~~CAUTIONARY STATEMENT~~Cautionary Statement

This report and the documents incorporated by reference into this report contain statements that constitute “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the Securities Act), Section 21E of the Securities Exchange Act of 1934, as amended (the Exchange Act), and the Private Securities Litigation Reform Act of 1995. All statements, other than statements of historical fact, included or incorporated by reference into this report, including, without limitation, statements regarding the financial position, business strategy and other plans and objectives for the Company’s future operations, are forward-looking statements.

These statements include declarations regarding the Company’s beliefs and current expectations. In some cases, forward-looking statements can be identified by terminology such as “may,” “will,” “should,” “expects,” “plans,” “anticipates,” “believes,” “estimates,” “predicts,” “potential” or “continue” or the negative of such terms or other comparable terminology. These forward-looking statements are subject to inherent risks and uncertainties in predicting future results and conditions that could cause the actual results to differ materially from those projected in these forward-looking statements. Some, but not all, of the risks and uncertainties include those described in Part II, Item 1A (Risk Factors) and the following:

•

numerous hazards and operating risks relating to the Company’s electric and natural gas distribution activities, which could result in accidents and other operating risks and costs;

•

fluctuations in the supply of, demand for, and the prices of, electric and gas energy commodities and transmission and transportation capacity and the Company’s ability to recover energy supply costs in its rates;

•

catastrophic events;

•

cyber-attacks, acts of terrorism, acts of war, severe weather, a solar event, an electromagnetic event, a natural disaster, the age and condition of information technology assets, human error, or other factors could disrupt the Company’s operations and cause the Company to incur unanticipated losses and expense;

•

outsourcing of services to third parties could expose the Company to substandard quality of service delivery or substandard deliverables, which may result in missed deadlines or other timeliness issues, ~~non-compliance~~ ~~(including with applicable legal requirements and industry standards) or reputational harm, which could negatively affect our results of operations;~~

•

~~the coronavirus~~ ~~(COVID-19)~~ pandemic (the coronavirus pandemic) could adversely affect the Company’s business, financial condition, results of operations and cash flows, including by disrupting the Company’s employees’ and contractors’ ability to provide ongoing services to the Company, by reducing customer demand for electricity or natural gas, or by reducing the supply of electricity or natural gas;

•

outsourcing of services to third parties could expose the Company to substandard quality of service delivery or substandard deliverables, which may result in missed deadlines or other timeliness issues, non-compliance (including with applicable legal requirements and industry standards) or reputational harm, which could negatively affect our results of operations;

•

unforeseen or changing circumstances, which could adversely affect the reduction of Company-wide direct greenhouse gas emissions;

•

the Company’s regulatory and legislative environment (including laws and regulations relating to climate change, greenhouse gas emissions and other environmental matters) could affect the rates the Company is able to charge, the Company’s authorized rate of return, the Company’s ability to recover costs in its rates, the Company’s financial condition, results of operations and cash flows, and the scope of the Company’s regulated activities;

•

general economic conditions, which could adversely affect (i) the Company’s customers and, consequently, the demand for the Company’s distribution services, (ii) the availability of credit and liquidity resources, and (iii) certain of the Company’s counterparty’s obligations (including those of its insurers and lenders);

•

the Company’s ability to obtain debt or equity financing on acceptable terms;

•

increases in interest rates, which could increase the Company’s interest expense;

•

declines in capital market valuations, which could require the Company to make substantial cash contributions to cover its pension obligations, and the Company’s ability to recover pension obligation costs in its rates;

•

restrictive covenants contained in the terms of the Company’s and its subsidiaries’ indebtedness, which restrict certain aspects of the Company’s business operations;

•

customers’ preferred energy sources;

•

severe storms and the Company’s ability to recover storm costs in its rates;

•

variations in weather, which could decrease demand for the Company’s distribution services;

•

long-term global climate change, which could adversely affect customer demand or cause extreme weather events that could disrupt the Company’s electric and natural gas distribution services;

•

the Company’s ability to retain its existing customers and attract new customers;

•

increased competition; and

•

other presently unknown or unforeseen factors.

Many of these risks are beyond the Company’s control. Any forward-looking statements speak only as of the date of this report, and the Company undertakes no obligation to update any forward-looking statements to reflect events or circumstances after the date on which such statements are made or to reflect the occurrence of unanticipated events, except as required by law. New factors emerge from time to time, and it is not possible for the Company to predict all such factors, nor can the Company assess the effect of any such factor on its business or the extent to which any factor, or combination of factors, may cause results to differ materially from those contained in any forward-looking statements.

PART I. FINANCIAL INFORMATION

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

See Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Unitil Corporation’s ~~2021~~2022 Annual Report on Form 10-K for additional information.

OVERVIEW

Unitil Corporation (Unitil or the Company) is a public utility holding company headquartered in Hampton, New Hampshire. Unitil and its subsidiaries are subject to regulation as a holding company system by the Federal Energy Regulatory Commission (FERC) under the Energy Policy Act of 2005.

Unitil’s principal business is the local distribution of electricity and gas throughout its service territory in the states of New Hampshire, Massachusetts and Maine. Unitil is the parent company of three wholly-owned distribution utilities:

~~Unitil Energy Systems, Inc. (Unitil Energy), which provides electric service in the southeastern seacoast and state capital regions of New Hampshire, including the capital city of Concord;~~

~~ii)~~

~~Fitchburg Gas and Electric Light Company (Fitchburg), which provides both electric and gas service in the greater Fitchburg area of north central Massachusetts; and~~

Unitil Energy Systems, Inc. (Unitil Energy), which provides electric service in the southeastern seacoast and state capital regions of New Hampshire, including the capital city of Concord;

ii)

Fitchburg Gas and Electric Light Company (Fitchburg), which provides both electric and gas service in the greater Fitchburg area of north central Massachusetts; and

iii)

Northern Utilities, Inc. (Northern Utilities), which provides gas service in southeastern New Hampshire and portions of southern and central Maine, including the city of Portland, which is the largest city in northern New England.

~~iii)~~

Unitil Energy, Fitchburg and Northern Utilities are collectively referred to as the “distribution utilities.” Together, the distribution utilities serve approximately ~~107,700~~108,100 electric customers and ~~86,600~~87,500 gas customers.

In addition, Unitil is the parent company of Granite State Gas Transmission, Inc. (Granite State), an interstate gas transmission pipeline company, operating 86 miles of underground gas transmission pipeline primarily located in Maine and New Hampshire. Granite State provides Northern Utilities with interconnection to major gas pipelines and access to domestic gas supplies in the south and Canadian gas supplies in the north.

Unitil had an investment in Net Utility Plant of ~~$1,303.8 million~~$1.4 billion at ~~September~~June 30, ~~2022.~~2023. Earnings from Unitil’s utility operations are derived primarily from the return on investment in the utility assets of the three distribution utilities and Granite State. Unitil’s total operating revenue includes revenue to recover the approved cost of purchased electricity and gas in rates on a fully reconciling basis. As a result of this reconciling rate structure, the Company’s earnings are not directly affected by changes in the cost of purchased electricity and gas.

Unitil Resources is the Company’s wholly-owned, non-regulated subsidiary. The Company’s other subsidiaries include Unitil Service Corp., which provides, at cost, a variety of administrative and professional services to Unitil’s affiliated companies; Unitil Realty Corp., which owns and manages Unitil’s corporate office building and property located in Hampton, New Hampshire; and Unitil Power Corp., which formerly functioned as the full requirements wholesale power supply provider for Unitil Energy. Unitil’s consolidated net income includes the earnings of the holding company and these subsidiaries.

RATES AND REGULATION

Regulation

Unitil is subject to comprehensive regulation by federal and state regulatory authorities. Unitil and its subsidiaries are subject to regulation as a holding company system by the FERC under the Energy Policy Act of 2005 with regard to certain bookkeeping, accounting and reporting requirements. Unitil’s utility operations related to wholesale and interstate energy business activities are also regulated by the FERC. Unitil’s distribution utilities are subject to regulation by the applicable state public utility commissions with regard to their rates, issuance of securities and other accounting and operational matters: Unitil Energy is subject to regulation by the New Hampshire Public Utilities Commission (NHPUC); Fitchburg is subject to regulation by the Massachusetts Department of Public Utilities (MDPU); and Northern Utilities is regulated by the NHPUC and the Maine Public Utilities Commission (MPUC). Granite State, Unitil’s interstate gas transmission pipeline, is subject to regulation by FERC with regard to its rates and operations. Because Unitil’s primary operations are subject to rate regulation, the regulatory treatment of various matters could significantly affect the Company’s operations and financial position.

Unitil’s distribution utilities deliver electricity and/or gas to all customers in their service territory, at rates established under cost of service regulation. Under this regulatory structure, Unitil’s distribution utilities recover the cost of providing distribution service to their customers based on historical test years, and earn a return on their capital investment in utility assets. The Company’s distribution utilities and its gas transmission pipeline company also may recover certain base rate costs, including capital project spending, qualifying storm expenses and enhanced reliability and vegetation management programs, through annual step adjustments or cost tracking rate mechanisms.

Revenue decoupling is the term given to the elimination of the dependency of a utility’s distribution revenue on the volume of electricity or gas sales. The difference between distribution revenue amounts billed to customers and the targeted revenue decoupling amounts is recognized as an increase or a decrease in Accrued Revenue, which forms the basis for resetting rates for future cash recoveries from, or credits to, customers. These revenue decoupling targets may be adjusted as a result of rate cases and other authorized adjustments that the Company files with the MDPU and NHPUC. Fitchburg has been subject to revenue decoupling since 2011. Unitil Energy is subject to revenue decoupling as of June 1, 2022. As a result of Unitil Energy now being subject to revenue decoupling, as of June 1, 2022, revenue decoupling now applies to substantially all of Unitil’s total annual electric sales volumes. As a result of the recently received final order in Northern Utilities’ base rate case in New Hampshire, substantially all of Northern Utilities’ gas sales volumes in New Hampshire are subject to decoupling as of August 1, 2022. As of August 1, 2022, the Company estimates that revenue decoupling applies to approximately 43% of Unitil’s total annual gas sales volumes. The Company's electric and gas sales in New Hampshire and Massachusetts are now largely decoupled. The following table shows the estimated percentages of electric and gas sales that are subject to revenue decoupling for the periods presented.


Revenue Decoupling
Estimated Percentage of Decoupled Sales
For Periods Presented
Electric
Before June 1, 2022	27%
After June 1, 2022	Substantially All
Gas
Before August 1, 2022	11%
After August 1, 2022	43%

RESULTS OF OPERATIONS

The following section of MD&A compares the results of operations for each of the two fiscal periods ended ~~September~~June 30, ~~2022~~2023 and ~~September~~June 30, ~~2021~~2022 and should be read in conjunction with the accompanying unaudited Consolidated Financial Statements and the accompanying Notes to unaudited Consolidated Financial Statements included in Part I, Item 1 of this report, which are prepared in accordance with accounting principles generally accepted in the United States of America (GAAP).

The Company continues to respond to the coronavirus pandemic by taking steps to mitigate the potential risks posed by its spread. The Company’s electric and gas utility distribution operating systems have continued to provide service to customers without disruption due to the coronavirus pandemic through the date of this filing. The Company has implemented its Crisis Response Plan to address specific aspects of the coronavirus pandemic. The Crisis Response Plan guides emergency response, business continuity, and the precautionary measures being taken on behalf of employees and the public. The Company has initiated extra precautions to protect employees who work in the field and for employees who continue to work in operations, distribution and corporate facilities. The Company has implemented social distancing and work from home policies, where appropriate. The Company continues to implement strong physical and cyber-security measures to ensure that its systems remain functional in order to serve both operational needs with a remote workforce and to help ensure uninterrupted service to customers.4

The extent to which the coronavirus pandemic affects the Company’s financial condition, results of operations, and cash flows will depend on future developments, that are highly uncertain and cannot be predicted with confidence, including the duration of the outbreak, new information that may emerge concerning the severity of the coronavirus pandemic, and the actions to contain the coronavirus pandemic or treat its effect, among others. In particular, the continued spread of the coronavirus could adversely affect the Company’s business, by (i) disrupting the Company’s employees and contractors ability to provide ongoing services to the Company, (ii) reducing customer demand for electricity or gas, or (iii) reducing the supply of electricity or gas, each of which could have an adverse effect on the Company’s financial condition, results of operations, and cash flows.

The Company’s results of operations historically have reflected the seasonal nature of the gas business. Annual gas revenues are substantially realized during the heating season as a result of higher sales of gas due to cold weather. Accordingly, the results of operations are historically most favorable in the first and fourth quarters. Fluctuations in seasonal weather conditions may have a significant effect on the results of operations. Sales of electricity are generally less sensitive to weather than gas sales, but also may be affected by the weather conditions in both the winter and summer seasons. ~~As a result of recent rate cases, the Company’s electric and gas GAAP gross margins and electric and gas adjusted gross margins (a~~ ~~non-GAAP~~ financial measure) are derived from a higher percentage of fixed billing components, including customer charges. As of June 1, 2022, substantially all of Unitil’s total annual electric sales volumes are decoupled and changes in sales to existing customers do not affect GAAP gross margin and adjusted gross margin. As a result of the recently received final order in Northern Utilities’ base rate case in New Hampshire, substantially all of Northern Utilities’ gas sales volumes in New Hampshire are subject to decoupling as of August 1, 2022. As of August 1, 2022, the Company estimates that revenue decoupling applies to approximately 43% of Unitil’s total annual gas sales volumes.

On August 6, 2021, the Company issued and sold 800,000 shares of its common stock at a price of $50.80 per share in a registered public offering (Offering). The Company’s net increase to Common Equity and Cash proceeds from the Offering was approximately $38.6 million. The proceeds were used to make capital contributions to the Company’s regulated utility subsidiaries, to repay debt and for other general corporate purposes.

~~As part of the Offering, the Company granted the underwriters a~~ ~~30-day~~ option to purchase additional shares. The underwriters exercised the option and purchased an additional 120,000 shares of the Company’s common stock on September 8, 2021. The Company’s net increase to Common Equity and Cash proceeds from the exercise of the option was approximately $5.9 million. The proceeds were used to make equity capital contributions to the Company’s regulated utility subsidiaries, to repay debt and for other general corporate purposes. Overall, the results of operations and earnings for the three and nine months ended September 30, 2022 reflect the higher number of average shares outstanding.

The Company analyzes operating results using Electric and Gas Adjusted Gross Margins, which are non-GAAP financial measures. Electric Adjusted Gross Margin is calculated as Total Electric Operating Revenue less Cost of Electric Sales. Gas Adjusted Gross Margin is calculated as Total Gas Operating Revenues less Cost of Gas Sales. The Company’s management believes Electric and Gas Adjusted Gross Margins provide useful information to investors regarding profitability. Also, the Company’s management believes Electric and Gas Adjusted Gross Margins are important financial measures to analyze revenue from the Company’s ongoing operations because the approved cost of electric and gas sales are tracked, reconciled and passed through directly to customers in electric and gas tariff rates, resulting in an equal and offsetting amount reflected in Total Electric and Gas Operating Revenue.

In the following tables the Company has reconciled Electric and Gas Adjusted Gross Margin to GAAP Gross Margin, which we believe to be the most comparable GAAP financial measure. GAAP Gross Margin is calculated as Revenue less Cost of Sales, and Depreciation and Amortization. The Company calculates Electric and Gas Adjusted Gross Margin as Revenue less Cost of Sales. The Company believes excluding Depreciation and Amortization, which are period costs and not related to volumetric sales, is a meaningful measure to inform investors of the Company’s profitability from electric and gas sales in the period.


Three Months Ended September 30, 2022 ($ millions)
Three Months Ended June 30, 2023 (millions)													Three Months Ended June 30, 2023 (millions)
	Electric			Gas			Non- Regulated and Other			Total				Electric			Gas			Other			Total
Total Operating Revenue	$	75.7		$	34.5		$	—		$	110.2			$	64.5		$	38.9		$	—		$	103.4
Less: Cost of Sales		(47.3	)		(14.1	)		—			(61.4	)			(40.3	)		(9.6	)		—			(49.9	)
Less: Depreciation and Amortization		(6.9	)		(9.5	)		(0.2	)		(16.6	)			(6.4	)		(9.9	)		(0.3	)		(16.6	)

GAAP Gross Margin		21.5			10.9			(0.2	)		32.2				17.8			19.4			(0.3	)		36.9
Depreciation and Amortization		6.9			9.5			0.2			16.6				6.4			9.9			0.3			16.6

Adjusted Gross Margin	$	28.4		$	20.4		$	—		$	48.8			$	24.2		$	29.3		$	—		$	53.5


Three Months Ended June 30, 2022 (millions)
	Electric			Gas			Other			Total
Total Operating Revenue	$	54.3		$	44.6		$	—		$	98.9
Less: Cost of Sales		(30.7	)		(16.4	)		—			(47.1	)
Less: Depreciation and Amortization		(5.7	)		(8.9	)		(0.2	)		(14.8	)
GAAP Gross Margin		17.9			19.3			(0.2	)		37.0
Depreciation and Amortization		5.7			8.9			0.2			14.8
Adjusted Gross Margin	$	23.6		$	28.2		$	—		$	51.8


Six Months Ended June 30, 2023 (millions)
	Electric			Gas			Other			Total
Total Operating Revenue	$	172.7		$	150.9		$	—		$	323.6
Less: Cost of Sales		(121.8	)		(66.7	)		—			(188.5	)
Less: Depreciation and Amortization		(12.9	)		(19.9	)		(0.5	)		(33.3	)
GAAP Gross Margin		38.0			64.3			(0.5	)		101.8
Depreciation and Amortization		12.9			19.9			0.5			33.3
Adjusted Gross Margin	$	50.9		$	84.2		$	—		$	135.1


Six Months Ended June 30, 2022 (millions)
	Electric			Gas			Other			Total
Total Operating Revenue	$	143.5		$	148.0		$	—		$	291.5
Less: Cost of Sales		(95.3	)		(67.8	)		—			(163.1	)
Less: Depreciation and Amortization		(12.4	)		(17.4	)		(0.5	)		(30.3	)
GAAP Gross Margin		35.8			62.8			(0.5	)		98.1
Depreciation and Amortization		12.4			17.4			0.5			30.3
Adjusted Gross Margin	$	48.2		$	80.2		$	—		$	128.4

Three Months Ended September 30, 2021 ($ millions)

   Electric    Gas    Non-
Regulated
and Other    Total
Total Operating Revenue
   $ 65.5    $ 32.6    $ —      $ 98.1
Less: Cost of Sales
   (40.1 )    (13.2 )    —      (53.3 )
Less: Depreciation and Amortization
   (6.5 )    (8.1 )    (0.2 )    (14.8 )








GAAP Gross Margin
   18.9    11.3    (0.2 )    30.0
Depreciation and Amortization
   6.5    8.1    0.2    14.8








Adjusted Gross Margin
   $ 25.4    $ 19.4    $ —      $ 44.8

Nine Months Ended September 30, 2022 ($ millions)

   Electric    Gas    Non-
Regulated
and Other    Total
Total Operating Revenue
   $ 219.2    $ 182.5    $ —      $ 401.7
Less: Cost of Sales
   (142.6 )    (81.9 )    —      (224.5 )
Less: Depreciation and Amortization
   (19.3 )    (26.9 )    (0.7 )    (46.9 )








GAAP Gross Margin
   57.3    73.7    (0.7 )    130.3
Depreciation and Amortization
   19.3    26.9    0.7    46.9








Adjusted Gross Margin
   $ 76.6    $ 100.6    $ —      $ 177.2

Nine Months Ended September 30, 2021 ($ millions)

   Electric    Gas    Non-
Regulated
and Other    Total
Total Operating Revenue
   $ 182.2    $ 151.3    $ —      $ 333.5
Less: Cost of Sales
   (108.8 )    (59.1 )    —      (167.9 )
Less: Depreciation and Amortization
   (19.4 )    (24.5 )    (0.6 )    (44.5 )








GAAP Gross Margin
   54.0    67.7    (0.6 )    121.1
Depreciation and Amortization
   19.4    24.5    0.6    44.5








Adjusted Gross Margin
   $ 73.4    $ 92.2    $ —      $ 165.6

Electric GAAP Gross Margin was ~~$21.5 million and $57.3~~$17.8 million in the three ~~and nine~~ months ended ~~September~~June 30, ~~2022, respectively, increases~~2023, a decrease of ~~$2.6~~$0.1 million ~~and $3.3 million, respectively~~ compared to the same ~~periods~~period in ~~2021. For~~2022. Electric GAAP Gross Margin was $38.0 million in the six months ended June 30, 2023, an increase of $2.2 million compared to the same period in 2022. The decrease in the three month period was driven by higher depreciation and amortization expense of $0.7, partially offset by higher rates and customer growth of $0.6 million. The increase in the ~~increase~~six month

period was driven by higher rates and customer growth of ~~$3.0~~$2.7 million, partially offset by higher depreciation and amortization expense of ~~$0.4~~$0.5 million. The increase in the nine month period was driven by higher rates and customer growth of $3.7 million and lower depreciation and amortization expense of $0.1 million, partially offset by the unfavorable effect on sales from cooler spring weather of $0.5 million when rates were not yet decoupled.

Gas GAAP Gross Margin was ~~$10.9~~$19.4 million in the three months ended ~~September~~June 30, ~~2022, a decrease~~2023, an increase of ~~$0.4~~$0.1 million compared to the same period in ~~2021.~~2022. Gas GAAP Gross Margin was ~~$73.7~~$64.3 million in the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, an increase of ~~$6.0~~$1.5 million compared to the same period in 2021. The decrease in the three month period was primarily driven by higher depreciation and amortization expense of $1.4 million, partially offset by higher rates of $1.0 million. The increase in the nine month period was driven by higher rates of $7.0 million and the favorable effect on sales from customer growth and colder weather of $1.4 million, partially offset by higher depreciation and amortization expense of $2.4 million.

~~Earnings Overview~~

The Company’s Net Income was $0.5 million, or $0.03 in Earnings Per Share (EPS) for the third quarter of 2022, an increase of $0.5 million in Net Income, or $0.03 in EPS, compared to the third quarter of 2021. The Company’s earnings in the third quarter of 2022 reflect higher Electric and Gas Adjusted Gross Margins (a ~~non-GAAP~~ ~~financial measure), partially offset by higher operating expenses.~~

For the nine months ended September 30, 2022, the Company reported Net Income of $26.9 million, or $1.68 per share, an increase of $5.3 million, or $0.26 per share, compared to the same nine month period in 2021. The Company’s earnings in the first nine months of 2022 reflect higher Electric and Gas Adjusted Gross Margins (a ~~non-GAAP~~ ~~financial measure), partially offset by higher operating expenses.~~

~~Electric Adjusted Gross Margin (a~~ ~~non-GAAP~~ financial measure) was $28.4 million and $76.6 million in the three and nine months ended September 30, 2022, respectively, increases of $3.0 million and $3.2 million, respectively, compared with the same periods in 2021.2022. The increase in the three month period was driven by higher rates and customer ~~growth.~~growth of $3.5 million, partially offset by higher depreciation and amortization of $1.0 million and the recognition, in the second quarter of 2022, of $2.4 million in higher rates resulting from the Company's base rate case in New Hampshire. The increase in the ~~nine~~six month period was driven by higher rates and customer growth of ~~$3.7~~$7.5 million, partially offset by the unfavorable ~~effect on sales from cooler spring~~effects of warmer winter weather in 2023 of ~~$0.5~~$1.1 million, ~~when rates were not yet decoupled.~~

~~Total electric kilowatt-hour (kWh) sales increased 1.0%~~higher depreciation and ~~0.4%~~amortization of $2.5 million, and the recognition, in the ~~three and nine month periods ended September 30,~~second quarter of 2022, ~~respectively,~~of $2.4 million in higher rates resulting from the Company's base rate case in New Hampshire.

Earnings Overview

The Company’s Net Income was $4.2 million, or $0.25 in Earnings Per Share (EPS) for the second quarter of 2023, a decrease of $0.7 million in Net Income, or $0.05 in EPS, compared to the ~~same periods in 2021. Sales to Residential customers increased 1.0% and sales to C&I customers increased 1.0%~~second quarter of 2022. The Company’s earnings in the ~~three month period ended September 30, 2022,~~second quarter of 2023 reflect higher Electric and Gas Adjusted Gross Margins (a non-GAAP financial measure), offset by higher depreciation and amortization expense and higher interest expense, net.

The Company’s Net Income was $28.3 million, or $1.76 in Earnings Per Share (EPS) for the first six months of 2023, an increase of $1.9 million in Net Income, or $0.11 in EPS, compared to the ~~same period~~first six months of 2022. The Company’s earnings in ~~2021. For~~ the nine month period ended September 30, 2022, sales to Residential customers decreased 0.6% while sales to C&I customers increased 1.1%, compared to the same period in 2021. The changes in sales to Residentialfirst six months of 2023 reflect higher Electric and ~~C&I customers reflect warmer summer weather in 2022 compared to 2021, and customer growth,~~Gas Adjusted Gross Margins (a non-GAAP financial measure), partially offset by ~~cooler spring weather~~higher operating expenses and higher interest expense, net.

The Company’s three and six months results for 2022, including Electric and Gas GAAP Gross Margins, reflect the effects of base rate case orders in ~~2022 compared to 2021. Based on weather data collected~~New Hampshire, which were issued in the ~~Company’s electric service areas, on average there were 1.4% fewer Cooling Degree Days (CDD) in the first nine months~~second quarter of 2022 ~~compared~~(See Note 6, Regulatory Matters, to the ~~same period in 2021. As of September 30, 2022, the number of electric customers increased by 734 over the previous year.~~accompanying Consolidated Financial Statements).

~~Gas~~Electric Adjusted Gross Margin (a non-GAAP financial measure) was ~~$20.4~~$24.2 million and ~~$100.6~~$50.9 million in the three and ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, respectively, increases of ~~$1.0~~$0.6 million and ~~$8.4~~$2.7 million, respectively, compared to the same periods in ~~2021.~~2022. These increases reflect higher rates ~~of $1.0 million~~ and ~~$7.0 million~~customer growth.

Total electric kilowatt-hour (kWh) sales decreased 5.4% and 5.0% in the three and ~~nine month periods,~~six months ended June 30, 2023, respectively, ~~while the remainder of the increase in the nine month period is attributable~~compared to the ~~favorable effect on sales of customer growth~~same periods in 2022. Sales to Residential and ~~colder weather.~~

~~Gas therm sales~~Commercial and Industrial (C&I) customers decreased ~~1.8%~~7.2% and 4.3%, respectively, in the three ~~month period~~months ended ~~September~~June 30, ~~2022,~~2023, compared to the same period in ~~2021.~~2022, reflecting lower average usage, partially offset by customer growth. Sales to Residential and C&I customers decreased 6.5% and 4.0%, respectively, in the six months ended June 30, 2023, compared to the same period in 2022, reflecting warmer winter weather in 2023 compared to 2022 and lower average usage, partially offset by customer growth. As of June 30, 2023, the number of electric customers increased by approximately 200 over the previous year.

Gas Adjusted Gross Margin (a non-GAAP financial measure) was $29.3 million and $84.2 million in the three and six months ended June 30, 2023, respectively, increases of $1.1 million and $4.0 million, respectively, compared to the same periods in 2022. These increases reflect higher rates and customer growth of $3.5 million and $7.5 million for the three and six month periods, respectively, partially offset by the recognition, in the second quarter of 2022, of $2.4 million in higher rates resulting from the Company's base rate case in New Hampshire and, for the six month period, the unfavorable effects of warmer winter weather in 2023 of $1.1 million.

Gas therm sales increased 0.2% and decreased 5.1% in the three and six months ended June 30, 2023, respectively, compared to the same periods in 2022. In the ~~third~~second quarter of ~~2022,~~2023, sales to Residential customers decreased 1.2% and sales to C&I customers increased 0.5%, compared to the same period in 2022. In the first six months of 2023, sales to Residential and C&I customers decreased ~~3.8%~~7.7% and ~~1.6%~~4.4%, respectively, compared to the same period in ~~2021,~~2022, reflecting lower average usage. Total gas therm sales increased 2.5% in the nine month period ended September 30, 2022, compared to the same period in 2021. For the nine months ended September 30, 2022, sales to Residential and C&I customers increased 2.3% and 2.5%, respectively, compared to the same period in 2021. The increase in gas therm sales for the first nine months of 2022 reflects colderwarmer winter weather in ~~the first quarter of 2022~~2023 compared to ~~the same period in 2021, and~~2022, partially offset by customer growth. Based on weather data collected in the Company’s gas service areas, on average there were ~~3.9% more~~9.2% fewer Effective Degree Days (EDD) in the first ~~nine~~six months of ~~2022~~2023 compared to the same period in ~~2021, although 2.4% fewer EDD compared to normal.~~2022. The Company estimates weather-normalized gas therm sales ~~excluding decoupled sales,~~for Northern Utilities’ Maine division, the Company’s only non-decoupled gas service area, increased ~~0.7%~~2.1% in the first ~~nine~~six months of ~~2022~~2023 compared to the same period in ~~2021.~~2022. As of ~~September~~June 30, ~~2022,~~2023, the number of gas customers increased by ~~1,154~~approximately 800 over the previous year.

