
	Three Months Ended June 30, 2021
Gas and Electric Operating Revenues ($ millions):	Gas			Electric			Total
Billed and Unbilled Revenue:
Residential	$	14.9		$	30.8		$	45.7
C&I		21.8			25.5			47.3
Other		1.3			2.0			3.3

Total Billed and Unbilled Revenue		38.0			58.3			96.3
Rate Adjustment Mechanism Revenue		2.0			(1.7	)		0.3

Total Gas and Electric Operating Revenues	$	40.0		$	56.6		$	96.6



	Three Months Ended June 30, 2020
Gas and Electric Operating Revenues ($ millions):	Gas			Electric			Total
Billed and Unbilled Revenue:
Residential	$	14.3		$	30.2		$	44.5
C&I		19.0			20.5			39.5
Other		1.2			1.5			2.7

Total Billed and Unbilled Revenue		34.5			52.2			86.7
Rate Adjustment Mechanism Revenue		(0.8	)		(2.0	)		(2.8	)

Total Gas and Electric Operating Revenues	$	33.7		$	50.2		$	83.9



	Six Months Ended June 30, 2021
Gas and Electric Operating Revenues ($ millions):	Gas			Electric			Total
Billed and Unbilled Revenue:
Residential	$	52.6		$	68.9		$	121.5
C&I		71.9			51.4			123.3
Other		6.7			3.8			10.5

Total Billed and Unbilled Revenue		131.2			124.1			255.3
Rate Adjustment Mechanism Revenue		(12.5	)		(7.4	)		(19.9	)

Total Gas and Electric Operating Revenues	$	118.7		$	116.7		$	235.4



	Six Months Ended June 30, 2020
Gas and Electric Operating Revenues ($ millions):	Gas			Electric			Total
Billed and Unbilled Revenue:
Residential	$	45.4		$	64.6		$	110.0
C&I		61.3			44.7			106.0
Other		4.2			3.5			7.7

Total Billed and Unbilled Revenue		110.9			112.8			223.7
Rate Adjustment Mechanism Revenue		(7.0	)		(2.4	)		(9.4	)

Total Gas and Electric Operating Revenues	$	103.9		$	110.4		$	214.3

Fitchburg is subject to revenue decoupling. 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 recorded 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 that the Company files with the MDPU.

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 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 include 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 June 30, 2021, June 30, 2020 and December 31, 2020, the Unitil subsidiaries had deposited $1.5 million, $1.4 million and $2.4 million, respectively to satisfy their

ISO-NE

obligations.

Financial Instruments -

In June 2016, the Financial Accounting Standards Board issued ASU

2016-13,

“Financial Instruments—Credit Losses (Topic 326)”, which provides a new model for recognizing credit losses on financial instruments based on an estimate of current expected credit losses. Under the new guidance, immediate recognition of all credit losses expected over the life of a financial instrument is required. The Company adopted this standard on the accounting for credit losses on its financial instruments, including accounts receivable, on January 1, 2020, and it did not have a material effect on the financial statement

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 management’s assessment of current and expected economic conditions, customer trends, or factors such as the extent and duration of any shut off or collection moratoriums. 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 their 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 June 30, 2021, June 30, 2020 and December 31, 2020, was as follows:


($ millions)
	June 30,				December 31,
	2021		2020		2020
Allowance for Doubtful Accounts	$	4.6	$	1.4	$	3.3

Accounts Receivable, Net includes $4.5 million, $1.3 million, and $3.1 million of the Allowance for Doubtful Accounts at June 30, 2021, June 30, 2020 and December 31, 2020, respectively. Unbilled Revenues, net (a component of Accrued Revenue, shown in the table below) includes $0.1 million, $0.1 million and $0.2 million of the Allowance for Doubtful Accounts at June 30, 2021, June 30, 2020 and December 31, 2020, 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 June 30, 2021, June 30, 2020 and December 31, 2020.


	June 30,				December 31,
Accrued Revenue ($ millions)	2021		2020		2020
Regulatory Assets – Current	$	25.0	$	26.8	$	37.3
Unbilled Revenues		9.6		8.1		13.6

Total Accrued Revenue	$	34.6	$	34.9	$	50.9

Exchange Gas Receivable -

Northern Utilities and Fitchburg have gas exchange and storage agreements whereby natural gas purchases during the months of April through October are delivered to a third party. The third party delivers natural 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 June 30, 2021, June 30, 2020 and December 31, 2020.


	June 30,				December 31,
Exchange Gas Receivable ($ millions)	2021		2020		2020
Northern Utilities	$	4.8	$	3.9	$	4.4
Fitchburg		0.4		0.3		0.5

Total Exchange Gas Receivable	$	5.2	$	4.2	$	4.9

Gas Inventory

The Company uses the weighted average cost methodology to value natural gas inventory. The following table shows the components of Gas Inventory as of June 30, 2021, June 30, 2020 and December 31, 2020.


	June 30,				December 31,
Gas Inventory ($ millions)	2021		2020		2020
Natural Gas	$	0.2	$	0.1	$	0.2
Propane		0.3		0.3		0.3
Liquefied Natural Gas & Other		0.1		0.1		0.1

Total Gas Inventory	$	0.6	$	0.5	$	0.6

Utility Plant -

The cost of 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 June 30, 2021, June 30, 2020 and December 31, 2020, the Company estimates that the cost of removal amounts, which are recorded on the Consolidated Balance Sheets in Cost of Removal Obligations are $105.1 million, $102.6 million, and $105.2 million, respectively.

