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Document and Entity Information - shares	9 Months Ended
Document and Entity Information - shares	Sep. 30, 2012	Oct. 19, 2012
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2012
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q3
Trading Symbol	UTL
Entity Registrant Name	UNITIL CORP
Entity Central Index Key	0000755001
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		13,769,825

Consolidated Statements of Earnings - USD ($) shares in Thousands, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Operating Revenues
Gas	$ 20.3	$ 21.2	$ 107.2	$ 112.3
Electric	49.5	50.5	143.0	141.6
Other	1.5	1.5	4.1	4.2
Total Operating Revenues	71.3	73.2	254.3	258.1
Operating Expenses
Purchased Gas	8.6	12.5	54.5	68.0
Purchased Electricity	28.3	31.0	85.1	88.0
Operation and Maintenance	14.4	13.6	42.7	38.3
Conservation & Load Management	2.6	2.2	6.8	5.3
Depreciation and Amortization	8.9	6.9	25.9	22.5
Provisions (Benefit) for Taxes:
Local Property and Other	3.5	3.2	10.7	9.5
Federal and State Income		(1.4)	5.3	3.7
Total Operating Expenses	66.3	68.0	231.0	235.3
Operating Income	5.0	5.2	23.3	22.8
Non-Operating Expenses	0.1	0.2	0.2	0.4
Income Before Interest Expense	4.9	5.0	23.1	22.4
Interest Expense, Net	4.4	6.6	13.9	16.0
Net Income (Loss)	0.5	(1.6)	9.2	6.4
Less: Dividends on Preferred Stock			0.1	0.1
Earnings (Loss) Applicable to Common Shareholders	$ 0.5	$ (1.6)	$ 9.1	$ 6.3
Weighted Average Common Shares Outstanding - Basic (000's)	13,707	10,887	12,318	10,875
Weighted Average Common Shares Outstanding - Diluted (000's)	13,709	10,887	12,321	10,877
Earnings Per Common Share (Basic and Diluted)	$ 0.03	$ (0.15)	$ 0.74	$ 0.58
Dividends Declared Per Share of Common Stock	$ 0.345	$ 0.345	$ 1.380	$ 1.380

Consolidated Balance Sheets - USD ($) $ in Millions	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2011
Utility Plant:
Electric	$ 348.2	$ 333.3	$ 326.6
Gas	398.4	382.3	363.9
Common	30.6	29.8	30.4
Construction Work in Progress	35.8	28.3	41.4
Total Utility Plant	813.0	773.7	762.3
Less: Accumulated Depreciation	277.9	263.0	262.5
Net Utility Plant	535.1	510.7	499.8
Current Assets:
Cash	9.5	7.5	7.9
Accounts Receivable, net	30.7	44.2	30.4
Accrued Revenue	34.6	56.6	35.2
Gas Inventory	12.3	14.8	15.6
Materials and Supplies	3.6	3.6	3.8
Prepayments and Other	4.3	4.5	4.5
Total Current Assets	95.0	131.2	97.4
Noncurrent Assets:
Regulatory Assets	136.9	139.8	130.9
Other Noncurrent Assets	17.0	18.5	20.6
Total Noncurrent Assets	153.9	158.3	151.5
TOTAL ASSETS	784.0	800.2	748.7
Capitalization:
Common Stock Equity	250.9	191.7	181.2
Preferred Stock	2.0	2.0	2.0
Long-Term Debt, Less Current Portion	287.5	287.8	288.0
Total Capitalization	540.4	481.5	471.2
Current Liabilities:
Long-Term Debt, Current Portion	0.5	0.5	0.5
Accounts Payable	17.1	26.4	16.0
Short-Term Debt	24.1	87.9	65.4
Energy Supply Contract Obligations	13.4	21.1	21.8
Taxes Payable	0.5	1.0	0.6
Other Current Liabilities	21.4	17.5	22.5
Total Current Liabilities	77.0	154.4	126.8
Deferred Income Taxes	51.7	46.3	46.7
Noncurrent Liabilities:
Energy Supply Contract Obligations	3.6	4.2	6.1
Retirement Benefit Obligations	88.9	91.2	74.1
Environmental Obligations	14.5	14.5	14.4
Other Noncurrent Liabilities	7.9	8.1	9.4
Total Noncurrent Liabilities	114.9	118.0	104.0
TOTAL CAPITALIZATION AND LIABILITIES	$ 784.0	$ 800.2	$ 748.7

Consolidated Statements of Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011
Operating Activities:
Net Income	$ 9.2	$ 6.4
Adjustments to Reconcile Net Income to Cash Provided by Operating Activities:
Depreciation and Amortization	25.9	22.5
Deferred Tax Provision	4.9	2.5
Changes in Working Capital Items:
Accounts Receivable	13.5	6.5
Accrued Revenue	22.0	11.5
Gas Inventory	2.5	(5.0)
Accounts Payable	(9.3)	(10.5)
Taxes Refundable / Payable	(0.5)	8.1
Other Changes in Working Capital Items	(1.8)	4.3
Deferred Regulatory and Other Charges	3.6	8.8
Other, net	(8.1)	(5.3)
Cash Provided by Operating Activities	61.9	49.8
Investing Activities:
Property, Plant and Equipment Additions	(47.4)	(42.7)
Cash (Used in) Investing Activities	(47.4)	(42.7)
Financing Activities:
Repayment of Short-Term Debt, net	(63.8)	(1.4)
Repayment of Long-Term Debt, net	(0.3)	(0.3)
Net Increase (Decrease) in Gas Inventory Financing	(1.8)	5.1
Dividends Paid	(12.4)	(11.4)
Proceeds from Issuance of Common Stock, net	66.5	0.7
Other, net	(0.7)	(0.8)
Cash (Used in) Financing Activities	(12.5)	(8.1)
Net Increase (Decrease) in Cash	2.0	(1.0)
Cash at Beginning of Period	7.5	8.9
Cash at End of Period	9.5	7.9
Supplemental Cash Flow Information:
Interest Paid	13.5	13.8
Income Taxes Paid (Refunded)	$ 0.7	$ (7.3)

Summary Of Significant Accounting Policies

9 Months Ended

Sep. 30, 2012

Summary Of Significant Accounting Policies

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.

The Company’s results of operations are expected to reflect the seasonal nature of the natural gas business. Annual gas revenues are substantially realized during the heating season as a result of higher sales of natural 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 result of operations. Sales of electricity are generally less sensitive to weather than natural gas sales, but may also be affected by the weather conditions in both the winter and summer seasons.

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 86 miles of underground gas transmission pipeline primarily located in Maine and New Hampshire. Granite State provides Northern Utilities with interconnection to 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 nine months ended September 30, 2012 are not necessarily indicative of results to be expected for the year ending December 31, 2012. 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, 2011, as filed with the Securities and Exchange Commission (SEC) on February 1, 2012, for a description of the Company’s Basis of Presentation.

Fair Value – The Financial Accounting Standards Board (FASB) Codification defines fair value, and establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (level 1 measurements) and the lowest priority to unobservable inputs (level 3 measurements). The three levels of the fair value hierarchy under the FASB Codification are described below:


Level 1 –		Inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity has the ability to access at the measurement date.

Level 2 –		Valuations based on quoted prices in markets that are not active or for which all significant inputs are observable, either directly or indirectly.

Level 3 –		Prices or valuations that require inputs that are both significant to the fair value measurement and unobservable.

To the extent that valuation is based on models or inputs that are less observable or unobservable in the market, the determination of fair value requires more judgment. Accordingly, the degree of judgment exercised by the Company in determining fair value is greatest for instruments categorized in Level 3. A financial instrument’s level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement.

Fair value is a market-based measure considered from the perspective of a market participant rather than an entity-specific measure. Therefore, even when market assumptions are not readily available, the Company’s own assumptions are set to reflect those that market participants would use in pricing the asset or liability at the measurement date. The Company uses prices and inputs that are current as of the measurement date, including during periods of market dislocation. In periods of market dislocation, the observability of prices and inputs may be reduced for many instruments. This condition could cause an instrument to be reclassified from Level 1 to Level 2 or from Level 2 to Level 3.

There have been no changes in the valuation techniques used during the current period.

Derivatives – The Company has a regulatory commission-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 natural gas futures contracts on the New York Mercantile Exchange (NYMEX) that correspond to the associated delivery month. Any gains or losses resulting from the change in the fair value of these derivatives are passed through to ratepayers directly through a regulatory commission-approved recovery mechanism. The fair value of these derivatives is determined using Level 2 inputs (valuations based on quoted prices available in active markets for similar assets or liabilities, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are directly observable, and inputs derived principally from market data), specifically based on the NYMEX closing prices for outstanding contracts as of the balance sheet date. As a result of the ratemaking process, the Company records gains and losses resulting from the change in fair value of the derivatives as regulatory liabilities or assets, then reclassifies these gains or losses into Purchased Gas when the gains and losses are passed through to customers in accordance with rate reconciling mechanisms.

As of September 30, 2012, September 30, 2011 and December 31, 2011, the Company had 2.1 billion, 1.7 billion and 1.6 billion cubic feet (BCF), respectively, outstanding in natural gas purchase contracts under its hedging program.

The tables below show derivatives, which are part of the regulatory approved hedging program, that are not designated as hedging instruments, under FASB ASC 815-20. As discussed above, the change in fair value related to these derivatives is recorded initially as a Regulatory Asset then reclassified to Purchased Gas in accordance with the recovery mechanism. The tables below include disclosure of the Regulatory Asset and reclassifications from the Regulatory Asset into Purchased Gas.


Fair Value Amount Offset in Regulatory Assets⁽¹⁾, as of:
		Fair Value
(millions) Description	Balance Sheet Location	September 30, 2012		September 30, 2011		December 31, 2011
Natural Gas Futures Contracts	Other Current Liabilities	$	1.0	$	1.2	$	1.7

Natural Gas Futures Contracts	Other Noncurrent Liabilities		0.2		0.3		0.6

Total		$	1.2	$	1.5	$	2.3

⁽¹⁾	The current portion of Regulatory Assets is recorded as Accrued Revenue on the Company’s unaudited Consolidated Balance Sheets.


	Three Months Ended September 30,					Nine Months Ended September 30,
(millions)	2012			2011		2012		2011
Amount of (Gain) / Loss Recognized in Regulatory Assets for Derivatives:
Natural Gas Futures Contracts	$	(0.3	)	$	0.9	$	1.1	$	1.5
Amount of Loss Reclassified into unaudited Consolidated Statements of Earnings⁽²⁾:
Purchased Gas	$	—		$	—	$	2.2	$	1.0

⁽²⁾	These amounts are offset in the unaudited Consolidated Statements of Earnings with Accrued Revenue and therefore there is no effect on earnings.

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.

The Allowance for Doubtful Accounts as of September 30, 2012, September 30, 2011 and December 31, 2011, which are included in Accounts Receivable, net on the accompanying unaudited consolidated balance sheets, were as follows:


	September 30,				December 31,
	2012		2011		2011
Allowance for Doubtful Accounts	$	2.7	$	2.5	$	2.3

Subsequent Events – The Company has evaluated all events or transactions through the date of this filing. During this period, the Company did not have any material subsequent events that impacted its consolidated financial statements.