Operation and Maintenance (O&M) expenses ~~increased $1.9~~decreased $0.1 million ~~or 11.4%,~~ and ~~$4.3~~$0.5 million ~~or 8.4%,~~ in the three and ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, respectively, compared to the same periods in ~~2021.~~2022. The ~~increase~~decrease in the three month period reflects lower labor costs of $0.5 million, partially offset by higher utility operating costs of ~~$1.0 million, higher~~$0.4 million. The decrease in the six month period reflects lower labor costs ~~of $0.8 million~~

and ~~higher~~ professional fees of ~~$0.1 million. The increase in the nine month period reflects higher labor costs of $2.5~~$1.1 million, ~~higher professional fees of $1.3 million and~~partially offset by higher utility operating costs of ~~$0.5~~$0.6 million. The lower labor costs primarily reflect lower service costs for retirement benefits and lower restricted stock compensation.

Depreciation and Amortization expense increased $1.8 million and ~~$2.4~~$3.0 million in the three and ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, respectively, compared to the same periods in ~~2021,~~2022, reflecting additional depreciation associated with higher levels of utility plant in service and higher amortization of rate case and other deferred costs.

Taxes Other Than Income Taxes increased ~~$0.3~~$0.1 million and ~~$1.4~~$0.6 million in the three and ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, respectively, compared to the same periods in ~~2021. The increase in the three month period reflects higher local property taxes on higher utility plant in service. The increase in the nine month period reflects~~2022, reflecting higher local property taxes on higher utility plant in service and higher payroll taxes.

Interest Expense, Net increased ~~$0.1~~$0.7 million and $1.6 million, in the three and six months ended ~~September~~June 30, ~~2022,~~2023, respectively, compared to the same ~~period~~periods in ~~2021,~~2022, primarily reflecting higher interest expense on short-term borrowings, partially offset by lower interest expense on long-term ~~debt. For the nine months ended September 30, 2022, Interest Expense, Net decreased $0.4 million compared to the same period in 2021, primarily reflecting lower interest expense on long-term~~ debt and higher interest income on regulatory ~~assets, partially offset by higher interest expense on short-term borrowings.~~assets.

Other Expense (Income), Net decreased ~~$0.4~~$0.7 million and ~~$1.5~~$1.4 million, in the three and ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, respectively, compared to the same periods in ~~2021,~~2022, reflecting lower retirement benefit costs.

Federal and State Income Taxes for the three and six months ended ~~September~~June 30, ~~2022 decreased $0.2~~2023 increased $0.6 million and $1.5 million, respectively, compared with the same ~~period~~periods in ~~2021, primarily resulting from the~~2022, reflecting higher flow back, in 2022, of excess Accumulated Deferred Income ~~Taxes. For~~Taxes per regulatory orders in New Hampshire, and, for the ~~nine months ended September 30, 2022, Federal and State Income Taxes increased $0.1 million compared to the same~~six month period, ~~in 2021, reflecting~~ higher pre-tax earnings in ~~the current period, partially offset by the flow back of excess Accumulated Deferred Income Taxes.~~2023.

At its January ~~2022,~~2023, April ~~2022,~~2023 and July ~~2022 and October 2022~~2023 meetings, the Unitil Corporation Board of Directors declared quarterly dividends on the Company’s common stock of ~~$0.39~~$0.405 per share. These quarterly dividends result in a current effective annualized dividend rate of ~~$1.56~~$1.62 per share, representing an unbroken record of quarterly dividend payments since trading began in Unitil’s common stock.

Electric Sales, Revenues and Adjusted Gross Margin

Kilowatt-hour Sales - Unitil’s total electric kWh sales ~~increased 1.0%~~decreased 5.4% and ~~0.4%~~5.0% in the three and ~~nine month periods~~six months ended ~~September~~June 30, ~~2022,~~2023, respectively, compared to the same periods in ~~2021.~~2022. Sales to Residential ~~customers increased 1.0%~~ and ~~sales to~~ C&I customers ~~increased 1.0%~~decreased 7.2% and 4.3%, respectively, in the three ~~month period~~months ended ~~September~~June 30, ~~2022,~~2023, compared to the same period in ~~2021. For the nine month period ended September 30,~~ 2022, ~~sales~~reflecting lower average usage, partially offset by customer growth. Sales to Residential ~~customers decreased 0.6% while sales to~~and C&I customers ~~increased 1.1%~~decreased 6.5% and 4.0%, respectively, in the six months ended June 30, 2023, compared to the same period in ~~2021. The changes in sales to Residential and C&I customers reflect~~2022, reflecting warmer ~~summer~~winter weather in ~~2022~~2023 compared to ~~2021,~~2022 and ~~customer growth,~~lower average usage, partially offset by cooler spring weather in 2022 compared to 2021. Based on weather data collected in the Company’s electric service areas, on average there were 1.4% fewer CDD in the first nine months of 2022 compared to the same period in 2021.customer growth. As of ~~September~~June 30, ~~2022,~~2023, the number of electric customers increased by ~~734~~approximately 200 over the previous year. Sales margins derived from decoupled unit sales are not sensitive to changes in electric kWh sales. As of June 1, 2022, substantially all of the Company’s electric kWh sales volumes are decoupled. Prior to June 1, 2022, approximately 27% of the Company’s total annual electric kWh sales volumes were decoupled.

The following table details total kWh sales for the three and ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021~~2022 by major customer class:


kWh Sales (millions)	kWh Sales (millions)																				kWh Sales (millions)
		Three Months Ended September 30,									Nine Months Ended September 30,											Three Months Ended June 30,										Six Months Ended June 30,
		2022		2021		Change		% Change			2022		2021		Change			% Change				2023		2022		Change			% Change			2023		2022		Change			% Change
Residential			201.7		199.7		2.0		1.0	%		538.2		541.4		(3.2	)		(0.6	%)			133.4		143.7		(10.3	)		(7.2	)%		314.7		336.5		(21.8	)		(6.5	%)
Commercial / Industrial			261.4		258.7		2.7		1.0	%		722.6		714.6		8.0			1.1	%			214.3		224.0		(9.7	)		(4.3	)%		442.8		461.2		(18.4	)		(4.0	)%

Total			463.1		458.4		4.7		1.0	%		1,260.8		1,256.0		4.8			0.4	%			347.7		367.7		(20.0	)		(5.4	)%		757.5		797.7		(40.2	)		(5.0	)%

Electric Operating Revenues and Electric Adjusted Gross Margin - The following table details Total Electric Operating Revenues and Electric Adjusted Gross Margin for the three and ~~nine month periods ended September 30, 2022 and 2021:~~

Electric Operating Revenues and Electric Adjusted Gross Margin ($ millions)

   Three Months Ended September 30, Nine Months Ended September 30,
   2022    2021    $ Change    % Change 2022    2021    $ Change    % Change
Electric Operating Revenue:

Residential
   $ 44.2    $ 37.6    $ 6.6    17.6 % $ 129.5    $ 105.3    $ 24.2    23.0 %
Commercial / Industrial
   31.5    27.9    3.6    12.9 % 89.7    76.9    12.8    16.6 %













Total Electric Operating Revenue
   $ 75.7    $ 65.5    $ 10.2    15.6 % $ 219.2    $ 182.2    $ 37.0    20.3 %













Cost of Electric Sales
   $ 47.3    $ 40.1    $ 7.2    18.0 % $ 142.6    $ 108.8    $ 33.8    31.1 %













Electric Adjusted Gross Margin
   $ 28.4    $ 25.4    $ 3.0    11.8 % $ 76.6    $ 73.4    $ 3.2    4.4 %

~~Electric Adjusted Gross Margin (a~~ ~~non-GAAP~~ ~~financial measure) was $28.4 million and $76.6 million in the three and nine~~six months ended ~~September~~June 30, ~~2022, respectively, increases of $3.0 million~~2023 and $3.2 million, respectively, compared with the same periods in 2021. The increase in the three month period was driven by higher rates and customer growth. The increase in the nine month period was driven by higher rates and customer growth of $3.7 million, partially offset by the unfavorable effect on sales from cooler spring weather of $0.5 million when rates were not yet decoupled.2022:


Electric Operating Revenues and Electric Adjusted Gross Margin (millions)
	Three Months Ended June 30,									Six Months Ended June 30,
	2023		2022		$ Change		% Change			2023		2022		$ Change		% Change
Electric Operating Revenue:
Residential	$	37.4	$	30.5	$	6.9		22.6	%	$	106.0	$	85.3	$	20.7		24.3	%
Commercial / Industrial		27.1		23.8		3.3		13.9	%		66.7		58.2		8.5		14.6	%
Total Electric Operating Revenue		64.5		54.3		10.2		18.8	%		172.7		143.5		29.2		20.3	%
Cost of Electric Sales		40.3		30.7		9.6		31.3	%		121.8		95.3		26.5		27.8	%
Electric Adjusted Gross Margin	$	24.2	$	23.6	$	0.6		2.5	%	$	50.9	$	48.2	$	2.7		5.6	%

Total Electric Operating Revenue increased $10.2 million, or 18.8%, and ~~$37.0~~$29.2 million, or 20.3%, in the three and ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, respectively, compared to the same periods in ~~2021~~2022, reflecting higher costs of electric sales, which are tracked and reconciled to costs that are passed through directly to customers, and higher ~~sales~~electric distribution rates.

Electric Adjusted Gross Margin (a non-GAAP financial measure) was $24.2 million and $50.9 million in the three and six months ended June 30, 2023, respectively, increases of ~~electricity.~~$0.6 million and $2.7 million, respectively, compared to the same periods in 2022. These increases reflect higher rates and customer growth.

Gas Sales, Revenues and Adjusted Gross Margin

Therm Sales - Unitil’s total gas therm sales increased 0.2% and decreased ~~1.8%~~5.1% in the three ~~month period~~and six months ended ~~September~~June 30, ~~2022,~~2023, respectively, compared to the same periods in 2022. In the second quarter of 2023, sales to Residential customers decreased 1.2% and sales to C&I customers increased 0.5%, compared to the same period in ~~2021.~~2022. In the ~~third quarter~~first six months of ~~2022,~~2023, sales to Residential and C&I customers decreased ~~3.8%~~7.7% and ~~1.6%~~4.4%, respectively, compared to the same period in ~~2021,~~2022, reflecting ~~lower average usage. Total gas therm sales increased 2.5% in the nine month period ended September 30, 2022, compared to the same~~

period in 2021. For the nine months ended September 30, 2022, sales to Residential and C&I customers increased 2.3% and 2.5%, respectively, compared to the same period in 2021. The increase in gas therm sales for the first nine months of 2022 reflects colderwarmer winter weather in ~~the first quarter of 2022~~2023 compared to ~~the same period in 2021, and~~2022, partially offset by customer growth. Based on weather data collected in the Company’s gas service areas, on average there were ~~3.9% more~~9.2% fewer EDD in the first ~~nine~~six months of ~~2022~~2023 compared to the same period in ~~2021, although 2.4% fewer EDD compared to normal.~~2022. The Company estimates weather-normalized gas therm sales ~~excluding decoupled sales,~~for Northern Utilities’ Maine division, the Company’s only non-decoupled gas service area, increased ~~0.7%~~2.1% in the first ~~nine~~six months of ~~2022~~2023 compared to the same period in ~~2021.~~2022. As of ~~September~~June 30, ~~2022,~~2023, the number of gas customers increased by ~~1,154~~approximately 800 over the previous year. Sales margins derived from decoupled unit sales (currently representing approximately 43% of total annual therm sales volume) are not sensitive to changes in gas therm sales.

The following table details total firm therm sales for the three and ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021,~~2022 by major customer class:


Therm Sales (millions)	Therm Sales (millions)																				Therm Sales (millions)
		Three Months Ended September 30,										Nine Months Ended September 30,										Three Months Ended June 30,										Six Months Ended June 30,
		2022		2021		Change			% Change			2022		2021		Change		% Change				2023		2022		Change			% Change			2023		2022		Change			% Change
Residential			2.5		2.6		(0.1	)		(3.8	%)		35.1		34.3		0.8		2.3	%			8.2		8.3		(0.1	)		(1.2	)%		30.1		32.6		(2.5	)		(7.7	%)
Commercial / Industrial			24.3		24.7		(0.4	)		(1.6	%)		136.0		132.7		3.3		2.5	%			37.4		37.2		0.2			0.5	%		106.8		111.7		(4.9	)		(4.4	)%

Total			26.8		27.3		(0.5	)		(1.8	%)		171.1		167.0		4.1		2.5	%			45.6		45.5		0.1			0.2	%		136.9		144.3		(7.4	)		(5.1	)%

Gas Operating Revenues and Adjusted Gross Margin - The following table details Total Gas Operating Revenues and Gas Adjusted Gross Margin for the three and ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021:~~2022:


Gas Operating Revenues and Gas Adjusted Gross Margin ($ millions)
Gas Operating Revenues and Gas Adjusted Gross Margin (millions)																			Gas Operating Revenues and Gas Adjusted Gross Margin (millions)
	Three Months Ended September 30,									Nine Months Ended September 30,										Three Months Ended June 30,										Six Months Ended June 30,
	2022		2021		$ Change		% Change			2022		2021		$ Change		% Change				2023		2022		$ Change			% Change			2023		2022		$ Change			% Change
Gas Operating Revenue:
Residential	$	12.1	$	12.0	$	0.1		0.8	%	$	72.3	$	61.4	$	10.9		17.8	%		$	15.7	$	17.4	$	(1.7	)		(9.8	)%	$	62.2	$	60.2	$	2.0			3.3	%
Commercial / Industrial		22.4		20.6		1.8		8.7	%		110.2		89.9		20.3		22.6	%			23.2		27.2		(4.0	)		(14.7	)%		88.7		87.8		0.9			1.0	%

Total Gas Operating Revenue	$	34.5	$	32.6	$	1.9		5.8	%	$	182.5	$	151.3	$	31.2		20.6	%			38.9		44.6		(5.7	)		(12.8	)%		150.9		148.0		2.9			2.0	%

Cost of Gas Sales	$	14.1	$	13.2	$	0.9		6.8	%	$	81.9	$	59.1	$	22.8		38.6	%			9.6		16.4		(6.8	)		(41.5	)%		66.7		67.8		(1.1	)		(1.6	)%

Gas Adjusted Gross Margin	$	20.4	$	19.4	$	1.0		5.2	%	$	100.6	$	92.2	$	8.4		9.1	%		$	29.3	$	28.2	$	1.1			3.9	%	$	84.2	$	80.2	$	4.0			5.0	%

Total Gas ~~Adjusted Gross Margin (a~~ ~~non-GAAP~~ ~~financial measure) was $20.4~~Operating Revenue decreased $5.7 million, or 12.8%, and ~~$100.6~~increased $2.9 million, or 2.0%, in the three and ~~nine~~six months ended ~~September~~June 30, ~~2022, respectively, increases of $1.0 million and $8.4 million,~~2023, respectively, compared to the same periods in ~~2021. These increases reflect higher rates of $1.0 million and $7.0 million~~2022. The decrease in the three ~~and nine month periods, respectively, while the remainder of the increase in the nine~~ month period ~~is attributable to the favorable effect on sales of customer growth and colder weather.~~

The increases in Total Gas Operating Revenue of $1.9 million and $31.2 million in the three and nine months ended September 30, 2022, respectively, compared to the same periods in 2021, reflect higherreflects lower costs of gas sales, which are tracked and reconciled costs that are passed through directly to customers, partially offset by higher gas distribution rates. The increase in the six month period reflects higher gas distribution rates, partially offset by lower costs of gas sales, which are tracked and reconciled costs that are passed through directly to customers.

Gas Adjusted Gross Margin (a non-GAAP financial measure) was $29.3 million and $84.2 million in the three and six months ended June 30, 2023, respectively, increases of $1.1 million and $4.0 million, respectively, compared to the same periods in 2022. These increases reflect higher rates and customer growth of $3.5 million and $7.5 million for the three and six month periods, respectively, partially offset by the recognition, in the second quarter of 2022, of $2.4 million in higher rates resulting from the Company's base rate case in New Hampshire and, for the ~~nine~~six month period, ~~higher gas sales volumes.~~the unfavorable effects of warmer winter weather in 2023 of $1.1 million.

Operating Expenses

Cost of Electric Sales- Cost of Electric Sales includes the cost of electric supply and spending on energy efficiency programs. Cost of Electric Sales increased ~~$7.2~~$9.6 million, or ~~18.0%~~31.3%, and ~~$33.8~~$26.5 million, or ~~31.1%~~27.8%, in the three and ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, respectively, compared to the same periods in ~~2021.~~2022. These increases reflect higher wholesale electricity prices, ~~and higher~~partially offset by lower sales of ~~electricity.~~electricity and an increase in the amount of electricity purchased by customers directly from third-party suppliers. Because the Company reconciles and recovers the approved Cost of Electric Sales in its rates at cost on a pass-through basis, changes in approved expenses do not affect earnings.

Cost of Gas Sales - Cost of Gas Sales includes the cost to supply the Company’s total gas requirements and spending on energy efficiency programs. Cost of Gas Sales ~~increased $0.9~~decreased $6.8 million, or ~~6.8%~~41.5%, and ~~$22.8~~$1.1 million, or ~~38.6%~~1.6%, in the three and ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, respectively, compared to the same periods in ~~2021. These increases reflect higher~~2022. The decrease in the three month period reflects lower wholesale gas commodity prices, ~~and,~~partially offset by higher gas sales. The decrease in the ~~nine~~six month period ~~higher~~primarily reflects lower gas sales, partially offset by a decrease in the amount of ~~gas.~~gas purchased by customers directly from third-party suppliers. Because the Company reconciles and recovers the approved Cost of Gas Sales in its rates at cost on a pass-through basis, changes in approved expenses do not affect earnings.

Operation and Maintenance (O&M) - O&M expense includes electric and gas utility operating costs, and the operating cost of the Company’s corporate and other business activities. O&M expense ~~increased $1.9~~decreased $0.1 million, or ~~11.4%~~0.5%, and ~~$4.3~~$0.5 million, or ~~8.4%~~1.4%, in the three and ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, respectively, compared to the same periods in ~~2021.~~2022. The ~~increase~~decrease in the three month period reflects lower labor costs of $0.5 million, partially offset by higher utility operating costs of ~~$1.0 million, higher~~$0.4 million. The decrease in the six month period reflects lower labor costs ~~of $0.8 million~~ and ~~higher~~ professional fees of ~~$0.1 million. The increase in the nine month period reflects higher labor costs of $2.5~~$1.1 million, ~~higher professional fees of $1.3 million and~~partially offset by higher utility operating costs of ~~$0.5~~$0.6 million. The lower labor costs primarily reflect lower service costs for retirement benefits and lower restricted stock compensation.

Depreciation and Amortization - Depreciation and Amortization expense increased $1.8 million, or 12.2%, and ~~$2.4~~$3.0 million, or ~~5.4%~~9.9%, in the three and ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, respectively, compared to the same periods in ~~2021,~~2022, reflecting additional depreciation associated with higher levels of utility plant in service and higher amortization of rate case and other deferred costs.

Taxes Other Than Income Taxes- Taxes Other Than Income Taxes increased ~~$0.3~~$0.1 million, or ~~4.9%~~1.5%, and ~~$1.4~~$0.6 million, or ~~7.6%~~4.4%, in the three and ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, respectively, compared to the same periods in ~~2021. The increase in the three month period reflects higher local property taxes on higher utility plant in service. The increase in the nine month period reflects~~2022, reflecting higher local property taxes on higher utility plant in service and higher payroll taxes.

Other Expense (Income), Net - Other Expense (Income), Net decreased ~~$0.4~~$0.7 million ~~or 40.0%,~~ and ~~$1.5~~$1.4 million, ~~or 44.1%,~~ in the three and ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, respectively, compared to the same periods in ~~2021,~~2022, reflecting lower retirement benefit costs.

Provision for Income Taxes- Federal and State Income Taxes for the three and six months ended ~~September~~June 30, ~~2022 decreased $0.2~~2023 increased $0.6 million and $1.5 million, respectively, compared with the same ~~period~~periods in ~~2021, primarily resulting from the~~2022, reflecting higher flow back, in 2022, of excess Accumulated Deferred Income ~~Taxes. For~~Taxes per regulatory orders in New Hampshire, and, for the ~~nine months ended September 30, 2022, Federal and State Income Taxes increased $0.1 million compared to the same~~six month period, ~~in 2021, reflecting~~ higher pre-tax earnings in ~~the current period, partially offset by the flow back of excess Accumulated Deferred Income Taxes.~~2023.

Interest Expense, Net - Interest expense is presented in the Consolidated Financial Statements net of interest income. Interest expense is mainly comprised of interest on long-term debt and short-term borrowings. In addition, certain reconciling rate mechanisms used by the Company’s distribution operating utilities give rise to regulatory assets and regulatory liabilities on which interest is accrued.

Unitil’s utility subsidiaries operate a number of reconciling rate mechanisms to recover specifically identified costs on a pass-through basis. These reconciling rate mechanisms track costs and revenue on a monthly basis. In any given month, this tracking and

reconciling process will produce either an under-collected or an over-collected position. In accordance with the distribution utilities’ rate tariffs, interest is accrued on these balances and will produce either interest income or interest expense. Consistent with regulatory precedent, interest income is recorded on an under-collection of costs which creates a regulatory asset to be recovered in future periods when rates are reset. Interest expense is recorded on an over-collection of costs, which creates a regulatory liability to be refunded in future periods when rates are reset.


Interest Expense, Net ($ millions)	Three Months Ended September 30,									Nine Months Ended September 30,
Interest Expense, Net (millions)																			Three Months Ended June 30,									Six Months Ended June 30,
	2022			2021			Change			2022			2021			Change			2023			2022			Change			2023			2022			Change
Interest Expense
Long-term Debt	$	6.2		$	6.5		$	(0.3	)	$	18.6		$	19.8		$	(1.2	)	$	6.0		$	6.2		$	(0.2	)	$	12.0		$	12.4		$	(0.4	)
Short-term Debt		1.0			0.2			0.8			1.7			0.5			1.2			2.3			0.4			1.9			4.4			0.7			3.7
Regulatory Liabilities		0.1			0.1			—			0.3			0.3			—			0.2			0.1			0.1			0.3			0.2			0.1

Subtotal Interest Expense		7.3			6.8			0.5			20.6			20.6			—			8.5			6.7			1.8			16.7			13.3			3.4

Interest (Income)
Regulatory Assets		(0.2	)		—			(0.2	)		(0.6	)		(0.4	)		(0.2	)		(0.9	)		(0.2	)		(0.7	)		(1.5	)		(0.4	)		(1.1	)
AFUDC⁽¹⁾ and Other		(0.5	)		(0.3	)		(0.2			(0.9	)		(0.7	)		(0.2	)		(0.6	)		(0.2	)		(0.4	)		(1.1	)		(0.4	)		(0.7	)

Subtotal Interest (Income)		(0.7	)		(0.3	)		(0.4	)		(1.5	)		(1.1	)		(0.4	)		(1.5	)		(0.4	)		(1.1	)		(2.6	)		(0.8	)		(1.8	)

Total Interest Expense, Net	$	6.6		$	6.5		$	0.1		$	19.1		$	19.5		$	(0.4	)	$	7.0		$	6.3		$	0.7		$	14.1		$	12.5		$	1.6

⁽¹⁾	~~AFUDC – Allowance for Funds Used During Construction.~~

(1)

AFUDC – Allowance for Funds Used During Construction.

Interest Expense, Net increased ~~$0.1~~$0.7 million, or ~~1.5%~~11.1%, and $1.6 million, or 12.8%, in the three and six months ended ~~September~~June 30, ~~2022,~~2023, respectively, compared to the same ~~period~~periods in ~~2021,~~2022, primarily reflecting higher interest expense on short-term borrowings, partially offset by lower interest expense on long-term debt. For the nine months ended September 30, 2022, Interest Expense, Net decreased $0.4 million, or 2.1%, compared to the same period in 2021, primarily reflecting lower interest expense on long-term debt and higher interest income on regulatory ~~assets, partially offset by higher interest expense on short-term borrowings.~~assets.

~~CAPITAL REQUIREMENTS~~Capital RequirementS

Sources of Capital

Unitil requires capital to fund utility plant additions, working capital and other utility expenditures recovered in subsequent periods through regulated rates. The capital necessary to meet these requirements is derived primarily from internally generated funds, which consist of cash flows from operating activities. The Company initially supplements internally generated funds through short-term bank borrowings, as needed, under its unsecured revolving Credit Facility. Periodically, the Company replaces portions of its short-term debt with long-term debt financings more closely matched to the long-term nature of its utility assets. Additionally, from time to time the Company accesses the public capital markets through public offerings of equity securities. The Company’s utility operations have a seasonal component and therefore are subject to seasonal fluctuations in cash flows. The amount, type and timing of any future financing will vary from year to year based on capital needs and maturity or redemptions of securities.

On August 6, 2021, the Company issued and sold 800,000 shares of its common stock at a price of $50.80 per share in a registered public offering (Offering). The Company’s net increase to Common Equity and Cash proceeds from the Offering was approximately $38.6 million and was used to make equity capital contributions to the Company’s regulated utility subsidiaries, to repay debt and for other general corporate purposes.

~~As part of the Offering, the Company granted the underwriters a~~ ~~30-day~~ over-allotment option to purchase additional shares. The underwriters exercised the over-allotment option and purchased an additional 120,000 shares of the Company’s common stock on September 8, 2021. The Company’s net increase to Common Equity and Cash proceeds from the over-allotment sales was approximately $5.9 million and was used to make capital contributions to the Company’s regulated utility subsidiaries, to repay debt and for other general corporate purposes.

The Company and its subsidiaries are individually and collectively members of the Unitil Cash Pool (Cash Pool). The Cash Pool is the financing vehicle for day-to-day cash borrowing and investing. The Cash Pool allows for an efficient exchange of cash among the Company and its subsidiaries. The interest rates charged to the subsidiaries for borrowing from the Cash Pool are based on actual interest costs from lenders under the Company’s revolving Credit Facility (as defined below). At ~~September~~June 30, ~~2022, September~~2023, June 30, ~~2021~~2022 and December 31, ~~2021,~~2022, the Company and all of its subsidiaries were in compliance with the regulatory requirements to participate in the Cash Pool.

On September 29, 2022, the Company entered into a Third Amended and Restated Credit Agreement with a syndicate of lenders (collectively, the ~~“Credit~~"Credit Facility”), which amended and restated in its entirety the prior credit facility. Unitil may borrow under the Credit Facility until September 29, 2027, subject to two one-year extensions under certain circumstances. The Credit Facility terminates and all amounts outstanding thereunder are due and payable on September 29, 2027, subject to the potential extension discussed in the prior sentence.

The Credit Facility has a borrowing limit of $200 million, which includes a $25 million sublimit for the issuance of standby letters of credit. Unitil may increase the borrowing limit under the Credit Facility by up to $75 million under certain circumstances. The Credit Facility generally provides Unitil with the ability to elect that borrowings under the Credit Facility bear interest under several options, including a daily fluctuating rate equal to (a) the forward-looking secured overnight financing rate (as administered by the Federal Reserve Bank of New York) term rate with a term equivalent to one month beginning on that date, plus (b) 0.1000%, plus (c) a margin of 1.125% to 1.375% (based on Unitil’s credit rating). As of the close of business on September 29, 2022, Unitil’s aggregate borrowings under the Credit Facility were approximately $65.5 million at an interest rate per annum of approximately 4.272% (which interest rate was based on the lowest end of the margin range discussed above).

The Company ~~uses~~utilizes the Credit Facility for cash management purposes related to its short-term operating activities. Total gross borrowings were ~~$214.0~~$193.6 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022.~~2023. Total gross repayments were ~~$206.1~~$177.9 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022.~~2023. The following table details the borrowing limits, amounts outstanding and amounts available under the Credit Facility as of ~~September~~June 30, 2023 and December 31, 2022 and for the prior credit facility as of ~~September 31, 2021 and December 31, 2021:~~June 30, 2022:


	Revolving Credit Facility ($ millions)						Revolving Credit Facility ($ millions)
	September 30,				December 31,		June 30,				December 31,
	2022		2021		2021		2023		2022		2022
Limit	$	200.0	$	120.0	$	120.0	$	200.0	$	120.0	$	200.0
Short-Term Borrowings Outstanding		72.0		30.5		64.1		131.7		46.2		116.0

Available	$	128.0	$	89.5	$	55.9	$	68.3	$	73.8	$	84.0

The Credit Facility contains customary terms and conditions for credit facilities of this type, including affirmative and negative covenants. There are restrictions on, among other things, Unitil’s and its subsidiaries’ ability to incur liens or incur indebtedness, and restrictions on Unitil’s ability to merge or consolidate with another entity or change its line of business. The affirmative and negative covenants under the Credit Facility shall apply to Unitil until the Credit Facility terminates and all amounts borrowed under Credit Facility are paid in full (or, with respect to letters of credit, they are cash-collateralized). The only financial covenant in the Credit Facility provides that Unitil’s Funded Debt to Capitalization (as each term is defined in the Credit Facility) cannot exceed 65% tested on a quarterly basis. At ~~September~~June 30, ~~2022, September~~2023, June 30, ~~2021~~2022 and December 31, ~~2021,~~2022, the Company was in compliance with the covenants contained in the Credit Facility or the prior credit facility, as applicable, in effect on those dates.

