and its impact on the accounting for non-employee share-based payments.

Our former President and Chief Executive Officer, Michael P. McMasters, retired as an executive officer on December 31, 2018 but continued as a member of the Board of Directors until the 2019 Annual Meeting of Stockholders. Mr. McMasters received a pro-rated grant of 276 shares of common stock under the SICP for service as a non-employee director from January 1, 2019 through May 8, 2019. These shares awarded to Mr. McMasters immediately vested upon issuance in January 2019, had a weighted average fair value of $75.70 per share, and were fully expensed as of April 30, 2019.

Key Employees

The table below presents the summary of the stock activity for awards to key employees for the nine months ended September 30, 2019:



	Number of Shares		Weighted Average Fair Value
Outstanding—December 31, 2018	131,741		$	67.24
Granted	45,016		$	94.34
Vested	(25,831	)	$	67.08
Expired	(15,086	)	$	69.28
Outstanding—September 30, 2019	135,840		$	76.05

In June 2018, the Company and a former executive officer entered into a separation agreement and release (the "Separation Agreement"). Pursuant to the Separation Agreement, three awards, representing a total of 14,107 shares of common stock previously granted to the executive officer under the SICP, immediately vested at the time of separation; 2,569 shares were forfeited, and we recognized $1.1 million as share-based compensation expense.

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In February 2019, our Board of Directors granted awards of 45,016 shares of common stock to key employees under the SICP. The shares granted are multi-year awards that will vest at the end of the three-year service period ending December 31, 2021. All of these stock awards are earned based upon the successful achievement of long-term financial results, which comprise market-based and performance-based conditions or targets. The fair value of each performance-based condition or target is equal to the market price of our common stock on the grant date of each award. For the market-based conditions, we used the Black-Scholes pricing model to estimate the fair value of each market-based award granted.

In March 2019, upon the election of certain of our executive officers, we withheld shares with a value at least equivalent to each such executive officer’s minimum statutory obligation for applicable income and other employment taxes related to shares that we awarded in February 2019 for the performance period ended December 31, 2018, remitted the cash to the appropriate taxing authorities, and paid the balance of such awarded shares to each such executive officer. We withheld 7,635 shares, based on the value of the shares on their award date, determined by the average of the high and low prices of our common stock. Total combined payments for the employees’ tax obligations to the taxing authorities were approximately $0.7 million.

At September 30, 2019, the aggregate intrinsic value of the SICP awards granted to key employees was approximately $12.9 million. At September 30, 2019, there was approximately $4.3 million of unrecognized compensation cost related to these awards, which is expected to be recognized as expense from October 1, 2019 through December 31, 2021.

Stock Options

We did not have any stock options outstanding at September 30, 2019 or 2018, nor were any stock options issued during these periods.


13.	Derivative Instruments

We use derivative and non-derivative contracts to manage risks related to obtaining adequate supplies and the price fluctuations of natural gas, electricity and propane. Our natural gas, electric and propane distribution operations have entered into agreements with suppliers to purchase natural gas, electricity and propane for resale to our customers. Aspire Energy has entered into contracts with producers to secure natural gas to meet its obligations. Purchases under these contracts typically either do not meet the definition of derivatives or are considered “normal purchases and normal sales” and are accounted for on an accrual basis. Our propane distribution may also enter into fair value hedges of their inventory or cash flow hedges of their future purchase commitments in order to mitigate the impact of wholesale price fluctuations. As of September 30, 2019, our natural gas and electric distribution operations did not have any outstanding derivative contracts.

PESCO's Derivative Instruments

As discussed in Note 3, Discontinued Operations, we reached an agreement to sell a majority of PESCO's operations to UET, NJRES and Gas South. The sale of assets and contracts to UET and NJRES closed on October 1, 2019. In anticipation of the consummation of the sale to UET and NJRES, the financial and commodity contracts sold were novated prior to the close of sale. At September 30, 2019, PESCO's natural gas futures contracts were primarily associated with the purchase and sale of natural gas for the producer services portfolio. We are actively marketing PESCO’s producer services portfolio and are targeting a sale by December 31, 2019. At September 30, 2019 and December 31, 2018, the fair value of PESCO's derivative assets was $3.2 million and $13.1 million, respectively. At September 30, 2019 and December 31, 2018, the fair value of PESCO's derivative liabilities was $0.9 million and $13.3 million, respectively. These amounts are reflected as assets and liabilities held for sale in the condensed consolidated balance sheets. The gains and losses associated with PESCO's financial instruments are reflected as discontinued operations in the condensed consolidated statements of income.

Volume of Derivative Activity

As of September 30, 2019, our financial instruments were comprised of both long and short commodity positions. A long position is a contract to purchase the commodity and a short position is a contract to sell the commodity. The volume of our open long/(short) commodity derivative contracts were as follows:



Business unit	Commodity	Quantity hedged (in millions)	Designation	Longest Expiration date of hedge
Sharp	Propane (gallons)	11.4	Cash flows hedges	June 2022

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Sharp entered into futures and swap agreements to mitigate the risk of fluctuations in wholesale propane index prices associated with the propane volumes expected to be purchased during the heating season. Under the futures and swap agreements, Sharp will receive the difference between: (i) the index prices (Mont Belvieu prices in August 2018 through March 2023), and (ii) the per gallon propane swap prices, to the extent the index prices exceed the contracted prices. If the index prices are lower than the swap prices, Sharp will pay the difference. We designated and accounted for propane swaps as cash flows hedges. The change in the fair value of the swap agreements is recorded as unrealized gain (loss) in other comprehensive income (loss) and later recognized in the statement of income in the same period and in the same line item as the hedged transaction. We expect to reclassify approximately $1.7 million from accumulated other comprehensive loss to earnings during the next 12-month period ended September 30, 2020.

Broker Margin

Futures exchanges have contract specific margin requirements that require the posting of cash or cash equivalents relating to traded contracts. Margin requirements consist of initial margin that is posted upon the initiation of a position, maintenance margin that is usually expressed as a percent of initial margin, and variation margin that fluctuates based on the daily MTM relative to maintenance margin requirements. We currently maintain a broker margin account for Sharp, and prior to September 30, 2019, we also maintained a broker margin account for PESCO. The balances related to the margin accounts are as follows:



(in thousands)	Balance Sheet Location	September 30, 2019			December 31, 2018
Sharp	Other Current Assets	$	2,488		$	2,170
PESCO	Other Current Assets	$	(524	)	$	2,810

Financial Statements Presentation

The following tables present information about the fair value and related gains and losses of our derivative contracts. We did not have any derivative contracts with a credit-risk-related contingency. PESCO's derivatives assets and derivative liabilities are presented as assets or liabilities held for sale in our condensed consolidated balance sheets.

The fair values of the derivative contracts recorded in the condensed consolidated balance sheets as of September 30, 2019 and December 31, 2018, are as follows:



	Derivative Assets
		Fair Value As Of
(in thousands)	Balance Sheet Location	September 30, 2019		December 31, 2018
Derivatives designated as fair value hedges
Propane put options	Derivative assets, at fair value	$	—	$	71
Derivatives designated as cash flow hedges
Propane swap agreements	Derivative assets, at fair value	—		11
Total asset derivatives		$	—	$	82



	Derivative Liabilities
		Fair Value As Of
(in thousands)	Balance Sheet Location	September 30, 2019		December 31, 2018
Derivatives designated as cash flow hedges
Propane swap agreements	Derivative liabilities, at fair value	$	2,216	$	1,604
Total liability derivatives		$	2,216	$	1,604

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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 September 30,						For the Nine Months Ended September 30,
(in thousands)	(Loss) on Derivatives	2019			2018			2019			2018
Derivatives not designated as hedging instruments
Propane swap agreements	Cost of sales	$	—		$	—		$	—		$	(13	)
Derivatives designated as cash flow hedges
Propane swap agreements	Cost of sales	290			(276		)	1,148			(921		)
Propane swap agreements	Other comprehensive income (loss)	(1,139		)	296			(624		)	(590		)
Natural gas swap contracts	Other comprehensive income (loss)	4			(25		)	(63		)	563
Natural gas futures contracts	Other comprehensive income (loss)	1,612			630			2,376			(241		)
Total		$	767		$	625		$	2,837		$	(1,202	)

Gains and losses associated with PESCO are presented in discontinued operations in the condensed consolidated statements of income. As of September 30, 2019, the following amounts were recorded in the condensed consolidated balance sheets related to fair value hedges:



(in thousands)	Carrying Amount of Hedged Item				Cumulative Adjustment Included in Carrying Amount of Hedged Item
Balance Sheet Location of Hedged Items	At September 30, 2019		At December 31, 2018		At September 30, 2019		At December 31, 2018
Inventory	$	—	$	212	$	—	$	—

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14.	Fair Value of Financial Instruments

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



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

Financial Assets and Liabilities Measured at Fair Value

The following tables summarize our financial assets and liabilities that are measured at fair value on a recurring basis and the fair value measurements, by level, within the fair value hierarchy as of September 30, 2019 and December 31, 2018:



			Fair Value Measurements Using:
As of September 30, 2019	Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
(in thousands)
Assets:
Investments—equity securities	$	27	$	27	$	—	$	—
Investments—guaranteed income fund	806		—		—		806
Investments—mutual funds and other	7,703		7,703		—		—
Total investments	8,536		7,730		—		806
Derivative assets (1)	—		—		—		—
Total assets	$	8,536	$	7,730	$	—	$	806
Liabilities:
Derivative liabilities (1)	$	2,216	$	—	$	2,216	$	—

⁽¹⁾PESCO's derivative assets and liabilities are included in assets held for sale or liabilities held for sale in the condensed consolidated balance sheets as of September 30, 2019. See Note 3, Discontinued Operations, for additional details.

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			Fair Value Measurements Using:
As of December 31, 2018	Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
(in thousands)
Assets:
Investments—equity securities	$	22	$	22	$	—	$	—
Investments—guaranteed income fund	686		—		—		686
Investments—mutual funds and other	6,003		6,003		—		—
Total investments	6,711		6,025		—		686
Derivative assets (1)	82		—		82		—
Total assets	$	6,793	$	6,025	$	82	$	686
Liabilities:
Derivative liabilities (1)	$	1,604	$	—	$	1,604	$	—

⁽¹⁾ PESCO's derivative assets and liabilities are included in assets held for sale or liabilities held for sale in the condensed consolidated balance sheets as of December 31, 2018. See Note 3, Discontinued Operations, for additional details.