Recently Issued Pronouncements – There are no recently issued pronouncements applicable to the Company that have not already been adopted.

Common Dividends Declared Per Share

9 Months Ended

Sep. 30, 2012

Common Dividends Declared Per Share

NOTE 2 – COMMON DIVIDENDS DECLARED PER SHARE

Declaration

Date

Date Paid

(Payable)

Shareholder of

Record Date

Dividend

Amount

9/19/12

11/15/12

11/01/12

0.345

6/6/12

08/15/12

08/01/12

0.345

03/22/12

05/15/12

05/01/12

0.345

01/17/12

02/15/12

02/01/12

0.345

09/21/11

11/15/11

11/01/11

0.345

06/16/11

08/15/11

08/01/11

0.345

03/24/11

05/16/11

05/02/11

0.345

01/18/11

02/15/11

02/01/11

0.345

As of September 30, 2012, September 30, 2011 and December 31, 2011, the Company had $4.8 million, $3.8 million and $0.0 million, respectively, of common dividends payable recorded in Other Current Liabilities on its unaudited Consolidated Balance Sheets.

Common Stock And Preferred Stock

9 Months Ended

Sep. 30, 2012

Common Stock And Preferred Stock

NOTE 3 – COMMON STOCK AND PREFERRED STOCK

Common Stock

The Company’s common stock trades under the symbol “UTL”.

The Company had 13,769,376, 10,944,675 and 10,954,065 of common shares outstanding at September 30, 2012, September 30, 2011 and December 31, 2011, respectively.

Unitil Corporation Common Stock Offering – On May 16, 2012, the Company issued and sold 2,760,000 shares of its common stock at a price of $25.25 per share in a registered public offering (Offering). The Company’s net increase to Common Equity and Cash proceeds from the Offering were approximately $65.7 million and were used to make equity capital contributions to the Company’s regulated utility subsidiaries, repay short-term debt and for general corporate purposes.

Dividend Reinvestment and Stock Purchase Plan – During the first nine months of 2012, the Company sold 30,490 shares of its common stock, at an average price of $26.70 per share, in connection with its Dividend Reinvestment and Stock Purchase Plan (DRP) and its 401(k) Plan resulting in net proceeds of approximately $814,200. The DRP provides participants in the plan a method for investing cash dividends on the Company’s common stock and cash payments in additional shares of the Company’s common stock.

Stock Plan – The Company maintains the Unitil Corporation Amended and Restated 2003 Stock Plan (the Stock Plan). Participants in the Stock Plan are selected by the Compensation Committee of the Board of Directors from the Company’s, its subsidiaries’ and its affiliates’ employees, directors and consultants to receive an award of shares of Company common stock, including restricted shares (RS), or of restricted stock units (RSU). The Compensation Committee has the authority to determine the sizes of awards; determine the terms and conditions of awards in a manner consistent with the Stock Plan; construe and interpret the Stock Plan and any agreement or instrument entered into under the Stock Plan as they apply to participants; establish, amend, or waive rules and regulations for the Stock Plan’s administration as they apply to participants; and, subject to the provisions of the Stock Plan, amend the terms and conditions of any outstanding award to the extent such terms and conditions are within the discretion of the Compensation Committee as provided for in the Stock Plan. On April 19, 2012, the Company’s shareholders approved an amendment to the Stock Plan to, among other things, increase the maximum number of shares of common stock available for awards to plan participants.

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. Awards may be grossed up to offset the participant’s tax obligations in connection with the award. 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. The maximum number of shares of restricted stock available for awards to participants under the Stock Plan is 677,500. The maximum aggregate number of shares or restricted stock units 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.

On February 3, 2012, 25,600 restricted shares were issued in conjunction with the Stock Plan with an aggregate market value at the date of issuance of $720,896. There were 53,942 and 52,362 non-vested shares under the Stock Plan as of September 30, 2012 and 2011, respectively. The weighted average grant date fair value of these shares was $24.67 and $22.21, respectively. The compensation expense associated with the issuance of shares under the Stock Plan is being recognized over the vesting period and was $1.1 million and $0.5 million for the nine months ended September 30, 2012 and 2011, respectively. At September 30, 2012, there was approximately $0.8 million of total unrecognized compensation cost under the Stock Plan which is expected to be recognized over approximately 2.6 years. There were 779 restricted shares forfeited and there were no cancellations under the Stock Plan during the nine months ended September 30, 2012.

There were no RSUs issued under the Stock Plan during the nine months ended September 30, 2012. On October 1, 2012, there were 5,470 fully-vested RSUs issued to members of the Company’s Board of Directors. These restricted stock units will 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.

Preferred Stock

Details on preferred stock at September 30, 2012, September 30, 2011 and December 31, 2011 are shown below:


	September 30,				December 31,
	2012		2011		2011
Preferred Stock
Unitil Energy Preferred Stock, Non-Redeemable, Non-Cumulative:
6.00% Series, $100 Par Value,	$	0.2	$	0.2	$	0.2
Fitchburg Preferred Stock, Redeemable, Cumulative:
5.125% Series, $100 Par Value		0.8		0.8		0.8
8.00% Series, $100 Par Value		1.0		1.0		1.0

Total Preferred Stock	$	2.0	$	2.0	$	2.0

Shares Outstanding

September 30,

December 31,

2012

2011

Preferred Stock

Unitil Energy Preferred Stock, Non-Redeemable, Non-Cumulative:

6.00% Series, $100 Par Value,

2,250

2,250

Fitchburg Preferred Stock, Redeemable, Cumulative:

5.125% Series, $100 Par Value

7,823

7,861

8.00% Series, $100 Par Value

9,654

9,696

There were $0.1 million and $0.1 million of total dividends declared on Preferred Stock in the nine months ended September 30, 2012 and September 30, 2011, respectively.

- Definition

The entire disclosure for shareholders' equity, comprised of portions attributable to the parent entity and noncontrolling interest, if any, including other comprehensive income (as applicable). Including, but not limited to: (1) balances of common stock, preferred stock, additional paid-in capital, other capital and retained earnings; (2) accumulated balance for each classification of other comprehensive income and total amount of comprehensive income; (3) amount and nature of changes in separate accounts, including the number of shares authorized and outstanding, number of shares issued upon exercise and conversion, and for other comprehensive income, the adjustments for reclassifications to net income; (4) rights and privileges of each class of stock authorized; (5) basis of treasury stock, if other than cost, and amounts paid and accounting treatment for treasury stock purchased significantly in excess of market; (6) dividends paid or payable per share and in the aggregate for each class of stock for each period presented; (7) dividend restrictions and accumulated preferred dividends in arrears (in aggregate and per share amount); (8) retained earnings appropriations or restrictions, such as dividend restrictions; (9) impact of change in accounting principle, initial adoption of new accounting principle and correction of an error in previously issued financial statements; (10) shares held in trust for Employee Stock Ownership Plan (ESOP); (11) deferred compensation related to issuance of capital stock; (12) note received for issuance of stock; (13) unamortized discount on shares; (14) description, terms, and number of warrants or rights outstanding; (15) shares under subscription and subscription receivables, effective date of new retained earnings after quasi-reorganization and deficit eliminated by quasi-reorganization and, for a period of at least ten years after the effective date, the point in time from which the new retained dates; and (16) retroactive effective of subsequent change in capital structure.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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-Subparagraph (SX 210.4-08.(d),(e))
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-Name Accounting Standards Codification
-Topic 505
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-Section 50
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-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21488-112644

Reference 5: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.29-31)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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-Section S99
-Paragraph 4
-Subparagraph (SAB TOPIC 4.C)
-URI http://asc.fasb.org/extlink&oid=6959260&loc=d3e187143-122770

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21506-112644

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.3-04)
-URI http://asc.fasb.org/extlink&oid=6959260&loc=d3e187085-122770

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 30
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6405834&loc=d3e23285-112656

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21475-112644

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Preferred Stock
-URI http://asc.fasb.org/extlink&oid=6521494

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21463-112644

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 11
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21564-112644

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 43
-Section B
-Paragraph 7, 11A
-Chapter 1
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 15: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Principles Board Opinion (APB)
-Number 12
-Paragraph 10
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 16: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 5
-Paragraph 15
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 17: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph d
-Article 4

Reference 18: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 02
-Paragraph 29, 30, 31
-Article 5

Reference 19: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 4
-Section E

Reference 20: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Article 4

Reference 21: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 4
-Section C

Reference 22: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 129
-Paragraph 2, 3, 4, 5, 6, 7, 8
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 23: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 04
-Article 3

+ Details

Long-Term Debt, Credit Arrangements And Guarantees

9 Months Ended

Sep. 30, 2012

Long-Term Debt, Credit Arrangements And Guarantees

NOTE 4 – LONG-TERM DEBT, CREDIT ARRANGEMENTS AND GUARANTEES

Long-Term Debt

Details on long-term debt at September 30, 2012, September 30, 2011 and December 31, 2011 are shown below ($ Millions):


	September 30,				December 31,
	2012		2011		2011
Unitil Corporation Senior Notes:
6.33% Notes, Due May 1, 2022	$	20.0	$	20.0	$	20.0

Unitil Energy Systems, Inc.:
First Mortgage Bonds:
5.24% Series, Due March 2, 2020		15.0		15.0		15.0
8.49% Series, Due October 14, 2024		15.0		15.0		15.0
6.96% Series, Due September 1, 2028		20.0		20.0		20.0
8.00% Series, Due May 1, 2031		15.0		15.0		15.0
6.32% Series, Due September 15, 2036		15.0		15.0		15.0

Fitchburg Gas and Electric Light Company:
Long-Term Notes:
6.75% Notes, Due November 30, 2023		19.0		19.0		19.0
7.37% Notes, Due January 15, 2029		12.0		12.0		12.0
7.98% Notes, Due June 1, 2031		14.0		14.0		14.0
6.79% Notes, Due October 15, 2025		10.0		10.0		10.0
5.90% Notes, Due December 15, 2030		15.0		15.0		15.0

Northern Utilities Senior Notes:
6.95% Senior Notes, Due December 3, 2018		30.0		30.0		30.0
5.29% Senior Notes, Due March 2, 2020		25.0		25.0		25.0
7.72% Senior Notes, Due December 3, 2038		50.0		50.0		50.0

Granite Senior Notes:
7.15% Senior Notes, Due December 15, 2018		10.0		10.0		10.0

Unitil Realty Corp.:
Senior Secured Notes:
8.00% Notes, Due Through August 1, 2017		3.0		3.5		3.3

Total Long-Term Debt		288.0		288.5		288.3
Less: Current Portion		0.5		0.5		0.5

Total Long-term Debt, Less Current Portion	$	287.5	$	288.0	$	287.8

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


(Millions)	September 30,				December 31,
	2012		2011		2011
Estimated Fair Value of Long-Term Debt	$	343.6	$	338.0	$	338.7

Credit Arrangements

Unitil has a revolving credit facility with a group of banks that extends to October 8, 2013. Effective July 24, 2012, Unitil reduced the borrowing limit under its revolving credit facility from $115 million to $60 million. The new $60 million borrowing limit reflects reduced borrowing needs as a result of the recent repayment of short-term debt with the proceeds of the Company’s public equity offering in May 2012.