~~The Company is monitoring~~

On July 6, 2023, Fitchburg issued $12.0 million of Notes due July 6, 2033 at 5.70% and $13.0 million of Notes due July 6, 2053 at 5.96%. Fitchburg used the ~~coronavirus pandemic, including any effect on planned capital expenditures. The Company does not believe the pandemic will adversely affect its access~~net proceeds from these offerings to ~~capital and funding sources. The Company believes its future operating cash flows, its available borrowing capacity, and its access to private and public capital markets for the issuance of long-term~~refinance existing debt and ~~equity securities~~for general corporate purposes. Approximately $0.2 million of costs associated with this issuance will be ~~sufficient to meet its working capital and capital investment needs.~~recorded as a reduction of Long-Term Debt for presentation purposes on the Consolidated Balance Sheet in the third quarter of 2023.

Unitil Corporation and its utility subsidiaries, Fitchburg, Unitil Energy, Northern Utilities, and Granite State currently are rated “BBB+” by Standard & Poor’s Ratings Services. Unitil Corporation and Granite State currently are rated “Baa2”, and Fitchburg, Unitil Energy and Northern Utilities are currently rated “Baa1” by Moody’s Investors Services.

The continued availability of various methods of financing, as well as the choice of a specific form of security for such financing, will depend on many factors, including, but not limited to: security market conditions; general economic climate; regulatory approvals; the ability to meet covenant issuance restrictions; the level of earnings, cash flows and financial position; and the competitive pricing offered by financing sources.

The Company provides limited guarantees on certain energy and gas storage management contracts entered into by the distribution utilities. The Company’s policy is to limit the duration of these guarantees. As of ~~September~~June 30, ~~2022,~~2023, there were ~~approximately $1.6 million of~~no guarantees ~~outstanding with a duration less than one year.~~outstanding.

Northern Utilities enters into asset management agreements under which Northern Utilities releases certain gas pipeline and storage assets, sells to an asset manager and subsequently repurchases the gas over the course of the gas heating season at the same price at which it sold the gas to the asset manager. There was ~~$23.4 million, $9.7 million and $8.3~~$8.7 million of natural gas storage inventory and corresponding obligations at ~~September~~June 30, ~~2022, September 30, 2021 and December 31, 2021, respectively,~~2023 related to these asset management agreements. The amount of natural gas inventory released in ~~September 2022 and~~June 30, 2023, which was payable in ~~October 2022 is $0.3 million and is recorded in Accounts Payable at September 30, 2022. The amount of gas released in September 2021 and payable in October 2021~~July 2023, was less than $0.1 million and was recorded in Accounts Payable at ~~September~~June 30, ~~2021. The amount of gas released in December 2021 and payable in January 2022 was $1.6 million and was recorded in Accounts Payable at December 31, 2021.~~2023.

Off-Balance Sheet Arrangements

The Company and its subsidiaries do not currently use, and are not dependent on the use of, off-balance sheet financing arrangements such as securitization of receivables or obtaining access to assets or cash through special purpose entities or variable interest entities. Unitil Corporation’s subsidiaries conduct a portion of their operations in leased facilities, and lease some of their vehicles, machinery and office equipment under both capital and operating lease arrangements. ~~As of September 30, 2022, there were approximately $1.6 million of guarantees on certain energy and gas storage management contracts entered into by the distribution utilities outstanding.~~ See Note 4 (Debt and Financing Arrangements) to the accompanying Consolidated Financial Statements.

~~CRITICAL ACCOUNTING POLICIES~~Critical Accounting Policies

The preparation of the Company’s financial statements in conformity with generally accepted accounting principles in the United States of America requires the Company to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. In making those estimates and assumptions, the Company sometimes is required to make difficult, subjective and/or complex judgments about the effect of matters that are inherently uncertain and for which different estimates that could reasonably have been used could have resulted in material differences in its financial statements. If actual results

were to differ significantly from those estimates, assumptions and judgment, the financial position of the Company could be materially affected and the results of operations of the Company could be materially different than reported. As of ~~September~~June 30, ~~2022,~~2023, the Company’s critical accounting policies and estimates had not changed significantly from December 31, ~~2021.~~2022. See Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Policies” in the Company’s ~~2021~~2022 Annual Report on Form 10-K for additional information.

EMPLOYEES

~~Unitil’s commitment to excellence begins with its employees.~~ As of ~~September~~June 30, ~~2022,~~2023, the Company and its subsidiaries had ~~517~~527 employees. The Company considers its relationship with employees to be good and has not experienced any major labor disruptions. ~~Unitil’s employees are focused on the Company’s mission to safely and reliably deliver “energy for life” and provide customers with affordable and sustainable energy solutions.~~

The Company strives to be the employer of choice in the communities it ~~serves –~~ serves—regardless of race, religion, color, gender, or sexual orientation. The Company works diligently to attract the best talent from a diverse range of sources to meet the current and future demands of our business.

To attract and retain a talented workforce, Unitil provides employee wages that are competitive and consistent with employee positions, skill levels, experience, knowledge and geographic location. All employees are eligible for health insurance, paid and unpaid leave, educational assistance, retirement plan and life and disability/accident coverage.

Feedback from employees is collected annually in the Company’s Employee Opinion survey. This feedback helps create action plans to improve the engagement of employees consistent with the Company’s culture of continuous improvement.

As of ~~September~~June 30, ~~2022,~~2023, a total of ~~171~~178 employees of certain of the Company’s subsidiaries were represented by labor unions. The following table details by subsidiary the employees covered by a collective bargaining agreement (CBA) as of ~~September~~June 30, ~~2022:~~2023:


	Employees Covered		CBA Expiration
Fitchburg	47	41		05/31/2027
Northern Utilities NH Division	37	36		06/07/2025
Northern Utilities ME Division	38	40		03/31/2026
Granite State	5	4		03/31/2026
Unitil Energy	41	41		05/31/~~2023~~	2028
Unitil Service – Gas Control	5	4		03/31/2024
Unitil Service	5	5		05/31/~~2023~~	2028

The CBAs provide discrete salary adjustments, established work practices and uniform benefit packages. The Company expects to negotiate new agreements prior to their expiration dates.

INTEREST RATE RISK

Unitil meets its external financing needs by issuing short-term and long-term debt. The majority of debt outstanding represents long-term notes or bonds bearing fixed rates of interest. Changes in market interest rates do not affect interest expense resulting from these outstanding long-term debt securities. However, the Company periodically repays its short-term debt borrowings through the issuance of new long-term debt securities. Changes in market interest rates may affect the interest rate and corresponding interest expense on any new issuances of long-term debt securities. In addition, short-term debt borrowings bear a variable rate of interest. As a result, changes in short-term interest rates will increase or decrease interest expense in future periods. For example, if the average amount of short-term debt outstanding was $25 million for the period of one year, a change in interest rates of 1% would result in a change in annual interest expense of approximately $250,000. The average interest rates on the Company’s short-term borrowings and intercompany money pool transactions for the three months ended ~~September~~June 30, 2023 and June 30, 2022 were 6.3% and ~~September 30, 2021 were 3.6% and 1.2%~~2.1%, respectively. The average interest rates on the Company’s short-term borrowings and intercompany money pool transactions for the ~~nine~~six months ended ~~September~~June 30, 2023 and June 30, 2022 were 6.1% and ~~September 30, 2021 were 2.4% and 1.2%~~1.7%, respectively. The average interest rate on the Company’s short-term borrowings for the twelve months ended December 31, ~~2021~~2022 was ~~1.2%~~3.3%.

COMMODITY PRICE RISK

Although Unitil’s three distribution utilities are subject to commodity price variations as part of their traditional operations, the current regulatory framework within which these companies operate allows for full collection of electric power and natural gas supply costs in rates on a pass-through basis. Consequently, there is limited commodity price risk after consideration of the related rate-making. As discussed in Note 6 (Regulatory Matters), the Company has divested its long-term power supply contracts and therefore, further reduced its exposure to commodity risk.

~~REGULATORY MATTERS~~Regulatory Matters

~~Please refer~~Refer to Note 6 to the Consolidated Financial Statements in Part I, Item 1 of this report for a discussion of Regulatory Matters.

ENVIRONMENTAL MATTERS

~~Please refer~~Refer to Note 7 to the Consolidated Financial Statements in Part I, Item 1 of this report for a discussion of Environmental Matters.

UNITIL CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF EARNINGS

(Millions except per share data)

(UNAUDITED)

Three Months Ended

September 30,

Nine Months Ended

September 30,


2022
2021
2022
   2021
Operating Revenues

Electric

$
75.7

$ 65.5
$
219.2

   $ 182.2
Gas


34.5

32.6

182.5

   151.3




Total Operating Revenues


110.2

98.1

401.7

   333.5




Operating Expenses

Cost of Electric Sales


47.3

40.1

142.6

   108.8
Cost of Gas Sales


14.1

13.2

81.9

   59.1
Operation and Maintenance


18.6

16.7

55.5

   51.2
Depreciation and Amortization


16.6

14.8

46.9

   44.5
Taxes Other Than Income Taxes


6.4

6.1

19.9

   18.5




Total Operating Expenses


103.0

90.9

346.8

   282.1




Operating Income


7.2

7.2

54.9

   51.4
Interest Expense, Net


6.6

6.5

19.1

   19.5
Other Expense (Income), Net


0.6

1.0

1.9

   3.4




Income (Loss) Before Income Taxes


—

(0.3 )

33.9

   28.5
Provision (Benefit) for Income Taxes


(0.5
)
(0.3 )

7.0

   6.9




Net Income

$
0.5

$ —
$
26.9

   $ 21.6




Net Income Per Common Share (Basic and Diluted)

$
0.03

$ —
$
1.68

   $ 1.42
Weighted Average Common Shares Outstanding – (Basic and Diluted)


16.0

15.5

16.0

   15.2


	Three Months Ended June 30,					Six Months Ended June 30,
	2023			2022		2023			2022
Operating Revenues
Electric	$	64.5		$	54.3	$	172.7		$	143.5
Gas		38.9			44.6		150.9			148.0
Total Operating Revenues		103.4			98.9		323.6			291.5
Operating Expenses
Cost of Electric Sales		40.3			30.7		121.8			95.3
Cost of Gas Sales		9.6			16.4		66.7			67.8
Operation and Maintenance		18.3			18.4		36.4			36.9
Depreciation and Amortization		16.6			14.8		33.3			30.3
Taxes Other Than Income Taxes		6.8			6.7		14.1			13.5
Total Operating Expenses		91.6			87.0		272.3			243.8
Operating Income		11.8			11.9		51.3			47.7
Interest Expense, Net		7.0			6.3		14.1			12.5
Other (Income) Expense, Net		(0.1	)		0.6		(0.1	)		1.3
Income Before Income Taxes		4.9			5.0		37.3			33.9
Provision for Income Taxes		0.7			0.1		9.0			7.5
Net Income	$	4.2		$	4.9	$	28.3		$	26.4
Net Income Per Common Share (Basic and Diluted)	$	0.25		$	0.30	$	1.76		$	1.65
Weighted Average Common Shares Outstanding – (Basic and Diluted)		16.0			16.0		16.0			16.0

(The accompanying notes are an integral part of these consolidated unaudited financial statements.)

~~Table of Contents~~

UNITIL CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Millions)

(UNAUDITED)

September 30,
   December 31,

2022
   2021    2021
ASSETS:

Current Assets
:

Cash and Cash Equivalents

$
7.9

   $ 8.8    $ 6.5
Accounts Receivable, Net


51.7

   46.3    66.9
Accrued Revenue


46.9

   38.6    61.2
Exchange Gas Receivable


25.1

   10.5    7.4
Gas Inventory


1.7

   0.9    1.0
Materials and Supplies


10.1

   8.6    8.6
Prepayments and Other


7.2

   7.3    8.1






Total Current Assets


150.6

   121.0    159.7






Utility Plant:

Electric


612.7

   581.0    602.4
Gas


995.7

   932.8    972.6
Common


66.7

   64.8    66.4
Construction Work in Progress


81.9

   84.8    47.5






Utility Plant


1,757.0

   1,663.4    1,688.9
Less: Accumulated Depreciation


453.2

   426.1    431.7






Net Utility Plant


1,303.8

   1,237.3    1,257.2






Other Noncurrent Assets:

Regulatory Assets


105.5

   132.4    108.9
Operating Lease Right of Use Assets


4.6

   5.1    4.7
Other Assets


14.4

   13.2    9.8






Total Other Noncurrent Assets


124.5

   150.7    123.4






TOTAL ASSETS

$
1,578.9

   $ 1,509.0    $ 1,540.3


	June 30,				December 31,
	2023		2022		2022
ASSETS:
Current Assets:
Cash and Cash Equivalents	$	6.8	$	5.1	$	9.0
Accounts Receivable, Net		59.5		54.3		73.8
Accrued Revenue		60.4		45.6		72.8
Exchange Gas Receivable		9.4		13.4		18.0
Gas Inventory		1.0		1.0		1.8
Materials and Supplies		12.9		9.7		11.4
Prepayments and Other		11.3		10.0		8.0
Total Current Assets		161.3		139.1		194.8
Utility Plant:
Electric		638.4		610.1		627.5
Gas		1,060.9		988.9		1,043.6
Common		68.9		66.7		67.6
Construction Work in Progress		64.2		56.2		52.6
Utility Plant		1,832.4		1,721.9		1,791.3
Less: Accumulated Depreciation		474.6		442.8		459.6
Net Utility Plant		1,357.8		1,279.1		1,331.7
Other Noncurrent Assets:
Regulatory Assets		51.5		106.6		47.8
Operating Lease Right of Use Assets		5.2		4.4		4.3
Other Assets		19.5		17.9		11.8
Total Other Noncurrent Assets		76.2		128.9		63.9
TOTAL ASSETS	$	1,595.3	$	1,547.1	$	1,590.4

(The accompanying notes are an integral part of these consolidated unaudited financial statements.)

~~Table of Contents~~

UNITIL CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS (Cont.)

(Millions, except number of shares)

(UNAUDITED)

September 30,
   December 31,

2022
   2021    2021
LIABILITIES AND CAPITALIZATION:

Current Liabilities:

Accounts Payable

$
35.2

   $ 29.5    $ 52.4
Short-Term Debt


72.0

   30.5    64.1
Long-Term Debt, Current Portion


8.2

   10.1    8.2
Regulatory Liabilities


20.8

   13.1    9.5
Energy Supply Obligations


29.8

   16.1    14.5
Interest Payable


6.5

   6.7    4.8
Environmental Obligations


0.6

   0.7    0.5
Other Current Liabilities


20.5

   19.9    19.5






Total Current Liabilities


193.6

   126.6    173.5






Noncurrent Liabilities:

Retirement Benefit Obligations


135.2

   166.2    133.9
Deferred Income Taxes, net


136.1

   115.7    127.7
Cost of Removal Obligations


115.4

   108.2    107.5
Regulatory Liabilities


37.9

   42.9    42.6
Environmental Obligations


2.2

   1.7    2.2
Other Noncurrent Liabilities


6.6

   6.8    6.6






Total Noncurrent Liabilities


433.4

   441.5    420.5






Capitalization:

Long-Term Debt, Less Current Portion


493.1

   501.3    497.8
Stockholders’ Equity:

Common Equity (Authorized: 25,000,000 and Outstanding: 16,039,141 15,971,962 and 15,977,766 Shares)


334.4

   331.6    332.1
Retained Earnings


124.2

   107.8    116.2






Total Common Stock Equity


458.6

   439.4    448.3
Preferred Stock


0.2

   0.2    0.2






Total Stockholders’ Equity


458.8

   439.6    448.5






Total Capitalization


951.9

   940.9    946.3






Commitments and Contingencies (Notes 6 & 7)

TOTAL LIABILITIES AND CAPITALIZATION

$
1,578.9

   $ 1,509.0    $ 1,540.3


	June 30,				December 31,
	2023		2022		2022
LIABILITIES AND CAPITALIZATION:
Current Liabilities:
Accounts Payable	$	36.7	$	34.3	$	68.6
Short-Term Debt		131.7		46.2		116.0
Long-Term Debt, Current Portion		6.9		8.2		6.7
Regulatory Liabilities		18.4		25.9		15.0
Energy Supply Obligations		13.9		16.6		24.1
Interest Payable		5.2		4.8		5.0
Environmental Obligations		0.6		0.6		0.6
Taxes Payable		2.3		0.1		0.4
Other Current Liabilities		22.3		18.3		23.7
Total Current Liabilities		238.0		155.0		260.1
Noncurrent Liabilities:
Retirement Benefit Obligations		44.3		135.9		46.8
Deferred Income Taxes, net		171.3		136.4		163.4
Cost of Removal Obligations		123.2		112.4		116.1
Regulatory Liabilities		35.5		38.9		36.9
Environmental Obligations		4.1		2.2		3.8
Other Noncurrent Liabilities		8.3		6.9		6.6
Total Noncurrent Liabilities		386.7		432.7		373.6
Capitalization:
Long-Term Debt, Less Current Portion		486.2		495.1		489.1
Stockholders’ Equity:
Common Equity (Authorized: 25,000,000 and Outstanding: 16,091,419, 16,034,635 and 16,043,355 Shares)		336.5		334.1		334.9
Retained Earnings		147.7		130.0		132.5
Total Common Stock Equity		484.2		464.1		467.4
Preferred Stock		0.2		0.2		0.2
Total Stockholders’ Equity		484.4		464.3		467.6
Total Capitalization		970.6		959.4		956.7
Commitments and Contingencies (Notes 6 & 7)
TOTAL LIABILITIES AND CAPITALIZATION	$	1,595.3	$	1,547.1	$	1,590.4

(The accompanying notes are an integral part of these consolidated unaudited financial statements.)

~~Table of Contents~~

UNITIL CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Millions) (UNAUDITED)

Nine Months Ended

September 30,


2022
2021
Operating Activities:

Net Income

$
26.9

$ 21.6
Adjustments to
Reconcile Net Income to Cash Provided by Operating Activities:

Depreciation and Amortization


46.9

44.5
Deferred Tax Provision


6.4

5.5
Changes in Working Capital Items:

Accounts Receivable


15.2

15.7
Accrued Revenue


14.3

12.3
Exchange Gas Receivable


(17.7
)
(5.6 )
Regulatory Liabilities


11.3

7.6
Accounts Payable


(17.2
)
(3.7 )
Other Changes in Working Capital Items


0.3

2.7
Deferred Regulatory and Other Charges


(8.3
)
(8.0 )
Other, net


4.6

3.3


Cash Provided by Operating Activities

82.7

95.9


Investing Activities:

Property, Plant and Equipment Additions

(82.5
)
(81.5 )


Cash (Used in) Investing Activities

(82.5
)
(81.5 )


Financing Activities:

Proceeds from (Repayment of) Short-Term Debt, net


7.9

(24.2 )
Repayment of Long-Term Debt


(4.9
)
(20.3 )
Net Increase in Exchange Gas Financing


16.4

5.2
Decrease in Capital Lease Obligations


(0.1
)
(0.1 )
Dividends Paid


(18.9
)
(17.5 )
Proceeds from Issuance of Common Stock


0.8

45.3


Cash Provided by (Used in) Financing Activities

1.2

(11.6 )


Net Increase in Cash and Cash Equivalents


1.4

2.8
Cash and Cash Equivalents at Beginning of Period


6.5

6.0


Cash and Cash Equivalents at End of Period

$
7.9

$ 8.8


Supplemental Cash Flow Information:

Interest Paid

$
17.7

$ 17.9
Income Taxes Paid

$
1.2

$ 1.4
Payments on Capital Leases

$
0.1

$ 0.2
Non-cash
Investing Activity:

Capital Expenditures Included in Accounts Payable

$
5.4

$ 4.2
Right-of-Use
Assets Obtained in Exchange for Lease Obligations

$
1.2

$ 0.9


	For the Six Months Ended June 30,
	2023			2022
Operating Activities:
Net Income	$	28.3		$	26.4
Adjustments to Reconcile Net Income to Cash Provided by Operating Activities:
Depreciation and Amortization		33.3			30.3
Deferred Tax Provision		8.8			7.2
Changes in Working Capital Items:
Accounts Receivable		14.3			12.6
Accrued Revenue		12.4			15.6
Exchange Gas Receivable		8.6			(6.0	)
Regulatory Liabilities		3.4			16.4
Accounts Payable		(31.9	)		(18.1	)
Other Changes in Working Capital Items		(6.1	)		(7.6	)
Deferred Regulatory and Other Charges		(13.6	)		(10.2	)
Other, net		4.9			4.4
Cash Provided by Operating Activities		62.4			71.0
Investing Activities:
Property, Plant and Equipment Additions		(57.6	)		(45.3	)
Cash (Used in) Investing Activities		(57.6	)		(45.3	)
Financing Activities:
Proceeds from (Repayment of) Short-Term Debt, net		15.7			(17.9	)
Repayment of Long-Term Debt		(2.8	)		(2.8	)
Net (Decrease) Increase in Exchange Gas Financing		(7.6	)		5.8
Increase (Decrease) in Capital Lease Obligations		0.2			(0.1	)
Dividends Paid		(13.1	)		(12.6	)
Proceeds from Issuance of Common Stock		0.6			0.5
Cash (Used in) Financing Activities		(7.0	)		(27.1	)
Net (Decrease) in Cash and Cash Equivalents		(2.2	)		(1.4	)
Cash and Cash Equivalents at Beginning of Period		9.0			6.5
Cash and Cash Equivalents at End of Period	$	6.8		$	5.1
Supplemental Cash Flow Information:
Interest Paid	$	15.5		$	12.8
Income Taxes Paid	$	—		$	1.1
Payments on Capital Leases	$	0.1		$	0.1
Non-cash Investing Activity:
Capital Expenditures Included in Accounts Payable	$	5.3		$	3.9
Right-of-Use Assets Obtained in Exchange for Lease Obligations	$	1.8		$	0.5

(The accompanying notes are an integral part of these consolidated unaudited financial statements.)

~~Table of Contents~~

UNITIL CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCK EQUITY

(Millions, except number of shares)

(UNAUDITED)

   Common
Equity    Retained
Earnings Total
Three Months Ended September 30, 2022

Balance at July 1, 2022
   $ 334.1    $ 130.0
$
464.1

Net Income
      0.5

0.5

Dividends on Common Shares ($0.39 per share)
      (6.3 )

(6.3
)
Stock Compensation Plans
   0.1

0.1

Issuance of 4,506 Common Shares
   0.2

0.2





Balance at September 30, 2022

$
334.4


$
124.2

$
458.6





Three Months Ended September 30, 2021

Balance at July 1, 2021
   $ 286.8    $ 113.8
$
400.6

Net Income
      —

—

Dividends on Common Shares ($0.38 per share)
      (6.0 )

(6.0
)
Stock Compensation Plans
   0.1

0.1

Issuance of 925,493 Common Shares
   44.7

44.7





Balance at September 30, 2021

$
331.6


$
107.8

$
439.4


	Common Equity		Retained Earnings			Total
Three Months Ended June 30, 2023
Balance at April 1, 2023	$	336.1	$	150.1		$	486.2
Net Income				4.2			4.2
Dividends ($0.405 per Common Share)				(6.6	)		(6.6	)
Stock Compensation Plans		0.1					0.1
Issuance of 5,189 Common Shares		0.3					0.3
Balance at June 30, 2023	$	336.5	$	147.7		$	484.2
Three Months Ended June 30, 2022
Balance at April 1, 2022	$	333.7	$	131.4		$	465.1
Net Income				4.9			4.9
Dividends ($0.39 per Common Share)				(6.3	)		(6.3	)
Stock Compensation Plans		0.2					0.2
Issuance of 4,352 Common Shares		0.2					0.2
Balance at June 30, 2022	$	334.1	$	130.0		$	464.1


	Common Equity		Retained Earnings			Total
Six Months Ended June 30, 2023
Balance at January 1, 2023	$	334.9	$	132.5		$	467.4
Net Income				28.3			28.3
Dividends ($0.81 per Common Share)				(13.1	)		(13.1	)
Stock Compensation Plans		1.0					1.0
Issuance of 10,524 Common Shares		0.6					0.6
Balance at June 30, 2023	$	336.5	$	147.7		$	484.2
Six Months Ended June 30, 2022
Balance at January 1, 2022	$	332.1	$	116.2		$	448.3
Net Income				26.4			26.4
Dividends ($0.78 per Common Share)				(12.6	)		(12.6	)
Stock Compensation Plans		1.5					1.5
Issuance of 9,863 Common Shares		0.5					0.5
Balance at June 30, 2022	$	334.1	$	130.0		$	464.1

(The accompanying notes are an integral part of these consolidated unaudited financial statements.)

~~Table of Contents~~

UNITIL CORPORATION AND SUBSIDIARY COMPANIES

~~CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCK EQUITY~~

~~(Millions, except number of shares)~~

~~(UNAUDITED)~~

   Common
Equity    Retained
Earnings Total
Nine Months Ended September 30, 2022

Balance at January 1, 2022
   $ 332.1    $ 116.2
$
448.3

Net Income
      26.9

26.9

Dividends on Common Shares ($1.17 per share)
      (18.9 )

(18.9
)
Stock Compensation Plans
   1.5

1.5

Issuance of 14,369 Common Shares
   0.8

0.8





Balance at September 30, 2022

$
334.4


$
124.2

$
458.6





Nine Months Ended
September
30, 2021

Balance at January 1, 2021
   $ 285.3    $ 103.7
$
389.0

Net Income
      21.6

21.6

Dividends on Common Shares ($1.14 per share)
      (17.5 )

(17.5
)
Stock Compensation Plans
   1.0

1.0

Issuance of 936,512 Common Shares
   45.3

45.3





Balance at September 30, 2021

$
331.6


$
107.8

$
439.4

~~(The accompanying notes are an integral part of these consolidated unaudited financial statements.)~~

~~Table of Contents~~

~~UNITIL CORPORATION AND SUBSIDIARY COMPANIES~~

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

~~(UNAUDITED)~~

~~NOTE~~

Note 1 - ~~SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES~~

Summary of Significant Accounting Policies

Nature of Operations

Unitil Corporation (Unitil or the Company) is a public utility holding company. Unitil and its subsidiaries are subject to regulation as a holding company system by the Federal Energy Regulatory Commission (FERC) under the Energy Policy Act of 2005. The following companies are wholly-owned subsidiaries of Unitil: Unitil Energy Systems, Inc. (Unitil Energy), Fitchburg Gas and Electric Light Company (Fitchburg), Northern Utilities, Inc. (Northern Utilities), Granite State Gas Transmission, Inc. (Granite State), Unitil Power Corp. (Unitil Power), Unitil Realty Corp. (Unitil Realty), Unitil Service Corp. (Unitil Service) and its

non-regulated

business unit Unitil Resources, Inc. (Unitil Resources).

The Company’s earnings historically have been seasonal and typically higher in the first and fourth quarters when customers use gas for heating purposes.

Unitil’s principal business is the local distribution of electricity in the southeastern seacoast and capital city areas of New Hampshire and the greater Fitchburg area of north central Massachusetts and the local distribution of gas in southeastern New Hampshire, portions of southern Maine to the Lewiston-Auburn area and in the greater Fitchburg area of north central Massachusetts. Unitil has three distribution utility subsidiaries, including Unitil Energy, which operates in New Hampshire; Fitchburg, which operates in Massachusetts; and Northern Utilities, which operates in New Hampshire and Maine (collectively referred to as the “distribution utilities”).

Granite State is an interstate gas transmission pipeline company, operating 86 miles of underground gas transmission pipeline primarily located in Maine and New Hampshire. Granite State provides Northern Utilities with interconnection to three major gas pipelines and access to domestic gas supplies in the south and Canadian gas supplies in the north. Granite State derives its revenues principally from transportation services provided to Northern Utilities and, to a lesser extent, third-party marketers.

A fifth utility subsidiary, Unitil Power, formerly functioned as the full requirements wholesale power supply provider for Unitil Energy. In connection with the implementation of electric industry restructuring in New Hampshire, on May 1, 2003 Unitil Power ceased being the wholesale supplier of Unitil Energy and divested of its long-term power supply contracts through the sale of the entitlements to the electricity associated with various electric power supply contracts it had acquired to serve Unitil Energy’s customers. In the period since, Unitil Power continued to flow revenues and expenses from remaining contracts to Unitil Energy under the Amended Unitil System Agreement. The last of those contracts expired October 31, 2020, and the Company no longer has material revenues or expenses associated with them.

