Unitil (UTL) 10-Q 24 Oct 19 2019 Q3 Quarterly report Financial data

Cover Page

Cover Page - shares	9 Months Ended
	Sep. 30, 2019	Oct. 21, 2019
Document Information [Line Items]
Entity Interactive Data Current	Yes
Document Type	10-Q
Document Quarterly Report	true
Document Transition Report	false
Amendment Flag	false
Document Period End Date	Sep. 30, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q3
Entity Registrant Name	UNITIL CORP
Entity Central Index Key	0000755001
Entity File Number	1-8858
Entity Tax Identification Number	02-0381573
Entity Incorporation, State or Country Code	NH
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Shell Company	false
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Address, Address Line One	6 Liberty Lane West
Entity Address, City or Town	Hampton
Entity Address, Postal Zip Code	03842-1720
Entity Address, State or Province	NH
City Area Code	603
Local Phone Number	772-0775
Trading Symbol	UTL
Security Exchange Name	NYSE
Entity Common Stock, Shares Outstanding		14,926,205
Title of 12(b) Security	Common Stock

CONSOLIDATED STATEMENTS OF EARN

CONSOLIDATED STATEMENTS OF EARNINGS - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Operating Revenues
Total Operating Revenues	$ 85.3	$ 88.2	$ 321.8	$ 318.5
Operating Expenses
Operation and Maintenance	15.5	16.4	49.9	51.5
Depreciation and Amortization	12.8	12.4	39	37.4
Taxes Other Than Income Taxes	5.5	5.5	17	16.5
Total Operating Expenses	75.3	77.9	270.7	269.5
Operating Income	10	10.3	51.1	49
Interest Expense, Net	5.8	6	17.9	17.9
Other Expense (Income), Net	1	1.1	(9.8)	4.1
Income Before Income Taxes	3.2	3.2	43	27
Provision for Income Taxes	0.9	0.4	10.2	5
Net Income	$ 2.3	$ 2.8	$ 32.8	$ 22
Net Income Per Common Share (Basic and Diluted)	$ 0.15	$ 0.19	$ 2.20	$ 1.49
Weighted Average Common Shares Outstanding – (Basic and Diluted)	14.9	14.8	14.9	14.8
Gas
Operating Revenues
Total Operating Revenues	$ 24.9	$ 25.7	$ 143.9	$ 147.4
Operating Expenses
Total Operating Expenses	6.2	8.1	58.4	67
Electric
Operating Revenues
Total Operating Revenues	60.4	61.4	177	167.6
Operating Expenses
Total Operating Expenses	$ 35.3	35.5	106.4	97.1
Other
Operating Revenues
Total Operating Revenues		$ 1.1	$ 0.9	$ 3.5

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions		Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018
Current Assets:
Cash and Cash Equivalents		$ 7.3	$ 7.8	$ 6.3
Accounts Receivable, Net		39.4	66.8	52.3
Accrued Revenue		35.3	54.7	36
Exchange Gas Receivable		8.6	8.1	10.1
Refundable Taxes		2.9	0.5
Gas Inventory		0.8	0.8	0.9
Materials and Supplies		7.7	7	7.2
Prepayments and Other		5.4	6.5	7.8
Total Current Assets		107.4	152.2	120.6
Utility Plant:
Gas		783.2	760.6	712.7
Electric		514.8	500.1	485.6
Common		61.6	83.1	82.1
Construction Work in Progress		72.9	25.5	68.4
Utility Plant		1,432.5	1,369.3	1,348.8
Less: Accumulated Depreciation		348.6	332.5	326.5
Net Utility Plant		1,083.9	1,036.8	1,022.3
Other Noncurrent Assets:
Regulatory Assets		98.7	99	111.6
Operating Lease Right of Use Assets		4.2
Other Assets		15.5	10.3	10
Total Other Noncurrent Assets		118.4	109.3	121.6
TOTAL ASSETS		1,309.7	1,298.3	1,264.5
Current Liabilities:
Accounts Payable		22.9	42.6	27.4
Short-Term Debt		49.2	82.8	69.1
Long-Term Debt, Current Portion	[1]	19.5	18.4	31.8
Regulatory Liabilities		14.4	11.5	12.2
Energy Supply Obligations		12.5	13.4	15
Interest Payable		7.1	4.3	7
Other Current Liabilities		18.8	19.5	18
Total Current Liabilities		144.4	192.5	180.5
Noncurrent Liabilities:
Retirement Benefit Obligations		120.8	121.5	142.4
Deferred Income Taxes, net		108.3	97.8	86.4
Cost of Removal Obligations		98.4	90.7	91.2
Regulatory Liabilities		46.7	47	47.9
Other Noncurrent Liabilities		10.2	10.1	10
Total Noncurrent Liabilities		384.4	367.1	377.9
Capitalization:
Long-Term Debt, Less Current Portion		410.9	387.4	361.1
Stockholders' Equity:
Common Equity (Authorized: 25,000,000 and Outstanding: 14,925,898, 14,872,011 and 14,876,955 Shares)		281.7	279.1	278.3
Retained Earnings		88.1	72	66.5
Total Common Stock Equity		369.8	351.1	344.8
Preferred Stock		0.2	0.2	0.2
Total Stockholders' Equity		370	351.3	345
Total Capitalization		780.9	738.7	706.1
TOTAL LIABILITIES AND CAPITALIZATION		$ 1,309.7	$ 1,298.3	$ 1,264.5
[1]	The Current Portion of Long-Term Debt includes sinking fund payments.

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018
Common Stock Authorized	25,000,000	25,000,000	25,000,000
Common Equity Outstanding	14,925,898	14,876,955	14,872,011

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Operating Activities:
Net Income	$ 32.8	$ 22
Adjustments to Reconcile Net Income to Cash Provided by Operating Activities:
Depreciation and Amortization	39	37.4
Deferred Tax Provision	9.3	4.6
Gain on Divestiture, Net (See Note 1)	(13.4)
Changes in Working Capital Items:
Accounts Receivable	27.4	15.1
Accrued Revenue	19.4	17.3
Exchange Gas Receivable	(0.5)	(4.3)
Regulatory Liabilities	2.9	3
Accounts Payable	(19.7)	(14.1)
Other Changes in Working Capital Items	(2.4)	3.7
Deferred Regulatory and Other Charges	(4.7)	(5.7)
Other, net	2.1	(9)
Cash Provided by Operating Activities	92.2	70
Investing Activities:
Property, Plant and Equipment Additions	(76.7)	(76.3)
Proceeds from Divestiture, Net (See Note 1)	13.4
Cash (Used in) Investing Activities	(63.3)	(76.3)
Financing Activities:
(Repayment of) Proceeds from Short-Term Debt, net	(33.6)	30.8
Repayment of Long-Term Debt	(15.2)	(13.5)
Issuance of Long-Term Debt	39.8
Decrease in Capital Lease Obligations	(5.1)	(2.3)
Net Increase in Exchange Gas Financing	0.5	4.1
Dividends Paid	(16.7)	(16.3)
Proceeds from Issuance of Common Stock, net	0.9	0.9
Cash (Used in) Provided by Financing Activities	(29.4)	3.7
Net Decrease in Cash and Cash Equivalents	(0.5)	(2.6)
Cash and Cash Equivalents at Beginning of Period	7.8	8.9
Cash and Cash Equivalents at End of Period	7.3	6.3
Supplemental Cash Flow Information:
Interest Paid	15.6	15.6
Income Taxes Paid	0.9	0.4
Payments on Capital Leases	5.4	2.3
Non-cash Investing Activity:
Capital Expenditures Included in Accounts Payable	0.8	$ 1.2
Right-of-Use Assets Obtained in Exchange for Lease Obligations	$ 4.2

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCK EQUITY - USD ($) $ in Millions	Total	Common Equity	Retained Earnings
Beginning Balance at Dec. 31, 2017	$ 336.6	$ 275.8	$ 60.8
Net Income	22		22
Dividends on Common Shares	(16.3)		(16.3)
Stock Compensation Plans	1.5	1.5
Issuance of Common Shares	1	1
Ending Balance at Sep. 30, 2018	344.8	278.3	66.5
Beginning Balance at Jun. 30, 2018	347	277.9	69.1
Net Income	2.8		2.8
Dividends on Common Shares	(5.4)		(5.4)
Stock Compensation Plans	0.1	0.1
Issuance of Common Shares	0.3	0.3
Ending Balance at Sep. 30, 2018	344.8	278.3	66.5
Beginning Balance at Dec. 31, 2018	351.1	279.1	72
Net Income	32.8		32.8
Dividends on Common Shares	(16.7)		(16.7)
Stock Compensation Plans	1.7	1.7
Issuance of Common Shares	0.9	0.9
Ending Balance at Sep. 30, 2019	369.8	281.7	88.1
Beginning Balance at Jun. 30, 2019	372.8	281.3	91.5
Net Income	2.3		2.3
Dividends on Common Shares	(5.7)		(5.7)
Stock Compensation Plans	0.1	0.1
Issuance of Common Shares	0.3	0.3
Ending Balance at Sep. 30, 2019	$ 369.8	$ 281.7	$ 88.1

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCK EQUITY (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Dividends per Common Share	$ 0.370	$ 0.365	$ 1.11	$ 1.095
Common stock, shares issued	4,727	5,423	15,793	19,700

