UNITIL CORP
10-Ks and 10-Qs
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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM
10-Q
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QUARTERLY REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
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For the quarterly period ended
June
30,
2022
or
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TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
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For the transition period from
to
Commission File Number
1-8858
(Exact name of registrant as specified in its charter)
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(State or other jurisdiction of
incorporation or organization)
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(I.R.S. Employer
Identification No.)
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(Address of principal executive office)
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(Zip Code)
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Registrant’s telephone number, including area code: (
603
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772-0775
Securities registered pursuant to Section 12(b) of the Act:
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Title of each class
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Trading Symbol
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Name of each exchange of which registered
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Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Yes
☒ No ☐
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).
Yes
☒ No ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer”, “accelerated filer”, “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
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☒ | Accelerated filer | ☐ | |||
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Non-accelerated filer
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☐ | Smaller reporting company |
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| Emerging growth company |
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If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No
☒
Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.
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Class
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Outstanding at July 31, 2022
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| Common Stock, no par value |
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UNITIL CORPORATION AND SUBSIDIARY COMPANIES
FORM
10-Q
For the Quarter Ended June 30, 2022
Table of Contents
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Page No.
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2-3
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Part I. Financial Information
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Item 1.
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Financial Statements—Unaudited
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18
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19-20
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21
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22-23
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24-50
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Item 2.
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3-17
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Item 3.
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50
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Item 4.
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50
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Part II. Other Information
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Item 1.
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50
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Item 1A.
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50
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Item 2.
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50-51
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Item 3.
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Defaults Upon Senior Securities
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Inapplicable
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Item 4.
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Mine Safety Disclosures
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Inapplicable
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Item 5.
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51
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Item 6.
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51-52
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53
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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:
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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;
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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;
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catastrophic events;
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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;
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outsourcing of services to third parties could expose us 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;
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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;
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unforeseen or changing circumstances, which could adversely affect the reduction of Company-wide direct greenhouse gas emissions;
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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;
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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);
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the Company’s ability to obtain debt or equity financing on acceptable terms;
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2
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increases in interest rates, which could increase the Company’s interest expense;
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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;
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restrictive covenants contained in the terms of the Company’s and its subsidiaries’ indebtedness, which restrict certain aspects of the Company’s business operations;
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customers’ preferred energy sources;
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severe storms and the Company’s ability to recover storm costs in its rates;
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variations in weather, which could decrease demand for the Company’s distribution services;
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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;
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the Company’s ability to retain its existing customers and attract new customers;
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increased competition; and
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other presently unknown or unforeseen factors.
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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 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:
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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;
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Fitchburg Gas and Electric Light Company (Fitchburg), which provides both electric and gas service in the greater Fitchburg area of north central Massachusetts; and
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3
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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.
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Unitil Energy, Fitchburg and Northern Utilities are collectively referred to as the “distribution utilities.” Together, the distribution utilities serve approximately 107,700 electric customers and 86,600 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 $1,279.1 million at June 30, 2022. 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 a historical test year, 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 and enhanced reliability and vegetation management programs, through annual step adjustments or cost tracking rate mechanisms.
Fitchburg has been subject to revenue decoupling since 2011. Unitil Energy is subject to revenue decoupling as of June 1, 2022. Revenue decoupling is the term given to the elimination of the
4
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. The Company estimates that the revenue decoupling for Fitchburg applied to approximately 27% and 11% of Unitil’s total annual electric and gas sales volumes, respectively. 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 and approximately 11% of Unitil’s total annual gas 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 will be subject to decoupling as of August 1, 2022. Accordingly, as of August 1, 2022, the Company estimates that revenue decoupling will apply to approximately 43% of Unitil’s total annual gas sales volumes.
RESULTS OF OPERATIONS
The following section of MD&A compares the results of operations for each of the two fiscal periods ended June 30, 2022 and June 30, 2021 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.
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 and approximately 11% of the Company’s total annual gas sales volumes are decoupled and changes in sales to existing customers do not affect GAAP gross margin and adjusted
5
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 will be subject to decoupling as of August 1, 2022. Accordingly, as of August 1, 2022, the Company estimates that revenue decoupling will apply 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 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
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 $5.9 million. The proceeds were used to make equity capital contributions to the Company’s regulated utility subsidiaries, to repay debt and for other general corporate purposes. Overall, the results of operations and earnings for the three and six months ended June 30, 2022 reflect the higher number of average shares outstanding.
The Company analyzes operating results using Electric and Gas Adjusted Gross Margins, which are
non-GAAP
financial measures. Electric Adjusted Gross Margin is calculated as Total Electric Operating Revenue less Cost of Electric Sales. Gas Adjusted Gross Margin is calculated as Total Gas Operating Revenues less Cost of Gas Sales. The Company’s management believes Electric and Gas Adjusted Gross Margins provide useful information to investors regarding profitability. Also, the Company’s management believes Electric and Gas Adjusted Gross Margins are important financial measures to analyze revenue from the Company’s ongoing operations because the approved cost of electric and gas sales are tracked, reconciled and passed through directly to customers in electric and gas tariff rates, resulting in an equal and offsetting amount reflected in Total Electric and Gas Operating Revenue.
In the following tables the Company has reconciled Electric and Gas Adjusted Gross Margin to GAAP Gross Margin, which we believe to be the most comparable GAAP financial measure. GAAP Gross Margin is calculated as Revenue less Cost of Sales, and Depreciation and Amortization. The Company calculates Electric and Gas Adjusted Gross Margin as Revenue less Cost of Sales. The Company believes excluding Depreciation and Amortization, which are period costs and not related to volumetric sales, is a meaningful measure to inform investors of the Company’s profitability from electric and gas sales in the period.
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Three Months Ended June 30, 2022 ($ millions)
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Regulated
and Other |
Total
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Total Operating Revenue
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$ | 54.3 | $ | 44.6 | $ | — | $ | 98.9 | ||||||||
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Less: Cost of Sales
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(30.7 | ) | (16.4 | ) | — | (47.1 | ) | |||||||||
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Less: Depreciation and Amortization
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(5.7 | ) | (8.9 | ) | (0.2 | ) | (14.8 | ) | ||||||||
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GAAP Gross Margin
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17.9 | 19.3 | (0.2 | ) | 37.0 | |||||||||||
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Depreciation and Amortization
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5.7 | 8.9 | 0.2 | 14.8 | ||||||||||||
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Adjusted Gross Margin
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$ | 23.6 | $ | 28.2 | $ | — | $ | 51.8 | ||||||||
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Three Months Ended June 30, 2021 ($ millions)
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Total
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Total Operating Revenue
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$ | 56.6 | $ | 40.0 | $ | — | $ | 96.6 | ||||||||
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Less: Cost of Sales
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(32.3 | ) | (15.0 | ) | — | (47.3 | ) | |||||||||
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Less: Depreciation and Amortization
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(6.4 | ) | (8.2 | ) | (0.2 | ) | (14.8 | ) | ||||||||
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GAAP Gross Margin
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17.9 | 16.8 | (0.2 | ) | 34.5 | |||||||||||
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Depreciation and Amortization
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6.4 | 8.2 | 0.2 | 14.8 | ||||||||||||
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Adjusted Gross Margin
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$ | 24.3 | $ | 25.0 | $ | — | $ | 49.3 | ||||||||
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Six Months Ended June 30, 2022 ($ millions)
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Electric
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Regulated and Other |
Total
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Total Operating Revenue
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$ | 143.5 | $ | 148.0 | $ | — | $ | 291.5 | ||||||||
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Less: Cost of Sales
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(95.3 | ) | (67.8 | ) | — | (163.1 | ) | |||||||||
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Less: Depreciation and Amortization
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(12.4 | ) | (17.4 | ) | (0.5 | ) | (30.3 | ) | ||||||||
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GAAP Gross Margin
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35.8 | 62.8 | (0.5 | ) | 98.1 | |||||||||||
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Depreciation and Amortization
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12.4 | 17.4 | 0.5 | 30.3 | ||||||||||||
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Adjusted Gross Margin
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$ | 48.2 | $ | 80.2 | $ | — | $ | 128.4 | ||||||||
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Six Months Ended June 30, 2021 ($ millions)
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Electric
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Gas
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Non-
Regulated and Other |
Total
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Total Operating Revenue
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$ | 116.7 | $ | 118.7 | $ | — | $ | 235.4 | ||||||||
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Less: Cost of Sales
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(68.7 | ) | (45.9 | ) | — | (114.6 | ) | |||||||||
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Less: Depreciation and Amortization
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(12.9 | ) | (16.4 | ) | (0.4 | ) | (29.7 | ) | ||||||||
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GAAP Gross Margin
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35.1 | 56.4 | (0.4 | ) | 91.1 | |||||||||||
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Depreciation and Amortization
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12.9 | 16.4 | 0.4 | 29.7 | ||||||||||||
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Adjusted Gross Margin
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$ | 48.0 | $ | 72.8 | $ | — | $ | 120.8 | ||||||||
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Electric GAAP Gross Margin was $17.9 million in the three months ended June 30, 2022, essentially unchanged compared to the same period in 2021. For the six months ended June 30, 2022, Electric GAAP Gross Margin was $35.8 million, an increase of $0.7 million compared to the same period in 2021. For the three month period, lower depreciation and amortization expense of $0.7 million was offset primarily by the unfavorable effect on sales from cooler late spring weather. The increase in the six month period was driven by higher rates of $0.5 million and lower depreciation and amortization expense of $0.5 million, partially offset by the unfavorable effect on sales from cooler weather of $0.3 million.
Gas GAAP Gross Margin was $19.3 million and $62.8 million in the three and six months ended June 30, 2022, respectively, increases of $2.5 million and $6.4 million, respectively, compared to the same periods in 2021. The increase in the three month period was primarily driven by higher rates of $3.2 million, partially offset by higher depreciation and amortization expense of $0.7 million. The increase in the six month period was driven by higher rates of $5.9 million and the favorable effect on sales from customer growth and colder weather of $1.5 million, partially offset by higher depreciation and amortization expense of $1.0 million.