The following table sets forth the summary of the changes in the fair value of Level 3 investments for the nine months ended September 30, 2019 and 2018:



	Nine Months Ended September 30,
	2019			2018
(in thousands)
Beginning Balance	$	686		$	648
Purchases and adjustments	123			64
Transfers	—			(29		)
Distribution	(14		)	(12		)
Investment income	11			8
Ending Balance	$	806		$	679

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

At September 30, 2019, there were no non-financial assets or liabilities required to be reported at fair value. We review our non-financial assets for impairment at least on an annual basis, as required.

Other Financial Assets and Liabilities

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

At September 30, 2019, long-term debt which includes current maturities but excludes debt issuance costs, had a carrying value of approximately $452.1 million, compared to the estimated fair value of $473.4 million. At December 31, 2018, long-term debt, which includes the current maturities but excludes finance lease obligations and debt issuance costs, had a carrying value of approximately $327.2 million, compared to a fair value of approximately $323.8 million. The fair value was calculated using a discounted cash flow methodology that incorporates a market interest rate based on published corporate borrowing rates for debt instruments with similar terms and average maturities, and with adjustments for duration, optionality, and risk profile. The valuation technique used to estimate the fair value of long-term debt would be considered a Level 3 measurement.

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15.	Long-Term Debt

Our outstanding long-term debt is shown below:



	September 30,			December 31,
(in thousands)	2019			2018
FPU secured first mortgage bonds ⁽¹⁾:
9.08% bond, due June 1, 2022	$	7,989		$	7,986
Uncollateralized senior notes:
5.50% note, due October 12, 2020	4,000			4,000
5.93% note, due October 31, 2023	13,500			15,000
5.68% note, due June 30, 2026	20,300			23,200
6.43% note, due May 2, 2028	6,300			7,000
3.73% note, due December 16, 2028	20,000			20,000
3.88% note, due May 15, 2029	50,000			50,000
3.25% note, due April 30, 2032	70,000			70,000
3.48% note, due May 31, 2038	50,000			50,000
3.58% note, due November 30, 2038	50,000			50,000
3.98% note, due August 20, 2039	100,000			—
Term Note due January 21, 2020	30,000			30,000
Term Note due February 28, 2020	30,000			—
Promissory notes	—			26
Finance lease obligation	—			1,310
Less: debt issuance costs	(679		)	(567		)
Total long-term debt	451,410			327,955
Less: current maturities	(75,600		)	(11,935		)
Total long-term debt, net of current maturities	$	375,810		$	316,020

⁽¹⁾ FPU secured first mortgage bonds are guaranteed by Chesapeake Utilities.

Uncollateralized Senior Notes

In October 2019, we reached commercial terms with four financial institutions with respect to the anticipated issuance of $70.0 million of 2.98% uncollateralized senior notes. The note issuance to these institutions is subject to the negotiation and execution of a note purchase agreement and satisfaction of customary conditions included therein. We expect to issue the notes in December 2019, with the notes having a maturity date of December 2034. If issued, we anticipate using the proceeds to pay the Term Notes described below.

Term Notes

In December 2018, we issued a $30.0 million unsecured term note through PNC Bank N.A. with a maturity date of January 21, 2020. The interest rate at September 30, 2019 and December 31, 2018 was 2.80% and 3.23%, respectively, which equals one-month LIBOR rate plus 75 basis points. In January 2019, we issued a $30.0 million unsecured term note through Branch Banking and Trust Company, with a maturity date of February 28, 2020. The interest rate, at September 30, 2019, was 2.84%, which equals the one-month LIBOR rate plus 75 basis points. As of September 30, 2019, these term notes totaling $60.0 million are included in the current maturities of long-term debt.

Shelf Agreements

We have entered into Shelf Agreements with Prudential, MetLife and NYL, whom are under no obligation to purchase any unsecured debt. We entered into the Prudential Shelf Agreement, totaling $150.0 million, in October 2015, and we issued $70.0 million of 3.25% unsecured debt in April 2017. The Prudential Shelf Agreement was then amended in September 2018 to increase the borrowing capacity back up to $150.0 million, and in August 2019, we issued $100.0 million of unsecured debt. We entered into the NYL Shelf Agreement, totaling $100.0 million, in March 2017, and we issued unsecured debt totaling $100.0 million during 2018. The NYL Shelf Agreement was amended in November 2018 to add incremental borrowing capacity of $50.0 million. As of September 30, 2019, we had not requested that MetLife

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purchase unsecured senior debt under the MetLife Shelf Agreement, which we entered into in March 2017. The following table summarizes the borrowing information under our Shelf Agreements at September 30, 2019:



	Total Borrowing Capacity		Less: Amount of Debt Issued			Less: Unfunded Commitments		Remaining Borrowing Capacity
(in thousands)
Shelf Agreement
Prudential Shelf Agreement	$	220,000	$	(170,000	)	$	—	$	50,000
MetLife Shelf Agreement	150,000		—			—		150,000
NYL Shelf Agreement	150,000		(100,000		)	—		50,000
Total	$	520,000	$	(270,000	)	$	—	$	250,000

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


16.	Leases

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

Some of our leases are subject to annual changes in the Consumer Price Index (“CPI”). While lease liabilities are not re-measured as a result of changes to the CPI, changes to the CPI are treated as variable lease payments and recognized in the period in which the obligation for those payments was incurred. A 100-basis-point increase in CPI would have resulted in immaterial additional annual lease costs.

Most of our leases include options to renew, with renewal terms that can extend the lease term from one to 25 years or more. The exercise of lease renewal options is at our sole discretion. The amounts disclosed in our condensed consolidated balance sheet at September 30, 2019, pertaining to the right of use assets and lease liabilities, are measured based on our current expectations of exercising our available renewal options.

Our existing leases are not subject to any restrictions or covenants which preclude our ability to pay dividends, obtain financing or enter into additional leases.

We utilize our incremental borrowing rate, as the basis to calculate the present value of future lease payments, at lease commencement. Our incremental borrowing rate represents the rate that we would have to pay to borrow funds on a collateralized basis over a similar term and in a similar economic environment.

Leases with an initial term of 12 months or less are not recorded on our balance sheet; we recognize lease expense for these leases on a straight-line basis over the lease term.

We have elected not to separate non-lease components from all classes of our existing leases. Non-lease components have been accounted for as part of the single lease component to which they are related.

As of September 30, 2019, we have not entered into any leases, which have not yet commenced, that would entitle us to significant rights or create additional obligations. The following table presents information related to our total lease cost included in our condensed consolidated statements of income:

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		Three Months Ended				Nine Months Ended
		September 30,				September 30,
( in thousands)	Classification	2019		2018		2019		2018
Operating lease cost ⁽¹⁾	Operations expense	$	638	$	1,055	$	1,926	$	2,860
Finance lease cost:
Amortization of lease assets	Depreciation and amortization	—		364		650		1,083
Interest on lease liabilities	Interest expense	—		11		5		42
Net lease cost		$	638	$	1,430	$	2,581	$	3,985

⁽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 September 30, 2019:



(in thousands)	Balance sheet classification	Amount
Assets
Operating lease assets	Operating lease right-of-use assets	$	12,004
Total lease assets		$	12,004
Liabilities
Current
Operating lease liabilities	Other accrued liabilities	$	1,694
Noncurrent
Operating lease liabilities	Operating lease - liabilities	10,392
Total lease liabilities		$	12,086

The following table presents our weighted-average remaining lease terms and weighted-average discount rates for our operating and financing leases at September 30, 2019:



	At September 30, 2019
Weighted-average remaining lease term (in years)
Operating leases	8.9
Weighted-average discount rate
Operating leases	3.8	%

The following table presents additional information related to cash paid for amounts included in the measurement of lease liabilities included in our condensed consolidated statements of cash flows as of September 30, 2019 and 2018:



	Nine Months Ended
	September 30,
(in thousands)	2019		2018
Operating cash flows from operating leases	$	1,580	$	2,272
Operating cash flows from finance leases	$	5	$	42
Financing cash flows from finance leases	$	650	$	1,083

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The following table presents the future undiscounted maturities of our operating and financing leases at September 30, 2019 and for each of the next five years and thereafter:



(in thousands)	Operating Leases ⁽¹⁾		Finance Leases		Total
Remainder of 2019	$	612	$	—	$	612
2020	2,104		—		2,104
2021	1,866		—		1,866
2022	1,705		—		1,705
2023	1,709		—		1,709
2024	1,463		—		1,463
Thereafter	4,916		—		4,916
Total lease payments	$	14,375	$	—	$	14,375
Less: Interest	2,289		—		2,289
Present value of lease liabilities	$	12,086	$	—	$	12,086

⁽¹⁾ Operating lease payments include $3.9 million related to options to extend lease terms that are reasonably certain of being exercised.

The following table presents future minimum lease payments for our operating leases at December 31, 2018 under ASC 840 and is being presented for comparative purposes:



Year(s)	2019	2020	2021	2022	2023	Thereafter	Total
(in thousands)
Expected payments	$2,335	$1,993	$1,761	$1,689	$1,642	$5,397	$14,817

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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, 2018, 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 that do not directly or exclusively relate to historical facts. Such statements are “forward-looking statements” within the meaning of 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, uncertainties and other important factors that could cause actual future results to differ materially from those expressed in the forward-looking statements. In addition to the risk factors described under Item 1A, Risk Factors in our 2018 Annual Report on Form 10-K, such factors include, but are not limited to:

• 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 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 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 electricity, natural gas, 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;

• the weather and other natural phenomena, including the economic, operational and other 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;

• 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 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;

• the results of financing efforts, including our ability to obtain financing on favorable terms, which can be affected by various factors, including credit ratings and general economic conditions;

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

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

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

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

Introduction

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

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Our strategy is focused on growing earnings from a stable utility foundation and investing in related businesses and services that provide opportunities for returns greater than traditional utility returns. We are focused on identifying and developing opportunities across the energy value chain, with emphasis on midstream and downstream investments that are accretive to earnings per share and consistent with our long-term growth strategy.

Our strategy is to consistently produce industry-leading total shareholder returns by profitably investing capital into opportunities that leverage our skills and expertise in energy distribution and transmission to achieve high levels of service and growth. The key elements of our strategy include:

•

capital investment in growth opportunities that generate our target returns;

•

expanding our energy distribution and transmission operations within our existing service areas as well as into new geographic areas;

•

providing new services in our current service areas;

•

expanding our footprint in potential growth markets through strategic acquisitions;

•

entering new energy markets and businesses that complement our existing operations and growth strategy; and

•

operating as a customer-centric full-service energy supplier/partner/provider of safe and reliable service.