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	9 Months Ended
	Sep. 30, 2019
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Note 1 Summary of Significant Accounting Policies Nature of Operations non-regulated The Company’s earnings are seasonal and are typically higher in the first and fourth quarters when customers use natural gas for heating purposes. 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 three 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 non-regulated Basis of Presentation – 10-Q 10-K Divestiture of Non-Regulated Business Subsidiary – non-regulated after-tax pre-tax Utility Revenue Recognition – Billed and unbilled revenue is recorded when service is rendered or energy is delivered to customers. However, the determination of energy sales to individual customers is based on the reading of their meters, which occurs on a systematic basis throughout the month. At the end of each calendar month, amounts of energy delivered to customers since the date of the last meter reading are estimated and the corresponding unbilled revenues are calculated. These unbilled revenues are calculated each month based on estimated customer usage by class and applicable customer rates and are then reversed in the following month when billed to customers. A majority of the Company’s revenue from contracts with customers continues to be recognized on a monthly basis based on applicable tariffs and customer monthly consumption. Such revenue is recognized using the invoice practical expedient which allows an entity to recognize revenue in the amount that directly corresponds to the value transferred to the customer. The Company’s billed and unbilled revenue meets the definition of “revenues from contracts with customers” as defined in ASU 2014-09. 980-605-25-3, 2014-09 In the following tables, revenue is classified by the types of goods/services rendered and market/customer type. Three Months Ended September 30, 2019 Gas and Electric Operating Revenues ($ millions): Gas Electric Total Billed and Unbilled Revenue: Residential $ 6.9 $ 31.3 $ 38.2 C&I 12.5 24.5 37.0 Other 1.1 1.5 2.6 Total Billed and Unbilled Revenue 20.5 57.3 77.8 Rate Adjustment Mechanism Revenue 4.4 3.1 7.5 Total Gas and Electric Operating Revenues $ 24.9 $ 60.4 $ 85.3 Three Months Ended September 30, 2018 Gas and Electric Operating Revenues ($ millions): Gas Electric Total Billed and Unbilled Revenue: Residential $ 6.6 $ 33.6 $ 40.2 C&I 11.9 25.3 37.2 Other 1.1 2.0 3.1 Total Billed and Unbilled Revenue 19.6 60.9 80.5 Rate Adjustment Mechanism Revenue 6.1 0.5 6.6 Total Gas and Electric Operating Revenues $ 25.7 $ 61.4 $ 87.1 Nine Months Ended September 30, 2019 Gas and Electric Operating Revenues ($ millions): Gas Electric Total Billed and Unbilled Revenue: Residential $ 61.4 $ 94.8 $ 156.2 C&I 89.5 72.2 161.7 Other 9.1 5.8 14.9 Total Billed and Unbilled Revenue 160.0 172.8 332.8 Rate Adjustment Mechanism Revenue (16.1 ) 4.2 (11.9 ) Total Gas and Electric Operating Revenues $ 143.9 $ 177.0 $ 320.9 Nine Months Ended September 30, 2018 Gas and Electric Operating Revenues ($ millions): Gas Electric Total Billed and Unbilled Revenue: Residential $ 58.3 $ 95.6 $ 153.9 C&I 84.7 74.1 158.8 Other 8.1 6.5 14.6 Total Billed and Unbilled Revenue 151.1 176.2 327.3 Rate Adjustment Mechanism Revenue (3.7 ) (8.6 ) (12.3 ) Total Gas and Electric Operating Revenues $ 147.4 $ 167.6 $ 315.0 Fitchburg is subject to revenue decoupling. Revenue decoupling is the term given to the elimination of the dependency of a utility’s distribution revenue on the volume of electricity or natural gas sales. The difference between distribution revenue amounts billed to customers and the targeted revenue decoupling amounts is recorded as an increase or a decrease in Accrued Revenue, which forms the basis for resetting rates for future cash recoveries from, or credits to, customers. These revenue decoupling targets may be adjusted as a result of rate cases that the Company files with the Massachusetts Department of Public Utilities (MDPU). The Company estimates that revenue decoupling applies to approximately 27% and 11% of Unitil’s total annual electric and natural gas sales volumes, respectively. Other Operating Revenue – Non-regulated – Other Operating Revenue – Non-regulated – Other Operating Revenue consists solely of revenue from Usource, Unitil’s non-regulated Income Taxes – Provisions for income taxes are calculated in each of the jurisdictions in which the Company operates for each period for which a statement of earnings is presented. The Company accounts for income taxes in accordance with the FASB Codification guidance on Income Taxes, which requires an asset and liability approach for the financial accounting and reporting of income taxes. Significant judgments and estimates are required in determining the current and deferred tax assets and liabilities. The Company’s current and deferred tax assets and liabilities reflect its best assessment of estimated future taxes to be paid. In accordance with the FASB Codification, the Company periodically assesses the realization of its deferred tax assets and liabilities and adjusts the income tax provision, the current tax liability and deferred taxes in the period in which the facts and circumstances which gave rise to the revision become known. Cash and Cash Equivalents – (ISO-NE) ISO-NE. 2-1/2 ISO-NE Allowance for Doubtful Accounts – written-off shut-off. The Allowance for Doubtful Accounts as of September 30, 2019, September 30, 2018 and December 31, 2018, which is included in Accounts Receivable, net on the accompanying unaudited consolidated balance sheets, was as follows: ($ millions) September 30, December 31, 2019 2018 2018 Allowance for Doubtful Accounts $ 1.0 $ 1.2 $ 1.3 Accrued Revenue – September 30, December 31, Accrued Revenue ($ millions) 2019 2018 2018 Regulatory Assets – Current $ 24.9 $ 26.4 $ 41.3 Unbilled Revenues 10.4 9.6 13.4 Total Accrued Revenue $ 35.3 $ 36.0 $ 54.7 Exchange Gas Receivable – The following table shows the components of Exchange Gas Receivable as of September 30, 2019, September 30, 2018 and December 31, 2018. September 30, December 31, Exchange Gas Receivable ($ millions) 2019 2018 2018 Northern Utilities $ 8.0 $ 9.5 $ 7.5 Fitchburg 0.6 0.6 0.6 Total Exchange Gas Receivable $ 8.6 $ 10.1 $ 8.1 Gas Inventory September 30, December 31, Gas Inventory ($ millions) 2019 2018 2018 Natural Gas $ 0.4 $ 0.4 $ 0.3 Propane 0.3 0.4 0.4 Liquefied Natural Gas & Other 0.1 0.1 0.1 Total Gas Inventory $ 0.8 $ 0.9 $ 0.8 Utility Plant – Leases – 2016-02, . Regulatory Accounting – (MPUC) and NHPUC. Granite State, the Company’s natural gas transmission pipeline, is regulated by the FERC. Accordingly, the Company uses the Regulated Operations guidance as set forth in the FASB Codification. The Company has recorded Regulatory Assets and Regulatory Liabilities which will be recovered from customers, or applied for customer benefit, in accordance with rate provisions approved by the applicable public utility regulatory commission. September 30, December 31, Regulatory Assets consist of the following ($ millions) 2019 2018 2018 Retirement Benefits $ 74.0 $ 88.0 $ 72.0 Energy Supply & Other Rate Adjustment Mechanisms 20.6 24.8 38.4 Deferred Storm Charges 5.0 6.3 6.3 Environmental 8.0 8.9 7.9 Income Taxes 4.3 5.9 5.7 Other 11.7 4.1 10.0 Total Regulatory Assets 123.6 138.0 140.3 Less: Current Portion of Regulatory Assets (1) 24.9 26.4 41.3 Regulatory Assets – noncurrent $ 98.7 $ 111.6 $ 99.0 (1) Reflects amounts included in Accrued Revenue, discussed above, on the Company’s Consolidated Balance Sheets. September 30, December 31, Regulatory Liabilities consist of the following ($ millions) 2019 2018 2018 Income Taxes (Note 8) $ 47.6 $ 47.9 $ 47.0 Energy Supply & Other Rate Adjustment Mechanisms 13.5 12.2 11.5 Total Regulatory Liabilities 61.1 60.1 58.5 Less: Current Portion of Regulatory Liabilities 14.4 12.2 11.5 Regulatory Liabilities—noncurrent $ 46.7 $ 47.9 $ 47.0 Generally, the Company receives a return on investment on its regulated assets for which a cash outflow has been made. As of September 30, 2019 there are $5.8 million of environmental costs, rate case costs and other expenditures to be recovered over varying periods in the next seven years which regulators have authorized recovery of, but without a return. Regulatory commissions can reach different conclusions about the recovery of costs, which can have a material impact on the Company’s Consolidated Financial Statements. The Company believes it is probable that its regulated distribution and transmission utilities will recover their investments in long-lived assets, including regulatory assets. If the Company, or a portion of its assets or operations, were to cease meeting the criteria for application of these accounting rules, accounting standards for businesses in general would become applicable and immediate recognition of any previously deferred costs, or a portion of deferred costs, would be required in the year in which the criteria are no longer met, if such deferred costs were not recoverable in the portion of the business that continues to meet the criteria for application of the FASB Codification topic on Regulated Operations. If unable to continue to apply the FASB Codification provisions for Regulated Operations, the Company would be required to apply the provisions for the Discontinuation of Rate-Regulated Accounting included in the FASB Codification. In the Company’s opinion, its regulated operations will be subject to the FASB Codification provisions for Regulated Operations for the foreseeable future. Derivatives – As discussed below in the “Fitchburg – Massachusetts RFP’s” section of Note 6 (Regulatory Matters), Fitchburg has entered into power purchase agreements for which contingencies exist. Until these contingencies are satisfied, these contracts will not qualify for derivative accounting. The Company believes that the power purchase obligations under these long-term contracts will have a material impact on the contractual obligations and regulatory assets of Fitchburg, once they qualify for derivative accounting. Investments in Marketable Securities T At September 30, 2019, September 30, 2018 and December 31, 2018, the fair value of the Company’s investments in these trading securities, which are recorded on the Consolidated Balance Sheets in Other Assets, were $5.9 million, $5.3 million and $4.8 million, respectively, as shown in the table below. These investments are valued based on quoted prices from active markets and are categorized in Level 1 as they are actively traded and no valuation adjustments have been applied. Changes in the fair value of these investments are recorded in Other Expense (Income), Net. September 30, December 31, Fair Value of Marketable Securities ($ millions) 2019 2018 2018 Equity Funds $ — $ 3.0 $ — Fixed Income Funds — 2.3 — Money Market Funds 5.9 — 4.8 Total Marketable Securities $ 5.9 $ 5.3 $ 4.8 The Company also sponsors the Unitil Corporation Deferred Compensation Plan (the “DC Plan”). The DC Plan is a non-qualified tax-deferred At September 30, 2019, September 30, 2018 and December 31, 2018, the fair value of the Company’s investments in these trading securities related to the DC Plan, which are recorded on the Consolidated Balance Sheets in Other Assets, were $0.1 million, $0 and $0, respectively, as shown in the table below. These investments are valued based on quoted prices from active markets and are categorized in Level 1 as they are actively traded and no valuation adjustments have been applied. September 30, December 31, Fair Value of Marketable Securities ($ millions) 2019 2018 2018 Equity Funds $ — $ — $ — Money Market Funds 0.1 — — Total Marketable Securities $ 0.1 $ — $ — Energy Supply Obligations September 30, December 31, Energy Supply Obligations ($ millions) 2019 2018 2018 Current: Exchange Gas Obligation $ 8.0 $ 9.5 $ 7.5 Renewable Energy Portfolio Standards 4.2 5.2 5.6 Power Supply Contract Divestitures 0.3 0.3 0.3 Total Energy Supply Obligations – Current 12.5 15.0 13.4 Noncurrent: Power Supply Contract Divestitures 0.4 0.7 0.6 Total Energy Supply Obligations $ 12.9 $ 15.7 $ 14.0 Exchange Gas Obligation – Renewable Energy Portfolio Standards Fitchburg has entered into long-term renewable contracts for the purchase of clean energy and/or renewable energy certificates (RECs) pursuant to Massachusetts legislation, specifically, An Act Relative to Green Communities (“Green Communities Act”, 2008), An Act Relative to Competitively Priced Electricity in the Commonwealth (2012) and An Act to Promote Energy Diversity (“Energy Diversity Act”, 2016). The generating facilities associated with four of these contracts have been constructed and are now operating. Since 2017, the Company has participated in two major statewide procurements which resulted in contracts for imported hydroelectric power and associated transmission and for offshore wind generation. The contracts were approved by the MDPU in the second quarter of 2019. Additional long-term clean energy contracts are expected in compliance with the Energy Diversity Act and An Act to Promote a Clean Energy Future (2018). Fitchburg recovers the costs associated with long-term renewable contracts on a fully reconciling basis through a MDPU-approved cost recovery mechanism. Power Supply Contract Divestitures – Recently Issued Pronouncements – 2016-02, Other than the pronouncement discussed above, there are no recently issued pronouncements that the Company has not already adopted or that have a material impact on the Company. Subsequent Events –