Unitil also has three other wholly-owned subsidiaries: Unitil Service, Unitil Realty and Unitil Resources. Unitil Service provides, at cost, a variety of administrative and professional services, including regulatory, financial, accounting, human resources, engineering, operations, technology, energy management and management services on a centralized basis to its affiliated Unitil companies. Unitil Realty owns and manages the Company’s corporate office in Hampton, New Hampshire and leases this facility to Unitil Service under a long-term lease arrangement. Unitil Resources is the Company’s wholly-owned

non-regulated subsidiary.

~~subsidiary.~~

Basis of Presentation -

The ac

~~companyi~~

ngaccompanying unaudited consolidated financial statements of Unitil have been prepared in accordance with the instructions to Form

10-Q

and include the information and footnotes required by generally accepted accounting principles. In the opinion of management, all adjustments considered necessary for a fair presentation have been included. The results of operations for the three and ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 are not necessarily indicative of results to be expected for the year ending December 31, ~~2022.~~2023. For additional information, refer to Note 1 of Part II to the Consolidated Financial Statements – “Summary of Significant Accounting Policies” of the Company’s Form

10-K

for the year ended December 31, ~~2021,~~2022, as filed with the Securities and Exchange Commission (SEC) on February ~~1, 2022,~~14, 2023, for a description of the Company’s Basis of ~~Presentation.~~

Presentation.

~~Table of Contents~~

Utility Revenue Recognition -

Electric Operating Revenues and Gas Operating Revenues consist of billed and unbilled revenue and revenue from rate adjustment mechanisms. Billed and unbilled revenue includes delivery revenue and pass-through revenue, recognized according to tariffs approved by federal and state regulatory commissions, which determine the amount of revenue the Company will record for these items. Revenue from rate adjustment mechanisms is accrued revenue, recognized in connection with rate adjustment mechanisms, and authorized by regulators for recognition in the current period for future cash recoveries from, or credits to, customers.

Revenue is recorded when service is rendered or energy is delivered to customers. However, the determination of energy sales to individual customers is based on the reading of their meters, which occurs on a systematic basis throughout the month. At the end of each calendar month, amounts of energy delivered to customers since the date of the last meter reading are estimated and the corresponding unbilled revenues are calculated. These unbilled revenues are estimated each month based on estimated customer usage by class and applicable customer rates, taking into account current and historical weather data, assumptions pertaining to metering patterns, billing cycle statistics, and other estimates and assumptions, and are then reversed in the following month when billed to customers.

A majority of the Company’s revenue from contracts with customers continues to be recognized on a monthly basis based on applicable tariffs and customer monthly consumption. Such revenue is recognized using the invoice practical expedient, which allows an entity to recognize revenue in the amount that directly corresponds to the value transferred to the customer.

The Company’s billed and unbilled revenue meets the definition of “revenues from contracts with customers” as defined in Accounting Standards Codification (ASC) 606. Revenue recognized in connection with rate adjustment mechanisms is consistent with the definition of alternative revenue programs in ASC

980-605-25-3,

as the Company has the ability to adjust rates in the future as a result of past activities or completed events. The rate adjustment mechanisms meet the criteria within ASC

980-605-25-4.

In cases where allowable costs are greater than operating revenues billed in the current period for the individual rate adjustment mechanism, additional operating revenue is recognized. In cases where allowable costs are less than operating revenues billed in the current period for the individual rate adjustment mechanism, operating revenue is reduced. ASC 606 requires the Company to disclose separately the amount of revenues from contracts with customers and alternative revenue program revenues.

In the following tables, revenue is classified by the types of goods/services rendered and market/customer type.


	Three Months Ended June 30, 2023
Electric and Gas Operating Revenues (millions):	Electric			Gas			Total
Billed and Unbilled Revenue:
Residential	$	39.8		$	17.9		$	57.7
Commercial and Industrial		28.1			26.4			54.5
Other		1.9			1.0			2.9
Total Billed and Unbilled Revenue		69.8			45.3			115.1
Rate Adjustment Mechanism Revenue		(5.3	)		(6.4	)		(11.7	)
Total Electric and Gas Operating Revenues	$	64.5		$	38.9		$	103.4


	Three Months Ended June 30, 2022
Electric and Gas Operating Revenues (millions):	Electric			Gas			Total
Billed and Unbilled Revenue:
Residential	$	33.8		$	18.1		$	51.9
Commercial and Industrial		25.7			28.0			53.7
Other		4.6			3.5			8.1
Total Billed and Unbilled Revenue		64.1			49.6			113.7
Rate Adjustment Mechanism Revenue		(9.8	)		(5.0	)		(14.8	)
Total Electric and Gas Operating Revenues	$	54.3		$	44.6		$	98.9


	Six Months Ended June 30, 2023
Electric and Gas Operating Revenues (millions):	Electric		Gas			Total
Billed and Unbilled Revenue:
Residential	$	99.9	$	67.0		$	166.9
Commercial and Industrial		62.9		95.6			158.5
Other		4.6		4.6			9.2
Total Billed and Unbilled Revenue		167.4		167.2			334.6
Rate Adjustment Mechanism Revenue		5.3		(16.3	)		(11.0	)
Total Electric and Gas Operating Revenues	$	172.7	$	150.9		$	323.6


	Six Months Ended June 30, 2022
Electric and Gas Operating Revenues (millions):	Electric			Gas			Total
Billed and Unbilled Revenue:
Residential	$	83.0		$	63.6		$	146.6
Commercial and Industrial		56.7			92.7			149.4
Other		9.1			7.0			16.1
Total Billed and Unbilled Revenue		148.8			163.3			312.1
Rate Adjustment Mechanism Revenue		(5.3	)		(15.3	)		(20.6	)
Total Electric and Gas Operating Revenues	$	143.5		$	148.0		$	291.5

Three Months Ended September 30, 2022

Electric and Gas Operating Revenues ($ millions):

  Electric

  Gas

  Total

Billed and Unbilled Revenue:

Residential
   $ 42.5    $

8.8    $

51.3
Commercial and Industrial
   30.2    17.8    48.0
Other
   5.1    0.8    5.9






Total Billed and Unbilled Revenue    77.8       27.4    105.2
Rate Adjustment Mechanism Revenue
   (2.1 )    7.1    5.0






Total Electric and Gas Operating Revenues

$
75.7


$
34.5


$
110.2

~~Table of Contents~~

Three Months Ended September 30, 2021

Electric and Gas Operating Revenues ($ millions):

  Electric

  Gas

  Total

Billed and Unbilled Revenue:

Residential
   $ 35.0    $ 7.9    $ 42.9
Commercial and Industrial
   26.8    14.4    41.2
Other
   3.2    0.8    4.0






Total Billed and Unbilled Revenue    65.0    23.1    88.1
Rate Adjustment Mechanism Revenue
   0.5    9.5    10.0






Total Electric and Gas Operating Revenues

$
65.5


$
32.6


$
98.1








Nine Months Ended September 30, 2022

Electric and Gas Operating Revenues ($ millions):

Electric

Gas

Total

Billed and Unbilled Revenue:

Residential
   $ 125.5    $ 72.4    $ 197.9
Commercial and Industrial
   86.9    110.5    197.4
Other
   14.3    7.7    22.0






Total Billed and Unbilled Revenue    226.7    190.6    417.3
Rate Adjustment Mechanism Revenue
   (7.5 )    (8.1 )    (15.6 )






Total Electric and Gas Operating Revenues

$
219.2


$
182.5


$
401.7








Nine Months Ended September 30, 2021

Electric and Gas Operating Revenues ($ millions):

Electric

Gas

Total

Billed and Unbilled Revenue:

Residential
   $ 104.0    $ 60.5    $ 164.5
Commercial and Industrial
   78.2    86.2    164.4
Other
   6.9    7.6    14.5






Total Billed and Unbilled Revenue    189.1    154.3    343.4
Rate Adjustment Mechanism Revenue
   (6.9 )    (3.0 )    (9.9 )






Total Electric and Gas Operating Revenues

$
182.2


$
151.3


$
333.5

~~tchbu~~

~~rg is subject to revenue decoupling. As of June1, 2022, Unitil Energy is subject to decoupling. As of August 1, 2022, the New Hampshire division of Northern Utilities also is subject to decoupling.~~

of rate cases and other authorized adjustments that the Company files with the Massachusetts Department of Public Utilities (MDPU) and ~~the~~ New Hampshire Public Utilities Commission

(NHPUC).

Fitchburg has been subject to revenue decoupling since 2011. Unitil Energy is subject to revenue decoupling as of June 1, 2022. As a result of Unitil Energy now being subject to revenue decoupling, as of June 1, 2022, revenue decoupling now applies to substantially all of Unitil’s total annual electric sales volumes. As a result of the 2022 final order in Northern Utilities’ base rate case in New Hampshire, substantially all of Northern Utilities’ gas sales volumes in New Hampshire are subject to decoupling as of August 1, 2022. As of August 1, 2022, the Company estimates that revenue decoupling applies to approximately 43% of Unitil’s total annual gas sales volumes. The Company's electric and gas sales in New Hampshire and Massachusetts are now largely decoupled. The following table shows the estimated percentages of electric and gas sales that are subject to revenue decoupling for the periods presented.


Revenue Decoupling
Estimated Percentage of Decoupled Sales
For Periods Presented
Electric
Before June 1, 2022	27%
After June 1, 2022	Substantially All
Gas
Before August 1, 2022	11%
After August 1, 2022	43%

~~Table of Contents~~

Income Taxes -

The Company is subject to Federal and State income taxes and various other business taxes. The Company’s process for determining income tax amounts involves estimating the Company’s current tax liabilities, and assessing temporary and permanent differences resulting from the timing of the deductions of expenses and recognition of taxable income for tax and book accounting purposes. These temporary differences result in deferred tax assets and liabilities, which are included in the Company’s Consolidated Balance Sheets. The Company accounts for income tax assets, liabilities and expenses in accordance with the Financial Accounting Standards Board (FASB) Codification guidance on Income Taxes. The Company classifies penalties and interest expense related to income tax liabilities as income tax expense and interest expense, respectively, in the Consolidated Statements of Earnings.

Provisions for income taxes are calculated in each jurisdiction in which the Company operates, for each period for which a statement of earnings is presented. The Company accounts for income taxes in accordance with the FASB Codification guidance on Income Taxes, which requires an asset and liability approach for the financial accounting and reporting of income taxes. Significant judgments and estimates are required in determining the current and deferred tax assets and liabilities. The Company’s deferred tax assets and liabilities reflect its best assessment of estimated future taxes to be paid. In accordance with the FASB Codification, the Company periodically assesses the realization of its deferred tax assets and liabilities and adjusts the income tax provision, the current tax liability and deferred taxes in the period in which the facts and circumstances which gave rise to the revision become known.

Cash and Cash Equivalents -

Cash and Cash Equivalents includes all cash and cash equivalents to which the Company has legal title. Cash equivalents include short-term investments with original maturities of three months or less and interest bearing deposits. The Company’s cash and cash equivalents are held at financial institutions and at times may exceed federally insured limits. The Company has not experienced any losses in such accounts. Under the Independent System Operator—New England

(ISO-NE)

Financial Assurance Policy (Policy), Unitil’s subsidiaries Unitil Energy, Fitchburg and Unitil Power are required to provide assurance of their ability to satisfy their obligations to

ISO-NE.

Under this Policy, Unitil’s subsidiaries provide cash deposits covering approximately

2-1/2

months of outstanding obligations, less credit amounts that are based on the Company’s credit rating. As of ~~September~~June

30, 2023, June 30, 2022 ~~September 30, 2021~~ and December 31, ~~2021,~~2022, the Unitil subsidiaries had deposited

$~~4.8~~3.3 million, ~~$5.7~~$1.7 million and ~~$2.7~~$6.0 million, respectively to satisfy their ISO-NE obligations.

~~ISO-NE~~

~~obligations.~~

Allowance for Doubtful Accounts -

The Company recognizes a provision for doubtful accounts that reflects the Company’s estimate of expected credit losses for electric and gas utility service accounts receivable. The allowance for doubtful accounts is calculated by applying a historical loss rate to customer account balances, and reflects management’s assessment of current and expected economic conditions, customer trends, or other ~~factors such as the extent and duration of any shutoff or collection moratoriums.~~factors. The Company also calculates the amount of

written-off

receivables that are recoverable through regulatory rate reconciling mechanisms. The Company’s distribution utilities are authorized by regulators to recover the costs of the energy commodity portion of bad debts through rate mechanisms. Also, the electric and gas divisions of Fitchburg are authorized to recover through rates past due amounts associated with protected hardship accounts. Evaluating the adequacy of the allowance for doubtful accounts requires judgment about the assumptions used in the analysis. The Company’s experience has been that the assumptions used in evaluating the adequacy of the allowance for doubtful accounts have proven to be reasonably accurate.

The Allowance for Doubtful Accounts as of ~~September~~June 30, ~~2022, September~~2023, June 30, ~~2021~~2022 and December 31, ~~2021,~~2022, was as follows:


	June 30,				December 31,
(millions)	2023		2022		2022
Allowance for Doubtful Accounts	$	2.2	$	2.7	$	2.6

($ millions)


September 30,
   December 31,

2022
   2021    2021
Allowance for Doubtful Accounts

$
2.4

   $ 4.3    $ 3.3

Accounts Receivable, Net includes ~~$2.4~~$2.2 million, ~~$4.2~~$2.6 million, and ~~$3.1~~$2.5 million of the Allowance for Doubtful Accounts at ~~September~~June 30, 2023, June 30, 2022 ~~September 30, 2021~~ and December

31, ~~2021,~~2022, respectively.

~~Table of Contents~~

Unbilled Revenues,

, net (a component of Accrued Revenue) includes less than ~~$0.1~~$0.1 million, ~~$0.1~~$0.1 million and ~~$0.2~~$0.1 million of the Allowance for Doubtful Accounts at ~~September~~June 30, ~~2022, September~~2023, June 30, ~~2021~~2022 and December 31, ~~2021,~~2022, respectively.

Accrued Revenue -

Accrued Revenue

includes the current portion of Regulatory Assets and unbilled revenues. The following table shows the components of Accrued Revenue as of ~~September~~June 30, ~~2022, September~~2023, June 30, ~~2021~~2022 and December 31, ~~2021.~~2022.


	June 30,				December 31,
Accrued Revenue (millions)	2023		2022		2022
Regulatory Assets – Current	$	56.8	$	41.4	$	66.5
Unbilled Revenues, net		3.6		4.2		6.3
Total Accrued Revenue	$	60.4	$	45.6	$	72.8

September 30,

December 31,

Accrued Revenue ($ millions)

2022
   2021    2021
Regulatory Assets – Current

$
44.0

   $ 30.6    $ 47.4
Unbilled Revenues, net


2.9

   8.0    13.8






Total Accrued Revenue

$
46.9

   $ 38.6    $ 61.2

Exchange Gas Receivable -

Northern Utilities and Fitchburg have gas exchange and storage agreements whereby gas purchases during the months of April through October are delivered to a third party. The third party delivers gas back to the Company during the months of November through March. The exchange and storage gas volumes are recorded at weighted average cost. The following table shows the components of Exchange Gas Receivable as of ~~September~~June 30, ~~2022, September~~2023, June 30, ~~2021~~2022 and December 31, ~~2021.~~2022.


	June 30,				December 31,
Exchange Gas Receivable (millions)	2023		2022		2022
Northern Utilities	$	8.7	$	12.5	$	16.3
Fitchburg		0.7		0.9		1.7
Total Exchange Gas Receivable	$	9.4	$	13.4	$	18.0

September 30,
   December 31,
Exchange Gas Receivable ($ millions)

2022
   2021    2021
Northern Utilities

$
23.1

   $ 9.7    $ 6.7
Fitchburg


2.0

   0.8    0.7






Total Exchange Gas Receivable

$
25.1

   $ 10.5    $ 7.4

Gas Inventory

- The Company uses the weighted average cost methodology to value gas inventory. The following table shows the components of Gas Inventory as of ~~September~~June 30, ~~2022, September~~2023, June 30, ~~2021~~2022 and December 31, ~~2021.~~2022.


	June 30,				December 31,
Gas Inventory (millions)	2023		2022		2022
Natural Gas	$	0.6	$	0.5	$	1.0
Propane		0.3		0.4		0.4
Liquefied Natural Gas & Other		0.1		0.1		0.4
Total Gas Inventory	$	1.0	$	1.0	$	1.8

September 30,
   December 31,
Gas Inventory ($ millions)

2022
   2021    2021
Natural Gas

$
1.1

   $ 0.4    $ 0.5
Propane


  0.4

     0.4    0.4
Liquefied Natural Gas & Other


0.2

   0.1    0.1






Total Gas Inventory

$
1.7

   $ 0.9    $ 1.0

Utility Plant -

The cost

~~addition~~

s additions to Utility Plant and the cost of renewals and betterments are capitalized. Cost consists of labor, materials, services and certain indirect construction costs, including an allowance for funds used during construction (AFUDC). The costs of current repairs and minor replacements are charged to appropriate operating expense accounts. The original cost of utility plant retired or otherwise disposed of is charged to the accumulated provision for depreciation. The Company includes in its mass

asset depreciation rates, which are periodically reviewed as part of its ratemaking proceedings, cost of removal amounts to provide for future negative salvage value. At ~~September~~June 30, ~~2022, September~~2023, June 30, ~~2021~~2022 and December 31, ~~2021,~~2022, the cost of removal amounts, which are recorded on the Consolidated Balance Sheets in Cost of Removal Obligations, were estimated to be ~~$115.4~~$123.2 million, ~~$108.2~~$112.4 million, and ~~$107.5~~$116.1 million, respectively.

~~Table of Contents~~

Leases -

The Company

records assets and liabilities on the balance sheet for all leases with terms longer than 12 months. Leases are classified as either finance or operating, with classification affecting the pattern of expense recognition in the income statement. The Company has elected the practical expedient to not separate

non-lease

components from lease components and instead to account for both as a single lease component. The Company’s accounting policy election for leases with a lease term of 12 months or less is to recognize the lease payments as lease expense in the Consolidated Statements of Earnings on a straight-line basis over the lease term. See additional discussion in the “Leases” section of Note 4 (Debt and Financing Arrangements).

Regulatory Accounting -

The Company’s principal business is the distribution of electricity and natural gas by the three distribution utilities: Unitil Energy, Fitchburg and Northern Utilities. Unitil Energy and Fitchburg are subject to regulation by the FERC. Fitchburg is also regulated by the MDPU, Unitil Energy is regulated by the NHPUC and Northern Utilities is regulated by the MPUC and NHPUC. Granite State, the Company’s natural gas transmission pipeline, is regulated by the FERC. Accordingly, the Company uses the Regulated Operations guidance as set forth in the FASB Codification. The Company has recorded Regulatory Assets and Regulatory Liabilities which will be recovered from customers, or applied for customer benefit, in accordance with rate provisions approved by the applicable public utility regulatory commission. The electric and gas divisions of Fitchburg are authorized to recover through rates past due amounts associated with hardship accounts that are protected from

shut-off.

As of ~~September~~June 30, ~~2022, September~~2023, June 30, ~~2021~~2022 and December 31, ~~2021,~~2022, the Company has recorded ~~$5.8~~$6.0 million, ~~$9.5~~$7.6 million and ~~$7.9~~$5.8 million, respectively, of hardship accounts in Regulatory Assets. These amounts are included in “Other Deferred Charges” in the following table. The Company currently receives recovery in rates or expects to receive recovery of these hardship accounts in future rate cases.


	June 30,				December 31,
Regulatory Assets consist of the following (millions)	2023		2022		2022
Retirement Benefits	$	27.2	$	86.9	$	29.1
Energy Supply and Other Rate Adjustment Mechanisms		54.0		38.2		63.0
Deferred Storm Charges		8.5		2.9		3.4
Environmental		6.1		4.5		5.9
Income Taxes		1.5		2.2		1.8
Other Deferred Charges		11.0		13.3		11.1
Total Regulatory Assets		108.3		148.0		114.3
Less: Current Portion of Regulatory Assets(1)		56.8		41.4		66.5
Regulatory Assets – noncurrent	$	51.5	$	106.6	$	47.8

~~cases.~~(1)

Reflects amounts included in the Accrued Revenue on the Company’s Consolidated Balance Sheets.


	June 30,				December 31,
Regulatory Liabilities consist of the following (millions)	2023		2022		2022
Income Taxes (Note 8)	$	39.6	$	42.6	$	41.0
Rate Adjustment Mechanisms		14.3		22.2		10.9
Total Regulatory Liabilities		53.9		64.8		51.9
Less: Current Portion of Regulatory Liabilities		18.4		25.9		15.0
Regulatory Liabilities – noncurrent	$	35.5	$	38.9	$	36.9

September 30,
   December 31,
Regulatory Assets consist of the following ($ millions)

2022
   2021    2021
Retirement Benefits

$
87.4

$ 107.0 $ 86.4
Energy Supply and Other Rate Adjustment Mechanisms

40.9

27.3 44.1
Deferred Storm Charges

2.7

3.4 3.3
Environmental

4.5

4.8 4.6
Income Taxes

2.0

2.8 2.6
Other Deferred Charges

12.0

17.7 15.3

Total Regulatory Assets

149.5

163.0 156.3
Less: Current Portion of Regulatory Assets
(1)

44.0

30.6 47.4

Regulatory Assets – noncurrent

$
105.5

$ 132.4 $ 108.9

~~(1)~~

~~Reflects amounts included in the Accrued Revenue on the Company’s Consolidated Balance Sheets.~~

September 30,
   December 31,
Regulatory Liabilities consist of the following ($ millions)

2022
   2021    2021
Income Taxes (Note 8)

$
42.1

$ 44.6 $ 44.3
Rate Adjustment Mechanisms


16.6

11.3 7.7
Other


—

0.1 0.1


Total Regulatory Liabilities


58.7

56.0 52.1
Less: Current Portion of Regulatory Liabilities


20.8

13.1 9.5


Regulatory Liabilities – noncurrent

$
37.9

$ 42.9 $ 42.6

~~Table of Contents~~

Generally, the Company receives a return on investment on its regulatory assets for which a cash outflow has been made. Included in Regulatory Assets as of ~~September~~June 30, ~~2022~~2023 are ~~$5.8~~$5.5 million of environmental costs, rate case costs and other expenditures to be recovered over varying periods in the next seven years. Regulators have authorized recovery of these expenditures, but without a return. Regulatory commissions can reach different conclusions about the recovery of costs, which can have a material effect on the Company’s Consolidated Financial Statements. The Company believes it is probable that its regulated distribution and transmission utilities will recover their investments in long-lived assets, including regulatory assets. If the Company, or a portion of its assets or operations, were to cease meeting the criteria for application of these accounting rules, accounting standards for businesses in general would become applicable and immediate recognition of any previously deferred costs, or a portion of deferred costs, would be required in the year in which the criteria are no longer met, if such deferred costs were not recoverable in the portion of the business that continues to meet the criteria for application of the FASB Codification topic on Regulated Operations. If unable to continue to apply the FASB Codification provisions for Regulated Operations, the Company would be required to apply the provisions for the Discontinuation of Rate-Regulated Accounting included in the FASB Codification. In the C

~~ompany~~

’sCompany’s opinion, its regulated operations will be subject to the FASB Codification provisions for Regulated Operations for the foreseeable future.

Derivatives -

The Company’s regulated energy subsidiaries enter into energy supply contracts to serve their electric and gas customers. The Company follows a procedure for determining whether each contract qualifies as a derivative instrument under the guidance provided by the FASB Codification on Derivatives and Hedging. For each contract, the Company reviews and documents the key terms of the contract. Based on those terms and any additional relevant components of the contract, the Company determines and documents whether the contract qualifies as a derivative instrument as defined in the FASB Codification. The Company has determined that its energy supply contracts either do not qualify as a derivative instrument under the guidance set forth in the FASB Codification, have been elected as a normal purchase, or have contingencies that have not yet been met in order to establish a notional amount.

Fitchburg has entered into power purchase agreements for which contingencies exist (see Note 6, Regulatory Matters—Fitchburg—Massachusetts Request for Proposal (RFPs)). Until these contingencies are satisfied, these contracts will not qualify for derivative accounting. The Company believes that the power purchase obligations under these long-term contracts will have a material effect on the contractual obligations of ~~Fitchburg.~~

Fitchburg.

Investments in Marketable Securities

The Company maintains a trust through which it invests in a money market fund. This fund is intended to satisfy obligations under the Company’s ~~SERP~~Supplemental Executive Retirement Plan (SERP) (See additional discussion of the SERP in Note 9).

At ~~September~~June 30, 2023, June 30, 2022 ~~September 30, 2021~~ and December 31, ~~2021,~~2022, the fair value of the Company’s investments in these trading securities, which are recorded on the Consolidated Balance Sheets in Other Assets, was ~~$5.6~~$5.8 million, ~~$5.6~~$5.4 million and ~~$5.7~~$5.8 million, respectively, as shown in the following table. These investments are valued based on quoted prices from active markets and are categorized in Level 1 as they are actively traded and no valuation adjustments have been applied. Changes in the fair value of these investments are recorded in Other ~~Expense,~~Expense, Net.


	June 30,				December 31,
Fair Value of Marketable Securities (millions)	2023		2022		2022
Money Market Funds	$	5.8	$	5.4	$	5.8
Total Marketable Securities	$	5.8	$	5.4	$	5.8

~~Net.~~

September 30,
   December 31,
Fair Value of Marketable Securities ($ millions)

2022
   2021    2021
Money Market Funds

$
5.6

   $ 5.6    $ 5.7






Total Marketable Securities

$
5.6

   $ 5.6    $ 5.7

The Company also sponsors the Unitil Corporation Deferred Compensation Plan (the “DC Plan”). The DC Plan is a

non-qualified

deferred compensation plan that provides a vehicle for participants to accumulate

tax-deferred

savings to supplement retirement income. The DC Plan, which was effective January 1,

~~Table of Contents~~

2019, is open to senior management or other highly compensated employees as determined by the Company’s Board of Directors, and may also be used for recruitment and retention purposes for newly hired senior executives. The DC Plan design mirrors the Company’s Tax Deferred Savings and Investment Plan formula, but provides for contributions on compensation above the IRS limit, which will allow participants to defer up to 85% of base salary, and up to 85% of any cash incentive for retirement. The Company may also elect to make discretionary contributions on behalf of any participant in an amount determined by the Company’s Board of Directors. A trust has been established to invest the funds associated with the DC Plan.

At ~~September~~June 30, 2023, June 30, 2022 ~~September 30, 2021~~ and December 31, ~~2021,~~2022, the fair value of the Company’s investments in these trading securities related to the DC Plan, which are recorded on the Consolidated Balance Sheets in Other Assets, were ~~$0.6~~$1.1 million, ~~$0.5~~$0.8 million and ~~$0.6~~$0.6 million, respectively, as shown in the following table. These investments are valued based on quoted prices from active markets and are categorized in Level 1 as they are actively traded and no valuation adjustments have been applied. Changes in the fair value of these investments are recorded in Other Expense, ~~~~

Net.

~~Net.~~


	June 30,				December 31,
Fair Value of Marketable Securities (millions)	2023		2022		2022
Equity Funds	$	1.0	$	0.4	$	0.5
Money Market Funds		0.1		0.4		0.1
Total Marketable Securities	$	1.1	$	0.8	$	0.6

September 30,
   December 31,
Fair Value of Marketable Securities ($ millions)

2022
   2021    2021
Equity Funds

$
0.5

   $ 0.1    $ 0.2
Money Market Funds


0.1

   0.4    0.4






Total Marketable Securities

$
0.6

   $ 0.5    $ 0.6

Energy Supply Obligations -

The following discussion and table summarize the nature and amounts of the items recorded as Energy Supply ~~Obligations~~Obligations (current portion) and Other Noncurrent Liabilities (noncurrent portion) on the Company’s Consolidated Balance Sheets.

~~Sheets.~~


	June 30,				December 31,
Energy Supply Obligations (millions)	2023		2022		2022
Current:
Exchange Gas Obligation	$	8.7	$	12.5	$	16.3
Renewable Energy Portfolio Standards		5.2		4.1		7.8
Total Energy Supply Obligations	$	13.9	$	16.6	$	24.1

September 30,
   December 31,
Energy Supply Obligations ($ millions)

2022
   2021    2021
Current:

Exchange Gas Obligation
$
23.1

   $ 9.7    $ 6.7
Renewable Energy Portfolio Standards

6.7

   6.4    7.8






Total Energy Supply Obligations

$
29.8

   $ 16.1    $ 14.5

Exchange Gas Obligation

Northern Utilities enters into gas exchange agreements under which Northern Utilities releases certain gas pipeline and storage assets, sells the gas storage inventory to an asset manager and subsequently repurchases the inventory over the course of the gas heating season at the same price at which it sold the gas inventory to the asset manager. The gas inventory related to these agreements is recorded in Exchange Gas Receivable on the Company’s Consolidated Balance Sheets while the corresponding obligations are recorded in Energy Supply Obligations.

