UNITIL CORP - Quarter Report: 2009 June (Form 10-Q)

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

QUARTERLY REPORT UNDER SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For Quarter Ended June 30, 2009

Commission File Number 1-8858

UNITIL CORPORATION

(Exact name of registrant as specified in its charter)

Registrant’s telephone number, including area code: (603) 772-0775

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  x    No  ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).    Yes  ¨    No  ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨    No  x

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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UNITIL CORPORATION AND SUBSIDIARY COMPANIES

FORM 10-Q

For the Quarter Ended June 30, 2009

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PART I. FINANCIAL INFORMATION

OVERVIEW

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

Unitil’s principal business is the local distribution of electricity and natural 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: (i) Unitil Energy Systems, Inc. (Unitil Energy), which provides electric service in the southeastern seacoast and state capital regions of New Hampshire, including the city of Concord, New Hampshire; (ii) Fitchburg Gas and Electric Light Company (Fitchburg), which provides both electric and natural gas service in the greater Fitchburg area of north central Massachusetts; and (iii) Northern Utilities, Inc. (Northern Utilities), which provides natural gas service in southeastern New Hampshire, including the city of Portsmouth, and portions of southern and central Maine, including the city of Portland. In addition, Unitil is the parent company of Granite State Gas Transmission, Inc. (Granite State), an interstate natural gas transmission pipeline company that principally provides interstate natural gas pipeline access and transportation services to Northern Utilities in its New Hampshire and Maine service territory.

The Company’s distribution utilities serve approximately 100,300 electric customers and 69,300 natural gas customers in their service territory. The Company’s distribution utilities are local “pipes and wires” operating companies and, combined with Granite State, had an investment in Net Utility Plant of $426.8 million at June 30, 2009. The Company does not own or operate electric generating facilities or major transmission facilities and substantially all of the Company’s utility assets are dedicated to the local delivery of electricity and natural gas to its customers. Substantially all of Unitil’s revenue and earnings are derived from regulated utility operations.

On December 1, 2008, Unitil purchased (i) all of the outstanding capital stock of Northern Utilities from Bay State Gas Company (Bay State) and (ii) all of the outstanding capital stock of Granite State from NiSource Inc. (NiSource) pursuant to the Stock Purchase Agreement dated as of February 15, 2008 by and among NiSource, Bay State and Unitil (the “Acquisitions”). Bay State is a wholly owned subsidiary of NiSource. The aggregate purchase price for the Acquisitions was $160 million in cash, plus an additional working capital adjustment of $49.2 million, including approximately $30.0 million of natural gas storage inventory. To finance the Acquisitions and recapitalize Northern Utilities and Granite State, the Company issued additional equity and debt.

A fifth wholly owned subsidiary, Unitil Power Corp. (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, Unitil Power ceased being the wholesale supplier of Unitil Energy on May 1, 2003 and divested of substantially all of its long-term power supply contracts through the sale of the entitlements to the electricity associated with those contracts.

The Company also has three other wholly owned subsidiaries: Unitil Service Corp. (Unitil Service); Unitil Realty Corp. (Unitil Realty); and Unitil Resources, Inc. (Unitil Resources). Unitil Service provides, at cost, a variety of administrative and professional services, including regulatory, financial, accounting, human resources, engineering, operations, technology and energy supply 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. Unitil Resources is the Company’s wholly owned non-regulated subsidiary. Usource, Inc. and Usource L.L.C. (collectively, “Usource”) are indirect subsidiaries that are wholly owned by Unitil Resources. Usource provides energy brokering and advisory services to large commercial and industrial customers in the northeastern United States.

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RATES AND 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 in regards to certain bookkeeping, accounting and reporting requirements. Unitil’s utility operations related to wholesale and interstate energy business activities are also regulated by FERC. Unitil’s distribution utilities are subject to regulation by the applicable state public utility commissions, in regards 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). 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 natural gas to all customers in their service territory, at rates established under traditional 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, in addition to earning a return on their capital investment in utility assets. As a result of a restructuring of the utility industry in New Hampshire, Massachusetts and Maine, Unitil’s customers have the opportunity to purchase their electricity or natural gas supplies from third party suppliers. A majority of Unitil’s largest commercial and industrial (C&I) customers purchase their electric and natural gas supplies from third party suppliers. However, most residential and small customers continue to purchase their electric and natural gas supplies through Unitil’s distribution utilities. Unitil’s distribution utilities purchase electricity or natural gas from unaffiliated wholesale suppliers and recover the actual costs of these supplies on a pass-through basis, as well as certain costs associated with industry restructuring, through reconciling rate mechanisms that are periodically adjusted.

The regulatory process in both New Hampshire and Maine, in connection with those states’ approvals of the Acquisitions, included the negotiation and filing of settlement agreements reflecting commitments by Unitil with respect to Northern Utilities’ rates, customer service and operations. The settlement agreements were separately negotiated and filed in each state but reflect a number of common features. For additional discussion, please refer to Unitil’s Annual Report on Form 10-K, as filed with the Securities and Exchange Commission on February 18, 2009.

CAUTIONARY STATEMENT

This report and the documents the Company incorporates by reference into this report contain statements that constitute “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, Section 21E of the Securities Exchange Act of 1934, as amended, 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 and its management’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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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. New factors emerge from time to time, and it is not possible for the Company to predict all of these factors, nor can the Company assess the impact 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.

RESULTS OF OPERATIONS

The following section of MD&A compares the results of operations for each of the two fiscal periods ended June 30, 2009 and June 30, 2008 and should be read in conjunction with the accompanying Consolidated Financial Statements and the accompanying Notes to Consolidated Financial Statements included in Part I, Item 1 of this report.