DIVIDENDS DECLARED PER SHARE

DIVIDENDS DECLARED PER SHARE	9 Months Ended
	Sep. 30, 2019
DIVIDENDS DECLARED PER SHARE [Abstract]
DIVIDENDS DECLARED PER SHARE	Note 2 Dividends Declared Per Share Declaration Date Date Paid (Payable) Shareholder of Record Date Dividend Amount 10/23/19 11/27/19 11/13/19 $ 0.370 07/24/19 08/29/19 08/15/19 $ 0.370 04/24/19 05/29/19 05/15/19 $ 0.370 01/30/19 02/28/19 02/14/19 $ 0.370 10/24/18 11/29/18 11/15/18 $ 0.365 07/25/18 08/29/18 08/15/18 $ 0.365 04/25/18 05/29/18 05/15/18 $ 0.365 01/30/18 02/28/18 02/14/18 $ 0.365

SEGMENT INFORMATION

SEGMENT INFORMATION	9 Months Ended
	Sep. 30, 2019
SEGMENT INFORMATION	note 3 Segment Information The following table provides significant segment financial data for the three and nine months ended September 30, 2019 and September 30, 2018 and as of December 31, 2018 (millions): Gas Electric Non- Regulated Other Total Three Months Ended September 30, 2019 Revenues: Billed and Unbilled Revenue $ 20.5 $ 57.3 $ — $ — $ 77.8 Rate Adjustment Mechanism Revenue 4.4 3.1 — — 7.5 Other Operating Revenue – Non-Regulated — — — — — Total Operating Revenues $ 24.9 $ 60.4 $ — $ — $ 85.3 Segment Profit (3.9 ) 4.4 — 1.8 2.3 Capital Expenditures 26.9 9.2 — 1.9 38.0 Three Months Ended September 30, 2018 Revenues: Billed and Unbilled Revenue $ 19.6 $ 60.9 $ — $ — $ 80.5 Rate Adjustment Mechanism Revenue 6.1 0.5 — — 6.6 Other Operating Revenue – Non-Regulated — — 1.1 — 1.1 Total Operating Revenues $ 25.7 $ 61.4 $ 1.1 $ — $ 88.2 Segment Profit (Loss) (3.2 ) 4.5 0.3 1.2 2.8 Capital Expenditures 30.9 7.2 — 1.0 39.1 Nine Months Ended September 30, 2019 Revenues: Billed and Unbilled Revenue $ 160.0 $ 172.8 $ — $ — $ 332.8 Rate Adjustment Mechanism Revenue (16.1 ) 4.2 — — (11.9 ) Other Operating Revenue – Non-Regulated — — 0.9 — 0.9 Total Operating Revenues $ 143.9 $ 177.0 $ 0.9 $ — $ 321.8 Segment Profit 10.1 9.7 10.2 2.8 32.8 Capital Expenditures 48.3 24.1 — 4.3 76.7 Segment Assets 780.7 507.6 0.3 21.1 1,309.7 Nine Months Ended September 30, 2018 Revenues: Billed and Unbilled Revenue $ 151.1 $ 176.2 $ — $ — $ 327.3 Rate Adjustment Mechanism Revenue (3.7 ) (8.6 ) — — (12.3 ) Other Operating Revenue – Non-Regulated — — 3.5 — 3.5 Total Operating Revenues $ 147.4 $ 167.6 $ 3.5 $ — $ 318.5 Segment Profit 9.1 10.2 0.9 1.8 22.0 Capital Expenditures 53.1 20.8 — 2.4 76.3 Segment Assets 730.0 485.7 6.6 42.2 1,264.5

DEBT AND FINANCING ARRANGEMENTS

DEBT AND FINANCING ARRANGEMENTS	9 Months Ended
	Sep. 30, 2019
DEBT AND FINANCING ARRANGEMENTS	Note 4 Debt AND FINANCING ARRANGEMENTS Details on long-term debt at September 30, 2019, Sept e ($ millions) September 30, December 31, 2019 2018 2018 Unitil Corporation: 6.33% Senior Notes, Due May 1, 2022 $ 20.0 $ 20.0 $ 20.0 3.70% Senior Notes, Due August 1, 2026 30.0 30.0 30.0 Unitil Energy First Mortgage Bonds: 5.24% Senior Secured Notes, Due March 2, 2020 5.0 10.0 10.0 8.49% Senior Secured Notes, Due October 14, 2024 6.0 7.5 6.0 6.96% Senior Secured Notes, Due September 1, 2028 18.0 20.0 20.0 8.00% Senior Secured Notes, Due May 1, 2031 15.0 15.0 15.0 6.32% Senior Secured Notes, Due September 15, 2036 15.0 15.0 15.0 4.18% Senior Secured Notes, Due November 30, 2048 30.0 — 30.0 Fitchburg: 6.75% Senior Notes, Due November 30, 2023 5.7 7.6 5.7 6.79% Senior Notes, Due October 15, 2025 10.0 10.0 10.0 3.52% Senior Notes, Due November 1, 2027 10.0 10.0 10.0 7.37% Senior Notes, Due January 15, 2029 12.0 12.0 12.0 5.90% Senior Notes, Due December 15, 2030 15.0 15.0 15.0 7.98% Senior Notes, Due June 1, 2031 14.0 14.0 14.0 4.32% Senior Notes, Due November 1, 2047 15.0 15.0 15.0 Northern Utilities: 6.95% Senior Notes, Due December 3, 2018 — 10.0 — 5.29% Senior Notes, Due March 2, 2020 8.2 16.6 16.6 3.52% Senior Notes, Due November 1, 2027 20.0 20.0 20.0 7.72% Senior Notes, Due December 3, 2038 50.0 50.0 50.0 4.42% Senior Notes, Due October 15, 2044 50.0 50.0 50.0 4.32% Senior Notes, Due November 1, 2047 30.0 30.0 30.0 4.04% Senior Notes, Due September 12, 2049 40.0 — — Granite State: 7.15% Senior Notes, Due December 15, 2018 — 3.3 — 3.72% Senior Notes, Due November 1, 2027 15.0 15.0 15.0 Total Long-Term Debt 433.9 396.0 409.3 Less: Unamortized Debt Issuance Costs 3.5 3.1 3.5 Total Long-Term Debt, net of Unamortized Debt Issuance Costs 430.4 392.9 405.8 Less: Current Portion (1) 19.5 31.8 18.4 Total Long-term Debt, Less Current Portion $ 410.9 $ 361.1 $ 387.4 (1) The Current Portion of Long-Term Debt ​​​​​​​includes sinking ​​​​​​​fund payments. Fair Value of Long-Term Debt ($ millions) September 30, December 31, 2019 2018 2018 Estimated Fair Value of Long-Term Debt $ 495.1 $ 418.7 $ 422.0 On July 25, 2018, the Company entered into a Second Amended and Restated Credit Agreement and related documents (collectively, the “Credit Facility”) with a syndicate of lenders, which amended and restated in its entirety the Company’s prior credit facility. The Credit Facility extends to July 25, 2023, subject to two one-year one-month The Company utilizes the Credit Facility for cash management purposes related to its short-term operating activities. Total gross borrowings were $187.1 million for the nine months ended September 30, 2019. Total gross repayments were $220.7 million for the nine months ended September 30, 2019. The following table details the borrowing limits, amounts outstanding and amounts available under the Credit Facility as of September 30 2019, September 30, 2018 and December 31, 2018: Revolving Credit Facility September 30, December 31, 2019 2018 2018 Limit $ 120.0 $ 120.0 $ 120.0 Short-Term Borrowings Outstanding 49.2 69.1 82.8 Letter of Credit Outstanding 0.1 — — Available $ 70.7 $ 50.9 $ 37.2 The Credit Facility contains customary terms and conditions for credit facilities of this type, including affirmative and negative covenants. There are restrictions on, among other things, the Company’s and its subsidiaries’ ability to permit liens or incur indebtedness, and restrictions on the Company’s ability to merge or consolidate with another entity or change its line of business. The affirmative and negative covenants under the Credit Facility shall apply until the Credit Facility terminates and all amounts borrowed under the Credit Facility are paid in full (or with respect to letters of credit, they are cash collateralized). The only financial covenant in the Credit Facility provides that Funded Debt to Capitalization (as each term is defined in the Credit Facility) cannot exceed 65%, tested on a quarterly basis. At September 30, 2019, September 30, 2018 and December 31, 2018, the Company was in compliance with the covenants contained in the Credit Facility in effect on that date. The Company believes the future operating cash flows of the Company, along with its existing borrowing availability and access to financial markets for the issuance of new long-term debt, will be sufficient to meet any working capital and future operating requirements, and capital investment forecast opportunities. The average interest rates on all short-term borrowings and intercompany money pool transactions were 3.4% and 3.3% for the three months ended September 30, 2019 and September 30, 2018, respectively. The average interest rates on all short-term borrowings and intercompany money pool transactions were 3.6% and 3.2% for the nine months ended September 30, 2019 and September 30, 2018, respectively. The average interest rate on all short-term borrowings for the twelve months ended December 31, 2018 was 3.3%. As discussed previously, the Company divested of its non-regulated On September 12, 2019, Northern Utilities issued $40 million of Notes due 2049 On November 30, 2018 Unitil Energy issued $30 million of First Mortgage Bonds due November 30, 2048 at 4.18%. Unitil Energy used the net proceeds from this offering to repay short-term debt and for general corporate purposes. Approximately $0.5 million of costs associated with these issuances have been netted against long-term debt for presentation purposes on the Consolidated Balance Sheets. In April 2014, Unitil Service Corp. entered into a financing arrangement, structured as a capital lease obligation, for various information systems and technology equipment. Final funding under this capital lease occurred on October 30, 2015, resulting in total funding of $13.4 million. This capital lease was paid off in the second quarter of 2019. Unitil Corporation and its utility subsidiaries, Fitchburg, Unitil Energy, Northern Utilities, and Granite State are currently rated “BBB+” by Standard & Poor’s Ratings Services. Unitil Corporation and Granite State are currently rated “Baa2”, and Fitchburg, Unitil Energy and Northern Utilities are currently rated “Baa1” by Moody’s Investors Services. Northern Utilities enters into asset management agreements under which Northern Utilities releases certain 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 was $8.1 million, $9.6 million and $8.4 million of natural gas storage inventory at September 30, 2019, September 30, 2018 and December 31, 2018, respectively, related to these asset management agreements. The amount of natural gas inventory released in September 2019 and payable in October 2019 is $0.1 million and is recorded in Accounts Payable at September 30, 2019. The amount of natural gas inventory released in September 2018 and payable in October 2018 was $0.1 million and was recorded in Accounts Payable at September 30, 2018. The amount of natural gas inventory released in December 2018 and payable in January 2019 was $0.9 million and was recorded in Accounts Payable at December 31, 2018. Guarantees The Company provides limited guarantees on certain energy and natural gas storage management contracts entered into by the distribution utilities. The Company’s policy is to limit the duration of these guarantees. As of September 30, 2019, there were approximately $4.3 million of guarantees outstanding. Leases Unitil’s subsidiaries lease some of their vehicles, machinery and office equipment under both capital and operating lease arrangements. Total rental expense under operating leases charged to operations for the three months ended September 30, 2019 and 2018 amounted to $0.4 million and $0.4 million, respectively. Total rental expense under operating leases charged to operations for the nine months ended September 30, 2019 and 2018 amounted to $1.1 million and $1.4 million, respectively. The balance sheet classification of the Company’s lease obligations was as follows: September 30, December 31, Lease Obligations ($ millions) 2019 2018 2018 Operating Lease Obligations: Other Current Liabilities (current portion) $ 1.2 $ — $ — Other Noncurrent Liabilities (long-term portion) 3.0 — — Total Operating Lease Obligations 4.2 — — Capital Lease Obligations: Other Current Liabilities (current portion) 0.3 3.1 3.1 Other Noncurrent Liabilities (long-term portion) 0.3 3.4 2.7 Total Capital Lease Obligations 0.6 6.5 5.8 Total Lease Obligations $ 4.8 $ 6.5 $ 5.8 Cash paid for amounts included in the measurement of operating lease obligations for the nine months ended September 30, 2019 was $1.1 million and was included in Cash Provided by Operating Activities on the Consolidated Statements of Cash Flows. Assets under capital leases amounted to approximately $1.3 million, $15.0 million and $15.0 million as of September 30, 2019, September 30, 2018 and December 31, 2018, respectively, less accumulated amortization of $0.6 million, $2.1 million and $1.7 million, respectively and are included in Net Utility Plant on the Company’s Consolidated Balance Sheets. The following table is a schedule of future operating lease payment obligations and future minimum lease payments under capital leases as of September 30, 2019. The payments for capital leases consist of $0.3​​​​​​​​​​​​​​ million of current capital lease obligations, which are included in Other​​​​​​​ Current Liabilities and $ million of noncurrent capital lease obligations, which are included in Other Noncurrent Liabilities, on the Company’s Consolidated Balance Sheets as of September 30, 2019. The payments for operating leases consist of $1.2 million of current operating lease obligations, which are included in Other Current Liabilities and $3.0 million of noncurrent operating lease obligations, which are included in Other Noncurrent Liabilities, on the Company’s Consolidated Balance Sheets as of September 30, 2019. Lease Payments ($000’s) Year Ending December 31, Operating Leases Capital Leases Rest of 2019 $ 356 $ 80 2020 1,338 262 2021 1,168 161 2022 887 97 2023 587 55 2024-2028 400 — Total Payments 4,736 655 Less: Interest 507 35 Amount of Lease Obligations Recorded on Consolidated Balance Sheets $ 4,229 $ 620 Operating lease obligations are based on the net present value of the remaining lease payments over the remaining lease term. In determining the present value of lease payments, the Company used the interest rate stated in each lease agreement. As of September 30, 2019, the weighted average remaining lease term is 4.0 years and the weighted average operating discount rate used to determine the operating lease obligations was 5.3%. Disclosures Related to Periods Prior to the Adoption of ASU NO. 2016-02 – Leases (See Note 1). The payment amounts in the following table, which are as of December 31, 2018, would not differ substantially from the payment amounts as of September 30, 2018. Lease Payments ($000’s) Year Ending December 31, Operating Leases Capital Leases 2019 $ 1,372 $ 3,069 2020 1,138 2,535 2021 969 93 2022 689 32 2023 390 14 2024-2028 120 — Total Payments $ 4,678 $ 5,743