Our employees strive to build meaningful connections that generate opportunities to grow our businesses, develop new markets, and enrich the communities in which we live, work and serve.

The following discussions and those later in the document on operating income and segment results include the use of the term “gross margin," which is determined by deducting the cost of sales from operating revenue. Cost of sales includes the purchased cost of natural gas, electricity and propane and the cost of labor spent on direct revenue-producing activities, and excludes depreciation, amortization and accretion. Gross margin should not be considered an alternative to operating income or net income, which are determined in accordance with GAAP. We believe that 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 unregulated energy operations. Our management uses gross margin in measuring our business units’ performance and has historically analyzed and reported gross margin information publicly. Other companies may calculate gross margin in a different manner.

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

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Results of Operations for the Three and Nine Months Ended September 30, 2019

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 Delmarva Peninsula and in Florida, Pennsylvania and Ohio and provide natural gas distribution and transmission; electric distribution and generation; propane operations; steam generation; and other energy-related services.

Operational Highlights

Our net income for the quarter ended September 30, 2019 was $5.6 million, compared to $5.5 million for the same quarter of 2018. Our earnings per share for both quarters ended September 30, 2019 and 2018 was $0.34 per share. Net income for the nine months ended September 30, 2019 was $42.6 million, or $2.59 per share, compared to $38.8 million, or $2.36 per share, for the same period in 2018. On October 9, 2019, we announced our exit from the natural gas marketing business through the sale of the majority of the assets of PESCO. Additional details on the transactions to sell PESCO’s assets and contracts are included in Note 3 Discontinued Operations. As a result of this decision and announcement, PESCO’s results for all periods presented have been separately reported as discontinued operations and its assets and liabilities have been reclassified as held for sale.

Our income from continuing operations for the quarter ended September 30, 2019 was $6.2 million, compared to $6.1 million for the same quarter of 2018. Our earnings per share from continuing operations for the quarter ended September 30, 2019 increased $0.01 to $0.38 per share, compared to the same quarter of 2018. Operating income increased by $1.5 million for the quarter ended September 30, 2019, compared to the same period in the prior year, as margin increased by $4.9 million, or 7.9 percent, and operating expenses increased by $3.4 million.

Higher earnings for the third quarter primarily reflect increased gross margin from recently completed and ongoing pipeline expansion projects, organic growth in the natural gas distribution operations and higher retail propane margins per gallon. These increases were largely offset by an increase in operating expenses and higher interest expense associated with financing our expansion projects.

Our income from continuing operations for the quarter was impacted by an increase in interest charges of $1.0 million, compared to the same period in 2018. The increase was attributable to: (1) an increase of $0.8 million in interest expense on long-term debt as a result of the issuance of the NYL Shelf Notes in November 2018 and Prudential Shelf Notes issued in August 2019; (2) an increase of $0.2 million in interest expense on higher levels of short-term borrowings as well as higher rates on those borrowings; and (3) an increase of interest expense on long-term debt of $0.1 million as a result of term notes issued in December 2018 and January 2019 to finance the restoration of service to customers who lost service due to the impact of Hurricane Michael.

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	Three Months Ended
	September 30,						Increase
	2019			2018			(decrease)
(in thousands except per share)
Business Segment:
Regulated Energy segment	$	17,540		$	15,915		$	1,625
Unregulated Energy segment	(3,168		)	(3,090		)	(78		)
Other businesses and eliminations	(14		)	54			(68		)
Operating Income	14,358			12,879			1,479
Other expense, net	(350		)	(4		)	(346		)
Interest charges	5,403			4,357			1,046
Income from Continuing Operations Before Income Taxes	8,605			8,518			87
Income Taxes on Continuing Operations	2,360			2,428			(68		)
Income from Continuing operations	6,245			6,090			155
Loss from Discontinued Operations	(624		)	(552		)	(72		)
Net Income	$	5,621		$	5,538		$	83
Basic Earnings Per Share of Common Stock
Earnings from Continuing Operations	$	0.38		$	0.37		$	0.01
Earnings from Discontinued Operations	(0.04		)	(0.03		)	(0.01		)
Basic Earnings Per Share of Common Stock	$	0.34		$	0.34		$	—

Diluted Earnings Per Share of Common Stock
Earnings from Continuing Operations	$	0.38		$	0.37		$	0.01
Earnings from Discontinued Operations	(0.04		)	(0.03		)	(0.01		)
Diluted Earnings Per Share of Common Stock	$	0.34		$	0.34		$	—

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Key variances in continuing operations, between the third quarter of 2019 and the third quarter of 2018, included:



(in thousands, except per share data)	Pre-tax Income			Net Income			Earnings Per Share
Third Quarter of 2018 Reported Results from Continuing Operations	$	8,518		$	6,090		$	0.37

Increased (Decreased) Gross Margins:
Eastern Shore and Peninsula Pipeline service expansions (including related Florida natural gas distribution operation expansions)*	2,312			1,678			0.10
Margin contribution from Marlin Gas Services and Ohl*	1,088			790			0.05
Natural gas distribution growth (excluding service expansions)	791			574			0.04
Increased retail propane margins per gallon	470			341			0.02
Sandpiper's margin from natural gas conversions	224			162			0.01
Increased margin primarily from the storm recovery surcharge for Florida electric distribution operations	169			122			0.01
TCJA impact from the 2019 retained tax savings for certain Florida natural gas operations*	109			79			0.01
Aspire Energy higher gas supply costs	(233		)	(169		)	(0.01		)
Florida GRIP* ⁽¹⁾	(144		)	(104		)	(0.01		)
	4,786			3,473			0.22

(Increased) Decreased Operating Expenses (Excluding Cost of Sales):
Depreciation, amortization and property tax costs due to growth investments	(1,152		)	(836		)	(0.05		)
Operating expenses for Marlin Gas Services and Ohl including costs to expand the future growth prospects for the businesses	(1,055		)	(766		)	(0.05		)
Insurance - both insured and self-insured components	(790		)	(573		)	(0.03		)
Payroll, benefits and other employee-related expenses	(392		)	(285		)	(0.02		)
	(3,389		)	(2,460		)	(0.15		)

Change in effective tax rate	—			23			—
Interest charges	(1,046		)	(759		)	(0.05		)
Net other changes	(264		)	(122		)	(0.01		)
	(1,310		)	(858		)	(0.06		)

Third Quarter of 2019 Reported Results from Continuing Operations	$	8,605		$	6,245		$	0.38

*See the Major Projects and Initiatives table.

(1) In the third quarter of 2019, we recorded a reduction in depreciation expense totaling $0.8 million retroactive to January 1, 2019, as a result of a Florida PSC approved depreciation study that lowered annual depreciation rates. We also recorded $0.4 million in lower GRIP margin due to a concurrent reduction in surcharge collected from customers as a result of the reduced depreciation rates during the third quarter of 2019.

Our net income for the nine months ended September 30, 2019 was $42.6 million compared to $38.8 million for the same period of 2018. Our earnings per share for the nine months ended September 30, 2019 increased $0.23 to $2.59 per share, compared to the same period of 2018. Our net income from continuing operations for the nine months ended September 30, 2019 was $44.0 million compared to $39.1 million for the same period of 2018.

Our earnings per share from continuing operations for the nine months ended September 30, 2019 increased $0.29 to $2.67 per share, compared to the same period in 2018. Operating income increased by $10.7 million for the nine months ended September 30, 2019, compared to the same period in the prior year, as margin increased by $19.0 million, or 8.8 percent, and was offset by a $5.6 million increase in depreciation amortization and property taxes, and a $2.7 million increase in other operating expenses.

The increase in operating income reflects continued growth generated by organic growth within existing businesses, recent expansion investments, regulatory initiatives and rate/pricing mechanisms, the successful integration of the Ohl acquisition,

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higher retail propane margins per gallon and the strong performance of Marlin Gas Services. In addition, the benefit of the absence of a one-time non-recurring severance charge recorded in 2018, was offset by the impact of warmer weather in 2019.

Our income from continuing operations for the nine months ended September 30, 2019 was impacted by an increase in interest charges of $4.8 million, compared to the same period in 2018. The increase was attributable to: (1) an increase of $1.9 million in interest expense on long-term debt, largely as a result of the issuance of the NYL Shelf Notes in May and November 2018 and Prudential Shelf Notes in August 2019; (2) an increase of $1.9 million in interest expense on higher levels of short-term borrowings as well as higher interest rates; (3) an increase of $0.6 million in other interest due primarily to lower capitalization of interest associated with Eastern Shore's 2017 System Expansion Project which is now fully completed; and (4) an increase of $0.3 million as a result of term notes issued in December 2018 and January 2019 to finance the restoration of service to customers who lost service due to the impact of Hurricane Michael.



	Nine Months Ended
	September 30,						Increase
	2019			2018			(decrease)
(in thousands except per share)
Business Segment:
Regulated Energy segment	$	65,310		$	56,930		$	8,380
Unregulated Energy segment	11,316			10,519			797
Other businesses and eliminations	18			(1,481		)	1,499
Operating Income	$	76,644		$	65,968		$	10,676
Other expense, net	(729		)	(168		)	(561		)
Interest charges	16,583			11,764			4,819
Income from Continuing Operations Before Income Taxes	59,332			54,036			5,296
Income taxes on Continuing Operations	15,355			14,918			437
Income from Continuing operations	43,977			39,118			4,859
Loss from Discontinued Operations	(1,388		)	(339		)	(1,049		)
Net Income	$	42,589		$	38,779		$	3,810
Basic Earnings Per Share of Common Stock
Earnings from Continuing Operations	$	2.68		$	2.39		$	0.29
Earnings from Discontinued Operations	(0.08		)	(0.02		)	(0.06		)
Basic Earnings Per Share of Common Stock	$	2.60		$	2.37		$	0.23

Diluted Earnings Per Share of Common Stock
Earnings from Continuing Operations	$	2.67		$	2.38		$	0.29
Earnings from Discontinued Operations	(0.08		)	(0.02		)	(0.06		)
Diluted Earnings Per Share of Common Stock	$	2.59		$	2.36		$	0.23

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Key variances in continuing operations, between the nine months ended 2019 and the nine months ended 2018, included:



(in thousands, except per share data)	Pre-tax Income			Net Income			Earnings Per Share
Nine Months Ended September 30, 2018 Reported Results from Continuing Operations	$	54,036		$	39,118		$	2.38