As a result of the acquisitions of Northern Utilities and Granite State on December 1, 2008, consolidated results for the Company in the current period may not be directly comparable to prior period results until such time as the acquisitions are fully reflected in both reporting periods. In particular, the Company expects that consolidated results of operations in current and future reporting periods will reflect to a greater degree the seasonal nature of the natural gas business. Specifically, the Company expects consolidated results of operations will be positively affected during the first and fourth quarters, and negatively affected during the second and third quarters of current and future reporting years.

Earnings Overview

The Company’s Earnings Applicable to Common Shareholders was $0.2 million for the second quarter of 2009, compared to earnings of $1.6 million for the second quarter of 2008. Earnings per common share (EPS) were $0.03 for the three months ended June 30, 2009 compared with $0.28 in the second quarter of 2008. For the six months ended June 30, EPS were $1.10 for 2009 compared to $0.85 for 2008, an increase of $0.25 per share, or 29%, reflecting the positive impact from the acquisitions of Northern Utilities and Granite State.

Earnings for the second quarter of 2009 reflect the greater degree to which the seasonal nature of the natural gas business now affects the Company’s earnings as a result of the acquisitions of Northern Utilities and Granite State, as discussed above. Earnings in the second quarter reflect higher gas utility sales margins offset by lower electric utility sales margins and higher operating, depreciation and interest costs in the quarter as well as a higher number of average shares outstanding year over year, discussed below.

Natural gas sales margin increased $8.4 million and $26.5 million in the three and six months ended June 30, 2009, respectively, compared to the same periods in 2008. These increases primarily reflect the contribution by Northern Utilities, the Company’s recently acquired local gas distribution utility. Natural gas sales in the six month period ended June 30, 2009 reflect a colder winter heating season this year. Average winter temperatures in the Company’s service territories were 6.4% colder than last year.

Electric sales margin decreased $1.6 million and $0.3 million in the three and six months ended June 30, 2009, respectively, compared to the same periods in 2008, reflecting lower sales volumes. Total electric kilowatt-hour (kWh) sales decreased 6.8% and 5.7% in the three and six months ended June 30, 2009, respectively, compared to the same periods in 2008 due to lower average usage by our customers reflecting the continued regional economic slowdown.

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Total Operation & Maintenance (O&M) expenses increased $5.0 million and $10.7 million for the three and six months ended June 30, 2009, respectively, compared to the same period in 2008. The addition of Northern Utilities and Granite State to consolidated operating results in 2009 accounted for $4.3 million of the increase in the six month period. For the six month period, in addition to the increases due to the acquisition of Northern Utilities and Granite State, higher professional fees expense of $1.9 million, primarily related to the December ice storm discussed below, higher compensation and employee benefit expenses of $0.6 million and higher utility operating costs of $1.1 million contributed to the increase in O&M expenses. The increase in O&M expenses for the six month period also reflects higher insurance costs in 2009 compared to the same period in 2008, due to the receipt of a $2.8 million insurance settlement in 2008.

Depreciation, Amortization, Taxes and Other expenses increased $2.1 million and $7.9 million in the three and six months ended June 30, 2009, respectively, compared to the same periods in 2008. The increases primarily reflect the addition of Northern Utilities and Granite State to consolidated operating results in 2009, and higher depreciation on normal utility plant additions partially offset by lower amortization on natural gas inventory carrying costs.

Interest Expense, Net increased $1.4 million and $3.6 million in the three and six month periods ended June 30, 2009, respectively, compared to the same periods in 2008. These increases are primarily due to the addition of Northern Utilities and Granite State, reflecting the issuance of long-term notes by Northern Utilities and Granite State in December 2008. In addition, these increases in Interest Expense, Net reflect higher average borrowings in the current periods.

Usource, our non-regulated energy brokering business, recorded revenues of $1.1 million and $2.2 million in the three and six month periods ended June 30, 2009, respectively, increases of $0.3 million and $0.4 million over the comparable periods of 2008. Usource’s revenues are primarily derived from fees and charges billed to suppliers as customers take delivery of energy from these suppliers under term contracts brokered by Usource.

On December 11 and 12, 2008, a severe ice storm struck the New England region, creating extended power outages for many residents of Massachusetts and New Hampshire, including Unitil’s electric customers in New Hampshire and the greater Fitchburg, Massachusetts service territory. Based on its preliminary assessment, the Company has accrued and deferred, excluding capital construction expenditures, approximately $12.5 million in costs for the repair and replacement of electric distribution systems damaged during the storm. The amount and timing of the cost recovery of these storm restoration expenditures will be determined in future regulatory proceedings. The Company does not believe these storm restoration expenditures and the timing of cost recovery will have a material adverse impact on the Company’s financial condition or results of operations.

Between December 2008 and June 2009, the Company issued and sold 4,970,000 shares of its common stock, including its underwriters’ excercise of overallotment options to purchase an additional 570,000 shares, at a price of $20.00 per share in registered public offerings. The Company used net proceeds of $93.1 million from these offerings (i) to repay all amounts outstanding under the bridge credit facility that the Company used to partially finance the acquisition of Northern Utilities and Granite State which closed on December 1, 2008, and (ii) for other general corporate purposes, including capital contributions to Unitil’s distribution utilities and repayment of short-term debt. See Note 4. Overall, the positive results of operations and net income are reflected over a higher number of average shares outstanding year over year.

In 2008, Unitil’s annual common dividend was $1.38, representing an unbroken record of quarterly dividend payments since trading began in Unitil’s common stock. At its January, 2009, March, 2009 and June, 2009 meetings, the Unitil Board of Directors declared quarterly dividends on the Company’s common stock of $0.345 per share.

A more detailed discussion of the Company’s results of operations for the three and six months ended June 30, 2009 and a period-to-period comparison of changes in financial position are presented below.