COMMON STOCK AND PREFERRED STOC

COMMON STOCK AND PREFERRED STOCK	9 Months Ended
	Sep. 30, 2019
COMMON STOCK AND PREFERRED STOCK	Note 5 Common Stock and preferred stock Common Stock The Company’s common stock trades on the New York Stock Exchange under the symbol, “UTL.” The Company had 14,872,011, 14,876,955 and 14,925,898 shares of common stock outstanding at September 30, 2018, December 31, 2018 and September 30, 2019, respectively. Dividend Reinvestment and Stock Purchase Plan – connection with its Dividend Reinvestment and Stock Purchase Plan (DRP) and its 401(k) plans resulting in net proceeds of approximately $889,000. 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 maximum number of shares available for awards to participants under the Stock Plan is 677,500. The maximum number of shares that may be awarded in any one calendar year to any one participant is 20,000. In the event of any change in capitalization of the Company, the Compensation Committee is authorized to make an equitable adjustment to the number and kind of shares of common stock that may be delivered under the Stock Plan and, in addition, may authorize and make an equitable adjustment to the Stock Plan’s annual individual award limit. Restricted Shares Outstanding awards of Restricted Shares fully vest over a period of four years On January 29, 2019, 33,150 Restricted Shares were issued in conjunction with the Stock Plan with an aggregate market value at the date of issuance of approximately $1.6 million. There were 50,917 and 49,581 non-vested 0.8 no Restricted Stock Units Non-management Stock Units will be paid such that the Director will receive (i) 70% of the shares of the Company’s common stock underlying the restricted stock units and (ii) cash in an amount equal to the fair market value of 30% of the shares of the Company’s common stock underlying the Restricted Stock Units. The equity portion of Restricted Stock Units activity during the nine months ended September 30, 2019 in conjunction with the Stock Plan is presented in the following table: Restricted Stock Units (Equity Portion) Units Weighted Average Stock Price Restricted Stock Units as of December 31, 2018 61,789 $ 38.25 Restricted Stock Units Granted — — Dividend Equivalents Earned 1,210 $ 57.08 Restricted Stock Units Settled — — Restricted Stock Units as of September 30, 2019 62,999 $ 38.61 There were 53,454 Restricted Stock Units outstanding as of September 30, 2018 with a weighted average stock price of $36.47. On October 1, 2019, there were 9,918 fully-vested Restricted Stock Units issued to members of the Company’s Board of Directors. Preferred Stock There was $0.2 million, or 1,887 shares, of Unitil Energy’s 6.00% Series Preferred Stock outstanding as of September 30, 2019. There was $0.2 million,