Adjusting for Unusual Items:
Decreased customer consumption - primarily due to warmer weather	(4,511		)	(3,344		)	(0.20		)
Nonrecurring separation expenses associated with a former executive	1,548			1,421			0.09
2018 retained tax savings for certain Florida natural gas operations*	1,321			990			0.06
	(1,642		)	(933		)	(0.05		)

Increased (Decreased) Gross Margins:
Eastern Shore and Peninsula Pipeline service expansions (including new service in Northwest Florida for related Florida natural gas distribution operations)*	10,452			7,747			0.47
Margin contribution from Marlin Gas Services and Ohl*	5,036			3,733			0.23
Natural gas distribution growth (excluding service expansions)	3,446			2,554			0.16
Increased retail propane margins per gallon	1,689			1,252			0.08
TCJA impact from the 2019 retained tax savings for certain Florida natural gas operations*	1,117			828			0.05
Aspire Energy rate increases	858			636			0.04
Sandpiper's margin from natural gas conversions	837			621			0.04
Florida GRIP* ⁽¹⁾	391			290			0.02
Absence of Bomb Cyclone impact on wholesale propane margins	(785		)	(582		)	(0.04		)
Aspire Energy higher gas supply costs	(429		)	(318		)	(0.02		)
	22,612			16,761			1.03

(Increased) Decreased Operating Expenses (Excluding Cost of Sales):
Depreciation, amortization and property tax costs due to new capital investments	(4,711		)	(3,492		)	(0.21		)
Operating expenses for Marlin Gas Services and Ohl including costs to expand the future growth prospects for the businesses	(3,367		)	(2,496		)	(0.15		)
Payroll, benefits and other employee-related expenses	(2,471		)	(1,832		)	(0.11		)
Insurance - both insured and self-insured components	(1,223		)	(907		)	(0.06		)
Vehicle expenses due to additional fleet to support growth	(331		)	(246		)	(0.01		)
Facilities and maintenance costs due to consolidation of facilities and lower levels of tank refurbishments	1,425			1,056			0.06
Outside services and regulatory costs due to lower consulting costs, absence of Eastern Shore rate case and the timing of expenses	865			641			0.04
	(9,813		)	(7,276		)	(0.44		)

Change in effective tax rate	—			556			0.03
Interest Charges	(4,819		)	(3,572		)	(0.22		)
Net other changes	(1,042		)	(677		)	(0.06		)
	(5,861		)	(3,693		)	(0.25		)

Nine Months Ended September 30, 2019 Reported Results from Continuing Operations	$	59,332		$	43,977		$	2.67

*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, with the intention to increase shareholder value. The following represent the major projects/initiatives recently completed and currently underway. In the future, we will add new projects and initiatives to this table once negotiations are substantially final and the associated earnings can be estimated.



	Gross Margin for the Period
	Three Months Ended				Nine Months Ended				Year Ended		Estimate for
	September 30,				September 30,				December 31,		Fiscal
in thousands	2019		2018		2019		2018		2018		2019		2020
Expansions:
2017 Eastern Shore System Expansion - including interim services	$	3,671	$	2,409	$	12,116	$	5,527	$	9,103	$	16,209	$	15,799
Northwest Florida Expansion (including related natural gas distribution services)	1,592		1,589		4,881		2,741		4,350		6,500		6,500
Western Palm Beach County, Florida Expansion	745		—		1,068		—		54		2,254		5,047
Del-Mar Energy Pathway - including interim services	189		—		542		—		—		725		3,039
Auburndale	113		—		113		—		—		283		679
Callahan Intrastate Pipeline	—		—		—		—		—		—		3,219
Total Expansions	6,310		3,998		18,720		8,268		13,507		25,971		34,283
Acquisitions:
Marlin Gas Services	993		—		4,353		—		110		5,500		6,400
Ohl Propane Acquisition	95		—		683		—		—		1,200		1,236
Total Acquisitions	1,088		—		5,036		—		110		6,700		7,636
Regulatory Initiatives
Florida GRIP ^{(1) (2)}	3,145		3,289		10,050		9,659		13,323		13,587		14,854
Tax benefit retained by certain Florida entities⁽³⁾	109		—		2,438		—		—		2,980		1,879
Total Regulatory Initiatives	3,254		3,289		12,488		9,659		13,323		16,567		16,733

Total	$	10,652	$	7,287	$	36,244	$	17,927	$	26,940	$	49,238	$	58,652

(1) All periods shown have been adjusted to reflect the lower customer rates as a result of the TCJA. Lower customer rates are offset by the corresponding decrease in federal income tax expense and have no negative impact on net income.

(2) In the third quarter of 2019, we recorded a reduction in depreciation expense totaling $0.8 million retroactive to January 1, 2019, as a result of a Florida PSC approved depreciation study that lowered annual depreciation rates. We also recorded $0.4 million in lower GRIP margin due to a concurrent reduction in surcharge collected from customers as a result of the reduced depreciation rates during the third quarter of 2019.

(3) The amount disclosed for the nine months ended September 30, 2019 includes tax savings of $1.3 million for the year ended December 31, 2018. The tax savings were recorded in the first quarter of 2019 due to an order by the Florida PSC allowing reversal of a TCJA refund reserve, recorded in 2018, which increased gross margin for the nine months ended by that amount.

Detailed Discussion of Major Projects and Initiatives

Expansions

2017 Eastern Shore System Expansion

Eastern Shore has completed the construction of a system expansion project that increased its capacity by 26 percent. The project generated $1.3 million and $6.6 million in incremental gross margin during the three and nine months ended September 30, 2019, respectively, compared to the same periods in 2018. The project is expected to produce gross margin of approximately $16.2 million in 2019; $15.8 million annually, from 2020 through 2022; and $13.2 million annually thereafter based on current customer capacity commitments.

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Northwest Florida Expansion

In May 2018, Peninsula Pipeline completed construction of transmission lines, and our Florida natural gas division completed construction of lateral distribution lines, to serve customers in Northwest Florida. The project generated incremental gross margin of $2.1 million for the nine months ended September 30, 2019, compared to the same periods in 2018. The estimated annual gross margin from this project is $6.5 million for 2019 and beyond, with the opportunity for additional margin as the remaining capacity is sold.

Western Palm Beach County, Florida Expansion

Peninsula Pipeline is constructing four transmission lines to bring additional natural gas to our distribution system in West Palm Beach, Florida. The first phase of this project was placed into service in December 2018 and generated $0.7 million and $1.1 million in additional gross margin for the three and nine months ended September 30, 2019, respectively. We expect to complete the remainder of the project in phases through early 2020, and estimate that the project will generate gross margin of $2.3 million in 2019, $5.0 million in 2020 and $5.2 million annually thereafter.

Del-Mar Energy Pathway

In September 2018, Eastern Shore filed for FERC authorization to construct the Del-Mar Energy Pathway project to provide an additional 14,300 dts/d of capacity to four customers. The project will provide additional natural gas transmission pipeline infrastructure in eastern Sussex County, Delaware, and it will represent the first extension of Eastern Shore’s pipeline system into Somerset County, Maryland. Interim services in advance of this project generated $0.2 million and $0.5 million for the three and nine months ended September 30, 2019, respectively. The estimated annual gross margin from this project is approximately $0.7 million in 2019, $3.0 million in 2020, $4.1 million in 2021 and $5.1 million annually thereafter. Eastern Shore anticipates that this project will be fully in-service by the beginning of the fourth quarter of 2021, contingent upon FERC issuing authorization for the project in the fourth quarter of 2019.

Auburndale

In August 2019, the Florida PSC approved Peninsula Pipeline's Transportation Service Agreement with the Florida Division of Chesapeake Utilities. Peninsula Pipeline will purchase an existing pipeline owned by the Florida Division of Chesapeake Utilities and Calpine and construct pipeline facilities in Polk County, Florida. Peninsula Pipeline will provide transportation service to the Florida Division of Chesapeake Utilities increasing both delivery capacity and downstream pressure as well as introducing a secondary source of natural gas for the Florida Division of Chesapeake Utilities' distribution system. Peninsula Pipeline generated gross margin of $0.1 million in the three and nine months ended September 30, 2019 from this project. This project is expected to generate $0.3 million in 2019 and $0.7 million annually thereafter.

Callahan Intrastate Pipeline

In May 2018, Peninsula Pipeline announced a plan to construct a jointly owned intrastate transmission pipeline in Nassau County, Florida with Seacoast Gas Transmission in Nassau County, Florida. The 26-mile pipeline, having an initial capacity of 148,000 dts/d, will serve growing demand in both Nassau and Duval counties, Florida. The project is expected to be placed in-service during the third quarter of 2020 and is expected to generate gross margin for Peninsula Pipeline of $3.2 million in 2020 and $6.4 million annually thereafter.

Guernsey Power Station

In December 2017, Guernsey Power Station, LLC, and a Chesapeake affiliate, Aspire Energy Express, LLC, entered into a precedent firm transportation capacity agreement whereby Guernsey Power Station will construct a power generation facility and Aspire Energy Express will provide natural gas transportation service to this facility. Aspire Energy Express will construct gas transmission facilities connecting to a third party natural gas supplier to provide the firm transportation service to the power generation facility. The Aspire Energy Express facilities are expected to be placed in service during the first quarter of 2021. This project is expected to produce gross margin of approximately $1.4 million annually once placed into service in 2021.

Acquisitions

Marlin Gas Services

In December 2018, Marlin Gas Services, our wholly-owned subsidiary, acquired certain operating assets of Marlin Gas Transport, a supplier of mobile compressed natural gas distribution and pipeline solutions. The acquisition enables us to offer solutions to supply interruption scenarios and provide other unique applications where pipeline supplies are unavailable or inadequate to meet customer requirements. Marlin Gas Services generated $1.0 million and $4.4 million of gross margin for the three and nine months ended September 30, 2019, respectively. We estimate that Marlin Gas Services will generate gross margin of approximately $5.5 million in 2019 and $6.4 million in 2020, and we expect gross margin to grow beyond 2020 as Marlin Gas Services continues to

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actively expand the territories it serves as well as leverages its patented technology to potentially serve liquefied natural gas transportation needs.