7
Earnings Overview
The Company’s Net Income was $4.9 million, or $0.30 in Earnings Per Share (EPS) for the second quarter of 2022, an increase of $2.2 million in Net Income, or $0.12 in EPS, compared to the second quarter of 2021. The Company’s earnings in the second quarter of 2022 reflect higher Gas Adjusted Gross Margin (a
non-GAAP
financial measure), partially offset by higher operating expenses.
For the six months ended June 30, 2022, the Company reported Net Income of $26.4 million, or $1.65 per share, an increase of $4.8 million, or $0.21 per share, compared to the same six month period in 2021. The Company’s earnings in the first six months of 2022 reflect higher Electric and Gas Adjusted Gross Margins (a
non-GAAP
financial measure), partially offset by higher operating expenses.
The Company’s three and six months results, including Electric and Gas GAAP Gross Margins, reflect the effects of recently completed base rate cases in New Hampshire (See Note 6, Regulatory Matters, to the accompanying Consolidated Financial Statements).
Electric Adjusted Gross Margin (a
non-GAAP
financial measure) was $23.6 million and $48.2 million in the three and six months ended June 30, 2022, respectively, a decrease of $0.7 million and an increase of $0.2 million, respectively, compared with the same periods in 2021. The decrease in the three month period was primarily driven by lower sales from the effect of cooler late spring weather. The increase in the six month period was driven by higher rates of $0.5 million, partially offset by the unfavorable effect on sales from cooler weather of $0.3 million.
Total electric kilowatt-hour (kWh) sales decreased 1.6% in the three month period ended June 30, 2022 compared to the same period in 2021. Sales to Residential customers decreased 3.9% and sales to C&I customers were essentially unchanged in the three month period ended June 30, 2022 compared to the same period in 2021. For the six month period ended June 30, 2022, total electric kWh sales were essentially unchanged. Sales to Residential customers decreased 1.5% while sales to C&I customers increased 1.2% in the six month period ended June 30, 2022 compared to the same period in 2021. The changes in sales to Residential and C&I customers reflect cooler late spring weather in 2022 compared to 2021, partially offset by customer growth. Based on weather data collected in the Company’s electric service areas, on average there were 61.8% fewer Cooling Degree Days (CDD) in the second quarter of 2022 compared to the same period in 2021. As of June 30, 2022, the number of electric customers increased by 490 over the previous year.
Gas Adjusted Gross Margin (a
non-GAAP
financial measure) was $28.2 million and $80.2 million in the three and six months ended June 30, 2022, respectively, increases of $3.2 million and $7.4 million, respectively, compared to the same periods in 2021. These increases reflect higher rates of $3.2 million and $5.9 million in the three and six month periods, respectively, while the remainder of the increases in these periods is attributable to the favorable effect on sales of customer growth and colder weather. Included in the higher rates for the three and six month periods in 2022 was an increase of $2.4 million resulting from the Company’s base rate case in New Hampshire.
Gas therm sales increased 2.2% and 3.3% in the three and six month periods ended June 30, 2022, respectively, compared to the same periods in 2021. The increase in gas therm sales reflects colder winter weather in the first quarter of 2022 compared to the same period in 2021, and customer growth. Based on weather data collected in the Company’s gas service areas, on average there were 3.9% more Effective Degree Days (EDD) in the first six months of 2022 compared to the same period in 2021, although 2.4% fewer EDD compared to normal. The Company estimates weather-normalized gas therm sales, excluding decoupled sales, increased 0.9% in the first six months of 2022 compared to the same period in 2021. As of June 30, 2022, the number of gas customers increased by 858 over the previous year.
Operation and Maintenance (O&M) expenses increased $0.9 million and $2.4 million in three and six months ended June 30, 2022, respectively, compared to the same periods in 2021. The increase in the three month period reflects higher professional fees of $0.6 million and higher labor costs of $0.3 million. The increase in the six month period reflects higher labor costs of $1.7 million and higher professional fees of $1.2 million partially offset by lower utility operating costs of $0.5 million.
8
Depreciation and Amortization expense was essentially unchanged in the three months ended June 30, 2022, compared to the same period in 2021, reflecting additional depreciation associated with higher levels of utility plant in service offset by lower depreciation rates resulting from the rate case order received for Unitil Energy. For the six months ended June 30, 2022, Depreciation and Amortization expense increased $0.6 million compared to the same period in 2021, reflecting additional depreciation associated with higher levels of utility plant in service, partially offset by lower depreciation rates resulting from the rate case order received for Unitil Energy.
Taxes Other Than Income Taxes increased $0.5 million and $1.1 million for the three and six months ended June 30, 2022, 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 six month period reflects higher local property taxes on higher utility plant in service and higher payroll taxes.
Interest Expense, Net was essentially unchanged in the three months ended June 30, 2022, compared to the same period in 2021, reflecting lower interest on long-term debt offset by higher interest on short-term borrowings. For the six months ended June 30, 2022, Interest Expense, Net decreased $0.5 million, compared to the same period in 2021, primarily reflecting lower interest on long-term debt, partially offset by higher interest on short-term borrowings.
Other Expense (Income), Net decreased $0.5 million and $1.1 million for the three and six months ended June 30, 2022, respectively, compared to the same periods in 2021, reflecting lower retirement benefit costs.
Federal and State Income Taxes for the three months ended June 30, 2022 decreased $0.6 million compared with the same period in 2021, primarily resulting from the flow back of excess Accumulated Deferred Income Taxes per regulatory orders received in New Hampshire. For the six months ended June 30, 2022, Federal and State Income Taxes increased $0.3 million compared to the same period in 2021, reflecting higher
pre-tax
earnings in the current period, partially offset by the flow back of excess Accumulated Deferred Income Taxes per regulatory orders received in New Hampshire.
At its January 2022, April 2022 and July 2022 meetings, the Unitil Corporation Board of Directors declared quarterly dividends on the Company’s common stock of $0.39 per share. These quarterly dividends result in a current effective annualized dividend rate of $1.56 per share, representing an unbroken record of quarterly dividend payments since trading began in Unitil’s common stock.
Electric Sales, Revenues and Adjusted Gross Margin
Kilowatt-hour Sales
9
The following table details total kWh sales for the three and six months ended June 30, 2022 and 2021 by major customer class:
|
kWh Sales (millions)
|
||||||||||||||||||||||||||||||||
| Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||||||||||||||||||||
|
2022
|
2021 | Change | % Change |
2022
|
2021 | Change | % Change | |||||||||||||||||||||||||
|
Residential
|
|
143.7
|
|
149.5 | (5.8 | ) | (3.9 | %) |
|
336.5
|
|
341.7 | (5.2 | ) | (1.5 | %) | ||||||||||||||||
|
Commercial / Industrial
|
|
224.0
|
|
224.0 | — | — |
|
461.2
|
|
455.9 | 5.3 | 1.2 | % | |||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
|
Total
|
|
367.7
|
|
373.5 | (5.8 | ) | (1.6 | %) |
|
797.7
|
|
797.6 | 0.1 | — | ||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
Electric Operating Revenues and Electric Adjusted Gross Margin
-
|
Electric Operating Revenues and Electric Adjusted Gross Margin ($ millions)
|
||||||||||||||||||||||||||||||||
| Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||||||||||||||||||||
|
2022
|
2021 | $ Change | % Change |
2022
|
2021 | $ Change | % Change | |||||||||||||||||||||||||
|
Electric Operating Revenue:
|
||||||||||||||||||||||||||||||||
|
Residential
|
$
|
30.5
|
|
$ | 31.5 | $ | (1.0 | ) | (3.2 | %) |
$
|
85.3
|
|
$ | 67.7 | $ | 17.6 | 26.0 | % | |||||||||||||
|
Commercial / Industrial
|
|
23.8
|
|
25.1 | (1.3 | ) | (5.2 | %) |
|
58.2
|
|
49.0 | 9.2 | 18.8 | % | |||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
|
Total Electric Operating Revenue
|
$
|
54.3
|
|
$ | 56.6 | $ | (2.3 | ) | (4.1 | %) |
$
|
143.5
|
|
$ | 116.7 | $ | 26.8 | 23.0 | % | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
|
Cost of Electric Sales
|
$
|
30.7
|
|
$ | 32.3 | $ | (1.6 | ) | (5.0 | %) |
$
|
95.3
|
|
$ | 68.7 | $ | 26.6 | 38.7 | % | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
|
Electric Adjusted Gross Margin
|
$
|
23.6
|
|
$ | 24.3 | $ | (0.7 | ) | (2.9 | )% |
$
|
48.2
|
|
$ | 48.0 | $ | 0.2 | 0.4 | % | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
Electric Adjusted Gross Margin (a
non-GAAP
financial measure) was $23.6 million and $48.2 million in the three and six months ended June 30, 2022, respectively, a decrease of $0.7 million and an increase of $0.2 million, respectively, compared with the same periods in 2021. The decrease in the three month period was primarily driven by lower sales from the effect of cooler late spring weather. The increase in the six month period was driven by higher rates of $0.5 million, partially offset by the unfavorable effect on sales from cooler weather of $0.3 million.
Total Electric Operating Revenue decreased $2.3 million in the three months ended June 30, 2022, compared to the same period in 2021 reflecting lower costs of electric sales, which are tracked and reconciled to costs that are passed through directly to customers, and lower sales of electricity. Total Electric Operating Revenue increased $26.8 million in the six months ended June 30, 2022, compared to the same period in 2021 reflecting higher costs of electric sales, which are tracked and reconciled to costs that are passed through directly to customers.
Gas Sales, Revenues and Adjusted Gross Margin
Therm Sales
-
10
fewer EDD compared to normal. The Company estimates weather-normalized gas therm sales, excluding decoupled sales, increased 0.9% in the first six months of 2022 compared to the same period in 2021. As of June 30, 2022, the number of gas customers increased by 858 over the previous year. Sales margins derived from decoupled unit sales (currently representing approximately 11% of total annual therm sales volume) are not sensitive to changes in gas therm sales.