The following table details the borrowing limits, amounts outstanding and amounts available under the revolving credit facility as of September 30, 2012, September 30, 2011 and December 31, 2011:


	September 30,				December 31,
Revolving Credit Facility (millions)	2012		2011		2011
Limit	$	60.0	$	80.0	$	115.0
Outstanding	$	24.1	$	65.4	$	87.9
Available	$	35.9	$	14.6	$	27.1

The revolving credit facility contains customary terms and conditions for credit facilities of this type, including, without limitation, covenants restricting the Company’s ability to incur liens, merge or consolidate with another entity or change its line of business. The revolving credit agreement also contains a covenant restricting the Company’s ability to permit funded debt to exceed 65% of capitalization at the end of each fiscal quarter. As of September 30, 2012, September 30, 2011 and December 31, 2011, the Company was in compliance with the financial covenants contained in the revolving credit agreement.

Northern Utilities enters into asset management agreements under which Northern Utilities releases certain natural gas pipeline and storage assets, resells the natural gas storage inventory to an asset manager and subsequently repurchases the inventory over the course of the natural gas heating season at the same price at which it sold the natural gas inventory to the asset manager. There were obligations of $10.6 million, $13.0 million and $14.9 million outstanding at September 30, 2012, September 30, 2011 and December 31, 2011, respectively, related to these asset management agreements. There were no amounts of natural gas inventory released in September 2012 and payable in October 2012 that were recorded in Accounts Payable at September 30, 2012. There were no amounts of natural gas inventory released in September 2011 and payable in October 2011 that were recorded in Accounts Payable at September 30, 2011. The amount of natural gas inventory released in December 2011, which was payable in January 2012, is $2.5 million and recorded in Accounts Payable at December 31, 2011.

Guarantees

The Company also 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 the duration of these guarantees. As of September 30, 2012, there were approximately $20.6 million of guarantees outstanding and the longest term guarantee extends through February 2014.

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 September 30, 2012, the principal amount outstanding for the 8% Unitil Realty notes was $3.0 million, and the principal amount outstanding for the 7.15% Granite State notes was $10.0 million.

- Definition

The entire disclosure for information about short-term and long-term debt arrangements, which includes amounts of borrowings under each line of credit, note payable, commercial paper issue, bonds indenture, debenture issue, own-share lending arrangements and any other contractual agreement to repay funds, and about the underlying arrangements, rationale for a classification as long-term, including repayment terms, interest rates, collateral provided, restrictions on use of assets and activities, whether or not in compliance with debt covenants, and other matters important to users of the financial statements, such as the effects of refinancing and noncompliance with debt covenants.

+ References + Details

Segment Information

9 Months Ended

Sep. 30, 2012

Segment Information

NOTE 5 – SEGMENT INFORMATION

The following table provides significant segment financial data for the three and nine months ended September 30, 2012 and September 30, 2011 (Millions):


Three Months Ended September 30, 2012	Electric		Gas			Other			Non-Regulated		Total
Revenues	$	49.5	$	20.3		$	—		$	1.5	$	71.3
Segment Profit (Loss)		2.5		(2.4	)		—			0.4		0.5
Capital Expenditures		6.1		16.8			0.6			—		23.5

Three Months Ended September 30, 2011
Revenues	$	50.5	$	21.2		$	—		$	1.5	$	73.2
Segment Profit (Loss)		2.3		(4.2	)		(0.1	)		0.4		(1.6	)
Capital Expenditures		6.7		9.9			1.0			—		17.6

Nine Months Ended September 30, 2012
Revenues	$	143.0	$	107.2		$	—		$	4.1	$	254.3
Segment Profit		5.1		3.0			—			1.0		9.1
Capital Expenditures		15.5		29.9			2.0			—		47.4
Segment Assets		377.9		394.1			5.8			6.2		784.0

Nine Months Ended September 30, 2011
Revenues	$	141.6	$	112.3		$	—		$	4.2	$	258.1
Segment Profit (Loss)		5.6		(0.4	)		(0.2	)		1.3		6.3
Capital Expenditures		16.5		23.9			2.3			—		42.7
Segment Assets		368.9		367.5			6.4			5.9		748.7

- Definition

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 34
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8981-108599

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 41
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9038-108599

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 33
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8971-108599

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 12
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8595-108599

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
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-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8380-108599

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
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Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 40
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9031-108599

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9054-108599

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-Name Accounting Standards Codification
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-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8538-108599

Reference 12: http://www.xbrl.org/2003/role/presentationRef
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Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8924-108599

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
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-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8906-108599

Reference 15: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 131
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Regulatory Matters

9 Months Ended

Sep. 30, 2012

Regulatory Matters

NOTE 6 – REGULATORY MATTERS

UNITIL’S REGULATORY MATTERS ARE DESCRIBED IN NOTE 5 TO THE FINANCIAL STATEMENTS IN ITEM 8 OF PART II OF UNITIL CORPORATION’S FORM 10-K FOR DECEMBER 31, 2011 AS FILED WITH THE SECURITIES AND EXCHANGE COMMISSION ON FEBRUARY 1, 2012.

Regulatory Matters

Fitchburg – Increase in Base Rates Approved – On August 1, 2011, the Massachusetts Department of Public Utilities (MDPU) issued an order approving increases of $3.3 million and $3.7 million in annual distribution revenues for Fitchburg’s electric and gas divisions, respectively. The MDPU also approved revenue decoupling mechanisms and a return on equity of 9.2% for both the electric and gas divisions of Fitchburg. The rate increase for Fitchburg’s electric division included the recovery of $11.4 million of previously deferred emergency storm restoration costs associated with the December 2008 ice storm, which costs are to be amortized and recovered over seven (7) years without carrying costs. The order provides resolution to the open regulatory matters concerning the ratemaking treatment and cost recovery related to the December 2008 ice storm event.

Granite State – Increase in Base Rates Filed – Granite State has in place a FERC approved rate settlement agreement under which it is permitted to file incremental annual rate adjustment filings to recover the revenue requirements for certain specified future capital cost additions to transmission plant projects totaling up to $11.4 million. Of the $11.4 million, $1.6 million has been expended and is being recovered in the 2011 approved rates. On June 29, 2012, Granite State submitted to the FERC an incremental annual rate adjustment filing of $0.3 million due to capital costs additions of $2.4 million, with rates effective August 1, 2012. On July 27 the FERC accepted the tariffs as proposed.

Unitil Energy – Increase in Base Rates Approved – On April 26, 2011, the New Hampshire Public Utilities Commission (NHPUC) approved a final rate settlement which makes permanent a temporary increase of $5.2 million in annual revenue effective July 1, 2010, and provided for an additional increase of $5.0 million in annual revenue effective May 1, 2011.

The settlement extends through May 1, 2016 and provides for a long-term rate plan and earnings sharing mechanism, with estimated future increases of $1.5 million to $2.0 million in annual revenue to occur on May 1, 2012, May 1, 2013 and May 1, 2014, to support Unitil Energy’s continued capital improvements to its distribution system. The rate plan allows Unitil to file for additional rate relief if its return on equity is less than 7% and a sharing of earnings with customers if its return on equity is greater than 10% in a calendar year.

Unitil Energy filed its first step adjustment filing for $1.47 million on February 29, 2012 for implementation on May 1, 2012, which included rate increases to recover the increased spending for its vegetation management program and reliability enhancement program. The adjustment filing was approved by the NHPUC with minor modifications.

Northern Utilities – Increase in Base Rates Approved, Settlement Reached – In May 2011, Northern Utilities filed two separate rate cases with the NHPUC and Maine Public Utilities Commission (MPUC) requesting approval to increase its natural gas distribution base rates in New Hampshire and Maine, respectively. The Maine rate case was settled with the Office of Public Advocate and approved by the MPUC in November 2011. It provided for a $7.8 million permanent increase in annual distribution revenue for Northern Utilities’ Maine operations, effective January 1, 2012, and an additional permanent increase in annual distribution revenue of $0.85 million to recover the costs of 2011 cast iron pipe replacement capital spending effective May 1, 2012. The settlement precludes Northern Utilities from filing for a new base rate increase with an effective date prior to January 1, 2014.

On March 22, 2012, Northern Utilities, the Staff of the NHPUC and the Office of Consumer Advocate agreed to a settlement agreement providing for a $3.7 million permanent increase in annual revenues, effective May 1, 2012. The NHPUC issued an order approving the settlement agreement on April 24, 2012. Permanent rates were reconciled back to August 1, 2011.

Fitchburg – Electric Operations – On November 30, 2011, Fitchburg submitted its annual reconciliation of costs and revenues for transition and transmission under its restructuring plan. The filing includes the reconciliation of costs and revenues for a number of surcharges and cost factors which are under individual review in separate proceedings before the MDPU, including the Pension/PBOP Adjustment, Residential Assistance Adjustment Factor, Net Metering Recovery Surcharge, Attorney General Consultant Expense Factor and Revenue Decoupling Adjustment Factor. The rates were approved effective January 1, 2012, subject to reconciliation pending investigation by the MDPU. This matter, as well as Fitchburg’s 2009 and 2010 annual reconciliation filings, was approved by Order on April 25, 2012.

Fitchburg – Gas Operations – On November 2, 2011, the Massachusetts Supreme Judicial Court (SJC) issued its decision vacating an MDPU order issued on November 2, 2009 which had ordered Fitchburg to refund $4.6 million of natural gas costs, plus interest. The SJC ordered instead, a $0.2 million refund, plus interest. The Company had previously recorded a pre-tax charge to earnings and recognized a Regulatory Liability of $4.9 million in the fourth quarter of 2009 based on the MDPU’s original order. As a result of the decision, the Regulatory Liability was adjusted and the Company recognized a credit of $4.7 million in the fourth quarter of 2011.

The Company began the recoupment of the amounts previously refunded, with interest, effective January 1, 2012. In order to minimize the rate impact on customers, the recoupment is scheduled to occur over three consecutive heating seasons, beginning January 1, 2012.

Fitchburg – Storm Cost Deferral Petition – On December 16, 2011, Fitchburg filed a request with the MDPU for authorization to defer, for future recovery in rates, the costs incurred to perform storm-related emergency repairs on its electric distribution system as a result of two recent storms, Tropical Storm Irene, which occurred on August 28, 2011, and a severe snow storm, which occurred on October 29-30, 2011. Fitchburg estimates that, including capitalized amounts, it incurred $1.5 million in costs for Tropical Storm Irene and $3.3 million in costs for the October 2011 snow storm. The Company has requested approval to defer and accrue carrying charges on approximately $4.3 million of the storm costs that were not capitalized into utility plant. On May 1, 2012 the MDPU approved the request to defer the storm costs and ordered that the issue of carrying charges would be addressed in the Company’s next base rate proceeding.