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 Massachusetts Department of Public Utilities (MDPU), Unitil Energy is regulated by the New Hampshire Public Utilities Commission (NHPUC) and Northern Utilities is regulated by the Maine Public Utilities Commission (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 June 30, 2021, June 30, 2020 and December 31, 2020, the Company has recorded $9.8 million, $7.3 million and $6.8

million, respectively, of hardship accounts in Regulatory Assets. These amounts are included in “Other Deferred Charges” in the table below. 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)	2021		2020		2020
Retirement Benefits	$	105.7	$	80.8	$	103.7
Energy Supply & Other Rate Adjustment Mechanisms		21.5		23.8		34.1
Deferred Storm Charges		3.4		4.9		4.1
Environmental		4.7		6.2		5.2
Income Taxes		3.0		3.8		3.4
Other Deferred Charges		17.8		12.2		14.2

Total Regulatory Assets	$	156.1	$	131.7	$	164.7
Less: Current Portion of Regulatory Assets (1)		25.0		26.8		37.3

Regulatory Assets – noncurrent	$	131.1	$	104.9	$	127.4

(1)	Reflects amounts included in Accrued Revenue, discussed above, on the Company’s Consolidated Balance Sheets.


	June 30,				December 31,
Regulatory Liabilities consist of the following ($ millions)	2021		2020		2020
Income Taxes (Note 8)	$	44.8	$	45.9	$	45.5
Rate Adjustment Mechanisms		15.3		11.2		4.1
Other		0.2		0.3		0.2

Total Regulatory Liabilities	$	60.3	$	57.4	$	49.8
Less: Current Portion of Regulatory Liabilities		17.1		12.6		5.5

Regulatory Liabilities – n oncurrent	$	43.2	$	44.8	$	44.3

Generally, the Company receives a return on investment on its regulatory assets for which a cash outflow has been made. Regulatory Assets at June 30, 2021 include $8.3 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 accounting rules for regulated operations, 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 Company’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). 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.

Investments in Marketable Securities

The Company has a trust through which it invests in a variety of equity and fixed income mutual funds. These funds are intended to satisfy obligations under the Company’s SERP Plan (See further discussion of the SERP Plan in Note 9.)

At June 30, 2021, June 30, 2020 and December 31, 2020, the fair value of the Company’s investments in these trading securities, which are recorded on the Consolidated Balance Sheets in Other Assets, were $5.5 million, $5.6 million and $5.7 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.


	June 30,				December 31,
Fair Value of Marketable Securities ($ millions)	2021		2020		2020
Money Market Funds	$	5.5	$	5.6	$	5.7

Total Marketable Securities	$	5.5	$	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, 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 June 30, 2021, June 30, 2020 and December 31, 2020, 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 $0.7 million, $0.4 million and $0.5 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.


	June 30,				December 31,
Fair Value of Marketable Securities ($ millions)	2021		2020		2020
Equity Funds	$	0.3	$	0.1	$	0.2
Money Market Funds		0.4		0.3		0.3

Total Marketable Securities	$	0.7	$	0.4	$	0.5

Energy Supply Obligations -

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


	June 30,				December 31,
Energy Supply Obligations ($ millions)	2021		2020		2020
Current:
Exchange Gas Obligation	$	4.8	$	3.9	$	4.4
Renewable Energy Portfolio Standards		5.0		4.2		5.7
Power Supply Contract Divestitures		0.1		0.3		0.3

Total Energy Supply Obligations - Current		9.9		8.4		10.4
Noncurrent:
Power Supply Contract Divestitures		—		0.1		—

Total Energy Supply Obligations	$	9.9	$	8.5	$	10.4

Exchange Gas Obligation -

Northern Utilities enters into gas exchange agreements under which Northern Utilities releases certain gas pipeline and storage assets, resells 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 in Accrued Revenue with a corresponding liability in Energy Supply Obligations on the Company’s Consolidated Balance Sheets.

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 seven of these contracts have been constructed and are now operating. In 2020, three of the long-term contracts were terminated due to an inability to meet critical milestones. In 2018, the Company filed two long-term contracts with the MDPU, one for offshore wind generation and another for imported hydroelectric power and associated transmission. Those contracts were approved in 2019. In 2019, the Company participated in an additional statewide procurement for offshore wind generation and the resulting contracts were filed with the MDPU during the first quarter of 2020. An Order approving the contracts was issued by the MDPU in November 2020. On November 25, 2020 the Office of the Attorney General filed a Motion for Reconsideration of the MDPU’s order regarding remuneration, which was denied. The MDPU order is now final. In compliance with An Act to Promote a Clean Energy Future (2018), in late 2020 in coordination with the other electric utilities in Massachusetts, the Company began efforts on the next long-term renewable procurement which will seek up to an additional 1,600 megawatts (MW) of offshore wind generation. Fitchburg recovers the costs associated with long-term renewable contracts on a fully reconciling basis through a MDPU-approved cost recovery mechanism.

Power Supply Contract Divestitures -

Unitil Energy’s and Fitchburg’s customers are entitled to purchase their electric or 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 March 31, 2021, Fitchburg has fully recovered its power supply-related stranded costs and Unitil Energy has $0.2 million remaining to recover. The obligations related to these divestitures are recorded in Energy Supply Obligations on the Company’s Consolidated Balance Sheets with corresponding regulatory assets recorded in Accrued Revenue.

Subsequent Events -

The Company evaluates all events or transactions through the date of the related filing. During the period subsequent to the balance sheet date and through the date of this filing, the Company did not have any material subsequent events that would result in adjustment to or disclosure in its Consolidated Financial Statements.