Renewable Energy Portfolio Standards

Renewable Energy Portfolio Standards (RPS) require retail electricity suppliers, including public utilities, to demonstrate that required percentages of their sales are met with power generated from certain types of resources or technologies. Compliance is demonstrated by purchasing and retiring Renewable Energy Certificates (REC) generated by facilities approved by the state as qualifying for REC treatment. Unitil Energy and Fitchburg purchase RECs in compliance with RPS legislation in New Hampshire and Massachusetts for supply provided to default service customers. RPS compliance costs are a supply cost that is recovered in customer default service rates. Unitil Energy and Fitchburg collect RPS compliance costs from customers throughout the year and demonstrate compliance for each calendar year on the following July 1. Due to timing differences between collection of revenue from customers and payment of REC costs to suppliers, Unitil Energy and Fitchburg typically defer costs for RPS compliance which are recorded within Accrued Revenue with a corresponding liability in Energy Supply Obligations on the Company’s Consolidated Balance Sheets.

~~Table of Contents~~

Fitchburg has entered into long-term renewable contracts for the purchase of clean energy and/or RECs pursuant to Massachusetts legislation, specifically, An Act Relative to Green Communities (Green Communities Act, 2008), An Act Relative to Competitively Priced Electricity in the Commonwealth (2012) and An Act to Promote Energy Diversity (Energy Diversity Act, 2016). The generating facilities associated with ten of these contracts have been constructed and are now operating. Three approved contracts are currently under development. These include two long-term contracts filed with the MDPU in 2018, one for offshore wind generation and one for imported hydroelectric power and associated transmission, both of which were approved in 2019, and another for offshore wind generation ~~contracts~~ filed with the MDPU during the first quarter of 2020 and approved in 2021. In compliance with An Act to Promote a Clean Energy Future (2018), in 2021, in coordination with the other electric utilities in Massachusetts, the Company issued its most recent long-term renewable solicitation seeking up to an additional 1,600 megawatts (MW) of offshore wind generation. In December 2021, a portfolio of projects comprising 1,600 MW of offshore wind capacity was selected for negotiation. Those contracts were ~~filed for approval with~~approved by the MDPU on ~~May 25, 2022, and remain pending.~~December 30, 2022. Fitchburg recovers the costs associated with long-term renewable contracts on a fully reconciling basis through a MDPU-approved cost recovery mechanism, and has received remuneration for entering into them.

Power Supply Contract Divestitures -

Unitil Energy’s and Fitchburg’s customers are entitled to purchase their electric or natural gas supplies from third-party suppliers. In connection with the implementation of retail choice, Unitil Power, which formerly functioned as the wholesale power supply provider for Unitil Energy, and Fitchburg divested their long-term power supply contracts through the sale of the entitlements to the electricity sold under those contracts. Unitil Energy and Fitchburg recover in their rates all the costs associated with the divestiture of their power supply portfolios and have secured regulatory approval from the NHPUC and MDPU, respectively, for the recovery of power supply-related stranded costs. As of ~~September~~June 30, ~~2022,~~2023, Fitchburg and Unitil Energy have fully recovered their power supply-related stranded costs. The obligations for prior periods related to these divestitures are recorded in Energy Supply Obligations on the Company’s Consolidated Balance Sheets with a corresponding regulatory asset recorded in Accrued Revenue.

Subsequent Events -

e The Company evaluates all events or transactions through the date of the related filing. During the period through the date of this filing, the Company did not have any material subsequent events, except for the Fitchburg issuance of $25 million of Notes on July 6, 2023, as disclosed in Note 4, that would result in adjustment to or disclosure in its Consolidated Financial ~~Statements.~~Statements.

Note 2 - Dividends Declared Per Share


Declaration Date	Date Paid (Payable)	Shareholder of Record Date	Dividend Amount
07/26/23	08/28/23	08/14/23	$	0.405
04/26/23	05/30/23	05/15/23	$	0.405
01/25/23	02/28/23	02/14/23	$	0.405
10/26/22	11/28/22	11/14/22	$	0.390
07/27/22	08/26/22	08/12/22	$	0.390
04/27/22	05/27/22	05/13/22	$	0.390
01/26/22	02/25/22	02/11/22	$	0.390

~~NOTE 2 - DIVIDENDS DECLARED PER~~

~~SHARE~~


Declaration Date	Date Paid (Payable)	Shareholder of Record Date	Dividend Amount
~~10/26/22~~	~~11/28/22~~	~~11/14/22~~	~~$0.39~~
~~07/27/22~~	~~08/26/22~~	~~08/12/22~~	~~$0.39~~
~~04/27/22~~	~~05/27/22~~	~~05/13/22~~	~~$0.39~~
~~01/26/22~~	~~02/25/22~~	~~02/11/22~~	~~$0.39~~
~~10/27/21~~	~~11/29/21~~	~~11/15/21~~	~~$0.38~~
~~07/28/21~~	~~08/27/21~~	~~08/13/21~~	~~$0.38~~
~~04/28/21~~	~~05/28/21~~	~~05/14/21~~	~~$0.38~~
~~01/27/21~~	~~02/26/21~~	~~02/12/21~~	~~$0.38~~

~~Table of Contents~~

~~NOTE~~

note 3 - ~~SEGMENT INFORMATION~~

Segment Information

The following table provides significant segment financial data for the three and ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~September~~June 30,

~~2021:~~ 2022.


	Electric			Gas			Other			Total
Three Months Ended June 30, 2023 (millions)
Revenues:
Billed and Unbilled Revenue	$	69.8		$	45.3		$	—		$	115.1
Rate Adjustment Mechanism Revenue		(5.3	)		(6.4	)		—			(11.7	)
Total Operating Revenues		64.5			38.9			—			103.4
Segment Profit (Loss)		3.6			0.9			(0.3	)		4.2
Capital Expenditures		13.4			22.0			—			35.4

Three Months Ended June 30, 2022 (millions)
Revenues:
Billed and Unbilled Revenue	$	64.1		$	49.6		$	—		$	113.7
Rate Adjustment Mechanism Revenue		(9.8	)		(5.0	)		—			(14.8	)
Total Operating Revenues		54.3			44.6			—			98.9
Segment Profit (Loss)		3.9			1.3			(0.3	)		4.9
Capital Expenditures		7.9			22.0			—			29.9

Six Months Ended June 30, 2023 (millions)
Revenues:
Billed and Unbilled Revenue	$	167.4		$	167.2		$	—		$	334.6
Rate Adjustment Mechanism Revenue		5.3			(16.3	)		—			(11.0	)
Total Operating Revenues		172.7			150.9			—			323.6
Segment Profit (Loss)		8.9			19.9			(0.5	)		28.3
Capital Expenditures		24.0			33.5			0.1			57.6
Segment Assets		610.5			961.9			22.9			1,595.3

Six Months Ended June 30, 2022 (millions)
Revenues:
Billed and Unbilled Revenue	$	148.8		$	163.3		$	—		$	312.1
Rate Adjustment Mechanism Revenue		(5.3	)		(15.3	)		—			(20.6	)
Total Operating Revenues		143.5			148.0			—			291.5
Segment Profit (Loss)		7.3			19.8			(0.7	)		26.4
Capital Expenditures		14.2			31.0			0.1			45.3
Segment Assets		593.0			936.0			18.1			1,547.1

Electric

Gas

Non-

Regulated

Other

Total

Three Months Ended Sept. 30, 2022 ($ millions)

Revenues:

Billed and Unbilled Revenue

$
77.8

$
27.4

$
—


$
—

$
105.2

Rate Adjustment Mechanism Revenue


(2.1
)

7.1

—



—

5.0

Other Operating Revenue –
Non-Regulated


—

—

—



—

—





Total Operating Revenues

$
75.7

$
34.5

$
—


$
—

$
110.2





Segment Profit (Loss)


5.9

(5.3
)

—



(0.1
)

0.5

Capital Expenditures


8.3

28.9

—



—

37.2

Three Months Ended Sept. 30, 2021 ($ millions)

Revenues:

Billed and Unbilled Revenue
   $ 65.0 $ 23.1 $ —      $ —   $ 88.1
Rate Adjustment Mechanism Revenue
   0.5 9.5 —      —   10.0
Other Operating Revenue –
Non-Regulated
   —   —   —      —   —




Total Operating Revenues
   $ 65.5 $ 32.6 $ —      $ —   $ 98.1




Segment Profit (Loss)
   4.4 (4.1 ) —      (0.3 ) —
Capital Expenditures
   10.1 28.5 —      0.4 39.0

Nine Months Ended Sept. 30, 2022 ($ millions)

Revenues:

Billed and Unbilled Revenue

$
226.7

$
190.6

$
—


$
—

$
417.3

Rate Adjustment Mechanism Revenue


(7.5
)

(8.1
)

—



—

(15.6
)
Other Operating Revenue –
Non-Regulated


—

—

—



—

—





Total Operating Revenues

$
219.2

$
182.5

$
—


$
—

$
401.7





Segment Profit (Loss)


13.2

14.5

—



(0.8
)

26.9

Capital Expenditures


22.5

59.9

—



0.1

82.5

Segment Assets


590.9

967.5

—



20.5

1,578.9

Nine Months Ended Sept. 30, 2021 ($ millions)

Revenues:

Billed and Unbilled Revenue
   $ 189.1 $ 154.3 $ —      $ —   $ 343.4
Rate Adjustment Mechanism Revenue
   (6.9 ) (3.0 ) —      —   (9.9 )
Other Operating Revenue –
Non-Regulated
   —   —   —      —   —




Total Operating Revenues
   $ 182.2 $ 151.3 $ —      $ —   $ 333.5




Segment Profit
   10.7 12.1 0.1    (1.3 ) 21.6
Capital Expenditures
   28.8 51.7 —      1.0 81.5
Segment Assets
   583.6 906.2 —      19.2 1,509.0

~~Table of Contents~~

~~NOTE~~

Note 4 - ~~DEBT~~Debt AND FINANCING ARRANGEMENTS

Details on long-term debt at ~~September~~June 30, ~~2022, September~~2023, June 30, ~~2021~~2022 and December 31, ~~2021~~2022 are shown below.


(millions)	June 30,				December 31,
	2023		2022		2022
Unitil Corporation:
3.70% Senior Notes, Due August 1, 2026	$	30.0	$	30.0	$	30.0
3.43% Senior Notes, Due December 18, 2029		30.0		30.0		30.0
Unitil Energy First Mortgage Bonds:
8.49% Senior Secured Notes, Due October 14, 2024		—		1.5		—
6.96% Senior Secured Notes, Due September 1, 2028		12.0		14.0		12.0
8.00% Senior Secured Notes, Due May 1, 2031		12.0		13.5		13.5
6.32% Senior Secured Notes, Due September 15, 2036		15.0		15.0		15.0
3.58% Senior Secured Notes, Due September 15, 2040		27.5		27.5		27.5
4.18% Senior Secured Notes, Due November 30, 2048		30.0		30.0		30.0
Fitchburg:
6.79% Senior Notes, Due October 15, 2025		2.0		6.0		2.0
3.52% Senior Notes, Due November 1, 2027		10.0		10.0		10.0
7.37% Senior Notes, Due January 15, 2029		7.2		8.4		8.4
5.90% Senior Notes, Due December 15, 2030		15.0		15.0		15.0
7.98% Senior Notes, Due June 1, 2031		14.0		14.0		14.0
3.78% Senior Notes, Due September 15, 2040		27.5		27.5		27.5
4.32% Senior Notes, Due November 1, 2047		15.0		15.0		15.0
Northern Utilities:
3.52% Senior Notes, Due November 1, 2027		20.0		20.0		20.0
7.72% Senior Notes, Due December 3, 2038		50.0		50.0		50.0
3.78% Senior Notes, Due September 15, 2040		40.0		40.0		40.0
4.42% Senior Notes, Due October 15, 2044		50.0		50.0		50.0
4.32% Senior Notes, Due November 1, 2047		30.0		30.0		30.0
4.04% Senior Notes, Due September 12, 2049		40.0		40.0		40.0
Granite State:
3.72% Senior Notes, Due November 1, 2027		15.0		15.0		15.0
Unitil Realty Corp.:
2.64% Senior Secured Notes, Due December 18, 2030		4.1		4.4		4.2
Total Long-Term Debt		496.3		506.8		499.1
Less: Unamortized Debt Issuance Costs		3.2		3.5		3.3
Total Long-Term Debt, net of Unamortized Debt Issuance Costs		493.1		503.3		495.8
Less: Current Portion		6.9		8.2		6.7
Total Long-term Debt, Less Current Portion	$	486.2	$	495.1	$	489.1

~~below:~~

($ millions)

September 30,
   December 31,

2022
   2021    2021
Unitil Corporation:

3.70% Senior Notes, Due August 1, 2026

$
30.0

   $ 30.0    $ 30.0
3.43% Senior Notes, Due December 18, 2029


30.0

   30.0    30.0
Unitil Energy First Mortgage Bonds:

8.49% Senior Secured Notes, Due October 14, 2024


1.5

   3.0    1.5
6.96% Senior Secured Notes, Due September 1, 2028


12.0

   14.0    14.0
8.00% Senior Secured Notes, Due May 1, 2031


13.5

   15.0    15.0
6.32% Senior Secured Notes, Due September 15, 2036


15.0

   15.0    15.0
3.58% Senior Secured Notes, Due September 15, 2040


27.5

   27.5    27.5
4.18% Senior Secured Notes, Due November 30, 2048


30.0

   30.0    30.0
Fitchburg:

6.79% Senior Notes, Due October 15, 2025


6.0

   10.0    6.0
3.52% Senior Notes, Due November 1, 2027


10.0

   10.0    10.0
7.37% Senior Notes, Due January 15, 2029


8.4

   9.6    9.6
5.90% Senior Notes, Due December 15, 2030


15.0

   15.0    15.0
7.98% Senior Notes, Due June 1, 2031


14.0

   14.0    14.0
3.78% Senior Notes, Due September 15, 2040


27.5

   27.5    27.5
4.32% Senior Notes, Due November 1, 2047


15.0

   15.0    15.0
Northern Utilities:

3.52% Senior Notes, Due November 1, 2027


20.0

   20.0    20.0
7.72% Senior Notes, Due December 3, 2038


50.0

   50.0    50.0
3.78% Senior Notes, Due September 15, 2040


40.0

   40.0    40.0
4.42% Senior Notes, Due October 15, 2044


50.0

   50.0    50.0
4.32% Senior Notes, Due November 1, 2047


30.0

   30.0    30.0
4.04% Senior Notes, Due September 12, 2049


40.0

   40.0    40.0
Granite State:

3.72% Senior Notes, Due November 1, 2027


15.0

   15.0    15.0
Unitil Realty Corp.:

2.64% Senior Secured Notes, Due December 18, 2030


4.3

   4.5    4.5






Total Long-Term Debt


504.7

   515.1    509.6
Less: Unamortized Debt Issuance Costs


3.4

   3.7    3.6






Total Long-Term Debt, net of Unamortized Debt Issuance Costs


501.3

   511.4    506.0
Less: Current Portion


8.2

   10.1    8.2






Total Long-term Debt, Less Current Portion

$
493.1

   $ 501.3    $ 497.8

~~Table of Contents~~

Fair Value of Long-Term Debt

Currently, the Company believes there is no active market in the Company’s debt securities, which have all been sold through private placements. If there were an active market for the Company’s debt securities, the fair value of the Company’s long-term debt would be estimated based on the quoted market prices for the same or similar issues, or on the current rates offered to the Company for debt of the same remaining maturities. The fair value of the Company’s long-term debt is estimated using Level 2 inputs (valuations based on quoted prices available in active markets for similar assets or liabilities, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are directly observable, and inputs derived principally from market data). In estimating the fair value of the Company’s long-term debt, the assumed market yield reflects the Moody’s Baa Utility Bond Average Yield. Costs, including prepayment costs, associated with the early settlement of long-term debt are not taken into consideration in determining fair value.

~~value.~~


(millions)	June 30,				December 31,
	2023		2022		2022
Estimated Fair Value of Long-Term Debt	$	446.2	$	477.3	$	455.3

($ millions)

September 30,
   December 31,

2022
   2021    2021
Estimated Fair Value of Long-Term Debt

$
458.3

   $ 598.2    $ 584.9

one-year

extensions under certain circumstances. The Credit Facility

terminates and all amounts outstanding thereunder are due and payable on September 29, 2027, subject to the potential extension discussed in the prior sentence.

The Credit Facility has a borrowing limit of ~~$200~~$200 million, which includes a ~~$25~~$25 million sublimit for the issuance of standby letters of credit. Unitil may increase the borrowing limit under the Credit Facility by up to ~~$75~~$75 million under certain circumstances. The Credit Facility generally provides Unitil with the ability to elect that borrowings under the Credit Facility bear interest under several options, including a daily fluctuating rate equal to (a) the forward-looking secured overnight financing rate (as administered by the Federal Reserve Bank of New York) term rate with a term equivalent to one month beginning on that date, plus (b) ~~0.1000%~~0.1000%, plus (c) a margin of ~~1.125%~~1.125% to ~~1.375%~~1.375% (based on Unitil’s credit rating). As of the close of business on September 29, 2022, Unitil’s aggregate borrowings under the Credit Facility were approximately $65.5 million at an interest rate per annum of approximately 4.272% (which interest rate was based on the lowest end of the margin range discussed above).

The Company ~~uses~~utilizes the Credit Facility for cash management purposes related to its short-term operating activities. Total gross borrowings were ~~$214.0~~$193.6 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022.~~2023. Total gross repayments were ~~$206.1~~$177.9 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022.~~ 2023. The following table details the borrowing limits, amounts outstanding and amounts available under the Credit Facility as of ~~September~~June 30, 2023 and December 31, 2022 and for the prior credit facility as of ~~September 31, 2021 and December 31,~~June 30, 2022:


	Revolving Credit Facility (millions)
	June 30,				December 31,
	2023		2022		2022
Limit	$	200.0	$	120.0	$	200.0
Short-Term Borrowings Outstanding		131.7		46.2		116.0
Available	$	68.3	$	73.8	$	84.0

~~2021:~~

Revolving Credit Facility ($ millions)


September 30,
   December 31,

2022
   2021    2021
Limit
��
$
200.0

   $ 120.0    $ 120.0
Short-Term Borrowings Outstanding


72.0

   30.5    64.1






Available

$
128.0

   $ 89.5    $ 55.9

~~Table of Contents~~

The Credit Facility contains customary terms and conditions for credit facilities of this type, including affirmative and negative covenants. There are restrictions on, among other things, Unitil’s and its subsidiaries’ ability to incur liens or incur indebtedness, and restrictions on Unitil’s ability to merge or consolidate with another entity or change its line of business. The affirmative and negative covenants under the Credit Facility shall apply to Unitil until the Credit Facility terminates and all amounts borrowed under Credit Facility are paid in full (or, with respect to letters of credit, they are cash-collateralized). The only financial covenant in the Credit Facility provides that Unitil’s Funded Debt to Capitalization (as each term is defined in the Credit Facility) cannot exceed ~~65%~~65% tested on a quarterly ~~basis.~~basis. At ~~September~~June 30, ~~2022, September~~2023, June 30, ~~2021~~2022 and December 31, ~~2021,~~2022, the Company was in compliance with the covenants contained in the Credit Facility or the prior credit facility, as applicable, in effect on those dates.

The average interest rates on all short-term borrowings and intercompany money pool transactions were ~~3.6%~~6.3% and ~~1.2%~~2.1% for the three months ended ~~September~~June 30, ~~2022~~2023 and ~~September~~June 30, ~~2021,~~2022, respectively. The average interest rates on all short-term borrowings and intercompany money pool transactions were ~~2.4%~~6.1% and ~~1.2%~~1.7% for the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~September~~June 30, ~~2021,~~2022, respectively. The average interest rate on all short-term borrowings for the twelve months ended December 31, ~~2021~~2022 was ~~1.2%~~3.3%.

~~Unitil Corporation~~

On July 6, 2023, Fitchburg issued $12.0 million of Notes due July 6, 2033 at 5.70% and ~~its utility subsidiaries,~~$13.0 million of Notes due July 6, 2053 at 5.96%. Fitchburg ~~Unitil Energy, Northern Utilities,~~used the net proceeds from these offerings to refinance existing debt and Granite State currently are rated “BBB+” by Standard & Poor’s Ratings Services. Unitil Corporation and Granite State currently are rated “Baa2”, and Fitchburg, Unitil Energy and Northern Utilities are currently rated “Baa1” by Moody’s Investors Services.

for general corporate purposes. Approximately $0.2 million of costs associated with this issuance will be recorded as a reduction of Long-Term Debt for presentation purposes on the Consolidated Balance Sheet in the third quarter of 2023.

Northern Utilities enters into asset management agreements under which Northern Utilities releases certain gas pipeline and storage assets, sells to an asset manager and subsequently repurchases the gas over the course of the gas heating season at the same price at which it sold the gas to the asset manager. There was ~~$23.4 million, $9.7 million and $8.3~~$8.7 million of natural gas storage inventory and corresponding obligations at ~~September~~June 30, ~~2022, September 30, 2021 and December 31, 2021, respectively,~~2023 related to these asset management agreements. The amount of natural gas inventory released in ~~September 2022 and~~June 30, 2023, which was payable in ~~October 2022 is $0.3 million and is recorded in Accounts Payable at September 30, 2022. The amount of gas released in September 2021 and payable in October 2021~~July 2023, was ~~$0.1~~less than $0.1 million and was recorded in Accounts Payable at ~~September~~June 30, ~~2021. The amount of gas released in December 2021 and payable in January 2022 was $1.6 million and was recorded in Accounts Payable at December 31, 2021.~~

2023.

Guarantees

The Company provides limited guarantees on certain energy and gas storage management contracts entered into by the distribution utilities. The Company’s policy is to limit the duration of these guarantees. As of ~~September~~June 30, ~~2022,~~2023 there were ~~approximately $1.6 million of~~no guarantees ~~outstanding with a duration less than one year.~~

outstanding.

Leases

Unitil’s subsidiaries lease some of their vehicles, machinery and office equipment under both capital and operating lease arrangements.

Total rental expense under operating leases charged to operations for the three months ended ~~September~~June 30, 2023 and June 30, 2022 ~~and 2021~~ amounted to ~~$0.5~~$0.5 million and ~~$0.5~~$0.5 million, respectively. Total rental expense under operating leases charged to operations for the ~~nine~~six months ended ~~September~~June 30, 2023 and June 30, 2022 ~~and 2021~~ amounted to ~~$1.4~~$1.0 million and ~~$1.4~~$0.9 million, respectively.

~~Table of Contents~~

The balance sheet classification of the Company’s lease obligations was as follows:


	June 30,				December 31,
Lease Obligations (millions)	2023		2022		2022
Operating Lease Obligations:
Other Current Liabilities (current portion)	$	1.7	$	1.5	$	1.5
Other Noncurrent Liabilities (long-term portion)		3.5		2.9		2.8
Total Operating Lease Obligations		5.2		4.4		4.3
Capital Lease Obligations:
Other Current Liabilities (current portion)		0.1		0.1		0.1
Other Noncurrent Liabilities (long-term portion)		0.3		0.1		0.1
Total Capital Lease Obligations		0.4		0.2		0.2
Total Lease Obligations	$	5.6	$	4.6	$	4.5

~~follows:~~

September 30,
   December 31,
Lease Obligations ($ millions)

2022
   2021    2021
Operating Lease Obligations:

Other Current Liabilities (current portion)
$
1.6

   $ 1.6    $ 1.6
Other Noncurrent Liabilities (long-term portion)

3.0

   3.5    3.1






Total Operating Lease Obligations
$
4.6

   $ 5.1    $ 4.7






Capital Lease Obligations:

Other Current Liabilities (current portion)
$
0.1

   $ 0.2    $ 0.1
Other Noncurrent Liabilities (long-term portion)

0.1

   0.2    0.2






Total Capital Lease Obligations
$
0.2

   $ 0.4    $ 0.3






Total Lease Obligations

$
4.8

   $ 5.5    $ 5.0

Cash paid for amounts included in the measurement of operating lease obligations for the ~~nine~~six months ended ~~September~~June 30, 2023 and June 30, 2022 ~~and September 30, 2021~~ was ~~$1.4~~$1.0 million and ~~$1.4~~$0.9 million and was included in Cash Provided by Operating Activities on the Consolidated Statements of Cash Flows.

Assets under capital leases amounted to approximately ~~$0.6~~$0.8 million, ~~$0.7~~$0.7 million and ~~$0.7~~$0.6 million as of ~~September~~June 30, ~~2022, September~~2023, June 30, ~~2021~~2022 and December 31, ~~2021,~~2022, respectively, less accumulated amortization of ~~$0.3~~$0.4 million, ~~$0.3~~$0.4 million and ~~$0.3~~$0.4 million, respectively and are included in Net Utility Plant on the Company’s Consolidated Balance Sheets.

The following table is a schedule of future operating lease payment obligations and future minimum lease payments under capital leases as of ~~September~~June 30, ~~2022.~~2023. The payments for operating leases consist of ~~$1.6~~$1.7 million of current operating lease obligations, which are included in Other Current Liabilities and ~~$3.0~~$3.5 million of noncurrent operating lease obligations, which are included in Other Noncurrent Liabilities, on the Company’s Consolidated Balance Sheets as of ~~September~~June 30, ~~2022.~~2023. The payments for capital leases consist of ~~$0.1~~$0.1 million of current capital lease obligations, which are included in Other Current Liabilities and ~~$0.1~~$0.3 million of noncurrent capital lease obligations, which are included in Other Noncurrent Liabilities, on the Company’s Consolidated Balance Sheets as of

~~September~~ June 30, 2023.


Lease Payments ($000’s)	Operating		Capital
Year Ending December 31,	Leases		Leases
Rest of 2023	$	1,040	$	71
2024		1,761		118
2025		1,189		86
2026		890		74
2027		613		70
2028 - 2032		238		2
Total Payments		5,731		421
Less: Interest		484		24
Amount of Lease Obligations Recorded on Consolidated Balance Sheets	$	5,247	$	397

~~2022.~~

Lease Payments ($000’s)
Year Ending December 31,

Operating
Leases

Capital
Leases

Rest of 2022
   $ 457    $ 36
2023
   1,655    114
2024
   1,325    59
2025
   759    26
2026
   456    6
2027-2031
   291    3




Total Payments


4,943



244





Less: Interest
   329    9




Amount of Lease Obligations Recorded on Consolidated Balance Sheets

$
4,614


$
235

Operating lease obligations are based on the net present value of the remaining lease payments over the remaining lease term. In determining the present value of lease payments, the Company used the interest rate stated in each lease agreement. As of ~~September~~June 30, ~~2022,~~2023, the weighted average remaining lease term is ~~3.4~~3.7 years and the weighted average operating discount rate used to determine the operating lease obligations was ~~3.7%~~4.5%. As of ~~September~~June 30, ~~2021,~~2022, the weighted average remaining lease term was ~~3.7~~3.3 years and the weighted average operating discount rate used to determine the operating lease obligations was ~~4.0%~~3.6%.

~~Table of Contents~~

~~NOTE~~

Note 5 – ~~COMMON STOCK AND PREFERRED STOCK~~

Common Stock

and preferred stock

Common Stock

The Company’s common stock trades on the New York Stock Exchange under the symbol, “UTL.”

The

Company had

~~16,039,141~~

16,091,419,

~~15,971,962~~

16,034,635and

~~15,977,766~~

16,043,355shares of common stock outstanding at ~~September~~June 30, ~~2022, September~~2023, June 30, ~~2021~~2022 and December 31, ~~2021,~~2022, respectively.

Dividend Reinvestment and Stock Purchase Plan -

During the first ~~nine~~six months of ~~2022,~~2023, the Company sold ~~14,369~~10,524 shares of its common stock, at an average price of ~~$52.35~~$54.61 per share, in connection with its Dividend Reinvestment and Stock Purchase Plan (DRP) and its 401(k) plans resulting in net proceeds of approximately ~~$752,200.~~$574,700. The DRP provides participants in the plan a method for investing cash dividends on the Company’s common stock and cash payments in additional shares of the Company’s common stock.

Stock Plan -

The Company maintains the Unitil Corporation Second Amended and Restated 2003 Stock Plan (the Stock Plan). Participants in the Stock Plan are selected by the Compensation Committee of the Board of Directors to receive awards under the Stock Plan, ~~including~~including: (i) awards of restricted shares ~~(Restricted~~that vest based on time (Time Restricted Shares); (ii) awards of restricted shares that vest based on performance (Performance Restricted Shares), effective January 24, 2023; or (iii) awards of restricted stock units (Restricted Stock Units). The Compensation Committee has the authority to determine the sizes of awards; determine the terms and conditions of awards in a manner consistent with the Stock Plan; construe and interpret the Stock Plan and any agreement or instrument entered into under the Stock Plan as they apply to participants; establish, amend, or waive rules and regulations for the Stock Plan’s administration as they apply to participants; and, subject to the provisions of the Stock Plan, amend the terms and conditions of any outstanding award to the extent such terms and conditions are within the discretion of the Compensation Committee as provided for in the Stock Plan. On April 19, 2012, the Company’s shareholders approved an amendment to the Stock Plan to, among other things, increase the maximum number of shares of common stock available for awards to plan participants.