Fitchburg – Service Quality – On March 1, 2012, Fitchburg submitted its 2011 Service Quality Reports for both its gas and electric divisions. Fitchburg reported that it met or exceeded its benchmarks for service quality performance in all metrics for both its gas and electric divisions. On January 13, 2012, the MDPU issued its order approving the 2010 Service Quality Report for Fitchburg’s gas division. The 2010 Service Quality report for Fitchburg’s electric division remains pending.

Unitil Energy – 2011 Storm Costs – On December 16, 2011, Unitil Energy filed a petition with the NHPUC to increase its storm recovery adjustment factor effective May 1, 2012. The increase would allow the Company to recover the approximately $4.4 million of costs of repairing damage to its electrical system resulting from the August 2011 Tropical Storm Irene and the October 2011 snow storm. The NHPUC Staff audited the costs and filed a memorandum with the NHPUC recommending that the costs be recovered by the Company over a five year period with carrying costs of 4.52%, subject to a full reconciliation of all costs recovered. The Company accepted the Staff recommendation. On April 24, 2012, the NHPUC issued an order approving the recommendation of the Staff.

Unitil Energy – Billing Adjustment – In August 2011, Unitil Energy and one of its larger customers in New Hampshire entered into an agreement regarding a billing error that resulted from a transformer connected to the customer’s meter, which had been mislabeled by the manufacturer, and caused Unitil Energy to overcharge the customer for bills issued from October 2004 through January 2011. The amount of the customer’s overpayment was calculated to be $1.8 million. As a result of the settlement, Unitil Energy reimbursed the customer $1.8 million plus $0.3 million of interest. The Company recognized a non-recurring charge of $0.4 million for distribution charges plus interest in 2011.

As a result of this metering issue, which was discovered in February 2011, certain other customers in the Company’s service areas were under-billed from October 2004 through January 2011 for supply-related charges. Accordingly, the Company requested authorization from the NHPUC to adjust reconciling account balances and process the billing correction. A settlement agreement between Unitil Energy, the Office of Consumer Advocate and the NHPUC Staff has been filed with the NHPUC. The settlement provides for recovery by the Company from its under-billed customers of approximately $1.4 million of the amount it had reimbursed the large customer. The settlement is pending approval before the NHPUC.

Unitil Energy – Annual Rate Reconciliation Filing – On June 15, 2012, Unitil Energy filed its annual reconciliation and rate filing, for rates effective August 1, 2012, including reconciliation of prior year costs and revenues. This filing was approved by the NHPUC on July 20, 2012 with minor modifications.

Northern Utilities – Cast Iron Pipe Replacement Program – On July 30, 2010, the MPUC approved a settlement agreement providing for an accelerated replacement program for cast iron distribution pipe remaining in portions of Northern Utilities’ Maine service areas. Under the agreement, Northern Utilities will proceed with a comprehensive upgrade and replacement program (the Program), which will provide for the systematic replacement of cast iron, wrought iron and bare steel pipe in Northern Utilities’ natural gas distribution system in Portland and Westbrook, Maine and the conversion of the system to intermediate pressure. The agreement establishes the objective of completing the Program by the end of the 2024 construction season.

Unitil Corporation – FERC Audit – On November 3, 2011, the FERC commenced an audit of Unitil Corporation, including its associated service company and its electric and natural gas distribution companies. Among other requirements, the audit will evaluate the Company’s compliance with: i) cross-subsidization restrictions on affiliate transactions; ii) regulations under the Energy Policy Act of 2005; and the iii) uniform system of accounts for centralized service companies. The Company expects the final audit report will be issued in the fourth quarter of 2012.

Legal Proceedings

The Company is involved in legal and administrative proceedings and claims of various types, 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 impact on the Company’s financial position.

A putative class action complaint was filed against Fitchburg on January 7, 2009 in Worcester Superior Court in Worcester, Massachusetts, captioned Bellerman v. Fitchburg Gas and Electric Light Company. On April 1, 2009, an Amended Complaint was filed in Worcester Superior Court and served on Fitchburg. The Amended Complaint seeks an unspecified amount of damages, including the cost of temporary housing and alternative fuel sources, emotional and physical pain and suffering and property damages allegedly incurred by customers in connection with the loss of electric service during the ice storm in Fitchburg’s service areas in December, 2008. The Amended Complaint includes M.G.L. ch. 93A claims for purported unfair and deceptive trade practices related to the December 2008 ice storm. On September 4, 2009, the Superior Court issued its order on the Company’s Motion to Dismiss the Complaint, granting it in part and denying it in part. The Company anticipates that the court will decide whether the lawsuit is appropriate for class action treatment in late 2012. The Company continues to believe the suit is without merit and will defend itself vigorously.

Environmental Matters

9 Months Ended

Sep. 30, 2012

Environmental Matters

NOTE 7 – ENVIRONMENTAL MATTERS

UNITIL’S ENVIRONMENTAL MATTERS ARE DESCRIBED IN NOTE 5 TO THE FINANCIAL STATEMENTS IN ITEM 8 OF PART II OF UNITIL CORPORATION’S FORM 10-K FOR DECEMBER 31, 2011 AS FILED WITH THE SECURITIES AND EXCHANGE COMMISSION ON FEBRUARY 1, 2012.

The Company’s past and present operations include activities that are generally subject to extensive and complex federal and state environmental laws and regulations including laws and regulations related to pipeline safety. The Company believes it is in substantial compliance with applicable environmental, health and safety laws and regulations, and the Company believes that as of September 30, 2012, there were no material losses reasonably likely to be incurred in excess of recorded amounts. However, there can be no assurance that significant costs and liabilities will not be incurred in the future. It is possible that other developments, such as increased stringent federal, state or local environmental health and safety laws and regulations, could result in increased compliance costs that we cannot currently quantify and that affect our operations.

Fitchburg is in the process of developing long-range plans for a feasible permanent remediation solution of a former manufactured gas plant (MGP) site at Sawyer Passway, located in Fitchburg, Massachusetts, including alternatives for re-use of the site. Included in Environmental Obligations on the Company’s unaudited Consolidated Balance Sheet at September 30, 2012 are accrued liabilities totaling $12.0 million related to estimated future cleanup costs for permanent remediation of the Sawyer Passway site. The amounts recorded do not assume any amounts are recoverable from insurance companies or other third parties. 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, without carrying costs. Fitchburg had filed suit against several of its former insurance carriers seeking coverage for past and future environmental response costs at the site. In January 2011, Fitchburg settled with the remaining insurance carriers for approximately $2.0 million and received these payments in the first quarter of 2011. Any recovery that Fitchburg receives from insurance or third-parties with respect to environmental response costs, net of the unrecovered costs associated therewith, are shared equally between Fitchburg and its gas customers.

Also included in Environmental Obligations on the Company’s Consolidated Balance Sheet at September 30, 2012 are accrued liabilities totaling $2.5 million associated with Northern Utilities’ environmental remediation obligations for former MGP sites. In addition to the amounts noted above, there are $0.3 million of accrued liabilities in Other Current Liabilities on the Company’s Consolidated Balance Sheet at September 30, 2012 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.

The Company’s ultimate liability for future environmental remediation costs, including MGP site costs, may vary from estimates, which may be adjusted as new information or future developments become available. Based on the Company’s 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. It is possible that other developments, such as increased stringent federal, state or local environmental health and safety laws and regulations, could result in increased compliance costs that we cannot currently quantify.

- Definition

The entire disclosure for environmental loss contingencies, such as presence of hazardous waste, relevant information from reports issued by regulators, and estimated costs to achieve compliance with regulatory requirements. This element may be used for all of an entity's disclosures about environmental loss contingencies.

+ References + Details

Income Taxes

9 Months Ended

Sep. 30, 2012

Income Taxes

NOTE 8: INCOME TAXES

The Company bills its customers for sales tax in Massachusetts and Maine and consumption tax in New Hampshire. These taxes are remitted to the appropriate departments of revenue in each state and are excluded from revenues on the Company’s unaudited Consolidated Statements of Earnings.

The Company filed its tax returns for the year ended December 31, 2011 with the Internal Revenue Service (IRS) in September 2012 in which it recognized a net operating loss (NOL) of $12.4 million for income tax purposes principally due to bonus depreciation deductions allowed in the period. In total for tax periods ended before December 31, 2011, the Company has generated federal and state NOL carryforward assets for income tax purposes of $9.3 million to offset against taxes payable in future periods. If unused, the Company’s state NOL carryforward assets will begin to expire in 2019 and the federal NOL carryforward assets will begin to expire in 2029. In addition, for periods ended before December 31, 2011, the Company had $1.5 million of Alternative Minimum Tax (AMT) credit carryforwards to offset future taxes payable indefinitely.

According to Internal Revenue Code rules, NOL refunds in excess of $2.0 million fall under the jurisdiction of the Joint Committee of Congress (Joint Committee) and are subject to review by the IRS and attorneys of the Joint Committee. As a result, the Company, on April 1, 2011, received notice that its federal income tax return filing for the year ended December 31, 2009 would be under examination by the IRS. The IRS has performed all fieldwork procedures and the Company and the IRS have entered into a settlement, pending approval of the Joint Committee, for certain timing items, originally reported in 2009, to be deducted in future periods. The result of the settlement agreement did not have a material impact on the Company’s consolidated financial position or results of operations. The settlement has been submitted to the Joint Committee where approval is pending.

The Company evaluated its tax positions at December 31, 2011 and for the current interim reporting period ended September 30, 2012 in accordance with the FASB Codification, and has concluded that no adjustment for recognition, derecognition, settlement and foreseeable future events to any unrecognized tax liabilities or assets as defined by the FASB Codification is required. The Company does not have any unrecognized tax positions for which it is reasonably possible that the total amounts recognized will significantly change within the next 12 months. The Company remains subject to examination by Federal, Maine, Massachusetts, and New Hampshire tax authorities for the tax periods ended December 31, 2009; December 31, 2010; and December 31, 2011.

- Definition

The entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information.

+ References

+ Details

Retirement Benefit Obligations

9 Months Ended

Sep. 30, 2012

Retirement Benefit Obligations

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 Supplemental Executive Retirement Plan (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, 2011 as filed with the SEC on February 1, 2012 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:


	2012			2011
Used to Determine Plan Costs
Discount Rate		4.60	%		5.35	%
Rate of Compensation Increase		3.00	%		3.50	%
Expected Long-term rate of return on plan assets		8.50	%		8.50	%
Health Care Cost Trend Rate Assumed for Next Year		6.50	%		7.00	%
Ultimate Health Care Cost Trend Rate		4.00	%		4.00	%
Year that Ultimate Health Care Cost Trend Rate is reached		2017			2017

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


	Pension Plan						PBOP Plan						SERP
Three Months Ended September 30,	2012			2011			2012			2011			2012		2011
Service Cost	$	807		$	735		$	517		$	479		$	72	$	71
Interest Cost		1,158			1,171			576			570			53		57
Expected Return on Plan Assets		(1,347	)		(1,210	)		(174	)		(204	)		—		—
Prior Service Cost Amortization		47			62			432			432			3		3
Transition Obligation Amortization		—			—			5			5			—		—
Actuarial Loss Amortization		904			783			32			—			16		19

Sub-total		1,569			1,541			1,388			1,282			144		150
Amounts Capitalized and Deferred		(703	)		(874	)		(571	)		(683	)		—		—

Net Periodic Benefit Cost Recognized	$	866		$	667		$	817		$	599		$	144	$	150


	Pension Plan						PBOP Plan						SERP
Nine Months Ended September 30,	2012			2011			2012			2011			2012		2011
Service Cost	$	2,420		$	2,206		$	1,550		$	1,438		$	217	$	214
Interest Cost		3,475			3,513			1,727			1,709			158		170
Expected Return on Plan Assets		(4,042	)		(3,630	)		(521	)		(613	)		—		—
Prior Service Cost Amortization		141			187			1,296			1,296			9		8
Transition Obligation Amortization		—			—			16			16			—		—
Actuarial Loss Amortization		2,712			2,349			97			—			47		59

Sub-total		4,706			4,625			4,165			3,846			431		451
Amounts Capitalized and Deferred		(1,984	)		(2,055	)		(1,551	)		(1,317	)		—		—

Net Periodic Benefit Cost Recognized	$	2,722		$	2,570		$	2,614		$	2,529		$	431	$	451

Employer Contributions

As of September 30, 2012, the Company had made $9.4 million of contributions to its Pension Plan in 2012. The Company, along with its subsidiaries, expects to continue to make contributions to its Pension Plan in 2012 and future years at minimum required and discretionary funding levels consistent with the amounts recovered in the distribution utilities’ rates for these Pension Plan costs.