Ohl Propane Acquisition

In December 2018, Sharp acquired certain propane customers and operating assets of Ohl. Located between two of Sharp's existing districts, Ohl provided propane distribution service to approximately 2,500 residential and commercial customers in Pennsylvania. The customers and assets acquired from Ohl have been assimilated into Sharp. The operations acquired from Ohl generated $0.1 million and $0.7 million of incremental gross margin for the three and nine months ended September 30, 2019 compared to the same periods in 2018, respectively. We estimate that this acquisition will generate additional gross margin of approximately $1.2 million for Sharp in 2019, with the potential for additional growth in future years.

Regulatory Initiatives

Florida GRIP

Florida GRIP is a natural gas pipe replacement program approved by the Florida PSC that allows automatic recovery, through rates, of costs associated with the replacement of mains and services. Since the program's inception in August 2012, we have invested $139.8 million of capital expenditures to replace 299 miles of qualifying distribution mains, including $12.5 million of new pipes during the first nine months of 2019. GRIP generated additional gross margin of $0.4 million for nine months ended September 30, 2019, compared to the same period in 2018.

In the third quarter of 2019, we recorded a reduction in depreciation expense totaling $0.8 million retroactive to January 1, 2019, as a result of a Florida PSC approved depreciation study that lowered annual depreciation rates. We also recorded $0.4 million in lower GRIP margin due to a concurrent reduction in surcharge collected from customers as a result of the reduced depreciation rates during the third quarter of 2019.

Florida Tax Savings Related to the TCJA

In February 2019, the Florida PSC issued orders authorizing certain of our natural gas distribution operations to retain a portion of the tax savings associated with the lower federal tax rates resulting from the TCJA. In accordance with the PSC orders, we recognized $1.3 million in margin during the first quarter of 2019, reflecting the reversal of reserves recorded during 2018. We expect the annual savings beginning in 2019 to continue in future years, and recognized additional margin of $0.1 million and $1.1 million during the three and nine months ended September 30, 2019, respectively.

Hurricane Michael

In October 2018, Hurricane Michael passed through FPU's electric distribution operation's service territory in Northwest Florida. The hurricane caused widespread and severe damage to FPU's infrastructure resulting in 100 percent of its customers in the Northwest Florida service territory losing electrical service. FPU, after exerting extraordinary hurricane restoration efforts, restored service to those customers who were able to accept it. FPU expended more than $65.0 million to restore service, which has been recorded as new plant and equipment, charged against FPU’s accumulated depreciation or charged against FPU’s storm reserve. In conjunction with the hurricane-related expenditures, we executed two 13-month unsecured term loans as temporary financing, each in the amount of $30 million. The interest cost associated with these loans is the one-month LIBOR rate plus 75 points. One of the term loans was executed in December 2018; the other was executed in January 2019.

Other major factors influencing gross margin

Weather and Consumption

Weather was not a factor during the third quarter of 2019, compared to the same period in 2018. For the nine months ended September 30, 2019, compared to the same period in 2018, weather conditions accounted for a $4.5 million decrease in gross

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margin. Lower period-over-period HDD's in all of our service territories and extreme conditions due to the absence of the impact of the "Bomb Cyclone" in early 2018 reduced consumption in the first nine months of 2019 compared to the same period in 2018 and impacted both our Regulated and Unregulated Energy segments. In terms of normal temperatures, our results for the first nine months of 2019 were negatively impacted by $2.6 million due to warmer temperatures.

The following table summarizes HDD and CDD variances from the 10-year average HDD/CDD ("Normal") for the three and nine months ended September 30, 2019 and 2018.



	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019		2018		Variance		2019		2018		Variance
Delmarva
Actual HDD	7		10		(3	)	2,576		2,729		(153	)
10-Year Average HDD ("Normal")	55		61		(6	)	2,803		2,846		(43	)
Variance from Normal	(48	)	(51	)			(227	)	(117	)
Florida
Actual HDD	—		—		—		379		507		(128	)
10-Year Average HDD ("Normal")	—		—		—		532		533		(1	)
Variance from Normal	—		—				(153	)	(26	)
Ohio
Actual HDD	2		55		(53	)	3,533		3,707		(174	)
10-Year Average HDD ("Normal")	90		91		(1	)	3,742		3,774		(32	)
Variance from Normal	(88	)	(36	)			(209	)	(67	)
Florida
Actual CDD	1,620		1,613		7		2,840		2,704		136
10-Year Average CDD ("Normal")	1,553		1,535		18		2,625		2,593		32
Variance from Normal	67		78				215		111

Natural Gas Distribution Margin Growth

New customer growth for our natural gas distribution operations generated $0.8 million and $3.4 million of additional margin for the three and nine months ended September 30, 2019, respectively. The details for the three and nine months ended September 30, 2019 are provided in the following table:



	Three Months Ended		Nine Months Ended
(in thousands)	September 30, 2019		September 30, 2019
Customer Growth:
Residential	$	358	$	1,450
Commercial and industrial	433		1,996
Total Customer Growth	$	791	$	3,446

The additional margin from new customers reflects an increase of approximately 3.8 percent in the average number of residential customers served on the Delmarva Peninsula for both the three and nine months ended September 30, 2019, and approximately 4.3 percent and 3.8 percent growth in new residential customers served in Florida. Additional gross margin was also generated by growth in commercial and industrial customers in Florida.

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Regulated Energy Segment

For the quarter ended September 30, 2019, compared to the quarter ended September 30, 2018:



	Three Months Ended
	September 30,				Increase
	2019		2018		(decrease)
(in thousands)
Revenue	$	74,580	$	72,770	$	1,810
Cost of sales	19,619		21,501		(1,882		)
Gross margin	54,961		51,269		3,692
Operations & maintenance	24,374		23,376		998
Depreciation & amortization	8,684		8,405		279
Other taxes	4,363		3,573		790
Total operating expenses	37,421		35,354		2,067
Operating income	$	17,540	$	15,915	$	1,625

Operating income for the Regulated Energy segment for the three months ended September 30, 2019 was $17.5 million, an increase of $1.6 million compared to the same period in 2018. The increased operating income resulted from increased gross margin of $3.7 million offset by $2.1 million in higher operating expenses.

Gross Margin

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



(in thousands)	Margin Impact
Eastern Shore and Peninsula Pipeline service expansions (including related Florida natural gas distribution operation expansions)	$	2,312
Natural gas distribution growth (excluding service expansions)	791
Sandpiper's margin primarily from natural gas conversions	224
Increased margin primarily from the storm recovery surcharge for Florida electric distribution operations	169
TCJA impact from the 2019 retained tax savings for certain Florida natural gas operations	109
Florida GRIP ⁽¹⁾	(144		)
Other variances	231
Quarter-over-quarter increase in gross margin	$	3,692

The following is a narrative discussion of the significant items in the foregoing table, which we believe is necessary to understand the information disclosed in the table.

Eastern Shore and Peninsula Pipeline Service Expansions (including new natural gas distribution service in Northwest Florida)

We generated additional gross margin of $2.3 million, primarily from the following natural gas service expansions:


•	$1.3 million from Eastern Shore's 2017 System Expansion Project.


•	$0.8 million generated from Peninsula Pipeline's Western Palm Beach County, Northwest Pipeline and Auburndale Projects.


•	$0.2 million generated from interim services in advance of Eastern Shore's Del-Mar Energy Pathway Project.

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Natural Gas Customer Growth

We generated additional gross margin of $0.8 million from natural gas customer growth. Gross margin increased by $0.5 million in Florida and $0.3 million on the Delmarva Peninsula for the three months ended September 30, 2019, as compared to the same period in 2018, due primarily to residential customer growth of 4.3 percent and 3.8 percent in Florida and on the Delmarva Peninsula, respectively. Gross margin generated by Florida's commercial and industrial customers increased by 8.6 percent during the third quarter compared to the same period in 2018.

Sandpiper's Margin Primarily from Natural Gas Conversions

Gross margin increased by $0.2 million in the third quarter of 2019, as compared to the same period in 2018, due primarily to the continuing conversion of the Sandpiper system from propane service to natural gas service.

Increased margin primarily from the storm recovery surcharge for Florida electric distribution operations

Gross margin increased by $0.2 million due to storm recovery surcharges collected by our Florida electric distribution operation in the third quarter of 2019, compared to the same period in 2018.

TCJA Impact

We generated additional gross margin of $0.1 million for the three months ended September 30, 2019, as compared to the same period in 2018, related to the tax savings we retained in 2019 as compared to reserving for those taxes in 2018 for our Florida natural gas businesses. See Note 5, Rates and Other Regulatory Activities, for additional information.

Florida GRIP

Florida GRIP generated lower gross margin of $0.1 million for the three months ended September 30, 2019, as compared to the same period in 2018. In the third quarter of 2019, we recorded a reduction in depreciation expense totaling $0.8 million retroactive to January 1, 2019, as a result of a Florida PSC approved depreciation study that lowered annual depreciation rates. We also recorded $0.4 million in lower GRIP margin due to a concurrent reduction in surcharge collected from customers as a result of the reduced depreciation rates during the third quarter of 2019. Excluding the impact of the retroactive adjustment of $0.4 million, additional gross margin generated from Florida GRIP for the three months ended September 30, 2019 increased by $0.3 million. as a result of recent investments.

Other Operating Expenses

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



(in thousands)
Depreciation, amortization and property tax costs due to growth investments⁽¹⁾	$	991
Insurance expense - both insured and self-insured components	718
Payroll, benefits and other employee-related expenses	345
Other variances	13
Quarter-over-quarter increase in other operating expenses	$	2,067

⁽¹⁾ Depreciation expense includes a year-to-date amount of $0.8 million recorded in the third quarter of 2019 resulting from the depreciation study approved by the Florida PSC that lowered annual depreciation rates.

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For the nine months ended September 30, 2019, compared to the nine months ended September 30, 2018:



	Nine Months Ended
	September 30,				Increase
	2019		2018		(decrease)
(in thousands)
Revenue	$	251,601	$	252,667	$	(1,066	)
Cost of sales	74,452		89,741		(15,289		)
Gross margin	177,149		162,926		14,223
Operations & maintenance	73,071		71,546		1,525
Depreciation & amortization	26,099		23,541		2,558
Other taxes	12,669		10,909		1,760
Total operating expenses	111,839		105,996		5,843
Operating income	$	65,310	$	56,930	$	8,380

Operating income for the Regulated Energy segment for the nine months ended September 30, 2019 was $65.3 million, an increase of $8.4 million or 14.7 percent, compared to the same period in 2018. The increased operating income resulted from increased gross margin of $14.2 million, offset by $4.3 million in higher depreciation, amortization and other taxes and $1.5 million in higher operating and maintenance expenses. In February 2019, the Florida PSC issued a final order regarding the treatment of the TCJA impact, allowing us to retain the savings associated with lower federal tax rates for certain of our natural gas distribution operations. As a result, $1.3 million in reserves for customer refunds, recorded in 2018, were reversed in the first quarter of 2019. Excluding the impact of the reversal, gross margin and operating income for the nine months ended September 30, 2019 increased by $12.9 million and $7.1 million, or 7.9 percent and 12.4 percent, respectively.