The following table details total firm therm sales for the three and six months ended June 30, 2022 and 2021, by major customer class:
|
Therm Sales (millions)
|
||||||||||||||||||||||||||||||||
| Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||||||||||||||||||||
|
2022
|
2021 | Change | % Change |
2022
|
2021 | Change | % Change | |||||||||||||||||||||||||
|
Residential
|
|
8.3
|
|
8.1 | 0.2 | 2.5 | % |
|
32.6
|
|
31.7 | 0.9 | 2.8 | % | ||||||||||||||||||
|
Commercial / Industrial
|
|
37.2
|
|
36.4 | 0.8 | 2.2 | % |
|
111.7
|
|
108.0 | 3.7 | 3.4 | % | ||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
|
Total
|
|
45.5
|
|
44.5 | 1.0 | 2.2 | % |
|
144.3
|
|
139.7 | 4.6 | 3.3 | % | ||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
Gas Operating Revenues and Adjusted Gross Margin -
|
Gas Operating Revenues and Gas Adjusted Gross Margin ($ millions)
|
||||||||||||||||||||||||||||||||
| Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||||||||||||||||||||
|
2022
|
2021 | $ Change | % Change |
2022
|
2021 | $ Change | % Change | |||||||||||||||||||||||||
|
Gas Operating Revenue:
|
||||||||||||||||||||||||||||||||
|
Residential
|
$
|
17.4
|
|
$ | 16.0 | $ | 1.4 | 8.8 | % |
$
|
60.2
|
|
$ | 49.4 | $ | 10.8 | 21.9 | % | ||||||||||||||
|
Commercial / Industrial
|
|
27.2
|
|
24.0 | 3.2 | 13.3 | % |
|
87.8
|
|
69.3 | 18.5 | 26.7 | % | ||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
|
Total Gas Operating Revenue
|
$
|
44.6
|
|
$ | 40.0 | $ | 4.6 | 11.5 | % |
$
|
148.0
|
|
$ | 118.7 | $ | 29.3 | 24.7 | % | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
|
Cost of Gas Sales
|
$
|
16.4
|
|
$ | 15.0 | $ | 1.4 | 9.3 | % |
$
|
67.8
|
|
$ | 45.9 | $ | 21.9 | 47.7 | % | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
|
Gas Adjusted Gross Margin
|
$
|
28.2
|
|
$ | 25.0 | $ | 3.2 | 12.8 | % |
$
|
80.2
|
|
$ | 72.8 | $ | 7.4 | 10.2 | % | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||
Gas Adjusted Gross Margin (a
non-GAAP
financial measure) was $28.2 million and $80.2 million in the three and six months ended June 30, 2022, respectively, increases of $3.2 million and $7.4 million, respectively, compared to the same periods in 2021. These increases reflect higher rates of $3.2 million and $5.9 million in the three and six month periods, respectively, while the remainder of the increases in these periods is attributable to the favorable effect on sales of customer growth and colder weather. Included in the higher rates for the three and six month periods in 2022 was an increase of $2.4 million resulting from the Company’s base rate case in New Hampshire.
The increases in Total Gas Operating Revenue of $4.6 million and $29.3 million in the three and six months ended June 30, 2022, respectively, compared to the same periods in 2021, reflect higher costs of gas sales, which are tracked and reconciled costs that are passed through directly to customers, and higher gas sales volumes.
11
Operating Expenses
Cost of Electric Sales
-
Cost of Gas Sales
-
Operation and Maintenance (O&M) -
Depreciation and Amortization -
Taxes Other Than Income Taxes
-
Other Expense (Income), Net -
Provision for Income Taxes
-
pre-tax
earnings in the current period, partially offset by the flow back of excess Accumulated Deferred Income Taxes per regulatory orders received in New Hampshire.
Interest Expense, Net -
12
Unitil’s utility subsidiaries operate a number of reconciling rate mechanisms to recover specifically identified costs on a pass-through basis. These reconciling rate mechanisms track costs and revenue on a monthly basis. In any given month, this tracking and reconciling process will produce either an under-collected or an over-collected position. In accordance with the distribution utilities’ rate tariffs, interest is accrued on these balances and will produce either interest income or interest expense. Consistent with regulatory precedent, interest income is recorded on an under-collection of costs which creates a regulatory asset to be recovered in future periods when rates are reset. Interest expense is recorded on an over-collection of costs, which creates a regulatory liability to be refunded in future periods when rates are reset.
|
Interest Expense, Net
($ millions)
|
Three Months Ended
June 30, |
Six Months Ended
June 30, |
||||||||||||||||||||||
|
2022
|
2021 | Change |
2022
|
2021 | Change | |||||||||||||||||||
|
Interest Expense
|
||||||||||||||||||||||||
|
Long-term Debt
|
$
|
6.2
|
|
$ | 6.5 | $ | (0.3 | ) |
$
|
12.4
|
|
$ | 13.2 | $ | (0.8 | ) | ||||||||
|
Short-term Debt
|
|
0.4
|
|
0.1 | 0.3 |
|
0.7
|
|
0.3 | 0.4 | ||||||||||||||
|
Regulatory Liabilities
|
|
0.1
|
|
0.1 | — |
|
0.2
|
|
0.2 | — | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
|
Subtotal Interest Expense
|
|
6.7
|
|
6.7 | — |
|
13.3
|
|
13.7 | (0.4 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
|
Interest (Income)
|
||||||||||||||||||||||||
|
Regulatory Assets
|
|
(0.2
|
)
|
(0.1 | ) | (0.1 | ) |
|
(0.4
|
)
|
(0.4 | ) | — | |||||||||||
|
AFUDC
(1)
and Other
|
|
(0.2
|
)
|
(0.3 | ) | 0.1 |
|
(0.4
|
)
|
(0.3 | ) | (0.1 | ) | |||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
|
Subtotal Interest (Income)
|
|
(0.4
|
)
|
(0.4 | ) | — |
|
(0.8
|
)
|
(0.7 | ) | (0.1 | ) | |||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
|
Total Interest Expense, Net
|
$
|
6.3
|
|
$ | 6.3 | $ | — |
$
|
12.5
|
|
$ | 13.0 | $ | (0.5 | ) | |||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
|
(1)
|
AFUDC – Allowance for Funds Used During Construction.
|
Interest Expense, Net was essentially unchanged in the three months ended June 30, 2022, compared to the same period in 2021, reflecting lower interest on long-term debt offset by higher interest on short-term borrowings. For the six months ended June 30, 2022, Interest Expense, Net decreased $0.5 million, or 3.8%, compared to the same period in 2021, primarily reflecting lower interest on long-term debt, partially offset by higher interest on short-term borrowings.
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 are seasonal in nature 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.
13
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 equity 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
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). At June 30, 2022, June 30, 2021 and December 31, 2021, the Company and all of its subsidiaries were in compliance with the regulatory requirements to participate in the Cash Pool.
day-to-day
On July 25, 2018, the Company entered into a Second Amended and Restated Credit Agreement and related documents (collectively, the Credit Facility) with a syndicate of lenders, which amended and restated in its entirety the Company’s prior credit facility. The Credit Facility has a borrowing limit of $120 million, which includes a $25 million sublimit for the issuance of standby letters of credit, extends to July 25, 2023, and, under certain conditions, allows for an increase in the borrowing limit by up to $50 million, and two
one-year
extensions. The Credit Facility provides the Company with the ability to elect that borrowings under the Credit Facility bear-interest under several options, including at a daily fluctuating rate of interest per annum equal to
one-month
London Interbank Offered Rate plus 1.125%. The terms of the current credit facility allow for a comparable successor rate to be used if the
one-month
LIBOR rate becomes unavailable. The Company believes that a change to a new rate will not have a material effect on its financial position, operating results, or cash flows.
The Company uses the Credit Facility for cash management purposes related to its short-term operating activities. Total gross borrowings were $151.9 million for the six months ended June 30, 2022. Total gross repayments were $169.8 million for the six months ended June 30, 2022. The following table details the borrowing limits, amounts outstanding and amounts available under the Credit Facility as of June 30, 2022, June 31, 2021 and December 31, 2021:
|
Revolving Credit Facility ($ millions)
|
||||||||||||
|
June 30,
|
December 31, | |||||||||||
|
2022
|
2021 | 2021 | ||||||||||
|
Limit
|
$
|
120.0
|
|
$ | 120.0 | $ | 120.0 | |||||
|
Short-Term Borrowings Outstanding
|
|
46.2
|
|
29.7 | 64.1 | |||||||
|
|
|
|
|
|
|
|||||||
|
Available
|
$
|
73.8
|
|
$ | 90.3 | $ | 55.9 | |||||
|
|
|
|
|
|
|
|||||||
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, the Company’s and its subsidiaries’ ability to permit liens or incur indebtedness, and restrictions on the Company’s ability to merge or consolidate with another entity or change its line of business. The affirmative and negative covenants under the Credit Facility apply until the Credit Facility terminates and all amounts borrowed under the Credit Facility are paid in full (or with respect to letters of credit, they are cash collateralized).
14
The only financial covenant in the Credit Facility provides that Funded Debt to Capitalization (as each term is defined in the Credit Facility) cannot exceed 65%, tested on a quarterly basis. At June 30, 2022, June 30, 2021 and December 31, 2021, the Company was in compliance with the covenants contained in the Credit Facility in effect on those dates.
The Company is monitoring the coronavirus pandemic, including any effect on planned capital expenditures. The Company does not believe the pandemic will adversely affect its access 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 debt and equity securities will be sufficient to meet its working capital and capital investment needs.
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 June 30, 2022, there were approximately $0.7 million of guarantees outstanding with a duration less than one year.
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 $12.6 million, $4.9 million and $8.3 million of gas obligations at June 30, 2022, June 30, 2021 and December 31, 2021, respectively, related to these asset management agreements. The amount of gas released in June 2022 and payable in July 2022 is $0.2 million and is recorded in Accounts Payable at June 30, 2022. The amount of gas released in June 2021 and payable in July 2021 was $0.1 million and was recorded in Accounts Payable at 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.
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 June 30, 2022, there were approximately $0.7 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
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
15
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 March 31, 2022, the Company’s critical accounting policies and estimates had not changed significantly from December 31, 2021. See Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Policies” in the Company’s 2021 Annual Report on Form
10-K
for additional information.
EMPLOYEES
Unitil’s commitment to excellence begins with its employees. As of June 30, 2022, the Company and its subsidiaries had 513 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 – 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.