As of September 30, 2012, the Company had made $2.2 million and $40,000 of contributions to the PBOP Plan and the SERP, respectively, in 2012. The Company presently anticipates contributing an additional $13,000 to the SERP in 2012.

- Definition

The entire disclosure for pension and other postretirement benefits.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-URI http://asc.fasb.org/topic&trid=2235017

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Implementation Guide (Q and A)
-Number FAS88
-Paragraph 63
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5
-Subparagraph b
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 106
-Paragraph 518
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5
-Subparagraph a
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number 03-2
-Paragraph 8
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 87
-Paragraph 264
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5
-Subparagraph q
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5
-Subparagraph h
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 8
-Subparagraph m
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5, 6, 7, 8
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 158
-Paragraph 7, 21, 22
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Staff Position (FSP)
-Number FAS106-2
-Paragraph 20, 21, 22
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Principles Board Opinion (APB)
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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Summary Of Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2012

Nature of Operations

Basis of Presentation

Fair Value


Level 1 –		Inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity has the ability to access at the measurement date.

Level 2 –		Valuations based on quoted prices in markets that are not active or for which all significant inputs are observable, either directly or indirectly.

Level 3 –		Prices or valuations that require inputs that are both significant to the fair value measurement and unobservable.

There have been no changes in the valuation techniques used during the current period.

Derivatives


Fair Value Amount Offset in Regulatory Assets⁽¹⁾, as of:
		Fair Value
(millions) Description	Balance Sheet Location	September 30, 2012		September 30, 2011		December 31, 2011
Natural Gas Futures Contracts	Other Current Liabilities	$	1.0	$	1.2	$	1.7

Natural Gas Futures Contracts	Other Noncurrent Liabilities		0.2		0.3		0.6

Total		$	1.2	$	1.5	$	2.3

⁽¹⁾	The current portion of Regulatory Assets is recorded as Accrued Revenue on the Company’s unaudited Consolidated Balance Sheets.


	Three Months Ended September 30,					Nine Months Ended September 30,
(millions)	2012			2011		2012		2011
Amount of (Gain) / Loss Recognized in Regulatory Assets for Derivatives:
Natural Gas Futures Contracts	$	(0.3	)	$	0.9	$	1.1	$	1.5
Amount of Loss Reclassified into unaudited Consolidated Statements of Earnings⁽²⁾:
Purchased Gas	$	—		$	—	$	2.2	$	1.0

⁽²⁾	These amounts are offset in the unaudited Consolidated Statements of Earnings with Accrued Revenue and therefore there is no effect on earnings.

Allowance for Doubtful Accounts

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.


	September 30,				December 31,
	2012		2011		2011
Allowance for Doubtful Accounts	$	2.7	$	2.5	$	2.3

Subsequent Events

Recently Issued Pronouncements

Recently Issued Pronouncements – There are no recently issued pronouncements applicable to the Company that have not already been adopted.

- Definition

Disclosure of accounting policy for its derivative instruments and hedging activities.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6367646&loc=d3e18780-107790

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=7476318&loc=d3e41620-113959

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(n))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=7476318&loc=SL5579240-113959

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=7476318&loc=SL5579245-113959

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=7476318&loc=d3e41675-113959

Reference 7: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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-Section 50
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-URI http://asc.fasb.org/extlink&oid=7476318&loc=d3e41638-113959

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 39
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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 44
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph n
-Article 4

+ Details

Summary Of Significant Accounting Policies (Tables)

9 Months Ended

Sep. 30, 2012

Fair Value Offset in Regulatory Assets

The tables below include disclosure of the Regulatory Asset and reclassifications from the Regulatory Asset into Purchased Gas.


Fair Value Amount Offset in Regulatory Assets⁽¹⁾, as of:
		Fair Value
(millions) Description	Balance Sheet Location	September 30, 2012		September 30, 2011		December 31, 2011
Natural Gas Futures Contracts	Other Current Liabilities	$	1.0	$	1.2	$	1.7

Natural Gas Futures Contracts	Other Noncurrent Liabilities		0.2		0.3		0.6

Total		$	1.2	$	1.5	$	2.3

⁽¹⁾	The current portion of Regulatory Assets is recorded as Accrued Revenue on the Company’s unaudited Consolidated Balance Sheets.

Regulatory Assets and Reclassification From the Regulatory Asset into Purchased Gas


	Three Months Ended September 30,					Nine Months Ended September 30,
(millions)	2012			2011		2012		2011
Amount of (Gain) / Loss Recognized in Regulatory Assets for Derivatives:
Natural Gas Futures Contracts	$	(0.3	)	$	0.9	$	1.1	$	1.5
Amount of Loss Reclassified into unaudited Consolidated Statements of Earnings⁽²⁾:
Purchased Gas	$	—		$	—	$	2.2	$	1.0

⁽²⁾	These amounts are offset in the unaudited Consolidated Statements of Earnings with Accrued Revenue and therefore there is no effect on earnings.

Allowance for Doubtful Accounts Included in Accounts Receivable, Net


	September 30,				December 31,
	2012		2011		2011
Allowance for Doubtful Accounts	$	2.7	$	2.5	$	2.3

Common Dividends Declared Per Share (Tables)

9 Months Ended

Sep. 30, 2012

Common Dividends Declared Per Share

Declaration

Date

Date Paid

(Payable)

Shareholder of

Record Date

Dividend

Amount

9/19/12

11/15/12

11/01/12

0.345

6/6/12

08/15/12

08/01/12

0.345

03/22/12

05/15/12

05/01/12

0.345

01/17/12

02/15/12

02/01/12

0.345

09/21/11

11/15/11

11/01/11

0.345

06/16/11

08/15/11

08/01/11

0.345

03/24/11

05/16/11

05/02/11

0.345

01/18/11

02/15/11

02/01/11

0.345

Common Stock And Preferred Stock (Tables)

9 Months Ended

Sep. 30, 2012

Details on Preferred Stock

Details on preferred stock at September 30, 2012, September 30, 2011 and December 31, 2011 are shown below:


	September 30,				December 31,
	2012		2011		2011
Preferred Stock
Unitil Energy Preferred Stock, Non-Redeemable, Non-Cumulative:
6.00% Series, $100 Par Value,	$	0.2	$	0.2	$	0.2
Fitchburg Preferred Stock, Redeemable, Cumulative:
5.125% Series, $100 Par Value		0.8		0.8		0.8
8.00% Series, $100 Par Value		1.0		1.0		1.0

Total Preferred Stock	$	2.0	$	2.0	$	2.0

Shares Outstanding

September 30,

December 31,

2012

2011

Preferred Stock

Unitil Energy Preferred Stock, Non-Redeemable, Non-Cumulative:

6.00% Series, $100 Par Value,

2,250

2,250

Fitchburg Preferred Stock, Redeemable, Cumulative:

5.125% Series, $100 Par Value

7,823

7,861

8.00% Series, $100 Par Value

9,654

9,696

Long-Term Debt, Credit Arrangements And Guarantees (Tables)

9 Months Ended

Sep. 30, 2012

Details on Long Term Debt

Details on long-term debt at September 30, 2012, September 30, 2011 and December 31, 2011 are shown below ($ Millions):


	September 30,				December 31,
	2012		2011		2011
Unitil Corporation Senior Notes:
6.33% Notes, Due May 1, 2022	$	20.0	$	20.0	$	20.0

Unitil Energy Systems, Inc.:
First Mortgage Bonds:
5.24% Series, Due March 2, 2020		15.0		15.0		15.0
8.49% Series, Due October 14, 2024		15.0		15.0		15.0
6.96% Series, Due September 1, 2028		20.0		20.0		20.0
8.00% Series, Due May 1, 2031		15.0		15.0		15.0
6.32% Series, Due September 15, 2036		15.0		15.0		15.0

Fitchburg Gas and Electric Light Company:
Long-Term Notes:
6.75% Notes, Due November 30, 2023		19.0		19.0		19.0
7.37% Notes, Due January 15, 2029		12.0		12.0		12.0
7.98% Notes, Due June 1, 2031		14.0		14.0		14.0
6.79% Notes, Due October 15, 2025		10.0		10.0		10.0
5.90% Notes, Due December 15, 2030		15.0		15.0		15.0

Northern Utilities Senior Notes:
6.95% Senior Notes, Due December 3, 2018		30.0		30.0		30.0
5.29% Senior Notes, Due March 2, 2020		25.0		25.0		25.0
7.72% Senior Notes, Due December 3, 2038		50.0		50.0		50.0

Granite Senior Notes:
7.15% Senior Notes, Due December 15, 2018		10.0		10.0		10.0

Unitil Realty Corp.:
Senior Secured Notes:
8.00% Notes, Due Through August 1, 2017		3.0		3.5		3.3

Total Long-Term Debt		288.0		288.5		288.3
Less: Current Portion		0.5		0.5		0.5

Total Long-term Debt, Less Current Portion	$	287.5	$	288.0	$	287.8

Estimated Fair Value of Long-Term Debt

directly observable, and inputs derived principally from market data.) In estimating the fair value of the Company’s long-term debt, the assumed market yield reflects the Moody’s Baa Utility Bond Average Yield. Costs, including prepayment costs, associated with the early settlement of long-term debt are not taken into consideration in determining fair value.