REGULATORY MATTERS

REGULATORY MATTERS	9 Months Ended
	Sep. 30, 2019
REGULATORY MATTERS	note 6 – REgulatory Matters Unitil’s Regulatory matters are described in Note 8 to the Financial Statements in Item 8 of Part II of Unitil Corporation’s Form 10-K for December 31, 2018 as filed with the Securities and Exchange Commission on january 31, 2019. Tax Cuts and Jobs Act of 2017 On December , , the Tax Cuts and Jobs Act of (TCJA) was signed into law. Among other things, the TCJA substantially reduced the corporate income tax rate to percent, effective January , . Each state public utility commission, with jurisdiction over the areas that are served by Unitil’s electric and gas subsidiary companies, issued orders directing how the tax law changes were to be reflected in rates. Unitil has complied with these orders and has made the required changes to its rates as directed by the commissions. The FERC opened a rulemaking proceeding on this matter which has been addressed in a rate settlement filing by Granite State. More recently, on November 15, 2018, the FERC issued a Notice of Proposed Rulemaking and a Policy Statement to address the TCJA’s effects on the Accumulated Deferred Income Taxes (ADIT) on transmission rates. Under the proposed rules all public utilities with transmission formula rates, including Fitchburg, would be required to: (1) include mechanisms to deduct any excess ADIT from or add any deficient ADIT to their rate bases; (2) include mechanisms in those rates that would raise or lower their income tax allowances by any amortized excess or deficient ADIT; and (3) incorporate a new permanent worksheet into their rates that will annually track information related to excess or deficient ADIT. The Company believes that these matters are substantially resolved and will not have a material impact on its financial position, operating results, or cash flows. Rate Case Activity Northern Utilities – Base Rates – Maine – percent increase over the Company’s test-year operating revenues. The intended rate effective date is April 1, 2020. In addition, Northern Utilities is requesting approval to implement a multi-year alternative rate mechanism (“Capital Investment Recovery Adjustment” or “CIRA”) that will allow for future changes to the Company’s distribution rates and mitigate the need to file a general rate case. The CIRA is designed to recover the costs of replacing, relocating and abandoning existing facilities and other operational and safety-related system improvements. The first annual adjustment is proposed for November 1, 2020, to recover the Company’s 2019 investment cost of eligible facilities and improvements. This matter remains pending. Northern Utilities – Targeted Infrastructure Replacement Adjustment (TIRA) – Maine – In its Final Order issued on February 28, 2018 for Northern Utilities’ last base rate case, the MPUC approved an extension of the TIRA mechanism, for an additional eight Northern Utilities – Base Rates – New Hampshire – Unitil Energy – Base Rates – effective May 1, 2017, followed by two annual rate step adjustments to recover the revenue requirements associated with certain capital expenditures. On April 30, 2018, the NHPUC approved Unitil Energy’s first step increase, effective May 1, 2018. On April 22, 2019, the NHPUC approved Unitil Energy’s second and final step adjustment, providing for a revenue increase of approximately , effective May 1, 2019. Fitchburg – Base Rates – Electric – Fitchburg’s base rates are decoupled, and subject to an annual revenue decoupling adjustment mechanism, which includes a cap on the amount that rates may be increased in any year. In addition, Fitchburg has an annual capital cost recovery mechanism to recover the revenue requirement associated with certain capital additions. On April 3, 2019, the DPU approved Fitchburg’s cumulative revenue requirement associated with the Company’s 2015 and 2016 capital expenditures, an increase of $0.4 million. The increase was effective January 1, 2018. On November 1, 2018 On September 5, 2019, Fitchburg’s electric division filed with the MDPU a letter of intent to file for a general increase in base rates. Under MDPU precedent, a utility company is required to provide no less than a 30 day advance notice of its intent to file for a base rate increase. At this time, Fitchburg anticipates that the filing will be made during the fourth quarter 2019. Fitchburg – Base Rates – Gas – they result in just and reasonable rates. On September 5, 2019, Fitchburg’s gas division filed with the MDPU a letter of intent to file for a general increase in base rates. Under MDPU precedent, a utility company is required to provide no less than a 30 day advance notice of its intent to file for a base rate increase. At this time, Fitchburg anticipates that the filing will be made during the fourth quarter 2019. Fitchburg – Gas System Enhancement Program – In an Order issued on April 30, 2019, the MDPU approved Fitchburg’s 2018 GSEP Filing and increased the annual cap on recovery. Because the amount approved for recovery, $1.6 million, still exceeded the annual cap, the Order resulted in a revenue increase of $1.0 million that went into effect on May 1, 2019, subject to reconciliation. The amount that exceeded the cap, $0.6 million, has been deferred to be recovered in a later proceeding. On May 1, 2019, the Company made its 2019 GREC Filing, seeking a waiver of the annual cap and a revenue increase of $1.0 million. This matter remains pending. Granite State – Base Rates – Other Matters Fitchburg – Independent Statewide Examination of the Safety of the Commonwealth’s Gas Distribution System – on-going Northern Utilities / Granite State – Firm Capacity Contract – one​​​​​​​-year 12-month Reconciliation Filings – Fitchburg – Massachusetts RFPs – one ISO-NE ISO-NE The EDCs issued the RFP pursuant to Section 83C for Long-Term Contracts for Offshore Wind Energy Generation in June 2017. Final selection of projects was made in May 2018, contracts were signed in July 2018 and on July 23, 2018, the EDCs, including Fitchburg, filed two long-term contracts, each for 400MW of offshore wind energy generation with MDPU for approval. On April 12, 2019, the MDPU approved the Offshore Wind Energy Generation power purchase agreements, including the EDCs’ proposal to sell the energy procured under the contract into the ISO-NE ISO-NE 2.75 The EDCs issued an RFP pursuant to Section 83C for Long-Term Contracts for Offshore Wind Energy Generation on May 23 400 Proposals were received on August 23, 2019, and selection is to occur on November 8, 2019, contracts are to be executed by December 13, 2019, and filed with the Department on January 10, 2020. Northern Utilities Gas Supply Cost Investigation – FERC Transmission Formula Rate Proceedings – ISO-New Also pending at FERC is a Section 206 proceeding concerning the justness and reasonableness of ISO-New to the Chief Administrative Law Judge to resume hearing procedures. On May , the judge appointed a Dispute Resolution Facilitator to aid parties in settlement negotiations. The procedural schedule was suspended September , in order to allow participants to focus on settlement negotiations. The initial decision has been rescheduled to be issued on November , . Fitchburg and Unitil Energy are Participating Transmission Owners, although Unitil Energy does not own transmission plant. To the extent that these proceedings result in any changes to the rates being charged, a retroactive reconciliation may be required. The Company does not believe that these proceedings will have a material adverse impact on the Company’s financial condition or results of operations. 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 its financial position, operating results or cash flows.

ENVIRONMENTAL MATTERS

ENVIRONMENTAL MATTERS	9 Months Ended
	Sep. 30, 2019
ENVIRONMENTAL MATTERS	NOTE 7 – ENVIRONMENTAL MATTERS UNITIL’S ENVIRONMENTAL MATTERS ARE DESCRIBED IN NOTE 8 TO THE FINANCIAL STATEMENTS IN ITEM 8 OF PART II OF UNITIL CORPORATION’S FORM 10-K 31, 2018 AS FILED WITH THE SECURITIES AND EXCHANGE COMMISSION ON JANUARY 31, 2019. The Company’s past and present operations include activities that are generally subject to extensive and complex federal and state environmental laws and regulations. The Company is in material compliance with applicable environmental and safety laws and regulations and, as of September 30, 2019, has not identified any material losses reasonably likely to be incurred in excess of recorded amounts. However, the Company cannot assure that significant costs and liabilities will not be incurred in the future. It is possible that other developments, such as increasingly stringent federal, state or local environmental laws and regulations could result in increased environmental compliance costs. Based on 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. Northern Utilities Manufactured Gas Plant Sites – mid-1800s mid-1900s. Northern Utilities has worked with the Maine Department of Environmental Protection and New Hampshire Department of Environmental Services (NH DES) to address environmental concerns with these sites. Northern Utilities or others have completed remediation activities at all sites; however, on site monitoring continues at several sites which may result in future remedial actions as directed by the applicable regulatory agency. In July 2019, the NH DES requested that Northern Utilities review modeled expectations for groundwater contaminants against observed data at Rochester. The results of the review, along with any recommendations, will be submitted to the NH DES in January 2020. The Company has accrued $0.7 million for estimated costs to complete the remediation at the Rochester site, which is included in the Environmental Obligations table below. The NHPUC and MPUC have approved regulatory mechanisms for the recovery of MGP environmental costs. For Northern Utilities’ New Hampshire division, the NHPUC has approved the recovery of MGP environmental costs over succeeding seven five The Environmental Obligations table below shows the amounts accrued for Northern Utilities related to estimated future cleanup costs associated with Northern Utilities’ environmental remediation obligations for former MGP sites. Corresponding Regulatory Assets were recorded to reflect that the future recovery of these environmental remediation costs is expected based on regulatory precedent and established practices. Fitchburg’s Manufactured Gas Plant Site – The Environmental Obligations table below shows the amounts accrued for Fitchburg related to estimated and periodic, regulatory review costs for the completed permanent remediation of the Sawyer Passway site. A corresponding Regulatory Asset was recorded to reflect that the recovery of these environmental remediation costs is probable through the regulatory process. 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. The following table sets forth a summary of changes in the Company’s liability for the current and long-term portions of the Company’s environmental obligations, which are included in Other Current Liabilities and Other Noncurrent Liabilities, respectively, on the Company’s ​​​​​​​Consolidated Balance Sheets as of September 30, 2019 and 2018. Environmental Obligations ($ millions) Fitchburg Northern Total Nine months ended September 30, 2019 2018 2019 2018 2019 2018 Total Balance at Beginning of Period $ — $ 0.1 $ 2.0 $ 2.0 $ 2.0 $ 2.1 Additions — — 1.0 0.6 1.0 0.6 Less: Payments / Reductions — 0.1 0.2 0.5 0.2 0.6 Total Balance at End of Period — — 2.8 2.1 2.8 2.1 Less: Current Portion — — 0.6 0.6 0.6 0.6 Noncurrent Balance at End of Period $ — $ $ 2.2 $ 1.5 $ 2.2 $ 1.5

INCOME TAXES

INCOME TAXES	9 Months Ended
	Sep. 30, 2019
INCOME TAXES	Note 8: INCOME TAXES In June 2019 the Company received notice that the Internal Revenue Service (IRS) completed​​​​​​​ all fieldwork for the tax years December 31, 2015 and December 31, 2016 income tax audit and closed the audit with no adjustment. Income tax filings for the year ended December 31, 2018 have been filed with the IRS, Massachusetts Department of Revenue, the Maine Revenue Service, and the New Hampshire Department of Revenue Administration. The Company evaluated its tax positions at September 30, 2019 de-recognition, In December 2017, the Tax Cuts and Jobs Act (TCJA), which included a reduction to the corporate federal income tax rate to 21% effective January 1, 2018, was signed into law. In accordance with GAAP Accounting Standard 740, the Company revalued its Accumulated Deferred Income Taxes (ADIT) at the new 21% tax rate at which the ADIT will be reversed in future periods. The Company recorded a net Regulatory Liability in the amount of $48.9 million at December 31, 2017 as a result of the ADIT revaluation. The MDPU issued a multi-utility Order D.P.U. 18-15-E non-plant D.P.U.18-15-E On November 15, 2018 the FERC issued two pronouncements regarding the accounting for income taxes due to the TCJA; 1) Notice of Proposed Rulemaking Docket No. RM 19-5-000 19-2-000 Based on communications received by the Company from its state regulators in rate cases and other regulatory proceedings in the first quarter of 2018 and as prescribed in the TCJA, the recent FERC guidance noted above and IRS normalization rules; the benefit of these protected excess ADIT amounts will be subject to flow back to customers in future utility rates according to the Average Rate Assumption Method (ARAM). ARAM reconciles excess ADIT at the reversal rate of the underlying book/tax temporary timing differences. The Company estimates the ARAM flow back period for protected and unprotected excess ADIT to be between fifteen In addition to the protected excess $47.1 million ADIT amounts the Company expects to flow through to customers in utility rates, as noted above, there is approximately $1.8 million of excess ADIT created through reconciling mechanisms at December 31, 2017, related to the implementation of the new federal tax rate of the TCJA, which had not been previously collected from customers through utility rates. The Company will reconcile these excess ADIT amounts through the specific reconciliation mechanisms in the next filing of each of those individual reconciling mechanisms which will be subject to the review of state regulators. In addition to the $48.9 million of net excess ADIT noted above; there wa has recognized $1.4 million in the first nine months of 2019. Of the remaining amount, the Company expects to recognize $0.4 million in the fourth quarter of 2019 and $1.6 million in 2020, in accordance with regulatory guidance as discussed above. In the fourth quarter of 2018 the Company was ordered in D.P.U. 18-15-E re-measurement Under the Company’s Tax Sharing Agreement (the “Agreement”) which was approved upon the formation of Unitil as a PUHC; the Company files consolidated Federal and State tax returns and Unitil Corporation and each of its utility operating subsidiaries recognize the results of their operations in its tax returns as if it were a stand-alone taxpayer. The Agreement provides that the Company will account for income taxes in compliance with U.S. GAAP and regulatory accounting principles. The Company filed its tax returns for the year ended December 31, 201 8 9 utilized federal NOLC assets of $5.7 million principally due to pension cost deductions, tax repair deductions, tax depreciation and research and development deductions. As of September 30, 2019, the Company had recorded cumulative federal and state NOLC assets of $11.9 million , on its filed tax returns 8 In assessing the near-term use of NOLCs and tax credits, the Company evaluates the expected level of future taxable income, available tax planning strategies, reversals of existing taxable temporary differences and taxable income available in carryback years. Based on all available evidence, both positive and negative, and the weight of that evidence to the extent such evidence can be objectively verified, the Company expects to utilize all of its NOLCs by December 31, 2020 prior to their expiration in 2029. The Company bills its customers for sales tax in Massachusetts and Maine. 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.