Employees at Unitil have the opportunity to be heard. 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 June 30, 2022, a total of 170 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 June 30, 2022:
|
Employees Covered
|
CBA Expiration
|
|||||||
|
Fitchburg
|
43 | 05/31/2027 | ||||||
|
Northern Utilities NH Division
|
36 | 06/07/2025 | ||||||
|
Northern Utilities ME Division
|
37 | 03/31/2026 | ||||||
|
Granite State
|
4 | 03/31/2026 | ||||||
|
Unitil Energy
|
40 | 05/31/2023 | ||||||
|
Unitil Service – Gas Control
|
5 | 03/31/2024 | ||||||
|
Unitil Service
|
5 | 05/31/2023 | ||||||
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
16
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 June 30, 2022 and June 30, 2021 were 2.1% and 1.2%, respectively. The average interest rates on the Company’s short-term borrowings for the six months ended June 30, 2022 and June 30, 2021 were 1.7% and 1.3%, respectively. The average interest rate on the Company’s short-term borrowings for the twelve months ended December 31, 2021 was 1.2%.
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
Please 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 to Note 7 to the Consolidated Financial Statements in Part I, Item 1 of this report for a discussion of Environmental Matters.
17
UNITIL CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF EARNINGS
(Millions except per share data)
(UNAUDITED)
|
Three Months Ended
June 30,
|
Six Months Ended
June 30,
|
|||||||||||||||
|
2022
|
2021 |
2022
|
2021 | |||||||||||||
|
Operating Revenues
|
||||||||||||||||
|
Electric
|
$
|
|
|
$ |
|
$
|
|
|
$ |
|
||||||
|
Gas
|
|
|
|
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|
|
|||||||||
|
Total Operating Revenues
|
|
|
|
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|
|
|||||||||
|
Operating Expenses
|
||||||||||||||||
|
Cost of Electric Sales
|
|
|
|
|
|
|
|
|
||||||||
|
Cost of Gas Sales
|
|
|
|
|
|
|
|
|
||||||||
|
Operation and Maintenance
|
|
|
|
|
|
|
|
|
||||||||
|
Depreciation and Amortization
|
|
|
|
|
|
|
|
|
||||||||
|
Taxes Other Than Income Taxes
|
|
|
|
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|
|
|||||||||
|
Total Operating Expenses
|
|
|
|
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|
|
|||||||||
|
Operating Income
|
|
|
|
|
|
|
|
|
||||||||
|
Interest Expense, Net
|
|
|
|
|
|
|
|
|
||||||||
|
Other Expense (Income), Net
|
|
|
|
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|
|
|||||||||
|
Income Before Income Taxes
|
|
|
|
|
|
|
|
|
||||||||
|
Provision for Income Taxes
|
|
|
|
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|
|
|||||||||
|
Net Income
|
$
|
|
|
$ |
|
$
|
|
|
$ |
|
||||||
|
|
|
|
|
|
|
|
|
|||||||||
|
Net Income Per Common Share (Basic and Diluted)
|
$
|
|
|
$ |
|
$
|
|
|
$ |
|
||||||
|
Weighted Average Common Shares Outstanding – (Basic and Diluted)
|
|
|
|
|
|
|
|
|
||||||||
(The accompanying notes are an integral part of these consolidated unaudited financial statements.)
18
UNITIL CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Millions)
(UNAUDITED)
|
June 30,
|
December 31, | |||||||||||
|
2022
|
2021 | 2021 | ||||||||||
|
ASSETS:
|
||||||||||||
|
Current Assets
|
||||||||||||
|
Cash and Cash Equivalents
|
$
|
|
|
$ |
|
$ |
|
|||||
|
Accounts Receivable, Net
|
|
|
|
|
|
|||||||
|
Accrued Revenue
|
|
|
|
|
|
|||||||
|
Exchange Gas Receivable
|
|
|
|
|
|
|||||||
|
Gas Inventory
|
|
|
|
|
|
|||||||
|
Materials and Supplies
|
|
|
|
|
|
|||||||
|
Prepayments and Other
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Current Assets
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Utility Plant:
|
||||||||||||
|
Electric
|
|
|
|
|
|
|||||||
|
Gas
|
|
|
|
|
|
|||||||
|
Common
|
|
|
|
|
|
|||||||
|
Construction Work in Progress
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Utility Plant
|
|
|
|
|
|
|||||||
|
Less: Accumulated Depreciation
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Net Utility Plant
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Other Noncurrent Assets:
|
||||||||||||
|
Regulatory Assets
|
|
|
|
|
|
|||||||
|
Operating Lease Right of Use Assets
|
|
|
|
|
|
|||||||
|
Other Assets
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Other Noncurrent Assets
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
TOTAL ASSETS
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
(The accompanying notes are an integral part of these consolidated unaudited financial statements.)
19
UNITIL CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS (Cont.)
(Millions, except number of shares)
(UNAUDITED)
|
|
June 30,
|
December 31, | ||||||||||
|
2022
|
2021 | 2021 | ||||||||||
|
LIABILITIES AND CAPITALIZATION:
|
||||||||||||
|
Current Liabilities:
|
||||||||||||
|
Accounts Payable
|
$
|
|
|
$ |
|
$ |
|
|||||
|
Short-Term Debt
|
|
|
|
|
|
|||||||
|
Long-Term Debt, Current Portion
|
|
|
|
|
|
|||||||
|
Regulatory Liabilities
|
|
|
|
|
|
|||||||
|
Energy Supply Obligations
|
|
|
|
|
|
|||||||
|
Interest Payable
|
|
|
|
|
|
|||||||
|
Environmental Obligations
|
|
|
|
|
|
|||||||
|
Other Current Liabilities
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Current Liabilities
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Noncurrent Liabilities:
|
||||||||||||
|
Retirement Benefit Obligations
|
|
|
|
|
|
|||||||
|
Deferred Income Taxes, net
|
|
|
|
|
|
|||||||
|
Cost of Removal Obligations
|
|
|
|
|
|
|||||||
|
Regulatory Liabilities
|
|
|
|
|
|
|||||||
|
Environmental Obligations
|
|
|
|
|
|
|||||||
|
Other Noncurrent Liabilities
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Noncurrent Liabilities
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Capitalization:
|
||||||||||||
|
Long-Term Debt, Less Current Portion
|
|
|
|
|
|
|||||||
|
Stockholders’ Equity:
|
||||||||||||
|
Common Equity (Authorized:
|
|
|
|
|
|
|||||||
|
Retained Earnings
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Common Stock Equity
|
|
|
|
|
|
|||||||
|
Preferred Stock
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Stockholders’ Equity
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Capitalization
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Commitments and Contingencies (Notes 6 & 7)
|
|
|||||||||||
|
TOTAL LIABILITIES AND CAPITALIZATION
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
(The accompanying notes are an integral part of these consolidated unaudited financial statements.)
20
UNITIL CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Millions) (UNAUDITED)
|
Six Months Ended
June 30,
|
||||||||
|
2022
|
2021
|
|||||||
|
Operating Activities:
|
||||||||
|
Net Income
|
$
|
|
|
$ |
|
|||
|
Adjustments to Reconcile Net Income to Cash Provided by Operating Activities:
|
||||||||
|
Depreciation and Amortization
|
|
|
|
|
||||
|
Deferred Tax Provision
|
|
|
|
|
||||
|
Changes in Working Capital Items:
|
||||||||
|
Accounts Receivable
|
|
|
|
|
||||
|
Accrued Revenue
|
|
|
|
|
||||
|
Exchange Gas Receivable
|
|
(
|
)
|
(
|
) | |||
|
Regulatory Liabilities
|
|
|
|
|
||||
|
Accounts Payable
|
|
(
|
)
|
(
|
) | |||
|
Other Changes in Working Capital Items
|
|
(
|
)
|
(
|
) | |||
|
Deferred Regulatory and Other Charges
|
|
(
|
)
|
(
|
) | |||
|
Other, net
|
|
|
|
|
||||
|
|
|
|
|
|||||
|
Cash Provided by Operating Activities
|
|
|
|
|
||||
|
|
|
|
|
|||||
|
Investing Activities:
|
||||||||
|
Property, Plant and Equipment Additions
|
|
(
|
)
|
(
|
) | |||
|
|
|
|
|
|||||
|
Cash (Used in) Investing Activities
|
|
(
|
)
|
(
|
) | |||
|
|
|
|
|
|||||
|
Financing Activities:
|
||||||||
|
Repayment of Short-Term Debt, net
|
|
(
|
)
|
(
|
) | |||
|
Repayment of Long-Term Debt
|
|
(
|
)
|
(
|
) | |||
|
Net Increase in Exchange Gas Financing
|
|
|
|
|
||||
|
Decrease in Capital Lease Obligations
|
|
(
|
)
|
|
||||
|
Dividends Paid
|
|
(
|
)
|
(
|
) | |||
|
Proceeds from Issuance of Common Stock
|
|
|
|
|
||||
|
|
|
|
|
|||||
|
Cash Used in Financing Activities
|
|
(
|
)
|
(
|
) | |||
|
|
|
|
|
|||||
|
Net Decrease in Cash and Cash Equivalents
|
|
(
|
)
|
(
|
) | |||
|
Cash and Cash Equivalents at Beginning of Period
|
|
|
|
|
||||
|
|
|
|
|
|||||
|
Cash and Cash Equivalents at End of Period
|
$
|
|
|
$ |
|
|||
|
|
|
|
|
|||||
|
Supplemental Cash Flow Information:
|
||||||||
|
Interest Paid
|
$
|
|
|
$ |
|
|||
|
Income Taxes Paid
|
$
|
|
|
$ |
|
|||
|
Payments on Capital Leases
|
$
|
|
|
$ |
|
|||
|
Non-cash Investing Activity:
|
||||||||
|
Capital Expenditures Included in Accounts Payable
|
$
|
|
|
$ |
|
|||
|
Right-of-Use Assets Obtained in Exchange for Lease Obligations
|
$
|
|
|
$ |
|
|||
(The accompanying notes are an integral part of these consolidated unaudited financial statements.)