Gross Margin

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



(in thousands)	Margin Impact
Eastern Shore and Peninsula Pipeline service expansions (including related Florida natural gas distribution operation expansions)	$	10,452
Natural gas distribution - customer growth (excluding service expansions)	3,446
2018 retained tax savings for certain Florida natural gas distribution operations	1,321
TCJA impact from the 2019 retained tax savings for certain Florida natural gas operations	1,117
Sandpiper's margin primarily from natural gas conversions	837
Florida GRIP ⁽¹⁾	391
Decreased customer consumption - primarily due to warmer weather	(3,248		)
Other variances	(93		)
Period-over-period increase in gross margin	$	14,223

The following is a narrative discussion of the significant items in the foregoing table, which we believe is necessary to understand the information disclosed in the table.

Eastern Shore and Peninsula Pipeline Service Expansions (including new natural gas distribution service in Northwest Florida)

We generated additional gross margin of $10.5 million, primarily from the following natural gas service expansions:


•	$6.6 million from Eastern Shore's services in conjunction with its 2017 System Expansion Project.


•	$3.3 million generated from Peninsula Pipeline's Western Palm Beach County Pipeline, Northwest Pipeline Expansion and Auburndale Projects.


•	$0.6 million generated from interim services in advance of Eastern Shore's Del-Mar Energy Pathway Project.

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Natural Gas Customer Growth

We generated additional gross margin of $3.4 million from natural gas customer growth. Gross margin increased by $2.0 million in Florida and $1.4 million on the Delmarva Peninsula for the nine months ended September 30, 2019, as compared to the same period in 2018, due primarily to residential customer growth of 3.8 percent in Florida and on the Delmarva Peninsula, as well as increases in the number of commercial and industrial customers served.

2018 Retained Tax Savings for Florida Natural Gas Operations

We generated additional gross margin of $1.3 million for the nine months ended September 30, 2019, as compared to the prior period, due to a final order from the Florida PSC allowing us to retain the tax savings associated with TCJA. Pursuant to the order, refund reserves recorded by our Florida natural gas businesses in 2018, were reversed in 2019. See Note 5, Rates and Other Regulatory Activities, for additional information.

Tax Reform Impact

We generated additional gross margin of $1.1 million for the nine months ended September 30, 2019, as compared to the prior period, related to the tax savings we retained in 2019 as compared to reserving for those taxes in 2018. See Note 5, Rates and Other Regulatory Activities, for additional information.

Sandpiper's Margin Primarily from Natural Gas Conversions

Gross margin increased by $0.8 million for the nine months ended September 30, 2019, as compared to the prior period, due primarily to the continuing conversion of the Sandpiper system from propane service to natural gas service.

Florida GRIP

Continued investment in the Florida GRIP generated additional gross margin of $0.4 million for the nine months ended September 30, 2019, compared to the same period in 2018. Excluding the impact of the retroactive adjustment of $0.4 million associated with the natural gas depreciation study, gross margin generated from Florida GRIP, for the nine months ended September 30, 2019 increased by $0.8 million.

Impact of Weather on Customer Consumption

Gross margin decreased by $3.2 million due to weather-related usage as weather on the Delmarva Peninsula was approximately 5.6 percent warmer and 25.2 percent warmer in Florida during the first nine months of 2019 compared to the same period in 2018.

Other Operating Expenses

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



(in thousands)
Depreciation, amortization and property tax costs due to growth investments⁽¹⁾	$	4,292
Payroll, benefits and other employee-related expenses	2,299
Insurance expense - both insured and self-insured components	975
Vehicle expenses due to additional fleet to support growth	168
Facilities and maintenance costs due to the consolidation of facilities	(1,194		)
Outside services and regulatory costs due to lower consulting fees and timing of expense	(1,062		)
Other variances	365
Period-over-period increase in other operating expenses	$	5,843

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Unregulated Energy Segment

For the quarter ended September 30, 2019, compared to the quarter ended September 30, 2018:



	Three Months Ended
	September 30,						Increase
	2019			2018			(decrease)
(in thousands)
Revenue	$	22,280		$	24,423		$	(2,143	)
Cost of sales	9,862			13,221			(3,359		)
Gross margin	12,418			11,202			1,216
Operations & maintenance	12,270			11,460			810
Depreciation & amortization	2,519			2,061			458
Other taxes	797			771			26
Total operating expenses	15,586			14,292			1,294
Operating loss ⁽¹⁾	$	(3,168	)	$	(3,090	)	$	(78	)

(1) These results exclude operating results from PESCO that are now reflected as discontinued operations.

Operating loss for the Unregulated Energy segment remained largely unchanged for both three month periods ended September 30, 2019 and 2018. Gross margin increased by $1.2 million largely driven by $1.0 million in additional gross margin from Marlin Gas Services and was offset by $0.5 million in higher depreciation and amortization and $0.8 million in higher other operating expenses largely associated with Marlin Gas Services' growth and expansion offerings.

Gross Margin

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



(in thousands)	Margin Impact
Marlin Gas Services (acquired assets of Marlin Gas Transport in December 2018)	$	993
Propane Operations
Increased retail propane margins per gallon driven by favorable market conditions and supply management	470
Ohl acquisition (assets acquired in December 2018)	95
Aspire Energy
Higher gas supply costs	(233		)
Other variances	(109		)
Quarter-over-quarter increase in gross margin	$	1,216

The following is a narrative discussion of the significant items in the foregoing table, which we believe is necessary to understand the information disclosed in the table.

Marlin Gas Services

Gross margin increased by $1.0 million in the third quarter of 2019, as compared to the same period in the prior year, as a result of the acquisition of certain assets of Marlin Gas Transport in December 2018.

Propane Operations - Increased Retail Propane Margins

Gross Margin increased by $0.5 million, in the third quarter of 2019, as compared to the same period in the prior year, due primarily to higher margins per gallon generated as a result of favorable market conditions and lower propane inventory costs.

Propane Operations - Ohl Asset Acquisition

Gross margin increased by $0.1 million in the third quarter of 2019, as compared to the same period in the prior year, as a result of the acquisition of certain assets of Ohl by Sharp in December 2018.

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Aspire Energy - Higher Gas Supply Costs

Gross margin decreased by $0.2 million in the third quarter of 2019, as compared to the same period in the prior year, due primarily to higher gas supply costs.

Other Operating Expenses

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



(in thousands)
Operating expenses for Marlin Gas Services and Ohl (Assets acquired in December 2018) including costs to expand the future growth prospects for the businesses	$	746
Depreciation and amortization due to new capital investments	458
Insurance expense - both insured and self-insured components	179
Other variances	(89		)
Quarter-over-quarter increase in other operating expenses	$	1,294

For the nine months ended September 30, 2019, compared to the nine months ended September 30, 2018:



	Nine Months Ended
	September 30,				Increase
	2019		2018		(decrease)
(in thousands)
Revenue	$	108,985	$	115,778	$	(6,793	)
Cost of sales	49,645		61,142		(11,497		)
Gross margin	59,340		54,636		4,704
Operations & maintenance	38,001		35,516		2,485
Depreciation & amortization	7,462		6,135		1,327
Other taxes	2,561		2,466		95
Total operating expenses	48,024		44,117		3,907
Operating income ⁽¹⁾	$	11,316	$	10,519	$	797

(1) These results exclude operating results from PESCO that are now reflected as discontinued operations.

The Unregulated Energy segment had operating income of $11.3 million and $10.5 million for the nine months ended September 30, 2019 and 2018, respectively. The increased operating income of approximately $0.8 million was due to an increase in gross margin of $4.7 million, offset by a $3.9 million increase in operating expenses.

Gross Margin

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



(in thousands)
Marlin Gas Services (acquired assets of Marlin Gas Transport in December 2018)	$	4,353
Propane Operations
Increased retail propane margins per gallon driven by favorable market conditions and supply management	1,689
Ohl acquisition (assets acquired in December 2018)	683
Decrease in customer consumption due primarily to the absence of the 2018 Bomb Cyclone	(1,559		)
Decrease in wholesale propane margins due primarily to the absence of the 2018 Bomb Cyclone	(785		)
Aspire Energy
Rate increases	858
Customer consumption growth	296
Higher gas supply costs	(429		)
Other variances	(402		)
Period-over-period increase in gross margin	$	4,704

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The following is a narrative discussion of the significant items in the foregoing table, which we believe is necessary to understand the information disclosed in the table.

Marlin Gas Services

Gross margin increased by $4.4 million for the nine months ended September 30, 2019, as compared to the prior year period, as a result of the acquisition of certain assets of Marlin Gas Transport in December 2018.

Propane Operations - Increased Retail Propane Margins

Gross margin increased by $1.7 million, due to lower propane inventory costs during the first nine months of 2019, compared to the same period in 2018. In addition, favorable market conditions further increased margins in the first nine months of 2019. These market conditions, which include 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.

Propane Operations - Ohl Asset Acquisition

Gross margin increased by $0.7 million as a result of the acquisition of certain assets of Ohl by Sharp in December 2018.

Propane Operations - Decreased Customer Consumption - (Weather)

The absence of extreme conditions during the January 2018 "Bomb Cyclone," drove weather-related consumption in the first nine months of 2018 compared to the same period in 2019 and, along with warmer weather in the Mid-Atlantic region during 2019, reduced gross margin by $1.3 million for the Mid-Atlantic propane operations during the nine months ended September 30, 2019, compared to the same period of the prior year. Weather in Florida was approximately 25 percent warmer in the first nine months of 2019 reducing consumption by propane distribution customers and decreasing gross margin by approximately $0.3 million, compared to the same period in 2018.

Propane Operations - Lower Wholesale Propane Margins and Volumes

Gross margin decreased by $0.8 million in 2019 due to a lower margin per gallon and a decrease in volumes delivered for the Mid-Atlantic propane operations as a result of higher demand in 2018 associated with the Bomb Cyclone.

Aspire Energy - Increased Margin Driven by Changes in Rates

Gross margin increased by $0.9 million during the nine months ended September 30, 2019, compared to the same period of the prior year period, due primarily to changes in customer rates on various dates during 2018.