(Millions)	September 30,				December 31,
	2012		2011		2011
Estimated Fair Value of Long-Term Debt	$	343.6	$	338.0	$	338.7

Borrowing Limits, Amounts Outstanding and Amounts Available Under Revolving Credit Facility

The following table details the borrowing limits, amounts outstanding and amounts available under the revolving credit facility as of September 30, 2012, September 30, 2011 and December 31, 2011:


	September 30,				December 31,
Revolving Credit Facility (millions)	2012		2011		2011
Limit	$	60.0	$	80.0	$	115.0
Outstanding	$	24.1	$	65.4	$	87.9
Available	$	35.9	$	14.6	$	27.1

- Definition

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.22)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 470
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6479336&loc=d3e64711-112823

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21475-112644

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(e),(f))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 55
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6584090&loc=d3e28878-108400

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21538-112644

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=6451184&loc=d3e28541-108399

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21506-112644

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6451184&loc=d3e28551-108399

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21521-112644

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 02
-Paragraph 22
-Article 5

+ Details

Segment Information (Tables)

9 Months Ended

Sep. 30, 2012

Significant Segment Financial Data

The following table provides significant segment financial data for the three and nine months ended September 30, 2012 and September 30, 2011 (Millions):


Three Months Ended September 30, 2012	Electric		Gas			Other			Non-Regulated		Total
Revenues	$	49.5	$	20.3		$	—		$	1.5	$	71.3
Segment Profit (Loss)		2.5		(2.4	)		—			0.4		0.5
Capital Expenditures		6.1		16.8			0.6			—		23.5

Three Months Ended September 30, 2011
Revenues	$	50.5	$	21.2		$	—		$	1.5	$	73.2
Segment Profit (Loss)		2.3		(4.2	)		(0.1	)		0.4		(1.6	)
Capital Expenditures		6.7		9.9			1.0			—		17.6

Nine Months Ended September 30, 2012
Revenues	$	143.0	$	107.2		$	—		$	4.1	$	254.3
Segment Profit		5.1		3.0			—			1.0		9.1
Capital Expenditures		15.5		29.9			2.0			—		47.4
Segment Assets		377.9		394.1			5.8			6.2		784.0

Nine Months Ended September 30, 2011
Revenues	$	141.6	$	112.3		$	—		$	4.2	$	258.1
Segment Profit (Loss)		5.6		(0.4	)		(0.2	)		1.3		6.3
Capital Expenditures		16.5		23.9			2.3			—		42.7
Segment Assets		368.9		367.5			6.4			5.9		748.7

- Definition

Tabular disclosure of the profit or loss and total assets for each reportable segment. An entity discloses certain information on each reportable segment if the amounts (a) are included in the measure of segment profit or loss reviewed by the chief operating decision maker or (b) are otherwise regularly provided to the chief operating decision maker, even if not included in that measure of segment profit or loss.

+ References + Details

Retirement Benefit Obligations (Tables)

9 Months Ended

Sep. 30, 2012

Key Weighted Average Assumptions Used In Determining Benefit Plan Costs and Obligations

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


	2012			2011
Used to Determine Plan Costs
Discount Rate		4.60	%		5.35	%
Rate of Compensation Increase		3.00	%		3.50	%
Expected Long-term rate of return on plan assets		8.50	%		8.50	%
Health Care Cost Trend Rate Assumed for Next Year		6.50	%		7.00	%
Ultimate Health Care Cost Trend Rate		4.00	%		4.00	%
Year that Ultimate Health Care Cost Trend Rate is reached		2017			2017

Components of Retirement Plan Costs

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


	Pension Plan						PBOP Plan						SERP
Three Months Ended September 30,	2012			2011			2012			2011			2012		2011
Service Cost	$	807		$	735		$	517		$	479		$	72	$	71
Interest Cost		1,158			1,171			576			570			53		57
Expected Return on Plan Assets		(1,347	)		(1,210	)		(174	)		(204	)		—		—
Prior Service Cost Amortization		47			62			432			432			3		3
Transition Obligation Amortization		—			—			5			5			—		—
Actuarial Loss Amortization		904			783			32			—			16		19

Sub-total		1,569			1,541			1,388			1,282			144		150
Amounts Capitalized and Deferred		(703	)		(874	)		(571	)		(683	)		—		—

Net Periodic Benefit Cost Recognized	$	866		$	667		$	817		$	599		$	144	$	150


	Pension Plan						PBOP Plan						SERP
Nine Months Ended September 30,	2012			2011			2012			2011			2012		2011
Service Cost	$	2,420		$	2,206		$	1,550		$	1,438		$	217	$	214
Interest Cost		3,475			3,513			1,727			1,709			158		170
Expected Return on Plan Assets		(4,042	)		(3,630	)		(521	)		(613	)		—		—
Prior Service Cost Amortization		141			187			1,296			1,296			9		8
Transition Obligation Amortization		—			—			16			16			—		—
Actuarial Loss Amortization		2,712			2,349			97			—			47		59

Sub-total		4,706			4,625			4,165			3,846			431		451
Amounts Capitalized and Deferred		(1,984	)		(2,055	)		(1,551	)		(1,317	)		—		—

Net Periodic Benefit Cost Recognized	$	2,722		$	2,570		$	2,614		$	2,529		$	431	$	451

Summary of Significant Accounting Policies - Additional Information (Detail) Bcf in Billions	9 Months Ended
	Sep. 30, 2012 Bcf mi Segment Entity	Dec. 31, 2011 Bcf	Sep. 30, 2011 Bcf
Significant Accounting Policies [Line Items]
Number of Operating Gas Transmission \| mi	86
Natural Gas Outstanding under purchase contract \| Bcf	2.1	1.6	1.7
Other Subsidiaries
Significant Accounting Policies [Line Items]
Number of Subsidiaries \| Segment	3
Utilities
Significant Accounting Policies [Line Items]
Number of Subsidiaries \| Entity	3

Fair Value Offset in Regulatory Assets (Detail) - Not Designated as Hedging Instrument - USD ($)
$ in Millions

Sep. 30, 2012

Dec. 31, 2011

Sep. 30, 2011

Regulatory Assets [Line Items]

Natural Gas Futures Contracts

^[1]

$ 1.2

$ 2.3

$ 1.5

Natural Gas Contracts | Other Current Liabilities

Regulatory Assets [Line Items]

Natural Gas Futures Contracts

^[1]

1.0

1.7

1.2

Natural Gas Contracts | Other Noncurrent Liabilities

Regulatory Assets [Line Items]

Natural Gas Futures Contracts

^[1]

$ 0.2

$ 0.6

$ 0.3

[1]	The current portion of Regulatory Assets is recorded as Accrued Revenue on the Company's unaudited Consolidated Balance Sheets.

Regulatory Assets and Reclassification From the Regulatory Asset into Purchased Gas (Detail) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2012

Sep. 30, 2011

Sep. 30, 2012

Sep. 30, 2011

Natural Gas Future Contract

Regulatory Assets [Line Items]

Gain (loss) recognized in Regulatory Assets

$ (0.3)

$ 0.9

$ 1.1

$ 1.5

Gas Purchase Costs

Regulatory Assets [Line Items]

Loss reclassification into unaudited Consolidated Statement of Earnings

^[1]

$ 2.2

$ 1.0

[1]	These amounts are offset in the unaudited Consolidated Statements of Earnings with Accrued Revenue and therefore there is no effect on earnings.

Allowance for Doubtful Accounts Included in Accounts Receivable, Net (Detail) - USD ($) $ in Millions	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2011
Valuation Allowance [Line Items]
Allowance for Doubtful Accounts	$ 2.7	$ 2.3	$ 2.5

Common Dividends Declared Per Share (Detail) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Dividends Payable [Line Items]
Dividend Amount	$ 0.345	$ 0.345	$ 1.380	$ 1.380
Group One
Dividends Payable [Line Items]
Declaration Date			Sep. 19, 2012
Date Paid (Payable)			Nov. 15, 2012
Shareholder of Record Date			Nov. 01, 2012
Dividend Amount			$ 0.345
Group Two
Dividends Payable [Line Items]
Declaration Date			Jun. 06, 2012
Date Paid (Payable)			Aug. 15, 2012
Shareholder of Record Date			Aug. 01, 2012
Dividend Amount			$ 0.345
Group Three
Dividends Payable [Line Items]
Declaration Date			Mar. 22, 2012
Date Paid (Payable)			May 15, 2012
Shareholder of Record Date			May 01, 2012
Dividend Amount			$ 0.345
Group Four
Dividends Payable [Line Items]
Declaration Date			Jan. 17, 2012
Date Paid (Payable)			Feb. 15, 2012
Shareholder of Record Date			Feb. 01, 2012
Dividend Amount			$ 0.345
Group Five
Dividends Payable [Line Items]
Declaration Date			Sep. 21, 2011
Date Paid (Payable)			Nov. 15, 2011
Shareholder of Record Date			Nov. 01, 2011
Dividend Amount			$ 0.345
Group Six
Dividends Payable [Line Items]
Declaration Date			Jun. 16, 2011
Date Paid (Payable)			Aug. 15, 2011
Shareholder of Record Date			Aug. 01, 2011
Dividend Amount			$ 0.345
Group Seven
Dividends Payable [Line Items]
Declaration Date			Mar. 24, 2011
Date Paid (Payable)			May 16, 2011
Shareholder of Record Date			May 02, 2011
Dividend Amount			$ 0.345
Group Eight
Dividends Payable [Line Items]
Declaration Date			Jan. 18, 2011
Date Paid (Payable)			Feb. 15, 2011
Shareholder of Record Date			Feb. 01, 2011
Dividend Amount			$ 0.345

Common Dividend Declared Per Share - Additional Information (Detail) - USD ($) $ in Millions	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2011
Dividends Payable [Line Items]
Dividends Payable	$ 4.8	$ 0.0	$ 3.8

Common Stock and Preferred Stock - Additional Information (Detail)	1 Months Ended		9 Months Ended
	Oct. 01, 2012 shares	May 16, 2012 USD ($) $ / shares shares	Sep. 30, 2012 USD ($) Year $ / shares shares	Sep. 30, 2011 USD ($) $ / shares shares	Dec. 31, 2011 shares
Class of Stock [Line Items]
Common stock, share outstanding			13,769,376	10,944,675	10,954,065
Restricted stock Issued			0
Dividend Declared \| $			$ 100,000	$ 100,000
Common Stock
Class of Stock [Line Items]
Percentage underlying restricted stock that directors will receive			70.00%
Cash
Class of Stock [Line Items]
Percentage underlying restricted stock that directors will receive			30.00%
Scenario, Forecast
Class of Stock [Line Items]
Fully-vested restricted stock units issued	5,470
Common Stock Offering
Class of Stock [Line Items]
Common stock, share issued		2,760,000
Common stock price per share \| $ / shares		$ 25.25
Proceed from issuance of common stock \| $		$ 65,700,000
Restricted Stock
Class of Stock [Line Items]
Restricted stock Vesting Period			4 years
Restricted stock Vesting Percentage Annually			25.00%
Restricted stock available for Awards			677,500
Restricted stock available for Awards			20,000
Restricted stock Issue date			Feb. 03, 2012
Restricted stock Issued			25,600
Restricted Stock Grant date Market Value \| $			$ 720,896
Restricted Stock Non-Vested			53,942	52,362
Restricted Stock Weighted Average Grant Date Fair Value \| $ / shares			$ 24.67	$ 22.21
Share Based compensation Expense \| $			$ 1,100,000	$ 500,000
unrecognized share Based compensation \| $			$ 800,000
Share Compensation Recognition period \| Year			2.6
Restricted shares forfeited			779
Forfeitures or cancellations under the Stock Plan			0
Dividend and Distribution Reinvestment and Share Purchase Plan
Class of Stock [Line Items]
Common stock, share issued			30,490
Common stock price per share \| $ / shares			$ 26.70
Proceed from issuance of common stock \| $			$ 814,200