The maximum number of shares available for awards to participants under the Stock Plan is ~~677,500.~~677,500. The maximum number of shares that may be awarded in any one calendar year to any one participant is ~~20,000.~~20,000. In the event of ~~any change~~certain changes in capitalization of the Company, the Compensation Committee is authorized to make an equitable adjustment to the number and kind of shares of common stock that may be delivered under the Stock Plan and, in addition, may authorize and make an equitable adjustment to the Stock Plan’s annual individual award limit.

Time Restricted Shares

Outstanding awards of Time Restricted Shares fully vest over a period of four years at a rate of ~~25%~~25% each year. During the vesting period, dividends on Time Restricted Shares underlying the award may be credited to a participant’s account. The Company may deduct or withhold, or require a participant to remit to the Company, an amount sufficient to satisfy any taxes required by federal, state, or local law or regulation to be withheld with respect to any taxable event arising in connection with an award. ~~For purposes of compensation expense, Restricted Shares vest immediately upon a participant becoming eligible for retirement, as defined in the Stock Plan.~~

Prior to the end of the vesting period, the ~~restricted shares~~Time Restricted Shares are subject to forfeiture if the participant ceases to be employed by the Company other than due to the participant’s ~~death.~~

death, disability or retirement.

On January ~~25, 2022, 36,770~~24, 2023, 18,770 Time Restricted Shares were issued in conjunction with the Stock Plan with an aggregate market value at the date of issuance of approximately ~~$1.7~~$1.0 million. There were ~~72,428~~64,243 and ~~57,408~~

73,178non-vested

~~shares~~ Time Restricted Shares under the Stock Plan as of ~~September~~June 30, ~~2022~~2023 and ~~2021,~~2022, respectively. The weighted average grant date fair value of these shares was ~~$47.46~~$48.02 and ~~$49.61,~~$47.44 per share, respectively. The

~~Table of Contents~~

compensation expense associated with the issuance of ~~shares~~Time Restricted Shares under the Stock Plan is being recognized over the vesting period and was ~~$1.9~~$1.3 million and ~~$1.4~~$1.8 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021,~~2022, respectively. At ~~September~~June 30, ~~2022,~~2023, there was approximately ~~$0.9~~$0.9 million of total unrecognized compensation cost for Time Restricted Shares under the Stock Plan which is expected to be recognized over approximately ~~2.7~~2.6 years. During the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023, there were zero ~~restricted shares~~ Time Restricted Shares forfeited and zero ~~restricted shares~~ Time Restricted Shares cancelled under the Stock Plan.

Performance Restricted Shares

Outstanding awards of Performance Restricted Shares vest after a performance period of three years based on the attainment of certain goals set by the Compensation Committee at the beginning of the performance period. If goals are met, awards of Performance Restricted Shares may vest fully; if goals are exceeded, awards of Performance Restricted Shares may vest fully and additional shares of common stock may be awarded; if goals are not met, a portion of the Performance Restricted Shares may vest and/or all or a portion of the Performance Restricted Shares may be forfeited. During the performance period, dividends on Performance Restricted Shares underlying the award may be credited to a participant’s account. The Company may deduct or withhold, or require a participant to remit to the Company, an amount sufficient to satisfy any taxes required by federal, state, or local law or regulation to be withheld with respect to any taxable event arising in connection with an award.

Prior to the end of the performance period, the Performance Restricted Shares are subject to forfeiture if the participant ceases to be employed by the Company other than due to the participant’s death, disability or retirement. Initial awards of Performance Restricted Shares were granted January 24, 2023. No Performance Restricted Shares were awarded in 2022. On January 24, 2023, there were 18,770 Performance Restricted Shares issued under the Stock Plan with an aggregate market value of $1.0 million. There were 18,770 non-vested Performance Restricted Shares under the Stock Plan as of June 30, 2023. The weighted average grant date fair value of these shares was $51.83 per share. The compensation expense associated with the issuance of Performance Restricted Shares under the Stock Plan is being recognized over the vesting period and was $0.2 million for the six months ended June 30, 2023. At June 30, 2023, there was approximately $1.0 million of total unrecognized compensation cost for Performance Restricted Shares under the Stock Plan which is expected to be recognized over approximately 2.5 years. During the six months ended June 30, 2023 there were zero

Performance Restricted Shares forfeited and zero Performance Restricted Shares cancelled under the Stock Plan.

Restricted Stock Units

Non-management

members of the Company’s Board of Directors (Directors) may elect to receive the equity portion of their annual retainer in the form of Restricted Stock Units (RSU). Restricted Stock Units earn dividend equivalents and will generally be settled by payment to each Director as soon as practicable following the Director’s separation from service to the Company. The Restricted Stock Units will be paid such that the Director will receive (i) ~~70%~~70% of the shares of the Company’s common stock underlying the restricted stock units and (ii) cash in an amount equal to the fair market value of ~~30%~~30% of the shares of the Company’s common stock underlying the Restricted Stock Units. The equity portion of Restricted Stock Units activity during the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 in conjunction with the Stock Plan is presented in the following table:


Restricted Stock Units (Equity Portion)
	Units		Weighted Average Stock Price
Restricted Stock Units as of December 31, 2022		43,799	$	40.17
Restricted Stock Units Granted		—	$	—
Dividend Equivalents Earned		669	$	53.24
Restricted Stock Units Settled		—	$	—
Restricted Stock Units as of June 30, 2023		44,468	$	40.37

Restricted Stock Units (Equity Portion)

   Units    Weighted
Average
Stock
Price
Restricted Stock Units as of December 31, 2021
   49,182    $ 41.67
Restricted Stock Units Granted
   —      —
Dividend Equivalents Earned
   932    $ 53.60
Restricted Stock Units Settled
   (10,236 )    $ 51.28



Restricted Stock Units as of September 30, 2022
   39,878    $ 39.48

There were ~~44,224~~39,595 Restricted Stock Units outstanding as of ~~September~~June 30, ~~2021~~2022 with a weighted average stock price of ~~$41.49.~~$39.37. Included in Other Noncurrent Liabilities on the Company’s Consolidated Balance Sheets as of ~~September~~June 30, ~~2022, September~~2023, June 30, ~~2021~~2022 and December 31, ~~2021~~2022 is ~~$0.8~~$1.0 million, ~~$0.8~~$1.0 million and ~~$1.0~~$1.0 million, respectively, representing the fair value of liabilities associated with the portion of fully vested RSUs that will be settled in cash.

Preferred Stock

There were ~~$0.2~~$0.2 million, or ~~1,861~~1,727 shares, of Unitil Energy’s ~~6.00%~~6.00% Series Preferred Stock outstanding as of ~~September~~June 30, ~~2022, September~~2023. There were $0.2 million, or 1,861 shares, Unitil Energy’s 6.00% Series Preferred Stock outstanding as of June 30, ~~2021~~2022 and December 31, ~~2021.~~2022. There were less than ~~$0.1~~$0.1 million of total dividends declared on Preferred Stock in each of the three month periods ended ~~September~~June 30, 2023 and June 30, 2022, ~~and September 30, 2021,~~ respectively.

~~NOTE~~

note 6 - ~~REGULATORY MATTERS~~

~~UNITIL’S REGULATORY MATTERS ARE DESCRIBED IN NOTE~~REgulatory Matters

Unitil’s Regulatory matters are described in Note 8 ~~TO THE FINANCIAL STATEMENTS IN ITEM~~to the Financial Statements in Item 8 ~~OF PART~~of Part II ~~OF UNITIL CORPORATION’S FORM~~

of Unitil Corporation’s Form 10-K

~~FOR DECEMBER~~ for December 31, ~~2021 AS FILED WITH THE SECURITIES AND EXCHANGE COMMISSION ON FEBRUARY 1, 2022.~~

2022 as filed with the Securities and Exchange Commission on february 14, 2023.

Rate Case Activity

Northern Utilities - Base Rates - Maine

On ~~March 26, 2020,~~May 1, 2023, Northern Utilities filed a rate case with the MPUC ~~approved an~~to increase toits base ~~revenue of $3.6~~distribution rates by $11.8 million, a ~~3.6%~~9.4% increase over the Company’s test year operating revenue. The filing is based on information for 12 months ending December 31, 2022 incorporating a forward-looking analysis of revenues, expenses, and spending through the rate year (February 1, 2024 through January 31, 2025). The last approved base revenue increase was $3.6 million, a 3.6% increase over the Company’s test year operating revenue, effective April 1, 2020. ~~The order approved a Return on Equity of 9.48%, and a hypothetical capital structure of 50% equity and 50% debt. As part of the order and increase in base revenue, the MPUC provided for~~

~~Table of Contents~~

recovery of some, but not all, of the Company’s implementation costs associated with its customer information system pending the completion of an investigation, including a third-party audit. On March 9, 2021, the MPUC opened a new docket to investigate the amount of customer information system costs that will be allowed in rates. On January 27, 2022, the Company and the Maine Office of the Public Advocate filed a stipulation in this docket. The stipulation includes no finding of imprudence or asset disallowance. The terms of the stipulation provide for recovery of the revenue requirement related to the Company’s customer information system in base rates starting November 1, 2022, which coincides with the timing of the Company’s winter cost of gas rate change. On February 9, 2022, the MPUC approved the stipulation. On September 30, 2022, the Company filed revised distribution rates to recover the annual revenue requirement of $0.6 million for effect November 1, 2022.

Northern Utilities - Targeted Infrastructure Replacement Adjustment (TIRA) - Maine

The settlement in Northern Utilities’ Maine division’s 2013 rate case authorized the Company to implement a TIRA rate mechanism to adjust base distribution rates annually to recover the revenue requirements associated with targeted investments in gas distribution system infrastructure replacement and upgrade projects, including the Company’s Cast Iron Replacement Program (CIRP). In its Final Order issued on February 28, 2018 for Northern Utilities’ 2017 base rate case, the MPUC approved an extension of the TIRA mechanism for an additional eight-year period, which will allow for annual rate adjustments through the end of the CIRP program. The Company’s most recent request under the TIRA mechanism, to increase annual base rates by ~~$1.5~~$2.1 million for ~~2021~~2022 eligible facilities, was filed with the MPUC on February 28, ~~2022.~~2023. On April ~~27, 2022,~~26, 2023, the MPUC issued an order approving the filing, for rates effective May 1, ~~2022.~~

2023.

Northern Utilities - Base Rates - New Hampshire

On July 20, 2022, the NHPUC issued an Order in the distribution base rate case filed with the NHPUC on August 2, 2021 by Northern Utilities. The Order approves a comprehensive Settlement Agreement between the Company, the New Hampshire ~~DOE~~Department of Energy (DOE), and the Office of the Consumer Advocate (OCA). As provided in

the Settlement Agreement, in addition to authorizing an increase to permanent distribution rates of ~~$6.1~~$6.1 million, effective August 1, 2022, the Order (1) approves a revenue decoupling mechanism and (2) allows for a step adjustment effective September 1, 2022 covering the additional revenue requirement resulting from changes in Net Plant in Service associated with

non-growth

investments for the period January 1, 2021, through December 31, 2021. On June 8, 2022, the Company filed for its first step increase of approximately $1.6 million of annual revenue, for rates effective as of September 1, 2022, to recover eligible 2021 capital investments. On August 31, 2022, the NHPUC approved the Company’s filing. The increase in permanent rates will be reconciled back to October 1, 2021, the effective date of temporary rates previously approved in this docket. This distribution base rate case reflects the Company’s operating costs and investments in utility plant for a test year ended December 31, 2020 as adjusted for known and measurable changes. The Order provides for a return on equity of ~~9.3%~~9.3% and a capital structure reflecting ~~52%~~52% equity and ~~48%~~48% long-term debt. In light of the Step Adjustment, the Company shall not file a distribution rate case with the Commission before January 1, 2024 (the

“Stay-Out

~~Period”)~~ Period). However, during the term of the

Stay-Out

Period, the Company will be allowed to adjust distribution rates upward or downward resulting from a singular (not collective) exogenous event that exceeds ~~$200,000.~~

$200,000. The increase in permanent rates was reconciled back to October 1, 2021, the effective date of temporary rates previously approved in this docket. On June 8, 2022, the Company filed for its step increase of approximately $1.6 million of annual revenue, for rates effective as of September 1, 2022, to recover eligible 2021 capital investments. On August 31, 2022, the NHPUC approved the Company’s filing. Under the terms of the Settlement Agreement, parties agreed that the Company shall recover revenues associated with the full rate year (August 1, 2022 – July 31, 2023) over an eleven-month period beginning September 1, 2022 and ending July 31, 2023. On May 5, 2023, the Company made a compliance filing to adjust base distribution rates downward to reflect a 12-month recovery period effective August 1, 2023. On July 13, 2023, the NHPUC approved the Company’s compliance filing.

Unitil Energy - Base Rates

- On May 3, 2022, the NHPUC issued an Order in the distribution base rate case filed with the NHPUC on April 2, 2021 by Unitil Energy. The Order approves, in part, a comprehensive Settlement Agreement between the Company, the New Hampshire DOE, the OCA, the New Hampshire Department of Environmental Services, Clean Energy New Hampshire, and ChargePoint, Inc. In addition to authorizing an increase to permanent distribution rates of ~~$6.3~~$6.3 million, effective June 1, 2022, the Order approves the following components of the Settlement Agreement: (1) a multi-year rate plan, (2) a revenue decoupling mechanism,

(3) time-of-use

rates, (4) resiliency programs to support the Company’s commitment to reliability, and (5) other rate design and tariff changes. On May 10, 2022, the Company filed a request for clarification with the NHPUC to clarify that the authorized revenue requirement should exclude expenses related to the Company’s proposed Arrearage Management Program (AMP), which was not approved in the Order. On May 12, 2022, the Commission issued an Order, which clarified that because the Company will not incur the expenses associated with the AMP, those costs should be removed from the revenue requirement, and that the adjusted increase of ~~$5.9~~$5.9 million will result in reasonable rates. The increase in permanent rates was reconciled back

to June 1,

~~Table of Contents~~

2021, the effective date of temporary rates previously approved in this docket. This distribution base rate case reflects the Company’s operating costs and investments in utility plant for a test year ended December 31, 2020 as adjusted for known and measurable changes. The Order provides for a return on equity of ~~9.2%~~9.2% and a capital structure reflecting ~~52%~~52% equity and ~~48%~~48% long-term debt. On July 28, 2022, the NHPUC approved, subject to reconciliation, the Company’s first step increase of approximately ~~$1.3~~$1.3 million of annual revenue to recover eligible 2021 capital investments, effective August 1, 2022.

On May 31, 2023, the NHPUC approved , the Company’s second and final step adjustment increase of approximately $1.2 million to recover eligible 2022 capital investments, effective June 1, 2023.

Fitchburg - Base Rates - Electric

- Fitchburg’s base rates are decoupled and subject to an annual revenue decoupling adjustment mechanism, which includes a cap on the amount that rates may be increased in any year. In addition, Fitchburg has an annual capital cost recovery mechanism to recover the revenue requirement associated with certain capital additions.

On November 2, 2020, Fitchburg filed its cumulative revenue requirement of $1.4 million associated with its 2019 capital expenditures. The MDPU allowed the associated rate increase to become effective on January 1, 2021, subject to further investigation and reconciliation. On June 15, 2021, final approval of the filing was issued

On November 2, 2021, Fitchburg filed its cumulative revenue requirement of ~~$1.6~~$1.6 million associated with its 2019 and 2020 capital expenditures. The MDPU allowed the associated rate increase to become effective on January 1, 2022, subject to further investigation and reconciliation. On June 24, 2022, the MDPU issued an Order approving the Company’s filing.

On November 2, 2022, Fitchburg filed its cumulative revenue requirement of $3.1 million associated with its 2019-2021 capital expenditures. The MDPU allowed the associated rate increase to become effective on January 1, 2023, subject to further investigation and reconciliation. On July 26, 2023, the MDPU issued an Order approving the Company's filing.

On April 17, 2020, the MDPU approved a settlement agreement entered into by the Company and the Massachusetts Office of the Attorney General providing for a distribution increase of ~~$1.1~~$1.1 million, effective November 1, 2020. The Company’s subsequent Compliance Filing reflected an adjusted distribution increase of ~~$0.9~~$0.9 million, a decrease of ~~$0.2~~$0.2 million from the original settlement ~~amount.~~amount due to the finalization of actual rate case expenses. On May 21, 2020, the MDPU approved the Company’s Compliance Filing. The agreement provides for a Return on Equity of ~~9.7%~~9.7% and a capital structure reflecting ~~52.45%~~52.45% equity and ~~47.55%~~47.55% long-term debt. Under the agreement, the Company will not increase or redesign base distribution rates to become effective prior to November 1, 2023, though the Company may seek cost recovery for certain exogenous events that meet a revenue threshold of ~~$0.1~~$0.1 million. The agreement also provides for the implementation of a major storm reserve fund, whereby the Company may recover the costs of restoration for qualifying storm events. In addition, the agreement provides for the extension of the annual capital cost recovery mechanism, modified to allow the recovery of property tax on the cumulative net capital expenditures.

On September 22, 2022, Fitchburg filed a petition with the MDPU to adjust its base distribution rates by ~~$0.7~~

$0.7million effective January 1, 2023 to recover costs due to the exogenous event described below. The filing also includes a request to recover the exogenous costs

incurred from July 2021 through December 2022 through a reconciling mechanism over a 24 month period, beginning January 1, 2023. The Massachusetts Department of Revenue has determined that the “net book value” or “NBV” of utility plant is no longer the basis of valuation for utility property. Most of the municipalities that levy property taxes on ~~Unitil~~Fitchburg have adopted a hybrid valuation approach that increases property tax expense over and above what it would be if NBV was used as the basis of valuation. The change in valuation is a regulatory change that is outside the Company’s control and it uniquely affects the electric and gas industries, thus it is an exogenous event. ~~As of September~~On December 30, 2022, the ~~Company has~~MDPU approved the Company’s request to adjust its base distribution rates effective January 1, 2023 and to recover deferred ~~$1.5~~costs of $1.1 million ~~related this exogenous event~~incurred from July 2021 through December 2022 through a reconciling mechanism over a 24 month period, also beginning January 1, 2023.

On June 30, 2023, Fitchburg filed a notice of intent to file a base rate case with the MDPU on or after July 31, 2023 to implement a general increase in rates and ~~believes recovery~~making other changes effective July 1, 2024. Under MDPU precedent, a utility company is required to provide no less than a 30 day advance notice of ~~this amount is probable. This matter remains pending.~~

its intent to file for a base rate increase.

Fitchburg - Base Rates - Gas

Pursuant to its revenue decoupling adjustment clause tariff, as approved in its last base rate case, the Company is allowed to modify, on a semi-annual basis, its base distribution rates to an established revenue per customer target in order to mitigate economic, weather, and energy efficiency ~~affect~~effects to the Company’s revenues. The MDPU consistently has found the Company’s filings are in accord with its approved tariffs, applicable law and precedent, and that they result in just and reasonable rates.

On February 28, 2020, the MDPU approved a settlement agreement between the Company and the Massachusetts Office of the Attorney General. The agreement provides for an annual distribution revenue increase of ~~$4.6~~$4.6 million to be phased in over two ~~years:~~years: (1) an increase of ~~$3.7~~$3.7 million, which became effective on March 1, 2020; and (2) an increase of ~~$0.9~~$0.9 million, which became effective on March 1, 2021. Under the agreement, the Company will not increase or redesign base distribution rates to become effective prior to March 1, 2023, though the Company may seek cost recovery for certain exogenous events that meet a revenue effect threshold of ~~$40,000.~~$40,000. The agreement provides for a Return on Equity of ~~9.7%~~9.7% and a capital structure reflecting ~~52.45%~~52.45% equity and ~~47.55%~~47.55% long-term debt.

~~Table of Contents~~

In its September 22, 2022 exogenous cost filing as discussed above, the Company also requested to adjust its gas base distribution rates by ~~$0.7~~$0.7 million effective March 1, 2023 to recover these exogenous costs. The filing also includes a request to recover the exogenous costs incurred from July 2021 through February 2023 through a reconciling mechanism over a 24 month period, beginning March 1, 2023. ~~This matter remains pending.~~

On December 30, 2022, the MDPU approved the Company’s request to adjust its base distribution rates effective March 1, 2023 and to recover deferred costs of $1.2 million incurred from July 2021 through February 2023 through a reconciling mechanism over a 24 month period, also beginning March 1, 2023.

On June 30, 2023, Fitchburg filed a notice of intent to file a base rate case with the MDPU on or after July 31, 2023 to implement a general increase in rates and making other changes effective July 1, 2024. Under MDPU precedent, a utility company is required to provide no less than a 30 day advance notice of its intent to file for a base rate increase.

Fitchburg - Gas System Enhancement Program

Pursuant to statute and MDPU order, Fitchburg has an approved Gas System Enhancement Plan tariff through which it may recover certain gas infrastructure replacement and safety related investment costs, subject to an annual cap. Under the plan, the Company is required to make two annual filings with the MDPU: a forward-looking filing for the subsequent construction year, to be filed on or before October 31; and a filing, submitted on or before May 1, of final project documentation for projects completed during the prior year, demonstrating substantial compliance with its plan in effect for that year and showing that project costs were reasonably and prudently incurred. Fitchburg’s forward-looking cumulative revenue requirement filing submitted on October

29,

~~, 202~~

2021 requested recovery of approximately ~~$3.3~~$3.3 million, and received final approval on April 2

~~, 202~~

,28, 2022, effective May 1, ~~202~~

.2022. The Company’s most recent forward-looking cumulative revenue requirement filing, filed on October

31,

~~, 202~~

, 2022, requested recovery of approximately ~~$4.5~~$4.5 million. On April 28, 2023, the MDPU issued an order approving this filing for rates effective May 1, 2023. The Company considers these to be routine regulatory proceedings, and there are no material issues outstanding.

Granite State - Base Rates

On November 30, 2020, the FERC approved Granite State’s filing of an uncontested rate settlement which provides for an increase in annual revenues of approximately ~~$1.3~~$1.3 million, effective November 1, 2020. The Settlement Agreement permits the filing of limited Section 4 rate adjustments for capital cost projects eligible for cost recovery in 2021, 2022, and 2023, and sets forth an overall investment cap of approximately ~~$14.6~~$14.6 million on the capital cost recoverable under such filings during the term of the Settlement. Under the Settlement Agreement, Granite may not file a new general rate case earlier than April 30, 2024 with rates to be effective no earlier than November 1, 2024 based on a test year ending no earlier than December 31, 2023.

On August 24, 2021, the FERC accepted Granite State’s first limited Section 4 rate adjustment pursuant to the Settlement Agreement, for an annual revenue increase of ~~$0.1~~$0.1 million, effective September 1, 2021. On ~~July 28,~~August 19, 2022, the FERC accepted Granite ~~State filed its~~State’s second limited Section 4 rate adjustment pursuant to the Settlement Agreement, for an annual revenue increase of ~~$0.3~~$0.3 million,

effective September 1, 2022. On ~~August 19, 2022,~~July 27, 2023, Granite State filed its third and final limited Section 4 rate adjustment pursuant to the ~~FERC approved this filing.~~

Settlement Agreement, for an annual revenue increase of $1.0 million, effective September 1, 2023. This matter remains pending.

Other Matters

Unitil Energy - Proposal to Construct Utility-Scale Solar Facility

- On October 31, 2022, Unitil Energy submitted a petition to the NHPUC for review of Unitil Energy’s proposal to construct, own, and operate a 4.99 MW utility-scale photovoltaic generating facility, which was subsequently revised to a 4.88 MW facility. The Company ~~has~~had requested a finding from the NHPUC within six months of the filing date that the project, as proposed, is in the public interest. ~~This matter is subject to review by~~On May 1, 2023, the NHPUC ~~and remains pending.~~

issued an Order approving the Company's petition.

Fitchburg - Grid Modernization

- On July 1, 2021, Fitchburg submitted its Grid Modernization Plan (GMP) to the MDPU. The GMP includes a ~~five year~~five-year strategic plan, including a plan for the full deployment of advanced metering functionality, and a four-year short-term investment plan, which focuses on foundational investments to facilitate the interconnection and integration of distributed energy resources, optimizing system performance through command and control and self-healing measures, and optimizing system demand by facilitating consumer price-responsiveness. On October 7, 2022, the MDPU issued a “Track 1” Order approving a budget cap of ~~$9.1~~$9.3 million through 2025 for previously deployed or preauthorized grid modernization investments. ~~Unitil had requested a budget of $9.8 million through 2025 for such investments. The~~On November 30, 2022, the MDPU ~~will issue a~~issued its “Track 2” Order addressing new ~~grid modernization~~technologies and Advanced Metering Infrastructure (AMI) proposals. The MDPU preauthorizes a four-year $1.5 million budget for Fitchburg’s additional grid-facing investments. Any spending over the total budget cap is not eligible for targeted cost recovery through its Grid Modernization Factor (GMF), and instead, may be recovered by the Company in a base distribution rate proceeding subsequent to a prudency finding by the MDPU in a GMF filing or term review Order. The MDPU also preauthorized the Company’s AMI meter replacement investments, atwith a ~~later time.~~

budget of $11.2 million through 2025. Additionally, the MDPU provided preliminary approval for the Company’s customer engagement and experience and data sharing platform investments, with a combined budget of $2.3 million through 2025. The Company may recover eligible costs incurred for preauthorized grid-facing investments and customer-facing investments that will be made during the 2022-2025 GMP term through the GMFs, subject to certain modifications to the Company’s GMF tariff and a final prudence review. On March 31, 2023, the Company submitted an AMI opt-out tariff with full support of proposed opt-out fees in compliance with the Track 2 Order. The MDPU approved the tariff on April 7, 2023.

On April 24, 2023, Fitchburg submitted its 2022 Grid Modernization Plan Annual Report to the MDPU. On May 31, 2023, the MDPU issued an Order on Fitchburg’s 2023 GMF filing, allowing proposed rates to take effect on June 1, 2023 subject to the further investigation and reconciliation.

Fitchburg - Grid Modernization Cost Recovery Factor

- On April 15, 2022, Fitchburg filed its ~~Grid Modernization Factor (GMF)~~GMF rate adjustment and reconciliation filing pursuant to the Company’s ~~proposed~~ GMF Tariff, for recovery of the costs incurred as a result of implementing the Company’s ~~2018- 2021~~2018-2021 GMP, previously approved by the MDPU on February 7, 2019. The proposed GMF of

$0.4 million was approved on May 27, 2022, effective June 1, 2022, subject to further investigation and reconciliation.

~~Table~~ On April 15, 2023, Fitchburg filed its GMF rate adjustment and reconciliation filing for recovery of ~~Contents~~

the costs incurred as a result of implementing the Company’s 2022-2025 GMP, approved by the MDPU in Orders dated October 7, 2022 and November 30, 2022. On May 31, 2023, the MDPU approved, subject to further investigation and reconciliation, the cumulative recovery of $1.0 million associated with the Company’s 2022 revenue requirement, effective June 1, 2023.

Fitchburg - Investigation into the role of gas LDCs to achieve Commonwealth 2050 climate goals -

The MDPU has opened an investigation to examine the role of Massachusetts gas local distribution companies (LDCs) in helping the Commonwealth achieve its 2050 climate goal of

net-zero

greenhouse gas (GHG) emissions. In its Order opening the inquiry, the MDPU stated it is required to consider new policies and structures as the Commonwealth reduces reliance on fossil fuels, including natural gas, which may require LDCs to make significant changes to their planning processes and business models. The LDCs, including Fitchburg, engaged an independent consultant to conduct a study and prepare a report (Consultant Report), including a detailed study of each LDC, that analyzes the feasibility of all identified pathways to help the Commonwealth achieve its

net-zero

GHG goal. The study includes an examination of the potential pathways identified in the 2050 Decarbonization Roadmap developed by the MA Executive Office of Energy and Environmental Affairs, in consultation with the Massachusetts Department of Environmental Protection and the Massachusetts Department of Energy ~~Resources.~~Resources (DOER). Following an active stakeholder process, on March 18, 2022, Consultant Reports on decarbonization pathways, regulatory designs and stakeholder engagement were submitted to the MDPU. Also on March 18, 2022, the LDCs, including Fitchburg, submitted proposals to the MDPU that include the LDCs’ recommendations and plans for helping the Commonwealth achieve its 2050 climate goals, supported by the Consultant Reports. The MDPU held a technical session on the Consultant Report on March 30, 2022 and a technical session on the LDC proposals on April 15, 2022. Discovery by the MDPU is complete, and the LDCs responded to stakeholder comments on July 29, 2022. Final comments from stakeholders replying to the LDCs’ comments and making any other final remarks for the MDPU’s consideration were filed on October 14, 2022.

~~Financial Effects of~~

~~COVID-19~~

~~Pandemic~~

The NHPUC and the MDPU have opened proceedings to consider the revenue and cost effects on the regulated electric and gas utilities within their respective jurisdictions of the requirement to continue the availability of gas, electric and water service to customers during the

~~COVID-19~~

pandemic. Among the effects under investigation are the revenue effects associated with service disconnection moratoriums, the waiver of fees and expanded customer payments arrangements; the increased cost of customer accounts that cannot be collected, including the cost of bad debt reserves and increased working capital costs; and increased operating and maintenance costs incurred for employees to work safely and protect the public.