RETIREMENT BENEFIT OBLIGATIONS

RETIREMENT BENEFIT OBLIGATIONS	9 Months Ended
	Sep. 30, 2019
RETIREMENT BENEFIT OBLIGATIONS	Note Retirement Benefit obligations The Company co-sponsors 10-K The following table includes the key weighted average assumptions used in determining the Company’s benefit plan costs and obligations: Used to Determine Plan Costs 2019 2018 Discount Rate 4.25 % 3.60 % Rate of Compensation Increase 3.00 % 3.00 % Expected Long-term rate of return on plan assets 7.75 % 7.75 % Health Care Cost Trend Rate Assumed for Next Year 7.00 % 7.50 % Ultimate Health Care Cost Trend Rate 4.50 % 4.50 % Year that Ultimate Health Care Cost Trend Rate is reached 2024 2024 The following tables provide the components of the Company’s Retirement plan costs ($000’s): Pension Plan PBOP Plan SERP Plan Three Months Ended September 30, 2019 2018 2019 2018 2019 2018 Service Cost $ 776 $ 848 $ 576 $ 733 $ 62 $ 122 Interest Cost 1,621 1,469 857 852 142 101 Expected Return on Plan Assets (2,119 ) (1,946 ) (412 ) (409 ) — — Prior Service Cost Amortization 80 81 304 327 14 47 Actuarial Loss Amortization 1,081 1,447 56 346 157 121 Sub-total 1,439 1,899 1,381 1,849 375 391 Amounts Capitalized and Deferred (650 ) (962 ) (650 ) (930 ) (107 ) (113 ) Net Periodic Benefit Cost Recognized $ 789 $ 937 $ 731 $ 919 $ 268 $ 278 Pension Plan PBOP Plan SERP Plan Nine Months Ended September 30, 2019 2018 2019 2018 2019 2018 Service Cost $ 2,328 $ 2,544 $ 1,728 $ 2,199 $ 185 $ 366 Interest Cost 4,863 4,407 2,569 2,554 426 303 Expected Return on Plan Assets (6,356 ) (5,838 ) (1,234 ) (1,227 ) — — Prior Service Cost Amortization 240 243 910 981 42 141 Actuarial Loss Amortization 3,243 4,341 170 1,038 471 365 Sub-total 4,318 5,697 4,143 5,545 1,124 1,175 Amounts Capitalized and Deferred (1,659 ) (2,590 ) (1,730 ) (2,557 ) (322 ) (339 ) Net Periodic Benefit Cost Recognized $ 2,659 $ 3,107 $ 2,413 $ 2,988 $ 802 $ 836 Employer Contributions As of September 30, 2019, the Company had made $6.9 million and $2.8 million of contributions to its Pension and PBOP Plans, respectively, in 2019. The Company, along with its subsidiaries, expects to continue to make contributions to its Pension and PBOP Plans in 2019 and future years at minimum required and discretionary funding levels consistent with the amounts recovered in the distribution utilities’ rates for these Pension and PBOP Plan costs. As of September 30, 2019, the Company had made $0.4 million of benefit​​​​​​​ payments under the SERP Plan in 2019. The Company presently anticipates making an additional $0.2 million of benefit payments under the SERP Plan in 2019.

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	9 Months Ended
	Sep. 30, 2019
Accounting Policies [Abstract]
Nature of Operations	Nature of Operations non-regulated The Company’s earnings are seasonal and are typically higher in the first and fourth quarters when customers use natural gas for heating purposes. 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 three 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 non-regulated
Basis of Presentation	Basis of Presentation – 10-Q 10-K
Divestiture of Non-Regulated Business Subsidiary	Divestiture of Non-Regulated Business Subsidiary – non-regulated after-tax pre-tax
Utility Revenue Recognition	Utility Revenue Recognition – Billed and unbilled revenue is recorded when service is rendered or energy is delivered to customers. However, the determination of energy sales to individual customers is based on the reading of their meters, which occurs on a systematic basis throughout the month. At the end of each calendar month, amounts of energy delivered to customers since the date of the last meter reading are estimated and the corresponding unbilled revenues are calculated. These unbilled revenues are calculated each month based on estimated customer usage by class and applicable customer rates and are then reversed in the following month when billed to customers. A majority of the Company’s revenue from contracts with customers continues to be recognized on a monthly basis based on applicable tariffs and customer monthly consumption. Such revenue is recognized using the invoice practical expedient which allows an entity to recognize revenue in the amount that directly corresponds to the value transferred to the customer. The Company’s billed and unbilled revenue meets the definition of “revenues from contracts with customers” as defined in ASU 2014-09. 980-605-25-3, 2014-09 In the following tables, revenue is classified by the types of goods/services rendered and market/customer type. Three Months Ended September 30, 2019 Gas and Electric Operating Revenues ($ millions): Gas Electric Total Billed and Unbilled Revenue: Residential $ 6.9 $ 31.3 $ 38.2 C&I 12.5 24.5 37.0 Other 1.1 1.5 2.6 Total Billed and Unbilled Revenue 20.5 57.3 77.8 Rate Adjustment Mechanism Revenue 4.4 3.1 7.5 Total Gas and Electric Operating Revenues $ 24.9 $ 60.4 $ 85.3 Three Months Ended September 30, 2018 Gas and Electric Operating Revenues ($ millions): Gas Electric Total Billed and Unbilled Revenue: Residential $ 6.6 $ 33.6 $ 40.2 C&I 11.9 25.3 37.2 Other 1.1 2.0 3.1 Total Billed and Unbilled Revenue 19.6 60.9 80.5 Rate Adjustment Mechanism Revenue 6.1 0.5 6.6 Total Gas and Electric Operating Revenues $ 25.7 $ 61.4 $ 87.1 Nine Months Ended September 30, 2019 Gas and Electric Operating Revenues ($ millions): Gas Electric Total Billed and Unbilled Revenue: Residential $ 61.4 $ 94.8 $ 156.2 C&I 89.5 72.2 161.7 Other 9.1 5.8 14.9 Total Billed and Unbilled Revenue 160.0 172.8 332.8 Rate Adjustment Mechanism Revenue (16.1 ) 4.2 (11.9 ) Total Gas and Electric Operating Revenues $ 143.9 $ 177.0 $ 320.9 Nine Months Ended September 30, 2018 Gas and Electric Operating Revenues ($ millions): Gas Electric Total Billed and Unbilled Revenue: Residential $ 58.3 $ 95.6 $ 153.9 C&I 84.7 74.1 158.8 Other 8.1 6.5 14.6 Total Billed and Unbilled Revenue 151.1 176.2 327.3 Rate Adjustment Mechanism Revenue (3.7 ) (8.6 ) (12.3 ) Total Gas and Electric Operating Revenues $ 147.4 $ 167.6 $ 315.0 Fitchburg is subject to revenue decoupling. Revenue decoupling is the term given to the elimination of the dependency of a utility’s distribution revenue on the volume of electricity or natural gas sales. The difference between distribution revenue amounts billed to customers and the targeted revenue decoupling amounts is recorded as an increase or a decrease in Accrued Revenue, which forms the basis for resetting rates for future cash recoveries from, or credits to, customers. These revenue decoupling targets may be adjusted as a result of rate cases that the Company files with the Massachusetts Department of Public Utilities (MDPU). The Company estimates that revenue decoupling applies to approximately 27% and 11% of Unitil’s total annual electric and natural gas sales volumes, respectively.
Other Operating Revenue - Non-regulated	Other Operating Revenue – Non-regulated – Other Operating Revenue – Non-regulated – Other Operating Revenue consists solely of revenue from Usource, Unitil’s non-regulated
Income Taxes	Income Taxes – Provisions for income taxes are calculated in each of the jurisdictions in which the Company operates for each period for which a statement of earnings is presented. The Company accounts for income taxes in accordance with the FASB Codification guidance on Income Taxes, which requires an asset and liability approach for the financial accounting and reporting of income taxes. Significant judgments and estimates are required in determining the current and deferred tax assets and liabilities. The Company’s current and deferred tax assets and liabilities reflect its best assessment of estimated future taxes to be paid. In accordance with the FASB Codification, the Company periodically assesses the realization of its deferred tax assets and liabilities and adjusts the income tax provision, the current tax liability and deferred taxes in the period in which the facts and circumstances which gave rise to the revision become known.
Cash and Cash Equivalents	Cash and Cash Equivalents – (ISO-NE) ISO-NE. 2-1/2 ISO-NE
Allowance for Doubtful Accounts	Allowance for Doubtful Accounts – written-off shut-off. The Allowance for Doubtful Accounts as of September 30, 2019, September 30, 2018 and December 31, 2018, which is included in Accounts Receivable, net on the accompanying unaudited consolidated balance sheets, was as follows: ($ millions) September 30, December 31, 2019 2018 2018 Allowance for Doubtful Accounts $ 1.0 $ 1.2 $ 1.3
Accrued Revenue	Accrued Revenue – September 30, December 31, Accrued Revenue ($ millions) 2019 2018 2018 Regulatory Assets – Current $ 24.9 $ 26.4 $ 41.3 Unbilled Revenues 10.4 9.6 13.4 Total Accrued Revenue $ 35.3 $ 36.0 $ 54.7
Exchange Gas Receivable	Exchange Gas Receivable – The following table shows the components of Exchange Gas Receivable as of September 30, 2019, September 30, 2018 and December 31, 2018. September 30, December 31, Exchange Gas Receivable ($ millions) 2019 2018 2018 Northern Utilities $ 8.0 $ 9.5 $ 7.5 Fitchburg 0.6 0.6 0.6 Total Exchange Gas Receivable $ 8.6 $ 10.1 $ 8.1
Gas Inventory	Gas Inventory September 30, December 31, Gas Inventory ($ millions) 2019 2018 2018 Natural Gas $ 0.4 $ 0.4 $ 0.3 Propane 0.3 0.4 0.4 Liquefied Natural Gas & Other 0.1 0.1 0.1 Total Gas Inventory $ 0.8 $ 0.9 $ 0.8
Utility Plan	Utility Plant –
Leases	Leases – 2016-02, .
Regulatory Accounting	Regulatory Accounting – (MPUC) and NHPUC. Granite State, the Company’s natural gas transmission pipeline, is regulated by the FERC. Accordingly, the Company uses the Regulated Operations guidance as set forth in the FASB Codification. The Company has recorded Regulatory Assets and Regulatory Liabilities which will be recovered from customers, or applied for customer benefit, in accordance with rate provisions approved by the applicable public utility regulatory commission. September 30, December 31, Regulatory Assets consist of the following ($ millions) 2019 2018 2018 Retirement Benefits $ 74.0 $ 88.0 $ 72.0 Energy Supply & Other Rate Adjustment Mechanisms 20.6 24.8 38.4 Deferred Storm Charges 5.0 6.3 6.3 Environmental 8.0 8.9 7.9 Income Taxes 4.3 5.9 5.7 Other 11.7 4.1 10.0 Total Regulatory Assets 123.6 138.0 140.3 Less: Current Portion of Regulatory Assets (1) 24.9 26.4 41.3 Regulatory Assets – noncurrent $ 98.7 $ 111.6 $ 99.0 (1) Reflects amounts included in Accrued Revenue, discussed above, on the Company’s Consolidated Balance Sheets. September 30, December 31, Regulatory Liabilities consist of the following ($ millions) 2019 2018 2018 Income Taxes (Note 8) $ 47.6 $ 47.9 $ 47.0 Energy Supply & Other Rate Adjustment Mechanisms 13.5 12.2 11.5 Total Regulatory Liabilities 61.1 60.1 58.5 Less: Current Portion of Regulatory Liabilities 14.4 12.2 11.5 Regulatory Liabilities—noncurrent $ 46.7 $ 47.9 $ 47.0 Generally, the Company receives a return on investment on its regulated assets for which a cash outflow has been made. As of September 30, 2019 there are $5.8 million of environmental costs, rate case costs and other expenditures to be recovered over varying periods in the next seven years which regulators have authorized recovery of, but without a return. Regulatory commissions can reach different conclusions about the recovery of costs, which can have a material impact on the Company’s Consolidated Financial Statements. The Company believes it is probable that its regulated distribution and transmission utilities will recover their investments in long-lived assets, including regulatory assets. If the Company, or a portion of its assets or operations, were to cease meeting the criteria for application of these accounting rules, accounting standards for businesses in general would become applicable and immediate recognition of any previously deferred costs, or a portion of deferred costs, would be required in the year in which the criteria are no longer met, if such deferred costs were not recoverable in the portion of the business that continues to meet the criteria for application of the FASB Codification topic on Regulated Operations. If unable to continue to apply the FASB Codification provisions for Regulated Operations, the Company would be required to apply the provisions for the Discontinuation of Rate-Regulated Accounting included in the FASB Codification. In the Company’s opinion, its regulated operations will be subject to the FASB Codification provisions for Regulated Operations for the foreseeable future.
Derivatives	Derivatives – As discussed below in the “Fitchburg – Massachusetts RFP’s” section of Note 6 (Regulatory Matters), Fitchburg has entered into power purchase agreements for which contingencies exist. Until these contingencies are satisfied, these contracts will not qualify for derivative accounting. The Company believes that the power purchase obligations under these long-term contracts will have a material impact on the contractual obligations and regulatory assets of Fitchburg, once they qualify for derivative accounting.
Investments in Marketable Securities	Investments in Marketable Securities T At September 30, 2019, September 30, 2018 and December 31, 2018, the fair value of the Company’s investments in these trading securities, which are recorded on the Consolidated Balance Sheets in Other Assets, were $5.9 million, $5.3 million and $4.8 million, respectively, as shown in the table below. These investments are valued based on quoted prices from active markets and are categorized in Level 1 as they are actively traded and no valuation adjustments have been applied. Changes in the fair value of these investments are recorded in Other Expense (Income), Net. September 30, December 31, Fair Value of Marketable Securities ($ millions) 2019 2018 2018 Equity Funds $ — $ 3.0 $ — Fixed Income Funds — 2.3 — Money Market Funds 5.9 — 4.8 Total Marketable Securities $ 5.9 $ 5.3 $ 4.8 The Company also sponsors the Unitil Corporation Deferred Compensation Plan (the “DC Plan”). The DC Plan is a non-qualified tax-deferred At September 30, 2019, September 30, 2018 and December 31, 2018, the fair value of the Company’s investments in these trading securities related to the DC Plan, which are recorded on the Consolidated Balance Sheets in Other Assets, were $0.1 million, $0 and $0, respectively, as shown in the table below. These investments are valued based on quoted prices from active markets and are categorized in Level 1 as they are actively traded and no valuation adjustments have been applied. September 30, December 31, Fair Value of Marketable Securities ($ millions) 2019 2018 2018 Equity Funds $ — $ — $ — Money Market Funds 0.1 — — Total Marketable Securities $ 0.1 $ — $ —
Energy Supply Obligations	Energy Supply Obligations September 30, December 31, Energy Supply Obligations ($ millions) 2019 2018 2018 Current: Exchange Gas Obligation $ 8.0 $ 9.5 $ 7.5 Renewable Energy Portfolio Standards 4.2 5.2 5.6 Power Supply Contract Divestitures 0.3 0.3 0.3 Total Energy Supply Obligations – Current 12.5 15.0 13.4 Noncurrent: Power Supply Contract Divestitures 0.4 0.7 0.6 Total Energy Supply Obligations $ 12.9 $ 15.7 $ 14.0 Exchange Gas Obligation – Renewable Energy Portfolio Standards Fitchburg has entered into long-term renewable contracts for the purchase of clean energy and/or renewable energy certificates (RECs) pursuant to Massachusetts legislation, specifically, An Act Relative to Green Communities (“Green Communities Act”, 2008), An Act Relative to Competitively Priced Electricity in the Commonwealth (2012) and An Act to Promote Energy Diversity (“Energy Diversity Act”, 2016). The generating facilities associated with four of these contracts have been constructed and are now operating. Since 2017, the Company has participated in two major statewide procurements which resulted in contracts for imported hydroelectric power and associated transmission and for offshore wind generation. The contracts were approved by the MDPU in the second quarter of 2019. Additional long-term clean energy contracts are expected in compliance with the Energy Diversity Act and An Act to Promote a Clean Energy Future (2018). Fitchburg recovers the costs associated with long-term renewable contracts on a fully reconciling basis through a MDPU-approved cost recovery mechanism. Power Supply Contract Divestitures –
Recently Issued Pronouncements	Recently Issued Pronouncements – 2016-02, Other than the pronouncement discussed above, there are no recently issued pronouncements that the Company has not already adopted or that have a material impact on the Company.
Subsequent Events	Subsequent Events –