Balance Sheet

The Company’s Total Assets increased by $230.9 million as of June 30, 2009 compared to June 30, 2008. The increase in Total Assets was primarily due to the inclusion of the acquisitions of Northern Utilities and Granite State and to capital expenditures related to Unitil Energy’s and Fitchburg’s electric and gas distribution systems.

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The Company’s Total Capitalization increased by $185.6 million as of June 30, 2009 compared to June 30, 2008 reflecting the issuance of common shares by the Company as part of its financing of the acquisitions of Northern Utilities and Granite State (See Note 4 to the accompanying Consolidated Financial Statements) and the issuance and sale of Senior Unsecured Notes by Northern Utilities and Granite State (See Note 5 to the accompanying Consolidated Financial Statements). The Company’s Total Liabilities increased $45.3 million primarily due to the acquisitions of Northern Utilities and Granite State.

Gas Sales, Revenues and Margin

Therm Sales – Overall, Unitil’s total therm sales of natural gas increased in the three and six month periods ended June 30, 2009 compared to the same periods in 2008. These increases primarily reflect the contribution of sales by Northern Utilities. Excluding the contribution to sales by Northern Utilities, total therm sales of natural gas decreased 9.7% in the three months ended June 30, 2009 compared to the same period in 2008 and increased 1.1% in the six months ended June 30, 2009 compared to the same period in 2008. The increase in the six month period ended June 30, 2009 reflects a colder winter heating season this year. Average winter temperatures in the Company’s service territories were 6.4% colder than last year. The lower sales in the three month period ended June 30, 2009 reflect energy conservation and lower usage of natural gas by C&I customers for production operations.

The following table details total firm therm sales for the three and six months ended June 30, 2009 and 2008, by major customer class:

Gas Operating Revenues and Sales Margin – The following table details total Gas Operating Revenues and Sales Margin for the three and six months ended June 30, 2009 and 2008:

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Total Gas Operating Revenues increased $16.8 million and $74.9 million in the three and six month periods ended June 30, 2009, respectively, compared to the same periods in 2008. These increases primarily reflect the natural gas sales for Northern Utilities. Total Gas Operating Revenues include the recovery of the cost of sales, which are recorded as Purchased Gas and Conservation & Load Management (C&LM) in Operating Expenses. The increase in Total Gas Operating Revenues in the second quarter of 2009 reflects higher Purchased Gas costs of $7.9 million, higher C&LM revenues of $0.5 million and higher gas sales margin of $8.4 million. The increase in Total Gas Operating Revenues in the first six months of 2009 reflects higher Purchased Gas costs of $47.3 million, higher C&LM revenues of $1.1 million and higher gas sales margin of $26.5 million.

The Purchased Gas and C&LM component of Gas Operating Revenues increased $8.4 million and $48.4 million in the three and six month periods ended June 30, 2009 compared to the same periods in 2008. These increases primarily reflect the natural gas sales for Northern Utilities. Purchased Gas revenues include the recovery of the cost of gas supply as well as other energy supply related costs. C&LM revenues include the recovery of the cost of energy efficiency and conservation programs. The Company recovers the cost of Purchased Gas and C&LM in its rates at cost on a pass through basis.

Natural gas sales margin increased $8.4 million and $26.5 million in the three and six months ended June 30, 2009, respectively, compared to the same periods in 2008. These increases primarily reflect the contribution by Northern Utilities.

Electric Sales, Revenues and Margin

Kilowatt-hour Sales – Unitil’s total electric kilowatt (kWh) sales decreased 6.8% and 5.7% in the three and six month periods ended June 30, 2009, respectively compared to the same periods in 2008. Electric kWh sales to residential customers in the three and six month periods ended June 30, 2009 decreased 4.3% and 2.5%, respectively, compared to the same periods in 2008 while sales to C&I customers decreased 8.2% and 7.7%, respectively, in those periods compared to the same periods in 2008. The lower kWh sales in 2009 compared to 2008 reflect lower average usage by our customers due to the continued regional economic slowdown.

The following table details total kWh sales for the three and six months ended June 30, 2009 and 2008 by major customer class:

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Electric Operating Revenues and Sales Margin – The following table details total Electric Operating Revenues and Sales Margin for the three and six month periods ended June 30, 2009 and 2008:

Total Electric Operating Revenues, decreased by $5.0 million, or 9.6%, and increased by $0.5 million, or 0.5%, in the three and six month periods ended June 30, 2009, respectively, compared to the same periods in 2008. Total Electric Operating Revenues include the recovery of costs of electric sales, which are recorded as Purchased Electricity and C&LM in Operating Expenses. The decrease in Total Electric Operating Revenues in the second quarter of 2009 reflects lower Purchased Electricity costs of $3.4 million and lower electric sales margin of $1.6 million. The increase in Total Electric Operating Revenues in the first six months of 2009 reflects higher Purchased Electricity costs of $0.9 million, partially offset by lower C&LM revenues of $0.1 million and lower electric sales margin of $0.3 million.

The Purchased Electricity and C&LM component of Total Electric Operating Revenues decreased $3.4 million, or 6.5%, and increased a net $0.8 million, or 0.8%, in the three and six month periods ended June 30, 2009, respectively, compared to the same periods in 2008. The decrease in the three month period reflects lower sales volumes and lower electric commodity prices. The increase in the six month period reflects higher electric commodity prices and a decrease in the amount of electricity purchased by customers directly from third-party suppliers, partially offset by lower sales volumes and lower spending on energy efficiency and conservation programs. Purchased Electricity revenues include the recovery of the cost of electric supply as well as other energy supply related restructuring costs, including long-term power supply contract buyout costs. C&LM revenues include the recovery of the cost of energy efficiency and conservation programs. The Company recovers the cost of Purchased Electricity and C&LM in its rates at cost on a pass through basis.