Aspire Energy - Increased Margin Driven by Customer Consumption Growth

Gross margin increased by $0.3 million during the nine months ended September 30, 2019, compared to the same period of the prior year period, due primarily to customer consumption growth and other factors.

Aspire Energy - Higher Gas Supply Costs

Gross margin decreased by $0.4 million during the nine months ended September 30, 2019 as compared to the same period in the prior year, due primarily to higher gas supply costs.

Other Operating Expenses

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



(in thousands)
Operating expenses for Marlin Gas Services and Ohl (Asset acquisitions in December 2018) including costs to expand the future growth prospects for the businesses	$	2,435
Depreciation and amortization due to new capital investments	1,327
Insurance expense - both insured and self-insured components	244
Facilities and maintenance costs primarily due to lower level of tank refurbishments for propane operations	(380		)
Other variances	281
Period-over-period increase in other operating expenses	$	3,907

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OTHER EXPENSE, NET

For the quarter ended September 30, 2019 compared to the quarter ended September 30, 2018

Other expense, net, which includes non-operating investment income (expense), interest income, late fees charged to customers, gains or losses from the sale of assets and pension and other benefits expense, increased by $0.3 million in the third quarter of 2019, compared to the same period in 2018.

For the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018

Other expense, net, which includes non-operating investment income (expense), interest income, late fees charged to customers, gains or losses from the sale of assets and pension and other benefits expense, increased by $0.5 million for the first nine months of 2019, compared to the same period in 2018.

INTEREST CHARGES

For the quarter ended September 30, 2019 compared to the quarter ended September 30, 2018

Interest charges for the quarter ended September 30, 2019 increased by $1.0 million, compared to the same period in 2018, attributable primarily to: (1) an increase of $0.8 million in interest expense on long-term debt as a result of the issuance of the NYL Shelf Notes in November 2018 and Prudential Shelf Notes issued in August 2019; (2) an increase of $0.2 million in interest expense on higher levels of short-term borrowings as well as higher rates on those borrowings; and (3) an increase of interest expense on long-term debt of $0.1 million as a result of term notes issued in December 2018 and January 2019 to finance the restoration of service to customers who lost service due to the impact of Hurricane Michael.

For the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018

Interest charges for the nine months ended September 30, 2019 increased by $4.8 million, compared to the same period in 2018, attributable primarily to: (1) an increase of $1.9 million in interest expense on long-term debt, largely as a result of the issuance of the NYL Shelf Notes in May and November 2018 and Prudential Shelf Notes in August 2019; (2) an increase of $1.9 million in interest expense on higher levels of short-term borrowings as well as higher interest rates; (3) an increase of $0.6 million in other interest due primarily to lower capitalization of interest associated with Eastern Shore's 2017 System Expansion Project which is now fully completed; and (4) an increase of interest expense in long-term debt of $0.3 million as a result of term notes issued in December 2018 and January 2019 to finance the restoration of service to customers who lost service due to the impact of Hurricane Michael.

INCOME TAXES

For the quarter ended September 30, 2019 compared to the quarter ended September 30, 2018

Income tax expense was $2.4 million for both quarters ended September 30, 2019 and 2018. Our effective income tax rate was 27.4 percent and 28.5 percent, for the three months ended September 30, 2019 and 2018, respectively.

For the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018

Income tax expense was $15.4 million for the nine months ended September 30, 2019, compared to $14.9 million in the same period in 2018. The increase in income tax expense was due primarily to higher taxable income. Our effective income tax rate was 25.9 percent and 27.6 percent for the nine months ended September 30, 2019 and 2018, respectively.

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FINANCIAL POSITION, LIQUIDITY AND CAPITAL RESOURCES

Our capital requirements reflect the capital-intensive and seasonal nature of our business and are principally attributable to investment in new plant and equipment, retirement of outstanding debt and seasonal variability in working capital. We rely on cash generated from operations, short-term borrowings, and other sources to meet normal working capital requirements and to temporarily finance capital expenditures. We may also issue long-term debt and equity to fund capital expenditures and to more closely align our capital structure with our target capital structure.

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 $124.2 million for the nine months ended September 30, 2019. The following table shows a range of the expected 2019 capital expenditures by segment and by business line:



	2019
(dollars in thousands)	Low		High
Regulated Energy:
Natural gas distribution	$	63,000	$	65,000
Natural gas transmission	62,000		64,000
Electric distribution	4,000		6,000
Total Regulated Energy	129,000		135,000
Unregulated Energy:
Propane distribution	12,000		13,000
Energy transmission	11,000		12,000
Other unregulated energy	8,000		14,000
Total Unregulated Energy	31,000		39,000
Other:
Corporate and other businesses	10,000		11,000
Total Other	10,000		11,000
Total 2019 Expected Capital Expenditures	$	170,000	$	185,000

The 2019 forecast, excluding possible acquisitions, includes: Eastern Shore's 2017 System Expansion and Del-Mar Energy Pathway, Florida's Palm Beach County Western Expansion, Callahan Intrastate Pipeline, Guernsey Power Station and other potential pipeline projects, continued expenditures under Florida GRIP, further expansions of our natural gas distribution and transmission systems, continued natural gas infrastructure improvement activities, information technology systems, new buildings and facilities, and other strategic initiatives and investments.

Beginning this quarter, we are providing a range of capital expenditures for 2019 rather than a definitive number. This range is subject to continuous review and modification. 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. Actual capital requirements may vary from the above estimates due to a number of factors, including changing economic conditions, customer growth in existing areas, regulation, new growth or acquisition opportunities and availability of capital.

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Capital Structure

We are committed to maintaining a sound capital structure and strong credit ratings to provide the financial flexibility needed to access capital markets when required. 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 September 30, 2019 and December 31, 2018:



	September 30, 2019				December 31, 2018
(in thousands)
Long-term debt, net of current maturities	$	375,810	41	%	$	316,020	38	%
Stockholders’ equity	544,711		59	%	518,439		62	%
Total capitalization, excluding short-term debt	$	920,521	100	%	$	834,459	100	%

	September 30, 2019				December 31, 2018
(in thousands)
Short-term debt	$	224,744	18	%	$	294,458	26	%
Long-term debt, including current maturities	451,410		37	%	327,955		29	%
Stockholders’ equity	544,711		45	%	518,439		45	%
Total capitalization, including short-term debt	$	1,220,865	100	%	$	1,140,852	100	%

Included in the long-term debt balances at December 31, 2018, were finance lease obligations for Sandpiper and Sharp. Sandpiper entered into a capacity, supply and operating agreement which expired in May 2019. The capacity portion of this agreement was accounted for as a finance lease. At December 31, 2018, the remaining balance of $0.6 million was included in current maturities. Sharp had previously entered into an agreement to rent property in Anne Arundel County, Maryland, which it subsequently acquired in April 2019 (at December 31, 2018, $0.7 million of current maturities).

Our target ratio of equity to total capitalization, including short-term borrowings, is between 50 and 60 percent. Including the funds expended specifically related to the impact of Hurricane Michael, our equity to total capitalization ratio, including short-term borrowings, was 45 percent as of September 30, 2019. Excluding the funds expended for Hurricane Michael restoration activities, our equity to total capitalization ratio, including short-term borrowings, would have been approximately 47 percent. We seek to align permanent financing with the in-service dates of its 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.

Uncollateralized Senior Notes

Term Notes

In December 2018, we issued a $30.0 million unsecured term note through PNC Bank N.A. with a maturity date of January 21, 2020. The interest rate at September 30, 2019 and December 31, 2018 was 2.80% and 3.23%, respectively, which equals the one-month LIBOR rate plus 75 basis points. In January 2019, we issued a $30.0 million unsecured term note through Branch Banking and Trust Company, with a maturity date of February 28, 2020. The interest rate at September 30, 2019 was 2.84% which equals the one-month LIBOR rate plus 75 basis points. These term notes totaling $60.0 million are included in the current maturities of long-term debt as of September 30, 2019.

Shelf Agreements

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2018. The NYL Shelf Agreement was amended in November 2018 to add incremental borrowing capacity of $50.0 million. As of September 30, 2019, we had not requested that MetLife purchase unsecured senior debt under the MetLife Shelf Agreement, which we entered into in March 2017. The following table summarizes the borrowing information under our Shelf Agreements at September 30, 2019:



	Total Borrowing Capacity		Less: Amount of Debt Issued			Less: Unfunded Commitments		Remaining Borrowing Capacity
(in thousands)
Shelf Agreement
Prudential Shelf Agreement	$	220,000	$	(170,000	)	$	—	$	50,000
MetLife Shelf Agreement	150,000		—			—		150,000
NYL Shelf Agreement	150,000		(100,000		)	—		50,000
Total	$	520,000	$	(270,000	)	$	—	$	250,000

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

Short-term Borrowings

Our outstanding short-term borrowings, including the Revolver, at September 30, 2019 and December 31, 2018 were $224.7 million and $294.5 million at weighted average interest rates of 2.99 percent and 3.44 percent, respectively. Our current short-term borrowing limit, authorized by our Board of Directors, is $400.0 million, including the Revolver.

We utilize bank lines of credit to provide funds for our short-term cash needs to meet seasonal working capital requirements and to temporarily fund portions of the capital expenditure program. As of September 30, 2019, we had five unsecured bank credit facilities with four financial institutions totaling $220.0 million in available credit. In addition, we have a $150.0 million Revolver under which borrowings can be designated as short-term debt. The terms of the Revolver are further described below. None of the unsecured bank lines of credit requires compensating balances.

The $150.0 million Revolver is available through October 8, 2020 and is subject to the terms and conditions set forth in the credit agreement among us and the lenders related to the Revolver ("Credit Agreement"). Borrowings under the Revolver will be used for general corporate purposes, including repayments of short-term borrowings, working capital requirements and capital expenditures. Borrowings under the Revolver will bear interest at: (i) the LIBOR rate plus an applicable margin of 1.125 percent or less, with such margin based on total indebtedness as a percentage of total capitalization, both as defined by the Credit Agreement, or (ii) the base rate plus 0.125 percent or less. Interest is payable quarterly, and the Revolver is subject to a commitment fee on the unused portion of the facility. We have the right, under certain circumstances, to extend the expiration date for up to two years on any anniversary date of the Revolver, with such extension subject to the lenders' approval. We may also request the lenders to increase the Revolver to $200.0 million, with any increase at the sole discretion of each lender.