Fitchburg ~~Unitil Energy and Northern Utilities are active participants in these proceedings, and are in full compliance with all regulatory orders governing service~~

~~shut-off~~

~~moratoriums and other customer service protection measures.~~ – Electric Vehicle (EV) Proceeding – On December ~~31, 2020, in docket DPU~~

~~20-58,~~

30, 2022, the MDPU issued an order ~~which, among other provisions, allows~~approving Fitchburg’s five-year EV program with a $1.0 million budget consisting of: (1) public infrastructure offering ($0.5 million); (2) Electric Vehicle Supply Equipment (EVSE) incentives for residential segment ($0.3 million); and (3) marketing and outreach ($0.2 million). The Company may shift spending between program segments and between years over the ~~utility~~five-year term of its program, subject to a 15 percent cap. Any spending above the approved EV program budget or above the 15 percent cap for each program segment is not eligible for targeted cost recovery through the GMF and, instead, may be recovered in a base distribution rate proceeding subsequent to a prudency finding by the MDPU. Further, the MDPU has convened an EV stakeholder process to finalize EV program performance metrics. On April 3, 2023, the electric companies filed comments on the MDPU’s proposed metrics. Once performance metrics are finalized, the MDPU will require the electric companies to ~~defer~~develop a joint state-wide program evaluation plan for ~~future recovery of bad debt expense in excess of a baseline. On July 7, 2021,~~MDPU approval and stakeholder input and will determine next steps at that time. The MDPU directs the ~~NHPUC issued an order which declined~~Companies to ~~authorize New Hampshire’s rate-regulated utilities’ establishment of a regulatory asset for incremental bad debt or waived late payment fees related to the~~

~~COVID-19~~

~~pandemic. The NHPUC stated~~submit annual reports that document their performance and these ~~costs~~reports will be ~~addressed in~~due on or before May 15th of each ~~utility’s next~~year. The first EV annual report is due May 15, 2024. The Company shall file annual rate case. On September 7, 2021, the NHPUC clarified its July 7 Order, determining that it has not foreclosed rate-regulated utilities from utilizing accounting mechanisms to defer costs in order to seek recovery in a future rate proceeding,adjustment and ~~that Unitil Energy’s and Northern Utilities’ respective pending rate cases are the appropriate venue to address incremental bad debt and/~~reconciliation filings on or ~~waived late payment fees resulting from the~~

~~COVID-19~~

~~public health emergency orders and directives. Consistent~~before April 15, with ~~the authorization provided in that Order, the Settling Parties agreed in Unitil Energy’s rate case that Unitil Energy be permitted to recover $386,957 in~~

~~COVID-19~~

~~related costs relating to expenses from calendar year 2020 by including those costs in its next Schedule EDC through the External Delivery Charge (EDC), a uniform rate per kWh, in~~rates effective June 1. The MDPU accepted the Company’s ~~next scheduled EDC rate change effective August~~Demand Charge Alternative proposal and directed implementation within six months. The Demand Charge Alternative is offered for a ten-year period beginning July 1, 2022. This provision was approved by the NHPUC Order issued May 3, 2022 on the rate case Settlement Agreement. In Northern Utilities case, the Settling Parties agreed that Northern Utilities shall be permitted2023 with tiered rates to ~~recover $68,061 in~~

~~COVID-19~~

~~related costs relating to expenses from calendar year 2020 by including those costs in its Regulatory Assessment Adjustment Mechanism (RAAM), a uniform rate per therm, in~~separately-metered EV general delivery service customers. The MDPU accepted the Company’s ~~next scheduled RAAM~~proposed residential EV TOU rate, ~~change~~ effective ~~November~~April 1, ~~2022. This provision was approved by the NHPUC Order, issued July 20, 2022, on the rate case Settlement Agreement.~~

~~Table of Contents~~

2023.

Northern Utilities / Granite State - Firm Capacity Contract

- Northern Utilities relies on the transportation of gas supply over its affiliate Granite State pipeline to serve its customers in the Maine and New Hampshire service territories. Granite State facilitates critical upstream interconnections with interstate pipelines and third party suppliers essential to Northern Utilities’ service to its customers. Northern Utilities reserves firm capacity through a contract with Granite State, which is renewed annually. Pursuant to statutory requirements in Maine and orders of the MPUC, Northern Utilities submits an annual informational report requesting approval of a

one-year

extension of its

12-month

contract for firm pipeline capacity reservation, with an evergreen provision and three-month termination notification requirement. On April ~~1, 2022,~~3, 2023, Northern Utilities submitted an annual informational report requesting approval on a

one-year

extension for the period of November 1, ~~2022~~2023 through October 31, ~~2023.~~2024. The MPUC issued an Order on June ~~14, 2022~~13, 2023 approving the

one-year

extension.

Reconciliation Filings

Fitchburg, Unitil Energy and Northern Utilities each have a number of regulatory reconciling accounts that require annual or semi-annual filings with the MDPU, NHPUC and MPUC, respectively, to reconcile costs and revenues, and to seek approval of any rate changes. These filings include: annual electric reconciliation filings by Fitchburg and Unitil Energy for a number of items, including default service, stranded cost changes and transmission charges; costs associated with energy efficiency programs in New Hampshire and Massachusetts, as directed by the NHPUC and MDPU; recovery of the ongoing costs of storm repairs incurred by Unitil Energy; and the actual wholesale energy costs for electric power and gas incurred by each of the three companies. Fitchburg, Unitil Energy and Northern Utilities have been, and remain in full compliance with all directives and orders regarding these filings. The Company considers these to be routine regulatory proceedings, and there are no material issues outstanding.

Fitchburg - Massachusetts Request for Proposals (RFPs)

Pursuant to ~~a comprehensive energy law enacted in 2016,~~Section 83C of “An Act to Promote Energy ~~Diversity,”~~Diversity” (2016) (the Act) ~~under Section 83C,~~, the Massachusetts electric distribution companies (EDCs), including Fitchburg, are required to jointly ~~solicit proposals for long-term contracts for at least 400~~procure a total of 1,600 MW of offshore wind ~~energy generation by June 30, 2017, as part of a total of 1,600 MW of offshore wind the EDCs are directed to procure~~ by June 30, 2027. Under Section 83D of the Act, the EDCs are required to jointly seek proposals for cost-effective clean energy (hydroelectric, solar and land-based wind) long-term contracts via one or more staggered solicitations for a total of 9,450,000 megawatt-hours (MWh) by December 31, 2022. ~~Unitil’s~~Fitchburg’s pro rata share of these contracts is approximately 1%.

The EDCs issued the RFP for Section 83D Long-Term Contracts ~~for Qualified Clean Energy Projects~~ in March 2017, and ~~after selection of final projects and negotiation, final contracts~~power purchase agreements (PPAs) for 9,554,940 MWh of ~~Qualified Clean Energy~~hydroelectric generation and associated ~~Environmental Attributes~~environmental attributes from Hydro-Quebec Energy Services (U.S.), Inc. ~~for hydroelectric generation~~ were filed in July 2018 for approval by the MDPU. On June 25, 2019, the MDPU approved the ~~power purchase agreements,~~PPAs, including the EDCs’ proposal to sell the energy procured under the contract into the

ISO-NE

wholesale market and to credit or charge the difference between the contract costs and the

ISO-NE

market costs to customers. The MDPU also ~~determined that~~approved the EDCs’ request for remuneration equal to ~~2.75%~~2.75% of the contract payments, ~~is reasonable and in the public interest and approved~~as well as the EDCs’ proposal to ~~amend their respective tariffs to include the recovery of~~recover costs associated with the contracts. On January 13, 2023, NECEC Transmission LLC (“NECEC”), the company with which Fitchburg and the other EDCs entered into transmission service agreements (“TSAs”) for the delivery of the Hydro-Quebec energy, provided a letter to the EDCs purporting to give notice of a “change in applicable law” related to a Maine ballot initiative and requesting a negotiated amendment to the TSAs. On June 27, 2023, NECEC sent a letter to the EDCs seeking schedule relief also in accordance with their “change in law” determination. The Massachusetts Supreme Judicial Court upheld the MDPU’s approval in an opinion dated September 3, 2020. The Company believes the power purchase obligations under these long-term contracts will have a material effect on the contractual obligations of Fitchburg, once certain conditions and contingenciesEDCs are ~~met.~~

evaluating NECEC’s requests.

The EDCs issued ~~the~~an initial RFP pursuant to Section 83C ~~for Long-Term Contracts for Offshore Wind Energy Generation~~ in June 2017. ~~The EDCs selected an 800 MW project submitted by Vineyard Wind in May 2018, contracts were signed in July 2018 and on~~On July 23, 2018, the EDCs, ~~including Fitchburg,~~ filed two long-term contracts with Vineyard Wind, each for 400 MW of offshore wind energy generation, ~~with~~for approval by the ~~MDPU for approval.~~MDPU. On April 12, 2019, the MDPU approved the offshore wind energy generation ~~power purchase agreements,~~PPAs, including the EDCs’ proposal to sell the energy procured under the contract into the

ISO-NE

wholesale market and to credit or charge the difference between the contract costs and the

ISO-NE

market costs to customers. ~~The MDPU also determined that the EDCs’ request for remuneration equal to 2.75% of the~~

~~Table of Contents~~

contract payments is reasonable and in the public interest and approved the EDCs’ proposal to amend their respective tariffs to include the recovery of costs associated with the contracts. The Company believes the power purchase obligations under these long-term contracts will have a material effect on the contractual obligations of Fitchburg, once certain conditions and contingencies are met.

The EDCs issued a second RFP pursuant to Section 83C ~~for Long-Term Contracts for Offshore Wind Energy Generation on May 23, 2019. This solicitation sought~~ to procure ~~the obligation remaining under 83C at the time,~~ an additional 800 MW of offshore wind energy ~~generation.~~generation in May 2019. The EDCs ~~selected an 800 MW project submitted by~~filed for approval of two PPAs with Mayflower Wind Energy LLC, ~~and contracts were executed on January 10, 2020. A filing with the MDPU for approval of two long-term contracts,~~ each for 400 MW of offshore

wind energy generation, ~~was made on~~in February 10, 2020. On November 5, 2020, the MDPU approved the ~~Offshore Wind Energy Generation power purchase agreements. The~~second RFP PPAs. In both cases, the MDPU ~~also determined that~~approved the EDCs’ request for remuneration equal to ~~2.75% is reasonable and in~~2.75% of the ~~public interest. The Company believes~~contract payments, as well as the ~~power purchase obligations under these long-term contracts will have a material effect on~~EDCs’ proposal to recover costs associated with the ~~contractual obligations of Fitchburg, once certain conditions and contingencies are met.~~

contracts.

In accordance with ~~the requirement of Chapter 227 of the Acts of 2018, An~~“An Act to Advance Clean ~~Energy, signed August 9, 2018,~~Energy” (2018) the Massachusetts Department of Energy Resources ~~(MDOER) prepared a report on the necessity, benefits and costs of requiring~~(DOER) recommended that the EDCs solicit up to ~~competitively conduct~~1,600 MW in additional offshore wind ~~generation RFPs~~in 2022 and 2024. On May 7, 2021, the EDCs issued a third RFP for up to an additional 1,600 MW. The MDOER filed its report with the Legislature in May, 2019, recommending that, “the EDCs should proceed with additional offshore wind solicitations for up to 1,600 MW of offshore wind in 2022 and 2024 and only enter into contracts if found to be cost-effective.” On March 10, 2021, Fitchburg, along with the other EDCs, filed a petition with the MDPU for approval of a proposed timetable and method of solicitation and execution of long-term contracts for up to an additional 1,600 MW of off shore wind generation. On May ~~5, 2021,~~25, 2022, the ~~DPU approved the proposed timetable~~EDCs sought approval of PPAs with Commonwealth Wind for 1,200 MW and ~~method~~with South Coast Wind (formerly Mayflower Wind) for ~~the solicitation, and the RFP was issued on May 7, 2021.~~400 MW. On December ~~17, 2021,~~16, 2022, Commonwealth Wind filed a motion requesting that the MDPU dismiss proceedings related to the approval of its contract, arguing that, due to various economic conditions, its contracts with the EDCs ~~selected a 1,600 MW portfolio~~would no longer facilitate the financing of offshore wind ~~generation that includes~~energy generation. On December 30, 2022, the MDPU denied Commonwealth’s motion and approved the PPAs. The MDPU also approved the EDCs’ request for remuneration equal to 2.25% as reasonable and in the public interest. On January 19, 2023, Commonwealth Wind filed a ~~1,200 MW project~~Petition for Appeal with the Massachusetts Supreme Judicial Court seeking to set aside and vacate the MDPU’s Order approving the PPAs. This appeal is pending. On the same day, Mayflower Wind submitted ~~by Vineyard Wind and~~ a ~~400 MW project submitted by Mayflower Wind. Contract negotiations were completed in early April 2022 and the contracts were submitted for approval~~motion to the MDPU requesting that it extend the period for filing an appeal (which otherwise expired on ~~May 25, 2022. This matter remains pending.~~

~~Section 83C of Chapter 169 of~~January 19, 2023) by five business days from the ~~Acts of 2008 was recently amended by~~date that the ~~Acts of~~motion is approved. The MDPU denied Mayflower Wind’s motion. The EDCs have negotiated termination agreements with Commonwealth Wind and submitted the agreements to the MDPU for approval on July 13, 2023.

In 2021, ~~to increase~~ the ~~aggregate amount of~~MA legislature increased the total solicitation target (including future solicitations) for offshore wind ~~capacity to be procured~~energy generation to 5,600 MW ~~not later than~~by June 30, ~~2027. After considering the two approved offshore wind contracts of 800 MW each and the most recent selection of 1,600 MW there is another~~2027; an additional 2,400 MW of offshore wind capacity remains to be procured in the ~~future.~~

future given the current PPAs under contract with the MA EDCs. The next RFP for offshore wind was filed with the MDPU for approval in May 2023 for at least 400 MW and up to 3,600 MW of additional offshore wind capacity.

Section 82 of the Acts of 2022 authorizes DOER to coordinate with other New England states to consider projects for long-term clean energy generation, transmission or capacity for the benefit of residents of the Commonwealth and the region. If DOER, in consultation with the Attorney General, determines that a project would satisfy all of the benefits listed in Section 82, then pursuant to Section 82 the EDCs shall enter into cost-effective long-term contracts with a maximum term of twenty years upon such a finding. On October 26, 2022, the Maine PUC announced its selection of a Transmission Project and a Generation Project to promote renewable energy development in northern Maine. On December 30, 2022, the DOER made a positive determination that the selected projects would have benefits to Massachusetts and the region and Massachusetts would procure up to 40% of the projects. Fitchburg is in the process of evaluating potential contractual commitments under Section 82. Negotiations for Section 82 have not yet begun.

FERC Transmission Formula Rate Proceedings

Pursuant to Section 206 of the Federal Power Act, there are several pending proceedings before the FERC concerning the justness and reasonableness of the Return on Equity (ROE) component of the

ISO-New

England, Inc. Participating Transmission Owners’ (PTOs) Regional Network Service and Local Network Service formula rates. In August 2013, FERC had found that the Transmission Owners existing ROE was unlawful, and set a new ROE. On April 14, 2017, the U.S. Court of Appeals for the D.C. Circuit (the Court) issued an opinion vacating aand remanding FERC’s decision, ~~of the FERC with respect to the ROE, and remanded it for further proceedings. The FERC had found~~finding that ~~the Transmission Owners existing ROE was unlawful, and set a new ROE. The Court found that the~~ FERC had failed to articulate a satisfactory explanation for its orders. At this time, the ROE set in the vacated order will remain in place until further FERC action is taken. Separately, on March 15, 2018, the Transmission Owners filed a petition for review with the Court of certain orders of the FERC setting for hearing other complaints challenging the allowed Return on Equity component of the formula rates. On November 21, 2019 the FERC issued an order in

EL14-12,

Midcontinent Independent System Operator ROE, in which FERC outlined a new methodology for calculating the ROE. ~~In response to the FERC order in EL~~

~~14-12,~~

~~the~~The New England Transmission Owners (NETOs) thereafter filed a motion to reopen the record in their pending ROE dockets, which has been granted. This matter remains pending. The Company does not believe these proceedings will have a material adverse effect on its financial condition or results of operations.

~~Table~~

On December 13, 2022, RENEW Northeast, Inc., a non-profit entity that advocates for the business interests of ~~Contents~~

~~The~~renewable power generators in New England filed a complaint with FERC ~~Section 206 proceeding concerning~~against ISO-NE and the ~~justness~~PTOs requesting a determination that certain open-access transmission tariff schedules are unjust and ~~reasonableness of~~

~~ISO-New~~

England, Inc. Participating Transmission Owners’ Regional Network Service and Local Network Service formula rates and to develop formula rate protocols for these rates has been resolved. On August 17, 2018 a joint settlement agreement among a number of the parties was filed with the FERC. FERC rejected the settlement agreement on May 22, 2019 and remanded the proceedingunreasonable to the ~~Chief Administrative Law Judge~~extent they permit PTOs to ~~resume hearing procedures. On May 24, 2019 the judge appointed a Dispute Resolution Facilitator~~directly assign to aid parties in settlement negotiations. The procedural schedule was suspended September 24, 2019 in order to allow participants to focus on settlement negotiations. On October 24, 2019, the NETOs filed an unopposed motion to suspend the procedural schedule and waiver of answer period indicating that the NETOs, Municipal Pool Transmission Facility Owners and the Commission Trial Staff have reached agreement in principle on the terms of a settlement to resolve all open issues in the proceeding. On June 15, 2020 a settlement was filed. The FERC approved the settlement agreement on December 28, 2020. Pursuant to the terms of the settlement agreement, the negotiated formula rates took effect on January 1, 2022.interconnection customers O&M costs associated with network upgrades. Fitchburg and Unitil Energy are ~~Participating Transmission Owners,~~PTOs, although Unitil Energy does not own transmission plant.

The PTOs answered the complaint on January 23, 2023. This matter remains pending.

Legal Proceedings

The Company is involved in legal and administrative proceedings and claims of various types, including those which arise in the ordinary course of business. The Company believes, based upon information furnished by counsel and others, that the ultimate resolution of these claims will not have a material effect on its financial position, operating results or cash flows.

~~NOTE~~

note 7 – ~~ENVIRONMENTAL~~eNVIRONMENTAL MATTERS

~~UNITIL’S ENVIRONMENTAL MATTERS ARE DESCRIBED IN NOTE~~

Unitil’s Environmental matters are described in Note 8 ~~TO THE FINANCIAL STATEMENTS IN ITEM~~to the Financial Statements in Item 8 ~~OF PART~~of Part II ~~OF UNITIL CORPORATION’S FORM~~

of Unitil Corporation’s Form 10-K

~~FOR DECEMBER~~ for December 31, ~~2021 AS FILED WITH THE SECURITIES AND EXCHANGE COMMISSION ON FEBRUARY 1, 2022.~~

2022 as filed with the Securities and Exchange Commission on february 14, 2023.

The Company’s past and present operations include activities that are generally subject to extensive and complex federal and state environmental laws and regulations. The Company is in material compliance with applicable environmental and safety laws and regulations and, as of ~~September~~June 30, ~~2022,~~2023, has not identified any material losses reasonably likely to be incurred in excess of recorded amounts. However, the Company cannot assure that significant costs and liabilities will not be incurred in the future. It is possible that other developments, such as increasingly stringent federal, state or local environmental laws and regulations could result in increased environmental compliance costs. Based on its current assessment of its environmental responsibilities, existing legal requirements and regulatory policies, the Company does not believe that these environmental costs will have a material adverse effect on the Company’s consolidated financial position or results of operations.

Northern Utilities Manufactured Gas Plant Sites

- Northern Utilities has an extensive program to identify, investigate and remediate former manufactured gas plant (MGP) sites, which were operated from the

mid-1800s

through the

mid-1900s.

In New Hampshire, MGP sites were identified in Dover, Exeter, Portsmouth, Rochester and Somersworth. In Maine, Northern Utilities has documented the presence of MGP sites in Lewiston and Portland, and a former MGP disposal site in Scarborough.

Northern Utilities has worked with the Maine Department of Environmental Protection and New Hampshire Department of Environmental Services (NH DES) to address environmental concerns with these sites. Northern Utilities or others have completed remediation activities at all sites; however, on site monitoring continues at several sites which may result in future remedial actions as directed by the applicable regulatory agency.

In July 2019, the NH DES requested that Northern Utilities review modeled expectations for groundwater contaminants against observed data at the Rochester site. In June 2020, the NH DES coupled the submittal of the review to a proposed extension of the gas distribution system by Northern Utilities. Northern Utilities submitted the review in January 2022, and the NH DES directed that soil treatability studies as part of a Remedial Action Plan (RAP) be developed in June 2022. The Company ~~anticipates submittal of these~~submitted the studies and RAP

~~later~~ to the NH DES in

December 2022 and continues to await a decision from the ~~fourth quarter of 2022.~~agency; the RAP included three remediation alternatives for consideration by NH DES. In anticipation of the probable NH DES ~~acceptance~~approval of one of the ~~RAP~~remediation alternatives and subsequent request for project design, the Company has accrued ~~$0.8~~$2.5 million for estimated costs to complete the remediation at the Rochester site, which is included in Environmental Obligations.

~~Table~~ The Company has determined that the high end of ~~Contents~~

the range of reasonably possible remediation costs for the Rochester site could be $5.6 million based on remediation alternatives. Northern Utilities anticipates the commencement of remediation activities in 2024.

The NHPUC and MPUC have approved regulatory mechanisms for the recovery of MGP environmental costs. For Northern Utilities’ New Hampshire division, the NHPUC has approved the recovery of MGP environmental costs over succeeding seven-year periods. For Northern Utilities’ Maine division, the MPUC has authorized the recovery of environmental remediation costs over succeeding five-year periods.

The Environmental Obligations table ~~shows the~~includes amounts accrued for Northern Utilities related to estimated future cleanup costs associated with Northern Utilities’ environmental remediation obligations for former MGP sites. Corresponding Regulatory Assets were recorded to reflect that the future recovery of these environmental remediation costs is expected based on regulatory precedent and established practices.

Fitchburg’s Manufactured Gas Plant Site

- Fitchburg has worked with the Massachusetts Department of Environmental Protection (Mass DEP) to address environmental concerns with the former MGP site at Sawyer Passway, and has substantially completed remediation activities, though on site monitoring continues. In April 2020, Fitchburg received notification from the Massachusetts Department of Transportation (Mass DOT) that a portion of the site may be incorporated into the proposed Twin City Rail Trail with an anticipated ~~completion now~~commencement date in ~~2024.~~2025. Depending upon the final agreement between Fitchburg and Mass DOT, additional minor costs are expected prior to completion.

In August 2021, the Mass DEP issued a Notice of

Non-compliance

to ~~FGE~~Fitchburg following a November 2020 audit of the September 2015 Response Action Outcome on the MGP site. Mass DEP directed Fitchburg to further define the extent of MGP site contaminants in the sediment and riverbank of an abutting watercourse. Fitchburg began the investigation in November 2021 with the Mass DEP expanding the scope in June 2022 to include an observed river seep. ~~FGE anticipates completion~~Fitchburg submitted the results of ~~the~~its investigation ~~by the end of 2022, while remedial action on~~and an Immediate Response Action (IRA) plan associated with the river seep ~~may occur before that time.~~to the Mass DEP in December 2022. The Mass DEP has review and approval authority over the IRA plan’s recommendations, and Fitchburg continues to anticipate a limited remediation effort associated with the seep in 2023. In June 2023, the IRA plan transitioned to a Mass DEP-required public risk characterization of the

site. The Company does not believe this ~~investigation~~risk characterization will have a material adverse effect on its financial condition, results of operations or cash flows.

Fitchburg recovers the environmental response costs incurred at this former MGP site in gas rates pursuant to the terms of a cost recovery agreement approved by the MDPU. Pursuant to this agreement, Fitchburg is authorized to amortize and recover environmental response costs from gas customers over succeeding seven-year periods.

Unitil Energy - Kensington Distribution Operations Center

Unitil Energy conducted a Phase I and II environmental site assessment (ESA) in the second quarter of 2021. The ESA results identified soil and groundwater contaminants in excess of state regulatory standards. In September 2021, the NH DES directed Unitil Energy to conduct a supplemental site investigation (SSI) and identify whether there is a need to conduct further investigation or remedial actions. Unitil Energy began the SSI in December 2021 with the NH DES extending the SSI scope in June 2022 to further delineate potential impacts. Unitil Energy completed the field portion of the SSI in September 2022 ~~with~~and submitted the ~~submittal of a~~ report to the NH DES ~~anticipated~~ in June 2023 and is awaiting a decision by the ~~fourth quarter~~agency. Unitil Energy anticipates the commencement of ~~2022.~~

~~Table~~remediation activities in 2025. The Company does not believe this investigation will have a material adverse effect on its financial condition, results of ~~Contents~~

operations or cash flows.

The following table sets forth a summary of changes in the Company’s liability for Environmental Obligations for the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021.~~2022.


Environmental Obligations (millions)
	June 30,
	2023		2022
Total Balance at Beginning of Period	$	4.4	$	2.7
Additions		0.5		0.3
Less: Payments / Reductions		0.2		0.2
Total Balance at End of Period		4.7		2.8
Less: Current Portion		0.6		0.6
Noncurrent Balance at End of Period	$	4.1	$	2.2

Environmental Obligations ($ millions)


September 30,


2022
   2021
Total Balance at Beginning of Period

$
2.7

   $ 2.1
Additions

0.4

   0.6
Less: Payments / Reductions

0.3

   0.3

Total Balance at End of Period


2.8

   2.4

Less: Current Portion

0.6

   0.7

Noncurrent Balance at End of Period

$
2.2

   $ 1.7

~~NOTE~~

Note 8: INCOME TAXES

The differences between the Company’s provisions for Income Taxes and the provisions calculated at the statutory federal tax rate, expressed in percentages, are shown in the following table:


	For the Six Months Ended June 30,
	2023			2022
Statutory Federal Income Tax Rate		21	%		21	%
Income Tax Effects of:
State Income Taxes, net		6			6
Utility Plant Differences		(3	)		(5	)
Effective Income Tax Rate		24	%		22	%

Nine Months Ended September 30,


2022

2021

Statutory Federal Income Tax Rate


21
%
21 %
Income Tax Effects of:

State Income Taxes, net


6

6
Utility Plant Differences


(6
)
(3 )


Effective Income Tax Rate

21
%

24 %

Under the Company’s Tax Sharing Agreement (the Agreement) which was approved upon the formation of Unitil as a public utility holding company, the Company files consolidated Federal and State tax returns and Unitil Corporation and each of its utility operating subsidiaries recognize the results of their operations in its tax returns as if it were a stand-alone taxpayer. The Agreement provides that the Company will account for income taxes in compliance with U.S. GAAP and regulatory accounting principles. The Company has evaluated its tax positions at ~~September~~June 30, ~~2022~~2023 in accordance with the FASB Codification, and has concluded that no adjustment for recognition,

de-recognition,

settlement or foreseeable future events to any tax liabilities or assets as defined by the FASB Codification is required. The Company remains subject to examination by the Internal Revenue Service (IRS), and Maine, Massachusetts, and New Hampshire tax authorities for the tax periods ended December 31, 2021; December 31, 2020; and December 31, 2019.

Income tax filings for the year ended December 31, 2021 have been filed with the IRS, Massachusetts Department of Revenue, the Maine Revenue Service, and the New Hampshire Department of Revenue Administration. In the Company’s federal tax returns for the year ended December 31, 2021, which were filed with the IRS in October 2022, the Company utilized federal Net Operating Loss Carryforward (NOLC) assets of ~~$2.4~~

~~million and has approximatel~~

$~~5.8~~

2.4 million. The Company had approximately $5.3million of NOLC assets available to offset current taxes payable as of December 31, 2021. In fiscal year 2022, ~~taxable income.~~the Company recognized the utilization of approximately $2.8 million of the NOLC asset. In addition, at ~~September 30,~~December 31, 2022, the Company had

$1.0 million of cumulative state tax credit carryforwards to offset future income taxes payable. If unused, the Company’s state tax credit carryforwards will begin to expire in 2027.

~~Table of Contents~~

In March 2020, the Coronavirus Aid, Relief and Economic Security (CARES) Act was signed into law. The CARES Act included several tax changes as part of its economic package. These changes principally related to expanded Net Operating Loss carryback periods, increases to interest deductibility limitations, and accelerated Alternative Minimum Tax refunds. Additionally, the CARES Act enacted the Employee Retention Credit (ERC) to incentivize companies to retain employees. The ERC is a

% credit on employee wages for employees that are retained and cannot perform their job duties at

100

% capacity as a result of coronavirus pandemic restrictions.