21
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 June 30, 2022
|
||||||||||||
|
Balance at April 1, 2022
|
$ |
|
$ |
|
$
|
|
|
|||||
|
Net Income
|
|
|
|
|
||||||||
|
Dividends on Common Shares ($
|
(
|
) |
|
(
|
)
|
|||||||
|
Stock Compensation Plans
|
|
|
|
|
||||||||
|
Issuance of
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|||||||
|
Balance at June 30, 2022
|
$
|
|
|
$
|
|
|
$
|
|
|
|||
|
|
|
|
|
|
|
|||||||
|
Three Months Ended June 30, 2021
|
||||||||||||
|
Balance at April 1, 2021
|
$ |
|
$ |
|
$
|
|
|
|||||
|
Net Income
|
|
|
|
|
||||||||
|
Dividends on Common Shares ($
|
(
|
) |
|
(
|
)
|
|||||||
|
Stock Compensation Plans
|
|
|
|
|
||||||||
|
Issuance of
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|||||||
|
Balance at June 30, 2021
|
$
|
|
|
$
|
|
|
$
|
|
|
|||
|
|
|
|
|
|
|
|||||||
(The accompanying notes are an integral part of these consolidated unaudited financial statements.)
22
UNITIL CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCK EQUITY
(Millions, except number of shares)
(UNAUDITED)
|
|
Common
Equity |
Retained
Earnings |
Total | |||||||||
|
Six Months Ended June 30, 2022
|
||||||||||||
|
Balance at January 1, 2022
|
$ |
|
$ |
|
$
|
|
|
|||||
|
Net Income
|
|
|
|
|
||||||||
|
Dividends on Common Shares ($
|
(
|
) |
|
(
|
)
|
|||||||
|
Stock Compensation Plans
|
|
|
|
|
||||||||
|
Issuance of
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|||||||
|
Balance at June 30, 2022
|
$
|
|
|
$
|
|
|
$
|
|
|
|||
|
|
|
|
|
|
|
|||||||
|
Six Months Ended June 30, 2021
|
||||||||||||
|
Balance at January 1, 2021
|
$ |
|
$ |
|
$
|
|
|
|||||
|
Net Income
|
|
|
|
|
||||||||
|
Dividends on Common Shares ($
|
(
|
) |
|
(
|
)
|
|||||||
|
Stock Compensation Plans
|
|
|
|
|
||||||||
|
Issuance of
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|||||||
|
Balance at June 30, 2021
|
$
|
|
|
$
|
|
|
$
|
|
|
|||
|
|
|
|
|
|
|
|||||||
(The accompanying notes are an integral part of these consolidated unaudited financial statements.)
23
UNITIL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Nature of Operations -
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
.
Basis of Presentation -
24
Utility Revenue Recognition -
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, 2022
|
|
|||||||||
|
Electric and Gas Operating Revenues ($ millions):
|
|
Electric
|
|
|
Gas
|
|
|
Total
|
|
|||
|
Billed and Unbilled Revenue:
|
||||||||||||
|
Residential
|
$ |
|
$ |
|
$ |
|
||||||
|
Commercial and Industrial
|
|
|
|
|||||||||
|
Other
|
|
|
|
|||||||||
|
|
|
|
|
|
|
|||||||
|
Total Billed and Unbilled Revenue
|
|
|
|
|||||||||
|
Rate Adjustment Mechanism Revenue
|
(
|
) |
(
|
) |
(
|
) | ||||||
|
|
|
|
|
|
|
|||||||
|
Total Electric and Gas Operating Revenues
|
$
|
|
|
$
|
|
|
$
|
|
|
|||
|
|
|
|
|
|
|
|||||||
25
|
|
|
Three Months Ended June 30, 2021
|
|
|||||||||
|
Electric and Gas Operating Revenues ($ millions):
|
|
Electric
|
|
|
Gas
|
|
|
Total
|
|
|||
|
Billed and Unbilled Revenue:
|
|
|
|
|||||||||
|
Residential
|
$ |
|
$ |
|
$ |
|
||||||
|
Commercial and Industrial
|
|
|
|
|||||||||
|
Other
|
|
|
|
|||||||||
|
|
|
|
|
|
|
|||||||
|
Total Billed and Unbilled Revenue
|
|
|
|
|||||||||
|
Rate Adjustment Mechanism Revenue
|
(
|
) |
|
|
||||||||
|
|
|
|
|
|
|
|||||||
|
Total Electric and Gas Operating Revenues
|
$
|
|
|
$
|
|
|
$
|
|
|
|||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|||||||||
|
|
|
Six Months Ended June 30, 2022
|
|
|||||||||
|
Electric and Gas Operating Revenues ($ millions):
|
|
Electric
|
|
|
Gas
|
|
|
Total
|
|
|||
|
Billed and Unbilled Revenue:
|
|
|
|
|||||||||
|
Residential
|
$ |
|
$ |
|
$ |
|
||||||
|
Commercial and Industrial
|
|
|
|
|||||||||
|
Other
|
|
|
|
|||||||||
|
|
|
|
|
|
|
|||||||
|
Total Billed and Unbilled Revenue
|
|
|
|
|||||||||
|
Rate Adjustment Mechanism Revenue
|
(
|
) |
(
|
) |
(
|
) | ||||||
|
|
|
|
|
|
|
|||||||
|
Total Electric and Gas Operating Revenues
|
$
|
|
|
$
|
|
|
$
|
|
|
|||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|||||||||
|
|
|
Six Months Ended June 30, 2021
|
|
|||||||||
|
Electric and Gas Operating Revenues ($ millions):
|
|
Electric
|
|
|
Gas
|
|
|
Total
|
|
|||
|
Billed and Unbilled Revenue:
|
||||||||||||
|
Residential
|
$ |
|
$ |
|
$ |
|
||||||
|
Commercial and Industrial
|
|
|
|
|||||||||
|
Other
|
|
|
|
|||||||||
|
|
|
|
|
|
|
|||||||
|
Total Billed and Unbilled Revenue
|
|
|
|
|||||||||
|
Rate Adjustment Mechanism Revenue
|
(
|
) |
(
|
) |
(
|
) | ||||||
|
|
|
|
|
|
|
|||||||
|
Total Electric
and
Gas Operating Revenues
|
$
|
|
|
$
|
|
|
$
|
|
|
|||
|
|
|
|
|
|
|
|||||||
Fitchburg and Unitil Energy are subject to revenue decoupling. As of August 1, 2022, the New Hampshire division of Northern Utilities also is subject to 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 Massachusetts Department of Public Utilities (MDPU) and the New Hampshire Public Utilities Commission (NHPUC).
26
Income Taxes -
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 -
obligations
, less credit amounts that are based on the Company’s credit rating. As of June 30, 2022, June 30, 2021 and December 31, 2021, the Unitil subsidiaries had deposited $
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. 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 June 30, 2022, June 30, 2021 and December 31, 2021, was as follows:
|
($ millions)
|
||||||||||||
|
June 30,
|
December 31, | |||||||||||
|
2022
|
2021 | 2021 | ||||||||||
|
Allowance for Doubtful Accounts
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
Accounts Receivable, Net includes $
2.6
million, $
4.5
million, and $
3.1
million of the Allowance for Doubtful Accounts at June 30, 2022, June 30, 2021 and December 31, 2021, respectively. Unbilled
27
Revenues
, net (a component of Accrued Revenue) includes $
million, $
million and $
million of the Allowance for Doubtful Accounts at June 30, 2022, June 30, 2021 and December 31, 2021, respectively.
Accrued Revenue -
|
June 30,
|
December 31, | |||||||||||
|
Accrued Revenue ($ millions)
|
2022
|
2021 | 2021 | |||||||||
|
Regulatory Assets – Current
|
$
|
|
|
$ |
|
$ |
|
|||||
|
Unbilled Revenues, net
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Accrued Revenue
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
Exchange Gas Receivable -
|
June 30,
|
December 31, | |||||||||||
|
Exchange Gas Receivable ($ millions)
|
2022
|
2021 | 2021 | |||||||||
|
Northern Utilities
|
$
|
|
|
$ |
|
$ |
|
|||||
|
Fitchburg
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Exchange Gas Receivable
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
Gas Inventory
|
June 30,
|
December 31, | |||||||||||
|
Gas Inventory ($ millions)
|
2022
|
2021 | 2021 | |||||||||
|
Natural Gas
|
$
|
0.5
|
|
$ | 0.2 | $ |
|
|||||
|
Propane
|
|
|
|
|
|
|||||||
|
Liquefied Natural Gas & Other
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Gas Inventory
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
Utility Plant -
$
112.4
million, $
105.1
million, and $
107.5
million,
respectively
.
28
Leases -
terms
longer than
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 -
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 June 30,
2022,
June 30, 2021 and December 31, 2021, the Company has recorded $
million, $
million and $
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)
|
2022
|
2021 | 2021 | |||||||||
|
Retirement Benefits
|
$
|
|
|
$ |
|
$ |
|
|||||
|
Energy Supply and Other Rate Adjustment Mechanisms
|
|
|
|
|
|
|||||||
|
Deferred Storm Charges
|
|
|
|
|
|
|||||||
|
Environmental
|
|
|
|
|
|
|||||||
|
Income Taxes
|
|
|
|
|
|
|||||||
|
Other Deferred Charges
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Regulatory Assets
|
|
|
|
|
|
|||||||
|
Less: Current Portion of Regulatory Assets
(1)
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Regulatory Assets – noncurrent
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
|
(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)
|
2022
|
2021 | 2021 | |||||||||
|
Income Taxes (Note 8)
|
$
|
|
|
$ |
|
$ |
|
|||||
|
Rate Adjustment Mechanisms
|
|
|
|
|
|
|||||||
|
Other
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Regulatory Liabilities
|
|
|
|
|
|
|||||||
|
Less: Current Portion of Regulatory Liabilities
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Regulatory Liabilities – noncurrent
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
29
Generally, the Company receives a return on investment on its regulatory assets for which a cash
6.6
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
outflow
has been made. Included in Regulatory Assets as of June 30, 2022 are $
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 Company’s opinion, its regulated operations will be subject to the FASB Codification provisions for Regulated Operations for the foreseeable future.
Derivatives -
Fitchburg has entered into power purchase agreements for which contingencies exist (see Note 6, Regulatory Matters - Fitchburg - Massachusetts Request for Proposals (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.