Electric sales margin decreased $1.6 million and $0.3 million in the three and six months ended June 30, 2009, respectively, compared to the same periods in 2008. The decrease in the three month period reflects lower sales volumes. The decrease in the six month period reflects lower sales volumes partially offset by higher electric base rates implemented in March 2008.

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Operating Revenue - Other

The following table details total Other Revenue for the three and six months ended June 30, 2009 and 2008:

Total Other Revenue increased $0.3 million, or 37.5% and $0.4 million, or 22.2%, in the three and six month periods ended June 30, 2009, respectively, compared to the same periods in 2008. These increases were the result of growth in revenues from the Company’s non-regulated energy brokering business, Usource.

Operating Expenses

Purchased Gas – Purchased Gas expenses include the cost of gas purchased and manufactured to supply the Company’s total gas supply requirements. Purchased Gas increased $7.9 million and $47.3 million in the three and six months ended June 30, 2009, respectively, compared to the same periods in 2008. These increases primarily reflect the natural gas supply purchases for Northern Utilities, which were not included in the prior year period. The Company recovers the costs of Purchased Gas in its rates at cost on a pass through basis and therefore changes in these expenses do not affect earnings.

Purchased Electricity – Purchased Electricity expenses include the cost of electric supply as well as other energy supply related restructuring costs, including long-term power supply contract buyout costs. Purchased Electricity decreased $3.4 million, or 9.2%, and increased $0.9 million, or 1.1%, in the three and six month periods ended June 30, 2009, respectively, compared to the same periods in 2008. The decrease in the three month period primarily reflects lower sales volumes and lower electric commodity prices. The increase in the six month period reflects higher electric commodity prices and a decrease in the amount of electricity purchased by customers directly from third-party suppliers, partially offset by lower sales volumes. The Company recovers the costs of Purchased Electricity in its rates at cost on a pass through basis and therefore changes in these expenses do not affect earnings.

Operation and Maintenance (O&M) – O&M expense includes electric and gas utility operating costs, and the operating cost of the Company’s unregulated business activities. Total O&M expenses increased $5.0 million and $10.7 million for the three and six months ended June 30, 2009, respectively, compared to the same period in 2008. The addition of Northern Utilities and Granite State to consolidated operating results in 2009 accounted for $1.9 million and $4.3 million of the increases in the three and six month periods, respectively. For the three month period, in addition to the increases due to the acquisition of Northern Utilities and Granite State, higher professional fees of $2.2 million, primarily related to the internal review and legal and regulatory proceedings associated with the ice storm of December 2008, higher compensation and employee benefit expenses of $0.2 million, reflecting normal annual increases, and higher utility operating costs of $0.7 million contributed to the increase in O&M expenses. For the six month period, in addition to the increases due to the acquisition of Northern Utilities and Granite State, higher professional fees of $1.9 million, primarily related to the internal review and legal and regulatory proceedings associated with the ice storm of December 2008, higher compensation and employee benefit expenses of $0.6 million and higher utility operating costs of $1.1 million contributed to the increase in O&M expenses. The increase in the six month period also reflects higher insurance costs in 2009 compared to 2008, due to the receipt of a $2.8 million insurance settlement in 2008.

Conservation & Load Management – Conservation and Load Management expenses are expenses associated with the development, management, and delivery of the Company’s energy efficiency programs. Energy efficiency programs are designed, in conformity to state regulatory requirements, to help consumers use natural gas and

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electricity more efficiently and thereby decrease their energy costs. Programs are tailored to residential, small business and large business customer groups and provide educational materials, technical assistance, and rebates that contribute toward the cost of purchasing and installing approved measures. Approximately 90% of these costs are related to electric operations and 10% to gas operations.

Total C&LM expenses decreased $0.5 million, or 55.6% and $1.0 million, or 66.7%, in the three and six month periods ended June 30, 2009 compared to the same periods in 2008. These costs are collected from customers on a fully reconciling basis and therefore, fluctuations in program costs do not affect earnings.

Depreciation, Amortization and Taxes

Depreciation and Amortization – Depreciation and Amortization expense increased $1.9 million, or 42.2% and $3.0 million, or 30.9% in the three and six month periods ended June 30, 2009, respectively, compared to the same periods in 2008. These increases primarily reflect the addition of Northern Utilities and Granite State to consolidated operating results in 2009, and higher depreciation on normal utility plant additions partially offset by lower amortization on natural gas inventory carrying costs.

Local Property and Other Taxes – Local Property and Other Taxes increased $0.8 million and $2.1 million in the three and six month periods ended June 30, 2009, respectively, compared to the same periods in 2008. These increases primarily reflect the addition of Northern Utilities and Granite State to consolidated operating results in 2009, and higher local property tax rates on higher levels of utility plant in service.

Federal and State Income Taxes – Federal and State Income Taxes were lower by $0.6 million in the three month period ended June 30, 2009 compared to the same period in 2008 reflecting lower pre-tax earnings. Federal and State Income Taxes were higher by $2.9 million in the six month period ended June 30, 2009 compared to the same period in 2008 reflecting higher pre-tax earnings.

Other Non-operating Expenses (Income)

Other Non-operating Expenses were flat in the three month period ended June 30, 2009 compared to the same period in 2008. For the six month period ended June 30, 2009, Other Non-operating Expenses decreased $0.1 million compared to the same period in 2008. This change reflects an adjustment of $0.1 million recorded in the first quarter of 2008 in conjunction with the Company’s approved electric base distribution rate increase in Massachusetts.

Interest Expense, Net

Interest expense is presented in the financial statements net of interest income. Interest expense is mainly comprised of interest on long-term debt and short-term borrowings. Certain reconciling rate mechanisms used by the Company’s distribution utilities give rise to regulatory assets (and regulatory liabilities) on which interest is calculated.