Details on Preferred Stock (Detail) - USD ($) shares in Millions, $ in Millions	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2011
Preferred Units [Line Items]
Preferred Stock	$ 2.0	$ 2.0	$ 2.0
Unitil Energy Systems Inc \| Nonredeemable Preferred Stock \| Noncumulative Preferred Stock \| Series 6
Preferred Units [Line Items]
Preferred Stock	$ 0.2	$ 0.2	$ 0.2
Preferred Stock	2,250	2,250	2,250
Fitchburg Gas and Electric Light Company \| Redeemable Preferred Stock \| Cumulative Preferred Stock \| Series 5
Preferred Units [Line Items]
Preferred Stock	$ 0.8	$ 0.8	$ 0.8
Preferred Stock	7,823	7,861	7,861
Fitchburg Gas and Electric Light Company \| Redeemable Preferred Stock \| Cumulative Preferred Stock \| Series 8
Preferred Units [Line Items]
Preferred Stock	$ 1.0	$ 1.0	$ 1.0
Preferred Stock	9,654	9,696	9,696

Details on Preferred Stock (Parenthetical) (Detail) - $ / shares	9 Months Ended		12 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Dec. 31, 2011
Unitil Energy Systems Inc \| Nonredeemable Preferred Stock \| Noncumulative Preferred Stock \| Series 6
Preferred Units [Line Items]
Dividend rate	6.00%	6.00%	6.00%
Preferred Stock Par Value	$ 100	$ 100	$ 100
Dividend rate	6.00%	6.00%	6.00%
Preferred Stock Par Value	$ 100	$ 100	$ 100
Fitchburg Gas and Electric Light Company \| Redeemable Preferred Stock \| Cumulative Preferred Stock \| Series 5
Preferred Units [Line Items]
Dividend rate	5.125%	5.125%	5.125%
Preferred Stock Par Value	$ 100	$ 100	$ 100
Dividend rate	5.125%	5.125%	5.125%
Preferred Stock Par Value	$ 100	$ 100	$ 100
Fitchburg Gas and Electric Light Company \| Redeemable Preferred Stock \| Cumulative Preferred Stock \| Series 8
Preferred Units [Line Items]
Dividend rate	8.00%	8.00%	8.00%
Preferred Stock Par Value	$ 100	$ 100	$ 100
Dividend rate	8.00%	8.00%	8.00%
Preferred Stock Par Value	$ 100	$ 100	$ 100

Details On Long Term Debt (Detail) - USD ($) $ in Millions	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2011
Debt Instrument [Line Items]
Long-Term Debt	$ 288.0	$ 288.3	$ 288.5
Less: Current Portion	0.5	0.5	0.5
Total Long-term Debt, Less Current Portion	287.5	287.8	288.0
Senior Notes Six Point Three Three Percent Due May One Twenty Twenty Two
Debt Instrument [Line Items]
Senior Notes	20.0	20.0	20.0
Unitil Energy Systems Inc \| First Mortgage Bonds Five Point Two Four Percent Due March Two Twenty Twenty
Debt Instrument [Line Items]
Long-Term Debt	15.0	15.0	15.0
Unitil Energy Systems Inc \| First Mortgage Bonds Eight Point Four Nine Percent Due October Fourteen Twenty Twenty Four
Debt Instrument [Line Items]
Long-Term Debt	15.0	15.0	15.0
Unitil Energy Systems Inc \| First Mortgage Bonds Six Point Nine Six Percent Due September One Twenty Twenty Eight
Debt Instrument [Line Items]
Long-Term Debt	20.0	20.0	20.0
Unitil Energy Systems Inc \| First Mortgage Bonds Eight Point Zero Zero Percent Due May One Twenty Thirty One
Debt Instrument [Line Items]
Long-Term Debt	15.0	15.0	15.0
Unitil Energy Systems Inc \| First Mortgage Bonds Six Point Three Two Percent Due September Fifteen Twenty Thirty Six
Debt Instrument [Line Items]
Long-Term Debt	15.0	15.0	15.0
Fitchburg Gas and Electric Light Company \| Notes Six Point Seven Five Percent Due November Thirty Twenty Twenty Three
Debt Instrument [Line Items]
Long-Term Debt	19.0	19.0	19.0
Fitchburg Gas and Electric Light Company \| Notes Seven Point Three Seven Percent Due January Fifteen Twenty Twenty Nine
Debt Instrument [Line Items]
Long-Term Debt	12.0	12.0	12.0
Fitchburg Gas and Electric Light Company \| Notes Seven Point Nine Eight Percent Due June One Twenty Thirty One
Debt Instrument [Line Items]
Long-Term Debt	14.0	14.0	14.0
Fitchburg Gas and Electric Light Company \| Notes Six Point Seven Nine Percent Due October Fifteen Twenty Twenty Five
Debt Instrument [Line Items]
Long-Term Debt	10.0	10.0	10.0
Fitchburg Gas and Electric Light Company \| Notes Five Point Nine Zero Percent Due December Fifteen Twenty Thirty
Debt Instrument [Line Items]
Long-Term Debt	15.0	15.0	15.0
Northern Utilities Inc \| Senior Notes Six Point Nine Five Percent Due December Three Twenty Eighteen
Debt Instrument [Line Items]
Senior Notes	30.0	30.0	30.0
Northern Utilities Inc \| Senior Notes Five Point Two Nine Percent Due March Two Twenty Twenty
Debt Instrument [Line Items]
Senior Notes	25.0	25.0	25.0
Northern Utilities Inc \| Senior Notes Seven Point Seven Two Percent Due December Three Twenty Thirty Eight
Debt Instrument [Line Items]
Senior Notes	50.0	50.0	50.0
Granite State Gas Transmission Inc \| Senior Notes Seven Point One Five Percent Due December Fifteen Twenty Eighteen
Debt Instrument [Line Items]
Senior Notes	10.0	10.0	10.0
Unitil Realty Corp \| Senior Secured Notes Eight Point Zero Zero Percent Due Through August One Twenty Seventeen
Debt Instrument [Line Items]
Senior Secured Notes	$ 3.0	$ 3.3	$ 3.5

Details On Long Term Debt (Parenthetical) (Detail)	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2011
Senior Notes Six Point Three Three Percent Due May One Twenty Twenty Two
Debt Instrument [Line Items]
Stated interest rate	6.33%	6.33%	6.33%
Unitil Energy Systems Inc \| First Mortgage Bonds Five Point Two Four Percent Due March Two Twenty Twenty
Debt Instrument [Line Items]
Stated interest rate	5.24%	5.24%	5.24%
Unitil Energy Systems Inc \| First Mortgage Bonds Eight Point Four Nine Percent Due October Fourteen Twenty Twenty Four
Debt Instrument [Line Items]
Stated interest rate	8.49%	8.49%	8.49%
Unitil Energy Systems Inc \| First Mortgage Bonds Six Point Nine Six Percent Due September One Twenty Twenty Eight
Debt Instrument [Line Items]
Stated interest rate	6.96%	6.96%	6.96%
Unitil Energy Systems Inc \| First Mortgage Bonds Eight Point Zero Zero Percent Due May One Twenty Thirty One
Debt Instrument [Line Items]
Stated interest rate	8.00%	8.00%	8.00%
Unitil Energy Systems Inc \| First Mortgage Bonds Six Point Three Two Percent Due September Fifteen Twenty Thirty Six
Debt Instrument [Line Items]
Stated interest rate	6.32%	6.32%	6.32%
Fitchburg Gas and Electric Light Company \| Notes Six Point Seven Five Percent Due November Thirty Twenty Twenty Three
Debt Instrument [Line Items]
Stated interest rate	6.75%	6.75%	6.75%
Fitchburg Gas and Electric Light Company \| Notes Seven Point Three Seven Percent Due January Fifteen Twenty Twenty Nine
Debt Instrument [Line Items]
Stated interest rate	7.37%	7.37%	7.37%
Fitchburg Gas and Electric Light Company \| Notes Seven Point Nine Eight Percent Due June One Twenty Thirty One
Debt Instrument [Line Items]
Stated interest rate	7.98%	7.98%	7.98%
Fitchburg Gas and Electric Light Company \| Notes Six Point Seven Nine Percent Due October Fifteen Twenty Twenty Five
Debt Instrument [Line Items]
Stated interest rate	6.79%	6.79%	6.79%
Fitchburg Gas and Electric Light Company \| Notes Five Point Nine Zero Percent Due December Fifteen Twenty Thirty
Debt Instrument [Line Items]
Stated interest rate	5.90%	5.90%	5.90%
Northern Utilities Inc \| Senior Notes Six Point Nine Five Percent Due December Three Twenty Eighteen
Debt Instrument [Line Items]
Stated interest rate	6.95%	6.95%	6.95%
Northern Utilities Inc \| Senior Notes Five Point Two Nine Percent Due March Two Twenty Twenty
Debt Instrument [Line Items]
Stated interest rate	5.29%	5.29%	5.29%
Northern Utilities Inc \| Senior Notes Seven Point Seven Two Percent Due December Three Twenty Thirty Eight
Debt Instrument [Line Items]
Stated interest rate	7.72%	7.72%	7.72%
Granite State Gas Transmission Inc \| Senior Notes Seven Point One Five Percent Due December Fifteen Twenty Eighteen
Debt Instrument [Line Items]
Stated interest rate	7.15%	7.15%	7.15%
Unitil Realty Corp \| Senior Secured Notes Eight Point Zero Zero Percent Due Through August One Twenty Seventeen
Debt Instrument [Line Items]
Stated interest rate	8.00%	8.00%	8.00%

Estimated Fair Value of Long-Term Debt (Detail) - USD ($) $ in Millions	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2011
Debt Instrument [Line Items]
Estimated Fair Value of Long-Term Debt	$ 343.6	$ 338.7	$ 338.0

Long Term Debt, Credit Arrangements and Guarantees - Additional Information (Detail) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2012	Jul. 24, 2012	Dec. 31, 2011	Sep. 30, 2011
Line of Credit Facility [Line Items]
Accounts Payable	$ 17.1		$ 26.4	$ 16.0
Guarantee outstanding	$ 20.6
Guarantee end date	Feb. 28, 2014
Northern Utilities Inc
Line of Credit Facility [Line Items]
Outstanding Inventory	$ 10.6		14.9	13.0
Accounts Payable	$ 0.0		2.5	0.0
Revolving Facility
Line of Credit Facility [Line Items]
Revolving credit facility expiration date	Oct. 08, 2013
Revolving credit facility	$ 60.0		$ 115.0	$ 80.0
Percentage of capitalization	The revolving credit agreement also contains a covenant restricting the Company's ability to permit funded debt to exceed 65% of capitalization at the end of each fiscal quarter. As of September 30,2012, September 30, 2011 and December 31, 2011, the Company was in compliance with the financial covenants contained in the revolving credit agreement.
Revolving Facility \| Scenario, Forecast
Line of Credit Facility [Line Items]
Revolving credit facility		$ 115.0
Reduced Borrowing Limit		$ 60.0
Senior Secured Notes Eight Point Zero Zero Percent Due Through August One Twenty Seventeen \| Unitil Realty Corp
Line of Credit Facility [Line Items]
Principal amount of notes outstanding	$ 3.0
Senior Notes Seven Point One Five Percent Due December Fifteen Twenty Eighteen \| Granite State Gas Transmission Inc
Line of Credit Facility [Line Items]
Principal amount of notes outstanding	$ 10.0