In December 2020, the Consolidated Appropriations Act, 2021 (CAA) was signed into law. The CAA included additional funding through tax credits as part of its economic package for 2021. These changes include the temporary removal of deduction limitations on business meals through December 2022 and additional funding for the ERC with expanded benefits extended through June 30, 2021. The expanded ERC is a ~~70%~~70% credit on employee wages for employees that are retained and cannot perform their job duties at ~~100%~~100% capacity as a result of coronavirus pandemic restrictions.

In March 2021, the American Rescue Plan Act of 2021 (ARPA) was signed into law. The ARPA included certain provisions that provide economic relief for the

ongoing COVID-19

pandemic, such as extending the ERC through December 31, 2021, and other future governmental revenue producing provisions, such as expanding the scope for deduction limitations on executive compensation in future years.

In August 2022, the Inflation Reduction Act of 2022 (IRA) was signed into law. The IRA ~~includes~~included new taxes on corporations, ~~such as~~including the Corporate Alternative Minimum Tax (AMT) and the Excise Tax on Repurchase of Corporate Stock. The AMT is equal to ~~15%~~15% of a corporation’s adjusted financial statement income (AFSI) ~~and~~. The AMT applies to companies that have a 3 year average AFSI of greater than $1$1 billion. The IRA also ~~extends~~extended and ~~modifies~~modified certain ~~tax incentives for investments in clean and~~ renewable energy ~~projects.~~

related credits.

The Company has evaluated each of the CARES, CAA ARPA, and IRA provisions and determined that they do not have a material effect on the Company’s financial statements as of ~~September~~June 30, ~~2022.~~

2023.

In December 2017, the Tax Cuts and Jobs Act (TCJA), which included a reduction to the corporate federal income tax rate to ~~21%~~21% effective January 1, 2018, was signed into law. In accordance with FASB Codification Topic 740, the Company revalued its Accumulated Deferred Income Taxes (ADIT) at the new ~~21%~~21% tax rate at which the ADIT will be reversed in future periods. Based on communications received by the Company from its state regulators in rate cases and other regulatory proceedings in the first quarter of 2018 and as prescribed in the TCJA, FERC guidance and IRS normalization rules, the benefit of protected excess ADIT amounts will be subject to flow back to customers in future utility rates according to the Average Rate Assumption Method (ARAM). ARAM reconciles excess ADIT at the reversal rate of the underlying book/tax temporary timing differences. The Company estimates the ARAM flow back period for protected and unprotected excess ADIT to be between fifteen and twenty years over the remaining life of the related utility plant. Subject to regulatory approval, the Company expects to flow back to customers a net ~~$47.1~~$47.1 million of protected excess ADIT created as a result of the lowering of the statutory tax rate by the TCJA over periods estimated to be fifteen to twenty years. As of ~~September~~June 30, ~~2022,~~2023, the Company flowed back ~~$5.4~~$7.8 million to customers in its Massachusetts, Maine, New Hampshire, and federal jurisdictions.

~~NOTE~~

Note 9: ~~RETIREMENT BENEFIT OBLIGATIONS~~

Retirement Benefit obligations

The Company

co-sponsors

the Unitil Corporation Retirement Plan (Pension Plan), the Unitil Retiree Health and Welfare Benefits Plan (PBOP Plan), and the Unitil Corporation SERP to provide certain pension and postretirement benefits for its retirees and current employees. ~~Please see~~Refer to Note 109 to the Consolidated Financial Statements in the Company’s Form

10-K

for the year ended December 31, ~~2021~~2022 as filed with the SEC on February ~~1, 2022~~14, 2023 for additional information regarding these plans.

~~Table of Contents~~

The following table includes the key weighted average assumptions used in determining the Company’s benefit plan costs and obligations:


Used to Determine Plan Costs	2023			2022
Discount Rate		5.25	%		2.85	%
Rate of Compensation Increase		3.00	%		3.00	%
Expected Long-term rate of return on plan assets		7.50	%		7.50	%

The health care cost trend rate used to determine benefit plan costs for 2023 for pre-65 retirees is 8.00%, with an ultimate rate of 4.50% in 2030, and for post-65 retirees, the health care cost trend rate is 6.25%, with an ultimate rate of 4.50% in 2030. The health care cost trend rate used to determine benefit plan costs for 2022 for both pre-65 and post-65 retirees is 6.20%, with an ultimate rate 4.50% in 2029.

Used to Determine Plan Costs

2022
2021
Discount Rate


2.85
%
2.50 %
Rate of Compensation Increase


3.00
%
3.00 %
Expected Long-term rate of return on plan assets


7.50
%
7.50 %
Health Care Cost Trend Rate Assumed for Next Year


6.20
%
6.60 %
Ultimate Health Care Cost Trend Rate


4.50
%
4.50 %
Year that Ultimate Health Care Cost Trend Rate is reached


2029

2029

The following tables provide the components of the Company’s Retirement plan costs ($000’s):


	Pension Plan						PBOP Plan						SERP
For the Three Months Ended June 30,	2023			2022			2023			2022			2023			2022
Service Cost	$	523		$	791		$	373		$	722		$	63		$	68
Interest Cost		1,870			1,371			725			799			188			118
Expected Return on Plan Assets		(2,672	)		(2,720	)		(852	)		(854	)		—			—
Prior Service Cost Amortization		88			89			199			273			14			14
Actuarial Loss Amortization		—			1,377			(366	)		255			—			199
Sub-total		(191	)		908			79			1,195			265			399
Amounts Capitalized and Deferred		366			(309	)		112			(622	)		(82	)		(119	)
Net Periodic Benefit Cost Recognized	$	175		$	599		$	191		$	573		$	183		$	280


	Pension Plan						PBOP Plan						SERP
For the Six Months Ended June 30,	2023			2022			2023			2022			2023			2022
Service Cost	$	1,046		$	1,582		$	746		$	1,444		$	125		$	136
Interest Cost		3,740			2,742			1,450			1,598			377			236
Expected Return on Plan Assets		(5,344	)		(5,440	)		(1,704	)		(1,708	)		—			—
Prior Service Cost Amortization		177			178			397			546			28			28
Actuarial Loss Amortization		—			2,754			(732	)		510			—			399
Sub-total		(381	)		1,816			157			2,390			530			799
Amounts Capitalized and Deferred		864			(464	)		333			(1,133	)		(164	)		(238	)
Net Periodic Benefit Cost Recognized	$	483		$	1,352		$	490		$	1,257		$	366		$	561

Pension Plan

PBOP Plan

SERP

Three Months Ended September 30,

2022
2021
2022
2021
2022
2021
Service Cost

$
792

$ 868
$
723

$ 759

$
69

$ 89

Interest Cost


1,372

1,250

798

685

118

114

Expected Return on Plan Assets


(2,722
)
(2,422 )

(853
)
(627 )

—

—

Prior Service Cost Amortization


89

76

273

302

14

14

Actuarial Loss Amortization


1,376

2,021

255

260

196

372



Sub-total


907

1,793

1,196

1,379

397

589

Amounts Capitalized and Deferred


(345
)
(944 )

(655
)
(904 )

(117
)
(178 )


Net Periodic Benefit Cost Recognized

$
562

$ 849
$
541

$ 475

$
280

$ 411



��

Pension Plan

PBOP Plan

SERP

Nine Months Ended September 30,

2022
2021
2022
2021
2022
2021
Service Cost

$
2,374

$ 2,604
$
2,167

$ 2,275
$
205

$ 266
Interest Cost


4,114

3,752

2,396

2,055

354

343
Expected Return on Plan Assets


(8,162
)
(7,268 )

(2,561
)
(1,881 )

—

—
Prior Service Cost Amortization


267

226

819

906

42

42
Actuarial Loss Amortization


4,130

6,065

765

784

595

1,117


Sub-total


2,723

5,379

3,586

4,139

1,196

1,768
Amounts Capitalized and Deferred


(810
)
(2,544 )

(1,788
)
(2,358 )

(354
)
(534 )


Net Periodic Benefit Cost Recognized

$
1,913

$ 2,835
$
1,798

$ 1,781
$
842

$ 1,234

Employer Contributions

As of ~~September~~June 30, ~~2022,~~2023, the Company had made ~~$3.8~~contributions of $1.9 million and ~~$2.0~~$0.6 million, ~~of contributions~~ to its Pension Plan and PBOP Plan, respectively, in ~~2022.~~2023. The Company, along with its subsidiaries, expects ~~to continue~~ to make contributions to its Pension and PBOP Plans in ~~2022~~2023 and future years at minimum required and discretionary funding levels consistent with the amounts recovered in the distribution utilities’ rates for these Pension and PBOP Plan costs.

As of ~~September~~June 30, ~~2022,~~2023, the Company had made ~~$0.5~~$0.3 million of benefit payments under the SERP Plan in ~~2022.~~2023. The Company presently anticipates making an additional ~~$0.1~~$0.3 million of benefit payments under the SERP Plan in ~~2022.~~

2023.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Reference is made to the “Interest Rate Risk” and “Market Risk” sections of Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” ~~(above)~~.

Item 4. Controls and Procedures

Management of the Company, under the supervision and with the participation of the Company’s Chief Executive Officer, Chief Financial Officer, and Chief Accounting Officer, carried out an evaluation of the effectiveness of the design and operation of the Company’s disclosure controls and procedures as of ~~September~~June 30, ~~2022.~~2023. Based upon this evaluation, the Company’s Chief Executive Officer, Chief Financial Officer and Chief Accounting Officer concluded as of ~~September~~June 30, ~~2022~~2023 that the Company’s disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15(d)-15(e)) are effective.

There have been no changes in the Company’s internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15(d)-15(f)) during the fiscal quarter covered by this Form 10-Q that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

The Company is involved in legal and administrative proceedings and claims of various types, which arise in the ordinary course of business. Certain specific matters are discussed in Notes 6 and 7 to the Consolidated Financial Statements. In the opinion of Management, based upon information furnished by counsel and others, the ultimate resolution of these claims will not have a material effect on the Company’s financial position.

Item 1A. Risk Factors

There have been no material changes to the risk factors disclosed in the Company’s Form 10-K for the year-ended December 31, ~~2021~~2022 as filed with the SEC on February ~~1, 2022.~~14, 2023.

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

Recent Sales of Unregistered Securities

There were no sales of unregistered equity securities by the Company for the fiscal period ended ~~September~~June 30, ~~2022.~~2023.

Issuer Purchases of Equity Securities

Pursuant to the Company’s written trading plan under Rule 10b5-1 under the Exchange Act, adopted and announced by the Company on ~~May~~June 1, ~~2022,~~2023, the Company will periodically repurchase shares of its Common Stock on the open market ~~related~~ to fulfill the ~~stock~~required equity portion of the Directors’ annual retainer for those Directors who elected to receive common stock. There is no pool or

maximum number of shares related to these purchases; however, the trading plan will terminate when ~~$587,000~~$614,000 in value of shares have been purchased or, if sooner, on May ~~1, 2023.~~31, 2024.

The Company may suspend or terminate this new trading plan at any time, so long as the suspension or termination is made in good faith and not as part of a plan or scheme to evade the prohibitions of Rule 10b-5 under the Exchange Act, or other applicable securities laws.

The following table provides information regarding repurchases by the Company of shares of its common stock pursuant to the trading plan for each month in the quarter ended ~~September~~June 30, ~~2022.~~2023.

   Total
Number
of Shares
Purchased    Average
Price Paid
per Share    Total Number of
Shares Purchased as
Part of Publicly
Announced Plans or
Programs    Approximate Dollar
Value of Shares that
May Yet Be
Purchased Under the
Plans or Programs
7/1/22 – 7/31/22
   —      —      —      $ 587,000
8/1/22 – 8/31/22
   —      —      —      $ 587,000
9/1/22 – 9/30/22
   —      —      —      $ 587,000





Total
   —      —      —


	Total Number of Shares Purchased		Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs		Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs
4/1/23 – 4/30/23		—		—		—	$	145,027
5/1/23 – 5/31/23		—		—		—	$	—
6/1/23 – 6/30/23		—		—		—	$	614,000
Total		—		—		—

Item 5. Other Information

(a) On ~~November~~August 1, ~~2022,~~2023, the Company issued a press release announcing its results of operations for the three and ~~nine~~six month periods ended ~~September~~June 30, ~~2022.~~2023. The press release is furnished with this Quarterly Report on Form 10-Q as Exhibit 99.1.

(c) During the quarter ended June 30, 2023, no director or officer (as defined in Rule 16a-1(f) promulgated under the Securities Exchange Act of 1934) adopted or terminated a Rule10b5-1 trading arrangement (as defined in Item 408(a)(1)(i) of Regulation S-K promulgated under the Securities Exchange Act of 1934) or any non-Rule 10b5-1 trading arrangement (as defined in Item 408(c) of Regulation S-K promulgated under the Securities Exchange Act of 1934).

Item 6. Exhibits

(a) Exhibits



Exhibit No.		Description of Exhibit	~~Reference~~Reference*
4.1* 4.1 (1)		~~Third Amended and Restated Credit~~Note Purchase Agreement dated ~~September~~ ~~29, 2022~~July 6, 2023 by and among ~~Unitil Corporation, Bank of America, N.A., as administrative agent,~~Fitchburg Gas and Electric Light Company and the ~~Lenders~~several purchasers named therein.	Exhibit 4.1 to Form 8-K dated ~~September 29, 2022~~July 6, 2023 (SEC File No. 1-8858)

4.2(2)	5.70% Senior Note, Series 2023A, due July 2, 2033, issued by Fitchburg Gas and Electric Light Company to MetLife Reinsurance Company of Hamilton, Ltd.	~~Second Amended and Restated Note issued to Citizens Bank, N.A.~~	Exhibit 4.2 to Form 8-K dated ~~September 29, 2022~~July 6, 2023 (SEC File No. 1-8858)

4.3(2)	5.96% Senior Note, Series 2023B, due July 2, 2053, issued by Fitchburg Gas and Electric Light Company to Mutual of Omaha Insurance Company.	~~Second Amended and Restated Note issued to TD Bank, N.A.~~	Exhibit 4.3 to Form 8-K dated ~~September 29, 2022~~July 6, 2023 (SEC File No. 1-8858)

10.1* 31.1		~~Third Amended and Restated Credit Agreement dated September~~ ~~29, 2022 among Unitil Corporation, Bank of America, N.A., as administrative agent, and the Lenders~~	~~Exhibit 4.1 to Form~~ ~~8-K~~ ~~dated September 29, 2022 (SEC File~~ ~~No. 1-8858)~~



~~31.1~~	Certification of Chief Executive Officer Pursuant to Rule 13a-14 of the Exchange Act, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002	Filed herewith

31.2	Certification of Chief Financial Officer Pursuant to Rule 13a-14 of the Exchange Act, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002	Filed herewith

31.3	Certification of Chief Accounting Officer Pursuant to Rule 13a-14 of the Exchange Act, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002	Filed herewith



Exhibit No.	Description of Exhibit	Reference*

32.1		Certifications of Chief Executive Officer, Chief Financial Officer and Chief Accounting Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002	Filed herewith

99.1		Unitil Corporation Press Release Dated ~~November~~August 1, ~~2022~~2023 Announcing Earnings For the Quarter Ended ~~September~~June 30, ~~2022.~~2023.	Furnished herewith

101.INS		Inline XBRL Instance Document. The instance document does not appear in the interactive data file because its XBRL tags are embedded within the Inline XBRL document.	Filed herewith

101.SCH		Inline XBRL Taxonomy Extension Schema Document.	Filed herewith

101.CAL		Inline XBRL Taxonomy Extension Calculation Linkbase Document.	Filed herewith

101.DEF		Inline XBRL Taxonomy Extension Definition Linkbase Document	Filed herewith

101.LAB		Inline XBRL Taxonomy Extension Label Linkbase Document.	Filed herewith

101.PRE		Inline XBRL Taxonomy Extension Presentation Linkbase Document.	Filed herewith

104		Cover Page Interactive Data File – The cover page interactive data file does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document.	Filed herewith

~~Each of these exhibits includes Schedule 2.01 (Commitments and Applicable Percentages). In accordance with Item 601(a)(5) of Regulation~~ ~~S-K,~~ the Registrant has omitted all other schedules and exhibits. Each exhibit’s table of contents includes a brief description of the subject matter of all schedules and exhibits, including the omitted schedules and exhibits. The Registrant acknowledges that it must provide a copy of any omitted schedules or exhibits to the Securities and Exchange Commission or its staff upon request.

* The exhibits referred to in this column by specific designations and dates have heretofore been filed with or furnished to the Securities and Exchange Commission under such designations and are hereby incorporated by reference.

(1) In accordance with Item 601(a)(5) of Regulation S-K, this exhibit omits certain of its schedules and exhibits. This exhibit’s table of contents includes a brief description of the subject matter of all of its schedules and exhibits, including the omitted schedules and exhibits. The Registrant acknowledges that it must provide a copy of any omitted schedules or exhibits to the Securities and Exchange Commission or its staff upon request.

(2) This note is substantially identical in all material respects to other notes that are otherwise required to be filed as exhibits, except as to the registered payee of such note, the identifying number of such note, and the principal amount of such note. In accordance with instruction no. 2 to Item 601 of Regulation S-K, the Registrant has filed a copy of only one of such notes, with a schedule identifying the other notes omitted and setting forth the material details in which such notes differ from the note that was filed. The Registrant acknowledges that the Securities and Exchange Commission may at any time in its discretion require filing of copies of any notes so omitted.

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.


		~~UNITIL CORPORATION~~
		~~(Registrant)~~

~~Date: November 1, 2022~~		~~/s/ Robert B. Hevert~~
		~~Robert B. Hevert~~ UNITIL CORPORATION
	(Registrant)

Date: August 1, 2023	/s/ Daniel J. Hurstak
	Daniel J. Hurstak
	Chief Financial Officer

5444



New Hampshire		02-0381573
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)



6 Liberty Lane West, Hampton, New Hampshire		03842-1720
(Address of principal executive office)		(Zip Code)



Title of each class		Trading Symbol	Name of each exchange of which registered
Common Stock, no par value	UTL	~~UTL~~	New York Stock Exchange



Large accelerated filer	☒	☒	Accelerated filer	☐

Non-accelerated filer	☐	☐	Smaller reporting company	☐

			Emerging growth company	☐



Class	Outstanding at July 28, 2023
Common Stock, no par value	16,092,469 Shares


~~Class~~		~~Outstanding at October 28, 2022~~
~~Common Stock, no par value~~	~~16,039,938 Shares~~


				Page No.
Cautionary Statement				2-3


Part I. Financial Information


Item 1.		Financial Statements—Unaudited

		Consolidated Statements of Earnings—Three and ~~Nine~~Six Months Ended ~~September~~June 30, 2023 and 2022	14

	Consolidated Balance Sheets, June 30, 2023, June 30, 2022 and ~~2021~~December 31, 2022			18	15-16

		~~Consolidated Balance Sheets, September 30, 2022, September 30, 2021 and December 31, 2021~~			~~19-20~~

		Consolidated Statements of Cash Flows—~~Nine~~Six Months Ended ~~September~~June 30, ~~2022~~2023 and ~~2021~~2022			21	17

		Consolidated Statements of Changes in Common Stock Equity – Three and ~~Nine~~Six Months Ended ~~September~~June 30, ~~2022~~2023 and ~~2021~~2022			~~22-23~~18

		Notes to Consolidated Financial Statements			~~24-51~~19-40

Item 2.		Management’s Discussion and Analysis (MD&A) of Financial Condition and Results of Operations			~~3-17~~	3-13

Item 3.		Quantitative and Qualitative Disclosures About Market Risk			51	41

Item 4.		Controls and Procedures			51
			41

Part II. Other Information

Item 1.		Legal Proceedings			51	41

Item 1A.		Risk Factors			51	41

Item 2.		Unregistered Sales of Equity Securities and Use of Proceeds			~~51-52~~41-42

Item 3.		Defaults Upon Senior Securities			Inapplicable

Item 4.		Mine Safety Disclosures			Inapplicable

Item 5.		Other Information			52	42

Item 6.	Exhibits	~~Exhibits~~			~~52-53~~42-43

Signatures				54	44


	Three Months Ended September 30,						Nine Months Ended September 30,
	2022			2021			2022		2021
Operating Revenues
Electric	$	75.7		$	65.5		$	219.2	$	182.2
Gas		34.5			32.6			182.5		151.3

Total Operating Revenues		110.2			98.1			401.7		333.5

Operating Expenses
Cost of Electric Sales		47.3			40.1			142.6		108.8
Cost of Gas Sales		14.1			13.2			81.9		59.1
Operation and Maintenance		18.6			16.7			55.5		51.2
Depreciation and Amortization		16.6			14.8			46.9		44.5
Taxes Other Than Income Taxes		6.4			6.1			19.9		18.5

Total Operating Expenses		103.0			90.9			346.8		282.1

Operating Income		7.2			7.2			54.9		51.4
Interest Expense, Net		6.6			6.5			19.1		19.5
Other Expense (Income), Net		0.6			1.0			1.9		3.4

Income (Loss) Before Income Taxes		—			(0.3	)		33.9		28.5
Provision (Benefit) for Income Taxes		(0.5	)		(0.3	)		7.0		6.9

Net Income	$	0.5		$	—		$	26.9	$	21.6

Net Income Per Common Share (Basic and Diluted)	$	0.03		$	—		$	1.68	$	1.42
Weighted Average Common Shares Outstanding – (Basic and Diluted)		16.0			15.5			16.0		15.2


	Three Months Ended September 30, 2022
Electric and Gas Operating Revenues ($ millions):	Electric			Gas		Total
Billed and Unbilled Revenue:
Residential	$	42.5		$	8.8	$	51.3
Commercial and Industrial		30.2			17.8		48.0
Other		5.1			0.8		5.9

Total Billed and Unbilled Revenue		77.8			27.4		105.2
Rate Adjustment Mechanism Revenue		(2.1	)		7.1		5.0

Total Electric and Gas Operating Revenues	$	75.7		$	34.5	$	110.2


	Three Months Ended September 30, 2021
Electric and Gas Operating Revenues ($ millions):	Electric			Gas			Total
Billed and Unbilled Revenue:
Residential	$	35.0		$	7.9		$	42.9
Commercial and Industrial		26.8			14.4			41.2
Other		3.2			0.8			4.0

Total Billed and Unbilled Revenue		65.0			23.1			88.1
Rate Adjustment Mechanism Revenue		0.5			9.5			10.0

Total Electric and Gas Operating Revenues	$	65.5		$	32.6		$	98.1


	Nine Months Ended September 30, 2022
Electric and Gas Operating Revenues ($ millions):	Electric			Gas			Total
Billed and Unbilled Revenue:
Residential	$	125.5		$	72.4		$	197.9
Commercial and Industrial		86.9			110.5			197.4
Other		14.3			7.7			22.0

Total Billed and Unbilled Revenue		226.7			190.6			417.3
Rate Adjustment Mechanism Revenue		(7.5	)		(8.1	)		(15.6	)

Total Electric and Gas Operating Revenues	$	219.2		$	182.5		$	401.7


	Nine Months Ended September 30, 2021
Electric and Gas Operating Revenues ($ millions):	Electric			Gas			Total
Billed and Unbilled Revenue:
Residential	$	104.0		$	60.5		$	164.5
Commercial and Industrial		78.2			86.2			164.4
Other		6.9			7.6			14.5

Total Billed and Unbilled Revenue		189.1			154.3			343.4
Rate Adjustment Mechanism Revenue		(6.9	)		(3.0	)		(9.9	)

Total Electric and Gas Operating Revenues	$	182.2		$	151.3		$	333.5


($ millions)
	September 30,				December 31,
	2022		2021		2021
Allowance for Doubtful Accounts	$	2.4	$	4.3	$	3.3


	September 30,				December 31,
Accrued Revenue ($ millions)	2022		2021		2021
Regulatory Assets – Current	$	44.0	$	30.6	$	47.4
Unbilled Revenues, net		2.9		8.0		13.8

Total Accrued Revenue	$	46.9	$	38.6	$	61.2


	September 30,				December 31,
Exchange Gas Receivable ($ millions)	2022		2021		2021
Northern Utilities	$	23.1	$	9.7	$	6.7
Fitchburg		2.0		0.8		0.7

Total Exchange Gas Receivable	$	25.1	$	10.5	$	7.4


	September 30,				December 31,
Gas Inventory ($ millions)	2022		2021		2021
Natural Gas	$	1.1	$	0.4	$	0.5
Propane		0.4		0.4		0.4
Liquefied Natural Gas & Other		0.2		0.1		0.1

Total Gas Inventory	$	1.7	$	0.9	$	1.0


	September 30,				December 31,
Fair Value of Marketable Securities ($ millions)	2022		2021		2021
Money Market Funds	$	5.6	$	5.6	$	5.7

Total Marketable Securities	$	5.6	$	5.6	$	5.7


	September 30,				December 31,
Energy Supply Obligations ($ millions)	2022		2021		2021
Current:
Exchange Gas Obligation	$	23.1	$	9.7	$	6.7
Renewable Energy Portfolio Standards		6.7		6.4		7.8

Total Energy Supply Obligations	$	29.8	$	16.1	$	14.5


	Electric			Gas			Non- Regulated		Other			Total
Three Months Ended Sept. 30, 2022 ($ millions)
Revenues:
Billed and Unbilled Revenue	$	77.8		$	27.4		$	—	$	—		$	105.2
Rate Adjustment Mechanism Revenue		(2.1	)		7.1			—		—			5.0
Other Operating Revenue – Non-Regulated		—			—			—		—			—

Total Operating Revenues	$	75.7		$	34.5		$	—	$	—		$	110.2

Segment Profit (Loss)		5.9			(5.3	)		—		(0.1	)		0.5
Capital Expenditures		8.3			28.9			—		—			37.2

Three Months Ended Sept. 30, 2021 ($ millions)
Revenues:
Billed and Unbilled Revenue	$	65.0		$	23.1		$	—	$	—		$	88.1
Rate Adjustment Mechanism Revenue		0.5			9.5			—		—			10.0
Other Operating Revenue – Non-Regulated		—			—			—		—			—

Total Operating Revenues	$	65.5		$	32.6		$	—	$	—		$	98.1

Segment Profit (Loss)		4.4			(4.1	)		—		(0.3	)		—
Capital Expenditures		10.1			28.5			—		0.4			39.0

Nine Months Ended Sept. 30, 2022 ($ millions)
Revenues:
Billed and Unbilled Revenue	$	226.7		$	190.6		$	—	$	—		$	417.3
Rate Adjustment Mechanism Revenue		(7.5	)		(8.1	)		—		—			(15.6	)
Other Operating Revenue – Non-Regulated		—			—			—		—			—

Total Operating Revenues	$	219.2		$	182.5		$	—	$	—		$	401.7

Segment Profit (Loss)		13.2			14.5			—		(0.8	)		26.9
Capital Expenditures		22.5			59.9			—		0.1			82.5
Segment Assets		590.9			967.5			—		20.5			1,578.9

Nine Months Ended Sept. 30, 2021 ($ millions)
Revenues:
Billed and Unbilled Revenue	$	189.1		$	154.3		$	—	$	—		$	343.4
Rate Adjustment Mechanism Revenue		(6.9	)		(3.0	)		—		—			(9.9	)
Other Operating Revenue – Non-Regulated		—			—			—		—			—

Total Operating Revenues	$	182.2		$	151.3		$	—	$	—		$	333.5

Segment Profit		10.7			12.1			0.1		(1.3	)		21.6
Capital Expenditures		28.8			51.7			—		1.0			81.5
Segment Assets		583.6			906.2			—		19.2			1,509.0


	September 30,				December 31,
Lease Obligations ($ millions)	2022		2021		2021
Operating Lease Obligations:
Other Current Liabilities (current portion)	$	1.6	$	1.6	$	1.6
Other Noncurrent Liabilities (long-term portion)		3.0		3.5		3.1

Total Operating Lease Obligations	$	4.6	$	5.1	$	4.7

Capital Lease Obligations:
Other Current Liabilities (current portion)	$	0.1	$	0.2	$	0.1
Other Noncurrent Liabilities (long-term portion)		0.1		0.2		0.2

Total Capital Lease Obligations	$	0.2	$	0.4	$	0.3

Total Lease Obligations	$	4.8	$	5.5	$	5.0


Lease Payments ($000’s) Year Ending December 31,	Operating Leases		Capital Leases
Rest of 2022	$	457	$	36
2023		1,655		114
2024		1,325		59
2025		759		26
2026		456		6
2027-2031		291		3

Total Payments		4,943		244

Less: Interest		329		9

Amount of Lease Obligations Recorded on Consolidated Balance Sheets	$	4,614	$	235


Environmental Obligations ($ millions)
	September 30,
	2022		2021
Total Balance at Beginning of Period	$	2.7	$	2.1
Additions		0.4		0.6
Less: Payments / Reductions		0.3		0.3

Total Balance at End of Period		2.8		2.4

Less: Current Portion		0.6		0.7

Noncurrent Balance at End of Period	$	2.2	$	1.7

Date: ~~November~~August 1, ~~2022~~2023

/s/ ~~Daniel J. Hurstak~~Todd R. Diggins

~~Daniel J. Hurstak~~
Todd R. Diggins

Chief Accounting Officer