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 monthly tracking and reconciling process will produce either an under-collected or an over-collected balance of costs. In accordance with the distribution utilities’ rate tariffs, interest is accrued on these balances and will produce either interest income or interest expense. 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.

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On December 3, 2008, Northern Utilities completed the sale of $80 million of Senior Unsecured Notes, through a private placement to institutional investors. The debt financing included $50 million of 30-year notes with a coupon rate of 7.72% and $30 million of 10-year notes with a coupon rate of 6.95%. The Company used the proceeds from the long-term Note financing to repay a portion of the bank financing for Unitil’s acquisition of Northern Utilities.

On December 15, 2008, Granite State completed the sale of $10 million of Senior Unsecured Notes, through a private placement to institutional investors. The Notes have a term of 10 years maturity and a coupon rate of 7.15%. The Company used the proceeds from the long-term Note financing to repay a portion of the bank financing for Unitil’s acquisition of Granite State.

Interest Expense, Net increased $1.4 million and $3.6 million in the three and six month periods ended June 30, 2009, respectively, compared to the same periods in 2009. These increases were primarily due to the issuance of the long-term notes, noted above, and higher average borrowings in the current periods, partially offset by lower interest expense related to the repayment of the bank financing facility in the second quarter of 2009. In the second quarter of 2009, the permanent financing of the acquisition was completed and the associated interim financing fees and costs of the acquisition were recognized as part of transaction costs, to be amortized over 10 years, in accordance with the provisions of the regulatory orders approving the acquisitions by the NHPUC and MPUC.

CAPITAL REQUIREMENTS

Sources of Capital

Unitil requires capital to fund utility plant additions, working capital and other utility expenditures recovered in subsequent and future 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 bank borrowings, as needed, under unsecured short-term bank credit facilities. Periodically, the Company replaces portions of its short-term debt with long-term financings more closely matched to the long-term nature of its utility assets. The Company’s utility operations are seasonal in nature and are therefore subject to seasonal fluctuations in cash flows.

The continued availability of these methods of financing, as well as the Company’s choice of a specific form of security, 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 the Company’s earnings, cash flows and financial position; and the competitive pricing offered by financing sources.

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At June 30, 2009, the Company had $30.6 million in short-term debt outstanding through bank borrowings under its revolving credit agreement. The revolving credit agreement contains customary terms and conditions for credit facilities of this type, including certain financial covenants. As of June 30, 2009, the Company was in compliance with financial covenants contained in the revolving credit agreement.

During the second quarter of 2009, the Company repaid the remaining $39.1 million outstanding under a bank financing facility utilized in connection with the financing of the acquisition of Northern Utilities and Granite State on December 1, 2008.

The Company provides limited guarantees on certain energy and natural gas storage management contracts entered into by the distribution utilities. The Company’s policy is to limit these guarantees to two years or less. As of June 30, 2009, there were approximately $18.3 million of guarantees outstanding and these guarantees extend through December 31, 2010.

The Company also guarantees the payment of principal, interest and other amounts payable on the notes issued by Unitil Realty and Granite State. As of June 30, 2009, the principal amount outstanding for the 8% Unitil Realty notes was $4.5 million, and the principal amount outstanding for the 7.15% Granite State notes was $10.0 million. The guarantee related to the Granite State notes will terminate if Granite State reorganizes and merges with and into Northern Utilities.

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’s subsidiaries conduct a portion of their operations in leased facilities and also lease some of their vehicles, machinery and office equipment under both capital and operating lease arrangements.

Cash Flows

On December 1, 2008, the Company acquired Northern Utilities and Granite State. Cash flow results for the first six months of 2009 include the activity for the acquired companies. Unitil’s utility operations, taken as a whole, are seasonal in nature and are therefore subject to seasonal fluctuations in cash flows. The tables below summarize the major sources and uses of cash (in millions) for the six months ended June 30, 2009 compared to the same period in 2008.

Cash Provided by Operating Activities – Cash Provided by Operating Activities was $18.7 million during the six months ended June 30, 2009, a decrease of $1.1 million over the comparable period in 2008. Cash flow from Net Income, adjusted for non-cash charges to depreciation, amortization and deferred taxes increased by $3.6 million as compared to 2008, and sources of cash for working capital increased $11.2 million, primarily related to the funding in 2009 of deferred regulatory charges related to the December ice storm, while all other sources and uses of cash from Operating Activities resulted in a net use of cash of $15.9 million in the first six months of 2009 compared to 2008.

Cash (Used in) Investing Activities – Cash (Used in) Investing Activities was $26.1 million for the six months ended June 30, 2009, an increase in capital spending of $15.9 million over the comparable period in 2008. Of

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this amount, $7.5 million is related to expenditures for the December 2008 ice storm, and $6.9 million is related to capital expenditures for Northern Utilities.

Cash Provided by (Used in) Financing Activities – Cash Provided by Financing Activities was $6.2 million in the six months ended June 30, 2009. Proceeds from the issuance of Common Stock of $56.2 million primarily reflect the issuance of common stock by the Company through public offerings, as discussed above (See Note 4). Short-term borrowings were reduced by $43.5 million in the first six months of 2009 which included the repayment of the temporary bank credit facility utilized in financing the acquisition of Northern Utilities and Granite State on December 1, 2008. Uses of cash of $5.6 million primarily reflect Unitil’s regular quarterly dividend payments on Common and Preferred Stock, and the scheduled repayment of long-term debt.

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 is sometimes required to make difficult, subjective and/or complex judgments about the impact 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. The following is a summary of the Company’s most critical accounting policies, which are defined as those policies where judgments or uncertainties could materially affect the application of those policies. For a complete discussion of the Company’s significant accounting policies, refer to the Note 1 to the Consolidated Financial Statements in the Company’s Annual Report on Form 10-K, as filed with the Securities and Exchange Commission on February 18, 2009.