Borrowing Limits, Amounts Outstanding and Amounts Available Under Revolving Credit Facility (Detail) - Revolving Facility - USD ($) $ in Millions	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2011
Debt Instrument [Line Items]
Revolving credit facility	$ 60.0	$ 115.0	$ 80.0
Outstanding revolving credit facility	24.1	87.9	65.4
Available revolving credit facility	$ 35.9	$ 27.1	$ 14.6

Significant Segment Financial Data (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011	Dec. 31, 2011
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Revenues	$ 71.3	$ 73.2	$ 254.3	$ 258.1
Segment Profit	0.5	(1.6)	9.1	6.3
Capital Expenditures	23.5	17.6	47.4	42.7
Segment Assets	784.0	748.7	784.0	748.7	$ 800.2
Electricity
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Revenues	49.5	50.5	143.0	141.6
Segment Profit	2.5	2.3	5.1	5.6
Capital Expenditures	6.1	6.7	15.5	16.5
Segment Assets	377.9	368.9	377.9	368.9
Gas Segment
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Revenues	20.3	21.2	107.2	112.3
Segment Profit	(2.4)	(4.2)	3.0	(0.4)
Capital Expenditures	16.8	9.9	29.9	23.9
Segment Assets	394.1	367.5	394.1	367.5
All Other Segments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Segment Profit		(0.1)		(0.2)
Capital Expenditures	0.6	1.0	2.0	2.3
Segment Assets	5.8	6.4	5.8	6.4
Unregulated Operation
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Revenues	1.5	1.5	4.1	4.2
Segment Profit	0.4	0.4	1.0	1.3
Segment Assets	$ 6.2	$ 5.9	$ 6.2	$ 5.9

Regulatory Matters - Additional Information (Detail) $ in Thousands	1 Months Ended								9 Months Ended
	Jun. 29, 2012 USD ($)	Apr. 24, 2012	Mar. 22, 2012 USD ($)	Dec. 16, 2011 USD ($)	Nov. 30, 2011 USD ($)	Aug. 31, 2011 USD ($)	Aug. 01, 2011 USD ($) Year	Apr. 26, 2011 USD ($)	Sep. 30, 2012 USD ($)	Nov. 02, 2011 USD ($)	Feb. 28, 2011 USD ($)	Nov. 02, 2009 USD ($)
Fitchburg Gas and Electric Light Company
Regulatory Assets [Line Items]
Return of Equity							9.20%
Deferred Emergency Storm Restoration Cost							$ 11,400
Amortized and Recovered Cost, Years \| Year							7
Portion of storm cost expenditures that the Company has requested deferral of and recovery of through rate adjustments				$ 4,300
Fitchburg Gas and Electric Light Company \| Natural Gas \| Court
Regulatory Assets [Line Items]
Refund of Cost										$ 4,600
Regulatory Liabilities										4,700		$ 4,900
Fitchburg Gas and Electric Light Company \| Natural Gas \| Supreme Court
Regulatory Assets [Line Items]
Refund of Cost										$ 200
Fitchburg Gas and Electric Light Company \| Tropical Storm Irene
Regulatory Assets [Line Items]
Storm expenditures				1,500
Fitchburg Gas and Electric Light Company \| Severe Snow Storm
Regulatory Assets [Line Items]
Storm expenditures				3,300
Fitchburg Gas and Electric Light Company \| Electric Distribution
Regulatory Assets [Line Items]
Increase in annual revenue							$ 3,300
Fitchburg Gas and Electric Light Company \| Gas Distribution
Regulatory Assets [Line Items]
Increase in annual revenue							$ 3,700
Unitil Energy Systems Inc
Regulatory Assets [Line Items]
Settlement agreement date									May 01, 2016
Adjustment to recover the increased spending for vegetation management program and reliability enhancement program									$ 1,470
Customer's Overpayment Amount						$ 1,800
Amount Reimbursed to Customer						1,800
Interest on Reimbursement						300
Non-Recurring Charge on Distribution						$ 400
Request for recovery of under-billed customers											$ 1,400
Unitil Energy Systems Inc \| Storm Costs
Regulatory Assets [Line Items]
Recovery of damage of electrical system				$ 4,400
Interest rate allowed by regulators on the unrecovered amount of storm costs which have been approved for recovery through rate adjustments				4.52%
Recovery of cost, over years				5 years
Unitil Energy Systems Inc \| Minimum
Regulatory Assets [Line Items]
Estimated increases for Capital Improvement									1,500
Unitil Energy Systems Inc \| Maximum
Regulatory Assets [Line Items]
Estimated increases for Capital Improvement									$ 2,000
Unitil Energy Systems Inc \| Range One
Regulatory Assets [Line Items]
Return of Equity									7.00%
Unitil Energy Systems Inc \| Range Two
Regulatory Assets [Line Items]
Return of Equity									10.00%
Unitil Energy Systems Inc \| Year One Policy
Regulatory Assets [Line Items]
Increase in annual revenue								$ 5,200
Amendment effective date								Jul. 01, 2010
Unitil Energy Systems Inc \| Year Two Policy
Regulatory Assets [Line Items]
Increase in annual revenue								$ 5,000
Amendment effective date								May 01, 2011
Granite State Gas Transmission Inc \| Gas Transportation and Storage
Regulatory Assets [Line Items]
Additional Cost to Transmission Plant	$ 2,400								$ 11,400
Annual revenue increase in rate adjustments	$ 300
Granite State Gas Transmission Inc \| Asset Recoverable Gas Costs
Regulatory Assets [Line Items]
Amount being Recovered									$ 1,600
Northern Utilities Inc
Regulatory Assets [Line Items]
Amendment effective date			May 01, 2012
Settlement agreement date		Apr. 24, 2012
Increase in annual revenue			$ 3,700
Northern Utilities Inc \| Year One Policy
Regulatory Assets [Line Items]
Increase in annual revenue					$ 7,800
Amendment effective date					Jan. 01, 2012
Northern Utilities Inc \| Year Two Policy
Regulatory Assets [Line Items]
Amendment effective date					May 01, 2012
Increase in annual distribution revenue					$ 850
Northern Utilities Inc \| Remainder of Year
Regulatory Assets [Line Items]
Amendment effective date					Jan. 01, 2014

Environmental Matters - Additional Information (Detail) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Dec. 31, 2011
Site Contingency [Line Items]
Accrued Liabilities	$ 14.5	$ 14.4	$ 14.5
Fitchburg Gas and Electric Light Company \| Environmental Issue
Site Contingency [Line Items]
Accrued Liabilities	$ 12.0
Settlement insurance		$ 2.0
Amortization period for environmental costs	7 years
Northern Utilities Inc
Site Contingency [Line Items]
Accrued Liabilities	$ 2.5
Northern Utilities Inc \| Other Current Liabilities
Site Contingency [Line Items]
Accrued Liabilities	0.3
Environmental Matters
Site Contingency [Line Items]
Income (loss) incurred in excess of recorded amount	$ 0.0

Income Taxes - Additional Information (Detail) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2012	Dec. 31, 2011
Operating Loss Carryforwards [Line Items]
Net operating loss		$ (12.4)
Alternative Minimum tax credit carryforwards		$ 1.5
Federal
Operating Loss Carryforwards [Line Items]
Tax examination description		The Company remains subject to examination by Federal, Maine, Massachusetts, and New Hampshire tax authorities for the tax periods ended December 31, 2009; December 31, 2010 and December 31, 2011
Federal and State
Operating Loss Carryforwards [Line Items]
Net Operating Loss carryforward assets		$ 9.3
State and Local Jurisdiction
Operating Loss Carryforwards [Line Items]
NOL carryforward assets expiration date		2019
Internal Revenue Service (IRS)
Operating Loss Carryforwards [Line Items]
NOL carryforward assets expiration date		2029
Internal Revenue Service (IRS) \| Net Operating Loss Carryforwards
Operating Loss Carryforwards [Line Items]
Operating Loss Refunds	$ 2.0

Key Weighted Average Assumptions Used In Determining Benefit Plan Costs and Obligations (Detail)	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011
Used to Determine Plan Costs
Discount Rate	4.60%	5.35%
Rate of Compensation Increase	3.00%	3.50%
Expected Long-term rate of return on plan assets	8.50%	8.50%
Health Care Cost Trend Rate Assumed for Next Year	6.50%	7.00%
Ultimate Health Care Cost Trend Rate	4.00%	4.00%
Year that Ultimate Health Care Cost Trend Rate is reached	2017	2017

Components of Retirement Plan Costs (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Pension Plans, Defined Benefit
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Service Cost	$ 807	$ 735	$ 2,420	$ 2,206
Interest Cost	1,158	1,171	3,475	3,513
Expected Return on Plan Assets	(1,347)	(1,210)	(4,042)	(3,630)
Prior Service Cost Amortization	47	62	141	187
Actuarial Loss Amortization	904	783	2,712	2,349
Sub-total	1,569	1,541	4,706	4,625
Amounts Capitalized and Deferred	(703)	(874)	(1,984)	(2,055)
Net Periodic Benefit Cost Recognized	866	667	2,722	2,570
Other Postretirement Benefit Plans, Defined Benefit
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Service Cost	517	479	1,550	1,438
Interest Cost	576	570	1,727	1,709
Expected Return on Plan Assets	(174)	(204)	(521)	(613)
Prior Service Cost Amortization	432	432	1,296	1,296
Transition Obligation Amortization	5	5	16	16
Actuarial Loss Amortization	32		97
Sub-total	1,388	1,282	4,165	3,846
Amounts Capitalized and Deferred	(571)	(683)	(1,551)	(1,317)
Net Periodic Benefit Cost Recognized	817	599	2,614	2,529
Supplemental Employee Retirement Plans, Defined Benefit
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Service Cost	72	71	217	214
Interest Cost	53	57	158	170
Prior Service Cost Amortization	3	3	9	8
Actuarial Loss Amortization	16	19	47	59
Sub-total	144	150	431	451
Net Periodic Benefit Cost Recognized	$ 144	$ 150	$ 431	$ 451

Retirement Benefit Obligations - Additional Information (Detail)	9 Months Ended
	Sep. 30, 2012 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Contributions to Pension plan	$ 9,400,000
Other Postretirement Benefit Plans, Defined Benefit
Defined Benefit Plan Disclosure [Line Items]
Contributions to Pension plan	2,200,000
Supplemental Employee Retirement Plans, Defined Benefit
Defined Benefit Plan Disclosure [Line Items]
Contributions to Pension plan	40,000.0
Expected additional contribution to SERP plan	$ 13,000