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	9 Months Ended
	Sep. 30, 2019
Components of Gas and Electric Operating Revenue	In the following tables, revenue is classified by the types of goods/services rendered and market/customer type. Three Months Ended September 30, 2019 Gas and Electric Operating Revenues ($ millions): Gas Electric Total Billed and Unbilled Revenue: Residential $ 6.9 $ 31.3 $ 38.2 C&I 12.5 24.5 37.0 Other 1.1 1.5 2.6 Total Billed and Unbilled Revenue 20.5 57.3 77.8 Rate Adjustment Mechanism Revenue 4.4 3.1 7.5 Total Gas and Electric Operating Revenues $ 24.9 $ 60.4 $ 85.3 Three Months Ended September 30, 2018 Gas and Electric Operating Revenues ($ millions): Gas Electric Total Billed and Unbilled Revenue: Residential $ 6.6 $ 33.6 $ 40.2 C&I 11.9 25.3 37.2 Other 1.1 2.0 3.1 Total Billed and Unbilled Revenue 19.6 60.9 80.5 Rate Adjustment Mechanism Revenue 6.1 0.5 6.6 Total Gas and Electric Operating Revenues $ 25.7 $ 61.4 $ 87.1 Nine Months Ended September 30, 2019 Gas and Electric Operating Revenues ($ millions): Gas Electric Total Billed and Unbilled Revenue: Residential $ 61.4 $ 94.8 $ 156.2 C&I 89.5 72.2 161.7 Other 9.1 5.8 14.9 Total Billed and Unbilled Revenue 160.0 172.8 332.8 Rate Adjustment Mechanism Revenue (16.1 ) 4.2 (11.9 ) Total Gas and Electric Operating Revenues $ 143.9 $ 177.0 $ 320.9 Nine Months Ended September 30, 2018 Gas and Electric Operating Revenues ($ millions): Gas Electric Total Billed and Unbilled Revenue: Residential $ 58.3 $ 95.6 $ 153.9 C&I 84.7 74.1 158.8 Other 8.1 6.5 14.6 Total Billed and Unbilled Revenue 151.1 176.2 327.3 Rate Adjustment Mechanism Revenue (3.7 ) (8.6 ) (12.3 ) Total Gas and Electric Operating Revenues $ 147.4 $ 167.6 $ 315.0
Allowance for Doubtful Accounts Included in Accounts Receivable Net	The Allowance for Doubtful Accounts as of September 30, 2019, September 30, 2018 and December 31, 2018, which is included in Accounts Receivable, net on the accompanying unaudited consolidated balance sheets, was as follows: ($ millions) September 30, December 31, 2019 2018 2018 Allowance for Doubtful Accounts $ 1.0 $ 1.2 $ 1.3
Components of Accrued Revenue	The following table shows the components of Accrued Revenue as of September 30, 2019, September 30, 2018 and December 31, 2018. September 30, December 31, Accrued Revenue ($ millions) 2019 2018 2018 Regulatory Assets – Current $ 24.9 $ 26.4 $ 41.3 Unbilled Revenues 10.4 9.6 13.4 Total Accrued Revenue $ 35.3 $ 36.0 $ 54.7
Components of Exchange Gas Receivable	The following table shows the components of Exchange Gas Receivable as of September 30, 2019, September 30, 2018 and December 31, 2018. September 30, December 31, Exchange Gas Receivable ($ millions) 2019 2018 2018 Northern Utilities $ 8.0 $ 9.5 $ 7.5 Fitchburg 0.6 0.6 0.6 Total Exchange Gas Receivable $ 8.6 $ 10.1 $ 8.1
Components of Gas Inventory	The following table shows the components of Gas Inventory as of September 30, 2019, September 30, 2018 and December 31, 2018. September 30, December 31, Gas Inventory ($ millions) 2019 2018 2018 Natural Gas $ 0.4 $ 0.4 $ 0.3 Propane 0.3 0.4 0.4 Liquefied Natural Gas & Other 0.1 0.1 0.1 Total Gas Inventory $ 0.8 $ 0.9 $ 0.8
Regulatory Assets	September 30, December 31, Regulatory Assets consist of the following ($ millions) 2019 2018 2018 Retirement Benefits $ 74.0 $ 88.0 $ 72.0 Energy Supply & Other Rate Adjustment Mechanisms 20.6 24.8 38.4 Deferred Storm Charges 5.0 6.3 6.3 Environmental 8.0 8.9 7.9 Income Taxes 4.3 5.9 5.7 Other 11.7 4.1 10.0 Total Regulatory Assets 123.6 138.0 140.3 Less: Current Portion of Regulatory Assets (1) 24.9 26.4 41.3 Regulatory Assets – noncurrent $ 98.7 $ 111.6 $ 99.0 (1) Reflects amounts included in Accrued Revenue, discussed above, on the Company’s Consolidated Balance Sheets.
Regulatory Liabilities	September 30, December 31, Regulatory Liabilities consist of the following ($ millions) 2019 2018 2018 Income Taxes (Note 8) $ 47.6 $ 47.9 $ 47.0 Energy Supply & Other Rate Adjustment Mechanisms 13.5 12.2 11.5 Total Regulatory Liabilities 61.1 60.1 58.5 Less: Current Portion of Regulatory Liabilities 14.4 12.2 11.5 Regulatory Liabilities—noncurrent $ 46.7 $ 47.9 $ 47.0
Fair Value of Marketable Securities	Changes in the fair value of these investments are recorded in Other Expense (Income), Net. September 30, December 31, Fair Value of Marketable Securities ($ millions) 2019 2018 2018 Equity Funds $ — $ 3.0 $ — Fixed Income Funds — 2.3 — Money Market Funds 5.9 — 4.8 Total Marketable Securities $ 5.9 $ 5.3 $ 4.8
Components of Energy Supply Obligations	The following ​​​​​​​discussion and table summarize the nature and amounts of the items recorded on the Company’s Consolidated Balance Sheets. The current portion of these obligations is recorded as Energy Supply Obligations and the noncurrent portion is included in Other Noncurrent Liabilities on the Company’s Consolidated Balance Sheets. September 30, December 31, Energy Supply Obligations ($ millions) 2019 2018 2018 Current: Exchange Gas Obligation $ 8.0 $ 9.5 $ 7.5 Renewable Energy Portfolio Standards 4.2 5.2 5.6 Power Supply Contract Divestitures 0.3 0.3 0.3 Total Energy Supply Obligations – Current 12.5 15.0 13.4 Noncurrent: Power Supply Contract Divestitures 0.4 0.7 0.6 Total Energy Supply Obligations $ 12.9 $ 15.7 $ 14.0
Deferred Compensation Plan [Member]
Fair Value of Marketable Securities	Changes in the fair value of these investments are recorded in Other Expense, Net. September 30, December 31, Fair Value of Marketable Securities ($ millions) 2019 2018 2018 Equity Funds $ — $ — $ — Money Market Funds 0.1 — — Total Marketable Securities $ 0.1 $ — $ —