Regulatory Accounting – The Company’s principal business is the distribution of electricity and natural gas by the three distribution utilities: Unitil Energy, Fitchburg and Northern Utilities. Unitil Energy is regulated by the FERC and the NHPUC. Fitchburg is regulated by the FERC and the MDPU. 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 provisions of FASB Statement No. 71, “Accounting for the Effects of Certain Types of Regulation.” (SFAS No. 71). In accordance with SFAS No. 71, 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.

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The Company receives a return on investment on its regulated assets for which a cash outflow has been made. Regulatory commissions can reach different conclusions about the recovery of costs, which can have a material impact on the Company’s consolidated financial statements. The Company believes it is probable that its regulated distribution and transmission utilities will recover their investments in long-lived assets, including regulatory assets. If the Company, or a portion of its assets or operations, were to cease meeting the criteria for application of these accounting rules, accounting standards for businesses in general would become applicable and immediate recognition of any previously deferred costs, or a portion of deferred costs, would be required in the year in which the criteria are no longer met, if such deferred costs were not recoverable in the portion of the business that continues to meet the criteria for application of SFAS No. 71. If unable to continue to apply the provisions of SFAS No. 71, the Company would be required to apply the provisions of FASB Statement No. 101, “Regulated Enterprises – Accounting for the Discontinuation of Application of Financial Accounting Standards Board Statement No. 71.” In the Company’s opinion, its regulated operations will be subject to SFAS No. 71 for the foreseeable future.

Utility Revenue Recognition – Regulated utility revenues are based on rates and charges approved by federal and state regulatory commissions. Revenues related to the sale of electric and gas service are 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 revenue is estimated. This unbilled revenue is estimated each month based on estimated customer usage by class and applicable customer rates.

Allowance for Doubtful Accounts – The Company recognizes a provision for doubtful accounts each month based upon the Company’s experience in collecting electric and gas utility service accounts receivable in prior years. At the end of each month, an analysis of the delinquent receivables is performed which takes into account an assumption about the cash recovery of delinquent receivables. The analysis also calculates the amount of written-off receivables that are recoverable through regulatory rate reconciling mechanisms. The Company’s distribution utilities are authorized by regulators to recover the costs of their energy commodity portion of bad debts through rate mechanisms. Evaluating the adequacy of the Allowance for Doubtful Accounts requires judgment about the assumptions used in the analysis, including expected fuel assistance payments from governmental authorities and the level of customers enrolling in payment plans with the Company. It has been the Company’s experience that the assumptions it has used in evaluating the adequacy of the Allowance for Doubtful Accounts have proven to be reasonably accurate.

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Retirement Benefit Obligations – The Company sponsors the Unitil Corporation Retirement Plan (Pension Plan), which is a defined benefit pension plan covering substantially all of its employees. The Company also sponsors an unfunded retirement plan, the Unitil Corporation Supplemental Executive Retirement Plan (SERP), covering certain executives of the Company and an employee 401(k) savings plan. Additionally, the Company sponsors the Unitil Employee Health and Welfare Benefits Plan (PBOP Plan), primarily to provide health care and life insurance benefits to retired employees.

In September 2006, the FASB issued SFAS No. 158, “Employers’ Accounting for Defined Benefit Pension and Other Postretirement Plans”, (SFAS No. 158), an amendment of SFAS No. 87, “Employers’ Accounting for Pensions”, SFAS No. 88, “Employers’ Accounting for Settlements and Curtailments of Defined Benefit Pension Plans and for Termination Benefits,” SFAS No. 106, “Employers’ Accounting for Postretirement Benefits other than Pensions” and SFAS No. 132(R), “Employers’ Disclosures about Pensions and Other Postretirement Benefits.” SFAS No. 158 requires companies to record on their balance sheets as an asset or liability the overfunded or underfunded status of their retirement benefit obligations (RBO) based on the projected benefit obligation. The Company has recognized a corresponding Regulatory Asset, to recognize the future collection of these obligations in electric and gas rates.

The Company’s reported costs of providing retirement benefits are dependent upon numerous factors resulting from actual plan experience and assumptions of future experience. The Company has made critical estimates related to actuarial assumptions, including assumptions of expected returns on plan assets, future compensation, health care cost trends, and appropriate discount rates. The Company’s RBO are affected by actual employee demographics, the level of contributions made to the plans, earnings on plan assets, and health care cost trends. Changes made to the provisions of these plans may also affect current and future costs.

The Company’s RBO may also be significantly affected by changes in key actuarial assumptions, including, anticipated rates of return on plan assets and the discount rates used in determining the Company’s RBO. If these assumptions were changed, the resultant change in benefit obligations, fair values of plan assets, funded status and net periodic benefit costs could have a material impact on the Company’s financial statements. The discount rate assumptions used in determining retirement plan costs and retirement plan obligations are based on a market average of long-term bonds that receive one of the two highest ratings given by a recognized rating agency. For the years ended December 31, 2008 and 2007, a change in the discount rate of 0.25% would have resulted in an increase or decrease of approximately $200,000 in the Net Periodic Benefit Cost for the Pension Plan. For the years ended December 31, 2008 and 2007, a 1.0% increase in the assumption of health care cost trend rates would have resulted in increases in the Net Periodic Benefit Cost for the PBOP Plan of $675,000 and $690,000, respectively. Similarly, a 1.0% decrease in the assumption of health care cost trend rates for those same time periods would have resulted in decreases in the Net Periodic Benefit Cost for the PBOP Plan of $531,000 and $539,000, respectively. (See Note 9 to the accompanying Consolidated Financial Statements).