Investments in Marketable Securities -
At June 30, 2022, June 30, 2021 and December 31, 2021, the fair value of the Company’s investments in these trading securities, which are recorded on the Consolidated Balance Sheets in Other Assets, was $
5.4
million, $
5.5
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)
|
2022
|
2021 | 2021 | |||||||||
|
Money Market Funds
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
|
Total Marketable Securities
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
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,
30
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, 2022, June 30, 2021 and December 31, 2021, 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 $
0.8
million, $
0.7
million and $
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.
|
June 30,
|
December 31, | |||||||||||
|
Fair Value of Marketable Securities ($ millions)
|
2022
|
2021 | 2021 | |||||||||
|
Equity Funds
|
$
|
|
|
$ |
|
$ |
|
|||||
|
Money Market Funds
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Marketable Securities
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
Energy Supply Obligations -
|
June 30,
|
December 31, | |||||||||||
|
Energy Supply Obligations ($ millions)
|
2022
|
2021 | 2021 | |||||||||
|
Current:
|
||||||||||||
|
Exchange Gas Obligation
|
$
|
|
|
$ |
|
$ |
|
|||||
|
Renewable Energy Portfolio Standards
|
|
|
|
|
|
|||||||
|
Power Supply Contract Divestitures
|
|
|
|
|
— | |||||||
|
|
|
|
|
|
|
|||||||
|
Total Energy Supply Obligations
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
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
31
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.
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, 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 the MDPU on May 25, 2022, and remain pending. 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 -
Obligations
on the Company’s Consolidated Balance Sheets with a corresponding regulatory asset recorded in Accrued Revenue.
Subsequent Events -
NOTE 2 - DIVIDENDS DECLARED PER SHARE
|
Declaration
Date |
Date
Paid (Payable) |
Shareholder of
Record Date |
Dividend
Amount |
|||
|
|
|
|
$
|
|||
|
|
|
|
$
|
|||
|
|
|
|
$
|
|||
|
|
|
|
$
|
|||
|
|
|
|
$
|
|||
|
|
|
|
$
|
|||
|
|
|
|
$
|
32
NOTE 3 - SEGMENT INFORMATION
The following table provides significant segment financial data for the three and six months ended June 30, 2022 and June 30, 2021:
|
Electric
|
Gas
|
Non-
Regulated
|
Other
|
Total
|
||||||||||||||||
|
Three Months Ended June 30, 2022 ($ millions)
|
||||||||||||||||||||
|
Revenues:
|
||||||||||||||||||||
|
Billed and Unbilled Revenue
|
$
|
|
|
$
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
|
|
|||||
|
Rate Adjustment Mechanism Revenue
|
|
(
|
)
|
|
(
|
) |
|
—
|
|
|
—
|
|
|
(
|
) | |||||
|
Other Operating Revenue – Non-Regulated
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
|
Total Operating Revenues
|
$
|
|
|
$
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
|
Segment Profit (Loss)
|
|
|
|
|
|
|
|
|
|
|
(
|
)
|
|
|
|
|||||
|
Capital Expenditures
|
|
|
|
|
|
|
|
— |
|
|
|
|
|
|
||||||
|
Three Months Ended June 30, 2021 ($ millions)
|
||||||||||||||||||||
|
Revenues:
|
||||||||||||||||||||
|
Billed and Unbilled Revenue
|
$ |
|
$ |
|
$ | — | $ | — | $ |
|
||||||||||
|
Rate Adjustment Mechanism Revenue
|
(
|
) |
|
— | — |
|
||||||||||||||
|
Other Operating Revenue – Non-Regulated
|
— | — | — | — | — | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
|
Total Operating Revenues
|
$ |
|
$ |
|
$ | — | $ | — | $ |
|
||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
|
Segment Profit (Loss)
|
|
(
|
) |
|
(
|
) |
|
|||||||||||||
|
Capital Expenditures
|
|
|
— |
|
|
|||||||||||||||
|
Six Months Ended June 30, 2022 ($ millions)
|
||||||||||||||||||||
|
Revenues:
|
||||||||||||||||||||
|
Billed and Unbilled Revenue
|
$
|
|
|
$
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
|
|
|||||
|
Rate Adjustment Mechanism Revenue
|
|
(
|
)
|
|
(
|
)
|
|
—
|
|
|
—
|
|
|
(
|
)
|
|||||
|
Other Operating Revenue – Non-Regulated
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
|
Total Operating Revenues
|
$
|
|
|
$
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
|
Segment Profit (Loss)
|
|
|
|
|
|
|
|
—
|
|
|
(
|
)
|
|
|
|
|||||
|
Capital Expenditures
|
|
|
|
|
|
|
|
—
|
|
|
|
|
|
|
|
|||||
|
Segment Assets
|
|
|
|
|
|
|
|
—
|
|
|
|
|
|
|
||||||
|
Six Months Ended June 30, 2021 ($ millions)
|
||||||||||||||||||||
|
Revenues:
|
||||||||||||||||||||
|
Billed and Unbilled Revenue
|
$ |
|
$ |
|
$ | — | $ | — | $ |
|
||||||||||
|
Rate Adjustment Mechanism Revenue
|
(
|
) |
(
|
) | — | — |
(
|
) | ||||||||||||
|
Other Operating Revenue – Non-Regulated
|
— | — | — | — | — | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
|
Total Operating Revenues
|
$ |
|
$ |
|
$ | — | $ | — | $ |
|
||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
|
Segment Profit
|
|
|
|
(
|
) |
|
||||||||||||||
|
Capital Expenditures
|
|
|
— |
|
|
|||||||||||||||
|
Segment Assets
|
|
|
— |
|
|
|||||||||||||||
33
NOTE 4 - DEBT AND FINANCING ARRANGEMENTS
Details on long-term debt at June 30, 2022, June 30, 2021 and December 31, 2021 are shown below:
|
($ millions)
|
June 30,
|
December 31, | ||||||||||
|
2022
|
2021 | 2021 | ||||||||||
|
Unitil Corporation:
|
||||||||||||
|
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Unitil Energy First Mortgage Bonds:
|
||||||||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Fitchburg:
|
||||||||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Northern Utilities:
|
||||||||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Granite State:
|
||||||||||||
|
|
|
|
|
|
|
|||||||
|
Unitil Realty Corp.:
|
||||||||||||
|
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Long-Term Debt
|
|
|
|
|
|
|||||||
|
Less: Unamortized Debt Issuance Costs
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Long-Term Debt, net of Unamortized Debt Issuance Costs
|
|
|
|
|
|
|||||||
|
Less: Current Portion
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Long-term Debt, Less Current Portion
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
34
Fair Value of Long-Term Debt -
|
($ millions)
|
June 30,
|
December 31, | ||||||||||
|
2022
|
2021 | 2021 | ||||||||||
|
Estimated Fair Value of Long-Term Debt
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
On July 25, 2018, the Company entered into a Second Amended and Restated Credit Agreement and related documents (collectively, the Credit Facility) with a syndicate of lenders, which amended and restated in its entirety the Company’s prior credit facility. The Credit Facility has a borrowing limit of $
120
million, which includes a $
25
million sublimit for the issuance of standby letters of credit, extends to July 25, 2023, and, under certain conditions, allows for an increase in the borrowing limit by up to $50 million, and two one-year extensions. The Credit Facility provides the Company with the ability to elect that borrowings under the Credit Facility bear-interest under several options, including at a daily fluctuating rate of interest per annum equal to one-month London Interbank Offered Rate plus
1.125
%. The terms of the current credit facility allow for a comparable successor rate to be used if the one-month LIBOR rate becomes unavailable. The Company believes that a change to a new rate will not have a material effect on its financial position, operating results, or cash flows.
The Company
uses
the Credit Facility for cash management purposes related to its short-term operating activities. Total gross borrowings were
$
151.9
million for the six months ended June 30, 2022. Total gross repayments were $
169.8
million for the six months ended June 30, 2022.
The following table details the borrowing limits, amounts outstanding and amounts available under the Credit Facility as of June 30 2022, June 30, 2021 and December 31, 2021:
|
Revolving Credit Facility ($ millions)
|
||||||||||||
|
June 30,
|
December 31, | |||||||||||
|
2022
|
2021 | 2021 | ||||||||||
|
Limit
|
$
|
|
|
$ |
|
$ |
|
|||||
|
Short-Term Borrowings Outstanding
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Available
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
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, the Company’s and its subsidiaries’ ability to permit liens or incur indebtedness, and restrictions on the Company’s ability to merge or consolidate with another entity or change its line of business. The affirmative and negative covenants under the Credit Facility apply until the Credit Facility terminates and all amounts borrowed under the 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 Funded Debt to Capitalization (as each
35
term is defined in the Credit Facility) cannot exceed
65
%, tested on a quarterly basis. At June 30, 2022, June 30, 2021 and December 31, 2021, the Company was in compliance with the covenants contained in the Credit Facility in effect on those dates.
The average interest rates on all short-term borrowings and intercompany money pool transactions were
2.1
% and
1.2
% for the three months ended June 30, 2022 and June 30, 2021, respectively. The average interest rates on all short-term borrowings and intercompany money pool transactions were
1.7
% and
1.3
% for the six months ended June 30, 2022 and June 30, 2021, respectively. The average interest rate on all short-term borrowings for the twelve months ended December 31, 2021 was
1.2
%.
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.
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 $
12.6
million, $
4.9
million and $
8.3
million of gas obligations at June 30, 2022, June 30, 2021 and December 31, 2021, respectively, related to these asset management agreements. The amount of gas released in June 2022 and payable in July 2022 is $
0.2
million and is recorded in Accounts Payable at June 30, 2022. The amount of gas released in June 2021 and payable in July 2021 was $
0.1
million and was recorded in Accounts Payable at 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.
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 June 30, 2022, there were approximately $
0.7
million of guarantees outstanding with a duration less than
one year
.
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 June 30, 2022 and 2021 amounted to $
0.5
million and $
million, respectively. Total rental expense under operating leases charged to operations for the six months ended June 30, 2022 and 2021 amounted to
$
0.9
million and $
1.0
million, respectively.