Cash Flows

The following table provides a summary of our operating, investing and financing cash flows for the nine months ended September 30, 2019 and 2018:



	Nine Months Ended
	September 30,
	2019			2018
(in thousands)
Net cash provided by (used in):
Operating activities	$	103,939		$	127,996
Investing activities	(139,913		)	(171,167		)
Financing activities	34,205			43,772
Net increase (decrease) in cash and cash equivalents	(1,769		)	601
Cash and cash equivalents—beginning of period	6,089			5,614
Cash and cash equivalents—end of period	$	4,320		$	6,215

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Cash Flows Provided By Operating Activities

Changes in our cash flows from operating activities are attributable primarily to changes in net income, adjusted for non-cash items such as depreciation and changes in deferred income taxes, and working capital. Changes in working capital 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 nine months ended September 30, 2019 and 2018, net cash provided by operating activities was $103.9 million and $128.0 million, respectively, resulting in a decrease in cash flows of $24.1 million. Significant operating activities generating the cash flows change were as follows:


•	Changes in net accounts receivable and accrued revenue and accounts payable and accrued liabilities decreased cash flows by $23.0 million, due primarily to the timing and receipt of payments.


•	Net cash flows from changes in customer deposits and prepaid expenses increased by approximately $12.4 million.


•	Changes in net regulatory assets and liabilities decreased cash flows by $11.1 million, due primarily to the change in fuel costs collected through the various cost recovery mechanisms.


•	Net income, adjusted for non-cash adjustments and reconciling activities, decreased cash flows by $3.7 million, primarily due to lower non-cash adjustments to deferred income taxes and loss on sale of assets.


•	Net cash flows from income taxes receivable decreased by $1.9 million due primarily to the absence of tax refunds associated with lower corporate tax rates implemented in the prior year as a component of the TCJA; and


•	Net cash flows from changes in propane inventory, storage gas and other inventories increased by approximately $1.6 million.

Cash Flows Used in Investing Activities

Net cash used in investing activities totaled $139.9 million and $171.2 million during the nine months ended September 30, 2019 and 2018, respectively, resulting in an increase in cash flows of $31.3 million. Cash paid for capital expenditures was $139.3 million for the first nine months of 2019, compared to $171.4 million for the same period in 2018, resulting in increased cash flows of $32.1 million.

Cash Flows Provided by Financing Activities

Net cash provided by financing activities totaled $34.2 million during the nine months ended September 30, 2019 compared to net cash of $43.8 million used in financing activities during the prior year period resulting in an decrease in cash flows of $9.6 million. The decrease in net cash provided by financing activities resulted primarily from the following:


•	Increased cash flows from lower repayments of long-term debt of $24.1 million.

•

Increased cash flows of $54.9 million associated with the issuance of long-term debt. For the nine months ended September 30, 2019 we received $129.8 million from the issuance of the Prudential Shelf Notes in August 2019 and term notes in January 2019. For the nine months ended September 30, 2018, we had received $74.9 million in net cash proceeds from the Revolver and the issuance of the NYL Shelf Notes (Series A).


•	Decreased cash flows from repayments of short-term borrowing of $83.5 million under our line of credit arrangements; and


•	Cash dividends of $18.2 million paid during the nine months ended September 30, 2019, compared to $16.2 million for the nine months ended September 30, 2018.

Off-Balance Sheet Arrangements

We have issued corporate guarantees to certain vendors of our subsidiaries that provide for the payment of propane and natural gas purchases in the event of the subsidiary’s default. The liabilities for these purchases are recorded in our financial statements when incurred. The aggregate amount guaranteed at September 30, 2019 was $72.4 million, with the guarantees expiring on various dates through December 31, 2020.

At September 30, 2019, a majority of our corporate guarantees were associated with the operations of PESCO. As a result of the sale of PESCO's assets and contracts we are finalizing the wind-down of corporate guarantees and letters of credit associated with the business. See Note 3, Discontinued Operations, for additional details on the sale of PESCO.

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As of September 30, 2019, we have issued letters of credit totaling approximately $7.0 million related to the electric transmission services for FPU's electric division, the firm transportation service agreement between TETLP and our Delaware and Maryland divisions, the payment of natural gas purchases for PESCO, and to our current and previous primary insurance carriers. These letters of credit have various expiration dates through August 22, 2020. There have been no draws on these letters of credit as of September 30, 2019. We do not anticipate that the counterparties will draw upon these letters of credit, and we expect that they will be renewed to the extent necessary in the future. Additional information is presented in Note 7, Other Commitments and Contingencies in the condensed consolidated financial statements. As a result of the sale of assets and contracts for PESCO, letters of credit associated with PESCO will be terminated or expire without being renewed. See Note 3, Discontinued Operations, for additional details on the sale of PESCO.

Contractual Obligations

There has been no material change in the contractual obligations presented in our 2018 Annual Report on Form 10-K, except for long-term debt and commodity purchase obligations entered into in the ordinary course of our business. The following table summarizes long-term debt and commodity purchase contract obligations at September 30, 2019:



	Payments Due by Period
	Less than 1 year		1 - 3 years		3 - 5 years		More than 5 years		Total
(in thousands)
Long-term debt ⁽¹⁾	$	75,600	$	40,689	$	39,700	$	296,100	$	452,089
Purchase obligations - Commodity ⁽²⁾	26,105		156		—		—		26,261
Total	$	101,705	$	40,845	$	39,700	$	296,100	$	478,350

⁽¹⁾ Excludes finance lease obligation, debt issuance costs and an unamortized discount of $0.7 million.

⁽²⁾ 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 is subject to regulation by the Florida PSC. At September 30, 2019, we were 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.

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. Our long-term debt at September 30, 2019, consists of fixed-rate Senior Notes and $8.0 million of fixed-rate secured debt. We evaluate whether to refinance existing debt or permanently refinance existing short-term borrowings based in part on the fluctuation in interest rates. Additional information about our long-term debt is disclosed in Note 15, Long-term Debt, 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 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.

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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 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.

PESCO is a party to natural gas swap and futures contracts, which provide us the right to purchase natural gas at a fixed price at future dates. Upon expiration, the contracts can be settled financially without taking delivery of natural gas, or PESCO can procure natural gas and deliver it to its customers. PESCO is subject to commodity price risk on its open positions to the extent that market prices for natural gas liquids and natural gas deviate from fixed contract settlement prices. Market risk associated with the trading of futures and forward contracts is monitored daily for compliance with our Risk Management Policy, which includes volumetric limits for open positions. To manage exposures to changing market prices, open positions are marked up or down to market prices and reviewed daily by our oversight officials. In addition, the Risk Management Committee reviews periodic reports on markets, approves any exceptions to the Risk Management Policy (within limits established by the Board of Directors) and authorizes the use of any new types of contracts. As discussed in Note 3, Discontinued Operations, we reached an agreement to sell a majority of PESCO's financial and commodity contracts to NJRES, UET and Gas South. PESCO's derivative assets and derivative liabilities are presented as assets or liabilities held for sale in our condensed consolidated balance sheets.

The following table reflects the changes in the fair market value of financial derivatives contracts related to propane purchases and sales from December 31, 2018 to September 30, 2019:



(in thousands)	Balance at December 31, 2018			Increase (Decrease) in Fair Market Value			Less Amounts Settled		Balance at September 30, 2019
Sharp	$	(1,522	)	$	(1,820	)	$	1,126	$	(2,216	)
Total	$	(1,522	)	$	(1,820	)	$	1,126	$	(2,216	)

There were no changes in methods of valuations during the nine months ended September 30, 2019.

The following is a summary of fair market value of financial derivatives as of September 30, 2019, by method of valuation and by maturity for each fiscal year period.



(in thousands)	2019			2020			2021			2022			2023		Total Fair Value
Price based on Mont Belvieu - Sharp	$	(491	)	$	(1,400	)	$	(301	)	$	(24	)	$	—	$	(2,216	)
Total	$	(491	)	$	(1,400	)	$	(301	)	$	(24	)	$	—	$	(2,216	)

WHOLESALE CREDIT RISK

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

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

INFLATION

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

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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 September 30, 2019. Based upon their evaluation, the Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of September 30, 2019.

Changes in Internal Control over Financial Reporting

Beginning January 1, 2019, we adopted ASU 2016-02, Leases. The impacts of the adoption are discussed in detail in Note 1, Summary of Accounting Policies, and Note 16, Leases, in the notes to the condensed consolidated financial statements within this Form 10-Q. In conjunction with this adoption, we implemented changes to our controls related to leases, which were not material to our internal controls over financial reporting. These included the development of new policies for the identification of leases and other ongoing monitoring activities. These controls were designed to provide assurance, at a reasonable level, of the fair presentation of our condensed consolidated financial statements and related disclosures. During the quarter ended September 30, 2019, 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.

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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, 2018, 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. Additional risks and uncertainties not known to us at present, or that we currently deem immaterial, also may affect Chesapeake Utilities. The occurrence of any of these known or unknown risks could have a material adverse impact on our business, financial condition and results of operations.

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



	Total Number of Shares	Average Price Paid		Total Number of Shares Purchased as Part of Publicly Announced Plans	Maximum Number of Shares That May Yet Be Purchased Under the Plans
Period	Purchased	per Share		or Programs ⁽²⁾	or Programs ⁽²⁾
July 1, 2019 through July 31, 2019 ⁽¹⁾	418	$	94.86	—	—
August 1, 2019 through August 31, 2019	—	—		—	—
September 1, 2019 through September 30, 2019	—	—		—	—
Total	418	$	94.86	—	—

⁽¹⁾ Chesapeake Utilities purchased shares of common stock on the open market for the purpose of reinvesting the dividend on shares held in the Rabbi Trust accounts for certain directors and senior executives under the Non-Qualified Deferred Compensation Plan. The Non-Qualified Deferred Compensation Plan is discussed in detail in Item 8 under the heading “Notes to the Consolidated Financial Statements—Note 9, Employee Benefit Plans” in our latest Annual Report on Form 10-K for the year ended December 31, 2018. During the quarter ended September 30, 2019, 418 shares were purchased through the reinvestment of dividends on deferred stock units.

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

Item 3. Defaults upon Senior Securities

None.

Item 5. Other Information

None.

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Item 6.	Exhibits




10.1*		Executive Retirement Agreement dated October 9, 2019, between Chesapeake Utilities Corporation and Stephen C. Thompson.

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.

*Filed herewith

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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, and Assistant Corporate Secretary

Date: November 7, 2019

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