Income Taxes – Provisions for income taxes are calculated in each of the jurisdictions in which the Company operates for each period for which a statement of earnings is presented. This process involves estimating the Company’s current tax liabilities as well as assessing temporary and permanent differences resulting from the timing of the deductions of expenses and recognition of taxable income for tax and book accounting purposes. These temporary differences result in deferred tax assets and liabilities, which are included in the Company’s consolidated balance sheets. The Company accounts for income tax assets, liabilities and expenses in accordance with FASB Statement No. 109, “Accounting for Income Taxes” (SFAS No. 109) and under FASB Interpretation No. 48, “Accounting for Uncertainty in Income Taxes” (FIN 48), an interpretation of FAS 109.

Depreciation – Depreciation expense is calculated on a group straight-line basis based on the useful lives of assets and judgment is involved when estimating the useful lives of certain assets. The Company conducts independent depreciation studies on a periodic basis as part of the regulatory ratemaking process and considers the results presented in these studies in determining the useful lives of the Company’s fixed assets. A change in the estimated useful lives of these assets could have a material impact on the Company’s consolidated financial statements.

Commitments and Contingencies – The Company’s accounting policy is to record and/or disclose commitments and contingencies in accordance with SFAS No. 5. SFAS No. 5 applies to an existing condition, situation, or set of circumstances involving uncertainty as to possible loss that will ultimately be resolved when one or more future

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events occur or fail to occur. As of June 30, 2009, the Company is not aware of any material commitments or contingencies other than those disclosed in the Commitments and Contingencies footnote to the Company’s consolidated financial statements below.

Refer to “Recently Issued Accounting Pronouncements in Note 1 of the Notes of Consolidated Financial Statements for information regarding recently issued accounting standards.

LABOR RELATIONS

As of June 30, 2009, 148 of the Company’s employees were represented by labor unions. These employees are covered by collective bargaining agreements. Two agreements expire on May 31, 2010, one agreement expires on June 5, 2010 and one agreement expires on March 31, 2012. The agreements provide discreet salary adjustments, established work practices and uniform benefit packages. The Company expects to successfully negotiate new agreements prior to their expiration dates.

INTEREST RATE RISK

As discussed above, Unitil meets its external financing needs by issuing short-term and long-term debt. The majority of debt outstanding represents long-term notes bearing fixed rates of interest. Changes in market interest rates do not affect interest expense resulting from these outstanding long-term debt securities. However, the Company periodically repays its short-term debt borrowings through the issuance of new long-term debt securities. Changes in market interest rates may affect the interest rate and corresponding interest expense on any new issuances of long-term debt securities. In addition, short-term debt borrowings bear a variable rate of interest. As a result, changes in short-term interest rates will increase or decrease interest expense in future periods. For example, if the average amount of short-term debt outstanding was $25 million for the period of one year, a change in interest rates of 1% would result in a change in annual interest expense of approximately $250,000. The average interest rates on the Company’s short-term borrowings for the three months ended June 30, 2009 and June 30, 2008 were 4.28% and 2.84%, respectively. The average interest rates on the Company’s short-term borrowings for the six months ended June 30, 2009 and June 30, 2008 were 4.53% and 3.40%, respectively.

MARKET RISK

Although Unitil’s three distribution utilities are subject to commodity price risk 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. Additionally, as discussed above and below in Regulatory Matters, the Company has divested its commodity-related contracts and therefore, further reduced its exposure to commodity risk.

REGULATORY MATTERS

Please refer to Note 7 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 8 to the Consolidated Financial Statements in Part I, Item 1 of this report for a discussion of Environmental Matters.

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UNITIL CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF EARNINGS

(Millions except common shares and per share data)

(UNAUDITED)

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

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UNITIL CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Millions)

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

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UNITIL CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS (Cont.)

(Millions)

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

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UNITIL CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Millions)

(UNAUDITED)

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

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UNITIL CORPORATION AND SUBSIDIARY COMPANIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE 1 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

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

On December 1, 2008, the Company purchased: (i) all of the outstanding capital stock of Northern Utilities, a natural gas distribution utility serving customers in Maine and New Hampshire, from Bay State Gas Company (Bay State) and (ii) all of the outstanding capital stock of Granite State, an interstate gas transmission pipeline company primarily serving the needs of Northern Utilities, from NiSource, Inc. (NiSource) pursuant to the Stock Purchase Agreement (SPA) dated as of February 15, 2008 by and among NiSource, Bay State, and Unitil (the “Acquisitions”).

Unitil’s principal business is the local distribution of electricity in the southeastern seacoast and state capital regions of New Hampshire and the greater Fitchburg area of north central Massachusetts and the local distribution of natural gas in southeastern New Hampshire, portions of southern and central Maine and in the greater Fitchburg area of north central Massachusetts. Unitil has three distribution utility subsidiaries, 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 a natural gas transportation pipeline, operating 87 miles of underground gas transmission pipeline primarily located in Maine, New Hampshire and Massachusetts. Granite State provides Northern Utilities with interconnection to three major natural gas pipelines and access to domestic natural gas supplies in the south and Canadian natural gas supplies in the north. Granite State derives its revenues principally from the 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, Unitil Power ceased being the wholesale supplier of Unitil Energy on May 1, 2003 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.

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. Usource, Inc. and Usource L.L.C. (collectively, Usource) are wholly-owned subsidiaries of Unitil Resources. Usource provides brokering and advisory services to large commercial and industrial customers in the northeastern United States.

Basis of Presentation – The accompanying unaudited consolidated financial statements of Unitil have been prepared in accordance with the instructions to Form 10-Q and include all of the information and footnotes required by generally accepted accounting principles. In the opinion of management, all adjustments considered necessary for a fair presentation have been included. The results of operations for the three and six months ended June 30, 2009 are not necessarily indicative of results to be expected for the year ending December 31, 2009. For further information, please refer to Note 1 of Part II to the Consolidated Financial Statements – “Summary of Significant Accounting Policies” of the Company’s Form 10-K for the year ended December 31,

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2008, as filed with the Securities and Exchange Commission (SEC) on February 18, 2008, for a description of the Company’s Basis of Presentation.