36
The balance sheet classification of the Company’s lease obligations was as follows:
|
June 30,
|
December 31, | |||||||||||
|
Lease Obligations ($ millions)
|
2022
|
2021 | 2021 | |||||||||
|
Operating Lease Obligations:
|
||||||||||||
|
Other Current Liabilities (current portion)
|
$
|
|
|
$ |
|
$ |
|
|||||
|
Other Noncurrent Liabilities (long-term portion)
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Operating Lease Obligations
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
|
Capital Lease Obligations:
|
||||||||||||
|
Other Current Liabilities (current portion)
|
$
|
|
|
$ |
|
$ |
|
|||||
|
Other Noncurrent Liabilities (long-term portion)
|
|
|
|
|
|
|||||||
|
|
|
|
|
|
|
|||||||
|
Total Capital Lease Obligations
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
|
Total Lease Obligations
|
$
|
|
|
$ |
|
$ |
|
|||||
|
|
|
|
|
|
|
|||||||
Cash paid for amounts included in the measurement of operating lease obligations for the six months ended June 30, 2022 and June 30, 2021 was
$
0.9
million and $
1.0
million and was included in Cash Provided by Operating Activities on the Consolidated Statements of Cash Flows.
Assets under capital leases amounted to approximately $
0.7
million, $
0.9
million and $
0.7
million as of June 30, 2022, June 30, 2021 and December 31, 2021, respectively, less accumulated amortization of $
0.4
million, $
0.5
million and $
0.3
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 June 30, 2022. The payments for operating leases consist of $
1.5
million of current operating lease obligations, which are included in Other Current Liabilities and $
2.9
million of noncurrent operating lease obligations, which are included in Other Noncurrent Liabilities, on the Company’s Consolidated Balance Sheets as of June 30, 2022. The payments for capital leases consist of $
0.1
million of current capital lease obligations, which are included in Other Current Liabilities and $
0.1
million of noncurrent capital lease obligations, which are included in Other Noncurrent Liabilities, on the Company’s Consolidated Balance Sheets as of June 30, 2022.
|
Lease Payments ($000’s)
Year Ending December 31,
|
Operating
Leases |
Capital
Leases |
||||||
|
Rest of 2022
|
$ |
|
$ |
|
||||
|
2023
|
|
|
||||||
|
2024
|
|
|
||||||
|
2025
|
|
|
||||||
|
2026
|
|
|
||||||
|
2027-2031
|
|
|
||||||
|
|
|
|
|
|||||
|
Total Payments
|
|
|
|
|
|
|
||
|
|
|
|
|
|||||
|
Less: Interest
|
|
|
||||||
|
|
|
|
|
|||||
|
Amount of Lease Obligations Recorded on Consolidated Balance Sheets
|
$
|
|
|
$
|
|
|
||
|
|
|
|
|
|||||
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 June 30, 2022, the weighted average remaining lease term is
3.3
years and the weighted average operating discount rate used to determine the operating lease
37
obligations was
3.6
%. As of June 30, 2021, the weighted average remaining lease term was
3.6
years and the weighted average operating discount rate used to determine the operating lease obligations was
4.2
%.
NOTE 5 - 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
16,034,635
,
15,046,469
and
15,977,766
shares of common stock outstanding at June 30, 2022, June 30, 2021 and December 31, 2021, respectively.
Dividend Reinvestment and Stock Purchase Plan -
Stock Plan -
The maximum number of shares available for awards to participants under the Stock Plan is
677,500
. The maximum number of shares that may be awarded in any one calendar year to any one participant is
20,000
. In the event of any change 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.
Restricted Shares
Outstanding awards of Restricted Shares fully vest over a period of
four years
at a rate of
25
% each year. During the vesting period, dividends on 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 are subject to forfeiture if the participant ceases to be employed by the Company other than due to the participant’s death.
On January 25, 2022,
36,770
Restricted Shares were issued in conjunction with the Stock Plan with an aggregate market value at the date of issuance of approximately $
1.7
million. There were
73,178
and
62,566
non-vested shares under the Stock Plan as of June 30, 2022 and 2021, respectively. The weighted average grant date fair value of these shares was $
47.44
and $
49.44
, respectively. The
38
compensation expense associated with the issuance of shares under the Stock Plan is being recognized over the vesting period and was $
1.8
million and $
1.3
million for the six months ended June 30, 2022 and 2021, respectively. At June 30, 2022, there was approximately $
1.0
million of total unrecognized compensation cost under the Stock Plan which is expected to be recognized over approximately
2.9
years. During the six months ended June 30, 2022 there were
zero
restricted shares forfeited and
zero
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
% 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
% of the shares of the Company’s common stock underlying the Restricted Stock Units.
The equity portion of Restricted Stock Units activity during the six months ended June 30, 2022 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, 2021
|
|
$ |
|
|||||
|
Restricted Stock Units Granted
|
|
|
||||||
|
Dividend Equivalents Earned
|
|
$ |
|
|||||
|
Restricted Stock Units Settled
|
(
|
) | $ |
|
||||
|
|
|
|||||||
|
Restricted Stock Units as of June 30, 2022
|
|
$ |
|
|||||
|
|
|
|||||||
There were
43,886
Restricted Stock Units outstanding as of June 30, 2021 with a weighted average stock price of $
41.43
. Included in Other Noncurrent Liabilities on the Company’s Consolidated Balance Sheets as of June 30, 2022, June 30, 2021 and December 31, 2021 is $
1.0
million, $
1.0
million and $
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
million, or
1,861
shares, of Unitil Energy’s
6.00
% Series Preferred Stock outstanding as of June 30, 2022 and December 31, 2021. There were $
0.2
million, or
1,887
shares, of Unitil Energy’s
6.00
% Series Preferred Stock outstanding as of June 30, 2021. There were less than
$
0.1
million of total dividends declared on Preferred Stock in each of the three month periods ended June 30, 2022 and June 30, 2021, respectively.
NOTE 6 - REGULATORY MATTERS
UNITIL’S REGULATORY MATTERS ARE DESCRIBED IN NOTE 8 TO THE FINANCIAL STATEMENTS IN ITEM 8 OF PART II OF UNITIL CORPORATION’S FORM 10-K FOR DECEMBER 31, 2021 AS FILED WITH THE SECURITIES AND EXCHANGE COMMISSION ON FEBRUARY 1, 2022.
Rate Case Activity
Northern Utilities - Base Rates - Maine
and a hypothetical capital structure
39
of
50
% equity and
50
% debt. As part of the order and increase in base revenue, the MPUC provided for 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.
Northern Utilities - Targeted Infrastructure Replacement Adjustment (TIRA) - Maine
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 b
Northern Utilities - Base Rates - New Hampshire
NHPUC on August 2, 2021 by Northern Utilities. The Order approves a comprehensive Settlement Agreement between the Company, the New
Hampshire DOE (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 o
$
(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
step increase of approximately $
1.6
million of annual revenue, for rates effective as of September 1, 2022, to recover eligible 2021 capital investments.
The NHPUC opened a separate docket to review the Company’s proposed step adjustment, and that matter remains pending. 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
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 $
The NHPUC opened a separate docket to review the Company’s proposed step adjustment, and that matter remains pending. 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
%
and a capital structure reflecting
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 $
Unitil Energy - Base Rates
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,
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
(3) time-of-use
40
$
5.9
million will result in reasonable rates. The increase in permanent
rates
was
reconciled
back to June 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
Fitchburg - Base Rates - Electric
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
million, effective November 1, 2020. The Company’s subsequent Compliance Filing reflected an adjusted distribution increase of $
0.9
million, a decrease of $
0.2
million from the original settlement amount. On May 21, 2020, the MDPU approved the Company’s Compliance Filing. The agreement provides for a Return on Equity of
9.7
% and a capital structure reflecting
52.45
% equity and
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
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.
Fitchburg - Base Rates - Gas
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
million to be phased in over
two years
: (1) an increase of $
3.7
million, which became effective on March 1, 2020; and (2) an increase of $
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
. The agreement provides for a Return on Equity of
9.7
% and a capital structure reflecting
52.45
% equity and
47.55
% long-term debt.
Fitchburg - Gas System Enhancement Program
41
On April 28, 2022, the MDPU issued an order approving this filing for rates effective May 1, 2022. The Company considers these to be routine regulatory proceedings, and there are no material issues outstanding.
Granite State - Base Rates
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
0.3
million, effective September 1, 2022. This matter remains pending.
million, effective September 1, 2021. On July 28, 2022, Granite State filed its second
4 rate adjustment, for an annual revenue increase of $
limited Section
Other Matters
Fitchburg - Grid Modernization
Fitchburg - Grid Modernization Cost Recovery Factor
Fitchburg - Investigation into the role of gas LDCs to achieve Commonwealth 2050 climate goals -
Financial Effects of COVID-19 Pandemic
42
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. On December 31, 2020, in docket DPU
20-58,
the MDPU issued an order which, among other provisions, allows the utility companies to defer for future recovery of bad debt expense in excess of a baseline. On July 7, 2021, the NHPUC issued an order which declined 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 that these costs will be addressed in each utility’s next 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, and that Unitil Energy’s and Northern Utilities’ respective pending rate cases are the appropriate venue to address incremental bad debt and/or waived late payment fees resulting from the
COVID-19
public health emergency orders and directives. Consistent 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 the Company’s next scheduled EDC rate change effective August 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 permitted 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 the Company’s next scheduled RAAM rate change effective November 1, 2022. This provision was approved by the NHPUC Order, issued July 20, 2022, on the rate case Settlement Agreement.
Northern Utilities / Granite State - Firm Capacity Contract
Reconciliation Filings
Fitchburg - Massachusetts Request for Proposals (RFPs)
43
long-term contracts for at least
400
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 pro rata share of these contracts is approximately
MW
of offshore wind energy generation by June 30, 2017, as part of a total of
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 for
9,554,940
MWh of Qualified Clean Energy and associated 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, 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 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 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 contingencies are met.
The EDCs issued the 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 July 23, 2018, the EDCs, including Fitchburg, filed two long-term contracts, each for
400
MW of offshore wind energy generation with the MDPU for approval. On April 12, 2019, the MDPU approved the offshore wind energy generation power purchase agreements, 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 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. The EDCs selected an
800
MW project submitted by 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 February 10, 2020. On November 5, 2020, the MDPU approved the Offshore Wind Energy Generation power purchase agreements. The MDPU also determined that the EDCs’ request for remuneration equal to
2.75
% is reasonable and in the public interest. 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.