As discussed above, the Company acquired Northern Utilities and Granite State on December 1, 2008. Accordingly, the operations of Northern Utilities and Granite State are included in the Company’s consolidated financial statements from the date of acquisition, including the three and six months ended June 30, 2009 but not for the three and six months ended June 30, 2008. See Note 11.

As a result of the acquisitions of Northern Utilities and Granite State on December 1, 2008, consolidated results for the Company in the current period may not be directly comparable to prior period results until such time as the acquisitions are fully reflected in both reporting periods. In particular, the Company expects that consolidated results of operations in future reporting periods will reflect to a greater degree the seasonal nature of natural gas sales by the acquired operating utilities. Accordingly, the Company expects that as a result of the acquisitions, consolidated results of operations will be positively affected during the first and fourth quarters, and negatively affected during the second and third quarters of future reporting years.

Derivatives – The Company has a regulatory approved hedging program for Northern Utilities designed to fix a portion of its gas supply costs for the coming year of service. In order to fix these costs, the Company purchases NYMEX futures that correspond to the associated delivery month. Any gains or losses on the fair value of these derivatives are passed through to ratepayers directly through a regulatory commission approved recovery mechanism. As a result of the ratemaking process, the Company records gains and losses as regulatory liabilities or assets and recognizes such gains or losses in Purchased Gas when recovered in revenues. The Company’s Consolidated Balance Sheets include derivative liabilities related to net unrealized losses on futures contracts in Other Current Liabilities and Noncurrent Liabilities which are offset in Accrued Revenues on the Company’s Consolidated Balance Sheets.

Reclassifications – Based on the Company’s analysis certain amounts previously reported have been reclassified to improve the financial statements’ presentation and to conform to current year presentation, principally including the reclassification of $23.0 million of Noncurrent Assets to Current Assets and $19.9 million of Noncurrent Liabilities to Current Liabilities related to current collections and obligations of Regulatory Assets and Regulatory Liabilities for 2008.

Recently Issued Pronouncements – In May 2009, the Financial Accounting Standards Board (FASB) issued FASB Statement No. 165, “Subsequent Events”, (SFAS No. 165), effective for interim and annual reporting periods ending after June 15, 2009. SFAS No. 165 establishes general standards of accounting for and disclosure of events that occur after the balance sheet date but before financial statements are issued or are available to be issued. The Company adopted SFAS No. 165 and it did not have an impact on the Company’s Consolidated Financial Statements. The Company evaluated all events or transactions that occurred after June 30, 2009 up through July 23, 2009. During this period no material subsequent events came to our attention.

On April 9, 2009, the FASB issued FASB Staff Position No. FAS 107-1 and APB 28-1, “Interim Disclosures about Fair Value of Financial Instruments” (FSP FAS 107-1). FSP FAS 107-1 amends FASB Statement No. 107, “Disclosures about Fair Value of Financial Instruments” to require disclosures about fair value of financial instruments for interim reporting periods of publicly traded companies as well as in annual financial statements. FSG FAS 107-1 also amends Accounting Principles Board Opinion No. 28, “Interim Financial Reporting”, to require those disclosures in summarized financial information at interim reporting periods. FSP FAS 107-1 is effective for interim reporting periods ending after June 15, 2009, with early adoption permitted for periods ending after March 15, 2009. The Company has adopted FSP FAS 107-1 and there was no impact on the Company’s Consolidated Financial Statements. See Note 5 for relevant disclosures on the fair value of the Company’s long-term debt.

On December 30, 2008, the FASB issued FASB Staff Position No. FAS 132(R)-1, “Employers’ Disclosures about Postretirement Benefit Plan Assets”, (FSP FAS 132(R)-1) to provide guidance on an employers’ disclosures about plan assets of a defined benefit pension or other postretirement plan. The disclosures about plan assets required by FSP FAS 132(R)-1 are to be provided for fiscal years ending after December 15, 2009. The Company does not expect that the adoption of FSP FAS 132(R)-1 will have an impact on the Company’s Consolidated Financial Statements.

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NOTE 2 – ACQUISITIONS

As discussed above, on December 1, 2008, the Company purchased (i) all of the outstanding capital stock of Northern Utilities from Bay State and (ii) all of the outstanding capital stock of Granite State from NiSource pursuant to the SPA dated as of February 15, 2008 by and among NiSource, Bay State, and Unitil. The aggregate purchase price for the Acquisitions was $209.2 million, comprised of $160 million in cash, plus an additional working capital adjustment of $49.2 million. The largest component of working capital was approximately $30.0 million of natural gas storage inventory.

The Company accounted for the Acquisitions under the purchase method of accounting for business combinations, in accordance with FASB Statement No. 141, “Business Combinations” (“SFAS No. 141”) and SFAS No. 71. Accordingly, the Company recognized its estimate of the bargain purchase price (see “Plant Acquisition Adjustment” in the table below) at December 1, 2008. The process of valuing the assets, liabilities and transaction, transition and financing costs as a result of the Acquisitions was substantially completed in the second quarter of 2009. As a result, the Company has recognized adjustments to its original estimate of the Plant Acquisition Adjustment (PAA) in the second quarter of 2009.

The adjusted PAA is ($24.2 million), a decrease of $4.1 million from the original estimate of ($28.3 million). The adjusted Transaction and Transition Costs is an increase of $5.4 million over the original estimate, reflecting additional costs to complete the acquisition and financing. Partially offsetting the decrease in the PAA estimate due to the additional Transaction and Transition Costs were subsequent payments, cash settlements between the purchaser and seller and other post-closing adjustments reflecting changes to working capital and Net Utility Plant.

The revised purchase price allocations are as follows:

Purchase Price Allocation

($ Millions)