In accordance with the requirement of Chapter 227 of the Acts of 2018, An Act to Advance Clean Energy, signed August 9, 2018, Massachusetts Department of Energy Resources (MDOER) prepared a report on the necessity, benefits and costs of requiring the EDCs to competitively conduct offshore wind generation RFPs 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, the DPU approved the proposed timetable and method for the solicitation, and the RFP was issued on May 7, 2021. On December 17, 2021, the EDCs selected a 1,600 MW portfolio of offshore wind generation that includes a 1,200 MW project submitted
by
44
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 to the MDPU on May 25, 2022. This matter remains pending.
Section 83C of Chapter 169 of the Acts of 2008 was recently amended by the Acts of 2021 to increase the aggregate amount of offshore wind capacity to be procured to 5,600 MW not later than 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 2,400 MW of offshore wind capacity to be procured in the future.
FERC Transmission Formula Rate Proceedings
The FERC Section 206 proceeding concerning the justness 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 proceeding to the Chief Administrative Law Judge to resume hearing procedures. On May 24, 2019 the judge appointed a Dispute Resolution Facilitator 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. Fitchburg and Unitil Energy are Participating Transmission Owners, although Unitil Energy does not own transmission plant.
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 7 - ENVIRONMENTAL MATTERS
UNITIL’S ENVIRONMENTAL MATTERS ARE DESCRIBED IN NOTE 8 TO THE FINANCIAL STATEMENTS IN ITEM 8 OF PART II OF UNITIL CORPORATION’S FORM
10-K
FOR DECEMBER 31, 2021 AS FILED WITH THE SECURITIES AND EXCHANGE COMMISSION ON FEBRUARY 1, 2022.
45
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 June 30, 2022, 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 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. In anticipation of the NH DES approval of the work plan, the Company has accrued $
0.8
million for estimated costs to complete the remediation at the Rochester site, which is included in Environmental Obligations.
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 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
In August 2021, the Mass DEP issued a Notice of
Non-compliance
to FGE 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 of the investigation by the end of 2022, while remedial action on the river seep may occur before that time. The Company does not believe this investigation will have a material adverse effect on its financial condition, results of operations or cash flows.
46
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
The following table sets forth a summary of changes in the Company’s liability for Environmental Obligations for the six months ended June 30, 2022 and 2021.
|
Environmental Obligations ($ millions)
|
||||||||
|
June 30,
|
||||||||
|
2022
|
2021 | |||||||
|
Total Balance at Beginning of Period
|
$
|
|
|
$ |
|
|||
|
Additions
|
|
|
||||||
|
Less: Payments / Reductions
|
|
|
||||||
|
|
|
|
|
|||||
|
Total Balance at End of Period
|
|
|
|
|
||||
|
|
|
|
|
|||||
|
Less: Current Portion
|
|
|
||||||
|
|
|
|
|
|||||
|
Noncurrent Balance at End of Period
|
$
|
|
|
$ |
|
|||
|
|
|
|
|
|||||
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:
|
Six Months Ended June 30,
|
||||||||
|
2022
|
2021
|
|||||||
|
Statutory Federal Income Tax Rate
|
|
|
%
|
|
% | |||
|
Income Tax Effects of:
|
||||||||
|
State Income Taxes, net
|
|
|
|
|
||||
|
Utility Plant Differences
|
|
(
|
)
|
(
|
) | |||
|
Other, net
|
|
|
||||||
|
|
|
|
|
|||||
|
Effective Income Tax Rate
|
|
|
%
|
|
% | |||
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
47
principles. The Company has evaluated its tax positions at June 30, 2022 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 Maine, Massachusetts, and New Hampshire tax authorities for the tax periods ended December 31, 2020; December 31, 2019; and December 31, 2018.
Income tax filings for the year ended December 31, 2020 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, 2020, which were filed with the IRS in October 2021, the Company generated federal Net Operating Loss Carryforward (NOLC) assets of $
7.7
million, principally due to tax repairs expense and tax depreciation. As of December 31, 2021, the Company recognized the utilization of approximately
$
3.6
million of the NOLC asset to offset current taxes payable. In addition, at December 31, 2021, the Company had $
0.7
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 2024.
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
50
% 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
% 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 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.
The Company has evaluated each of the CARES, CAA and ARPA provisions and determined that they do not have a material effect on the Company’s financial statements as of June 30, 2022.
In December 2017, the Tax Cuts and Jobs Act (TCJA), which included a reduction to the corporate federal income tax rate to
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
% 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
and
twenty years
over the remaining life of the related utility plant.
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 June 30, 2022, the Company flowed back $
4.9
million to customers in its Massachusetts, Maine, New Hampshire, and federal jurisdictions.
T
he Company expects to flow back to customers a net $
48
NOTE 9: 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 Note 10 to the Consolidated Financial Statements in the Company’s Form 10-K for the year ended December 31, 2021 as filed with the SEC on February 1, 2022 for additional information regarding these plans.
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
|
2022
|
2021
|
||||||
|
Discount Rate
|
|
|
%
|
|
% | |||
|
Rate of Compensation Increase
|
|
|
%
|
|
% | |||
|
Expected Long-term rate of return on plan assets
|
|
|
%
|
|
% | |||
|
Health Care Cost Trend Rate Assumed for Next Year
|
|
|
%
|
|
% | |||
|
Ultimate Health Care Cost Trend Rate
|
|
|
%
|
|
% | |||
|
Year that Ultimate Health Care Cost Trend Rate is reached
|
|
|
|
|
||||
The following tables provide the components of the Company’s Retirement plan costs ($000’s):
|
Pension Plan
|
PBOP Plan
|
SERP
|
||||||||||||||||||||||
|
Three Months Ended June 30,
|
2022
|
2021
|
2022
|
2021
|
2022
|
2021
|
||||||||||||||||||
|
Service Cost
|
$
|
|
|
$
|
|
|
$
|
|
|
$
|
|
|
$
|
|
|
$
|
|
|
||||||
|
Interest Cost
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
|
Expected Return on Plan Assets
|
|
(
|
)
|
|
(
|
)
|
|
(
|
)
|
|
(
|
)
|
|
—
|
|
|
—
|
|
||||||
|
Prior Service Cost Amortization
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
|
Actuarial Loss Amortization
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
|
Sub-total
|
|
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Amounts Capitalized and Deferred
|
|
(
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)
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(
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)
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(
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)
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(
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)
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(
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(
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)
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Net Periodic Benefit Cost Recognized
|
$
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$
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$
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|
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$
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$
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$
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Pension Plan
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PBOP Plan
|
SERP
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Six Months Ended June 30,
|
2022
|
2021 |
2022
|
2021 |
2022
|
2021 | ||||||||||||||||||
|
Service Cost
|
$
|
|
|
$ |
|
$
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|
|
$ |
|
$
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|
|
$ |
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|||||||||
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Interest Cost
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Expected Return on Plan Assets
|
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(
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)
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(
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) |
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(
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)
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(
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) |
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—
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— | ||||||||||
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Prior Service Cost Amortization
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Actuarial Loss Amortization
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Sub-total
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Amounts Capitalized and Deferred
|
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(
|
)
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(
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) |
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(
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)
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(
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) |
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(
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)
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(
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) | |||||||||
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|||||||||||||
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Net Periodic Benefit Cost Recognized
|
$
|
|
|
$ |
|
$
|
|
|
$ |
|
$
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$ |
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49
Employer Contributions
As of June 30, 2022, the Company had made $
1.9
million and $
0.8
million of contributions to its Pension Plan and PBOP Plan, respectively, in 2022. The Company, along with its subsidiaries, expects to continue to make contributions to its Pension and PBOP Plans in 2022 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 June 30, 2022, the Company had made $
0.3
million of benefit payments under the SERP Plan in 2022. The Company presently anticipates making an additional $
0.3
million of benefit payments under the SERP Plan in 2022.
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 June 30, 2022. Based upon this evaluation, the Company’s Chief Executive Officer, Chief Financial Officer and Chief Accounting Officer concluded as of June 30, 2022 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 as filed with the SEC on February 1, 2022.
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 June 30, 2022.
50
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 1, 2022, the Company will periodically repurchase shares of its Common Stock on the open market related to the stock 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 in value of shares have been purchased or, if sooner, on May 1, 2023.
The Company may suspend or terminate this 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 June 30, 2022.
|
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 |
|||||||||||||
|
4/1/22 – 4/30/22
|
— | — | — | $ | 11 | |||||||||||
|
5/1/22 – 5/31/22
|
— | — | — | $ | 587,000 | |||||||||||
|
6/1/22 – 6/30/22
|
— | — | — | $ | 587,000 | |||||||||||
|
|
|
|
|
|||||||||||||
|
Total
|
— | — | — | |||||||||||||
|
|
|
|
|
|||||||||||||
Item 5. Other Information
On August 2, 2022, the Company issued a press release announcing its results of operations for the three and six month periods ended June 30, 2022. The press release is furnished with this Quarterly Report on Form
10-Q
as Exhibit 99.1.
Item 6. Exhibits
(a) Exhibits
51
| 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 August 2, 2022 Announcing Earnings For the Quarter Ended June 30, 2022. | 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 | ||
52
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: August 2, 2022
|
/s/ Robert B. Hevert | |||||
| Robert B. Hevert | ||||||
| Chief Financial Officer | ||||||
| Date: August 2, 2022 | /s/ Daniel J. Hurstak | |||||
| Daniel J. Hurstak | ||||||
| Chief Accounting Officer |
53
TABLE OF CONTENTS
Part I. Financial InformationItem 2. Management S Discussion and Analysis Of Financial Condition and Results Of OperationsNote 1 - Summary Of Significant Accounting PoliciesNote 2 - Dividends Declared Per ShareNote 3 - Segment InformationNote 4 - Debt and Financing ArrangementsNote 5 - Common Stock and Preferred StockNote 6 - Regulatory MattersNote 7 - Environmental MattersNote 8: Income TaxesNote 9: Retirement Benefit ObligationsItem 3. Quantitative and Qualitative Disclosures About Market RiskItem 4. Controls and ProceduresPart II. Other InformationItem 1. Legal ProceedingsItem 1A. Risk FactorsItem 2. Unregistered Sales Of Equity Securities and Use Of ProceedsItem 5. Other InformationItem 6. Exhibits