DIVIDENDS DECLARED PER SHARE (T

DIVIDENDS DECLARED PER SHARE (Tables)	9 Months Ended
	Sep. 30, 2019
DIVIDENDS DECLARED PER SHARE [Abstract]
Schedule of Dividends Declared	Declaration Date Date Paid (Payable) Shareholder of Record Date Dividend Amount 10/23/19 11/27/19 11/13/19 $ 0.370 07/24/19 08/29/19 08/15/19 $ 0.370 04/24/19 05/29/19 05/15/19 $ 0.370 01/30/19 02/28/19 02/14/19 $ 0.370 10/24/18 11/29/18 11/15/18 $ 0.365 07/25/18 08/29/18 08/15/18 $ 0.365 04/25/18 05/29/18 05/15/18 $ 0.365 01/30/18 02/28/18 02/14/18 $ 0.365

SEGMENT INFORMATION (Tables)

SEGMENT INFORMATION (Tables)	9 Months Ended
	Sep. 30, 2019
Significant Segment Financial Data	The following table provides significant segment financial data for the three and nine months ended September 30, 2019 and September 30, 2018 and as of December 31, 2018 (millions): Gas Electric Non- Regulated Other Total Three Months Ended September 30, 2019 Revenues: Billed and Unbilled Revenue $ 20.5 $ 57.3 $ — $ — $ 77.8 Rate Adjustment Mechanism Revenue 4.4 3.1 — — 7.5 Other Operating Revenue – Non-Regulated — — — — — Total Operating Revenues $ 24.9 $ 60.4 $ — $ — $ 85.3 Segment Profit (3.9 ) 4.4 — 1.8 2.3 Capital Expenditures 26.9 9.2 — 1.9 38.0 Three Months Ended September 30, 2018 Revenues: Billed and Unbilled Revenue $ 19.6 $ 60.9 $ — $ — $ 80.5 Rate Adjustment Mechanism Revenue 6.1 0.5 — — 6.6 Other Operating Revenue – Non-Regulated — — 1.1 — 1.1 Total Operating Revenues $ 25.7 $ 61.4 $ 1.1 $ — $ 88.2 Segment Profit (Loss) (3.2 ) 4.5 0.3 1.2 2.8 Capital Expenditures 30.9 7.2 — 1.0 39.1 Nine Months Ended September 30, 2019 Revenues: Billed and Unbilled Revenue $ 160.0 $ 172.8 $ — $ — $ 332.8 Rate Adjustment Mechanism Revenue (16.1 ) 4.2 — — (11.9 ) Other Operating Revenue – Non-Regulated — — 0.9 — 0.9 Total Operating Revenues $ 143.9 $ 177.0 $ 0.9 $ — $ 321.8 Segment Profit 10.1 9.7 10.2 2.8 32.8 Capital Expenditures 48.3 24.1 — 4.3 76.7 Segment Assets 780.7 507.6 0.3 21.1 1,309.7 Nine Months Ended September 30, 2018 Revenues: Billed and Unbilled Revenue $ 151.1 $ 176.2 $ — $ — $ 327.3 Rate Adjustment Mechanism Revenue (3.7 ) (8.6 ) — — (12.3 ) Other Operating Revenue – Non-Regulated — — 3.5 — 3.5 Total Operating Revenues $ 147.4 $ 167.6 $ 3.5 $ — $ 318.5 Segment Profit 9.1 10.2 0.9 1.8 22.0 Capital Expenditures 53.1 20.8 — 2.4 76.3 Segment Assets 730.0 485.7 6.6 42.2 1,264.5

DEBT AND FINANCING ARRANGEMEN_2

DEBT AND FINANCING ARRANGEMENTS (Tables)	9 Months Ended
	Sep. 30, 2019
Details on Long Term Debt	Details on long-term debt at September 30, 2019, Sept e ($ millions) September 30, December 31, 2019 2018 2018 Unitil Corporation: 6.33% Senior Notes, Due May 1, 2022 $ 20.0 $ 20.0 $ 20.0 3.70% Senior Notes, Due August 1, 2026 30.0 30.0 30.0 Unitil Energy First Mortgage Bonds: 5.24% Senior Secured Notes, Due March 2, 2020 5.0 10.0 10.0 8.49% Senior Secured Notes, Due October 14, 2024 6.0 7.5 6.0 6.96% Senior Secured Notes, Due September 1, 2028 18.0 20.0 20.0 8.00% Senior Secured Notes, Due May 1, 2031 15.0 15.0 15.0 6.32% Senior Secured Notes, Due September 15, 2036 15.0 15.0 15.0 4.18% Senior Secured Notes, Due November 30, 2048 30.0 — 30.0 Fitchburg: 6.75% Senior Notes, Due November 30, 2023 5.7 7.6 5.7 6.79% Senior Notes, Due October 15, 2025 10.0 10.0 10.0 3.52% Senior Notes, Due November 1, 2027 10.0 10.0 10.0 7.37% Senior Notes, Due January 15, 2029 12.0 12.0 12.0 5.90% Senior Notes, Due December 15, 2030 15.0 15.0 15.0 7.98% Senior Notes, Due June 1, 2031 14.0 14.0 14.0 4.32% Senior Notes, Due November 1, 2047 15.0 15.0 15.0 Northern Utilities: 6.95% Senior Notes, Due December 3, 2018 — 10.0 — 5.29% Senior Notes, Due March 2, 2020 8.2 16.6 16.6 3.52% Senior Notes, Due November 1, 2027 20.0 20.0 20.0 7.72% Senior Notes, Due December 3, 2038 50.0 50.0 50.0 4.42% Senior Notes, Due October 15, 2044 50.0 50.0 50.0 4.32% Senior Notes, Due November 1, 2047 30.0 30.0 30.0 4.04% Senior Notes, Due September 12, 2049 40.0 — — Granite State: 7.15% Senior Notes, Due December 15, 2018 — 3.3 — 3.72% Senior Notes, Due November 1, 2027 15.0 15.0 15.0 Total Long-Term Debt 433.9 396.0 409.3 Less: Unamortized Debt Issuance Costs 3.5 3.1 3.5 Total Long-Term Debt, net of Unamortized Debt Issuance Costs 430.4 392.9 405.8 Less: Current Portion (1) 19.5 31.8 18.4 Total Long-term Debt, Less Current Portion $ 410.9 $ 361.1 $ 387.4 (1) The Current Portion of Long-Term Debt ​​​​​​​includes sinking ​​​​​​​fund payments.
Fair Value of Long Term Debt	($ millions) September 30, December 31, 2019 2018 2018 Estimated Fair Value of Long-Term Debt $ 495.1 $ 418.7 $ 422.0
Borrowing Limits Amounts Outstanding and Amounts Available under Credit Facility	The following table details the borrowing limits, amounts outstanding and amounts available under the Credit Facility as of September 30 2019, September 30, 2018 and December 31, 2018: Revolving Credit Facility September 30, December 31, 2019 2018 2018 Limit $ 120.0 $ 120.0 $ 120.0 Short-Term Borrowings Outstanding 49.2 69.1 82.8 Letter of Credit Outstanding 0.1 — — Available $ 70.7 $ 50.9 $ 37.2
Classification of the Company Lease Obligations	The balance sheet classification of the Company’s lease obligations was as follows: September 30, December 31, Lease Obligations ($ millions) 2019 2018 2018 Operating Lease Obligations: Other Current Liabilities (current portion) $ 1.2 $ — $ — Other Noncurrent Liabilities (long-term portion) 3.0 — — Total Operating Lease Obligations 4.2 — — Capital Lease Obligations: Other Current Liabilities (current portion) 0.3 3.1 3.1 Other Noncurrent Liabilities (long-term portion) 0.3 3.4 2.7 Total Capital Lease Obligations 0.6 6.5 5.8 Total Lease Obligations $ 4.8 $ 6.5 $ 5.8
Future Operating Lease Payment Obligations and Future Minimum Lease Payments under Capital Leases	The following table is a schedule of future operating lease payment obligations and future minimum lease payments under capital leases as of September 30, 2019. The payments for capital leases consist of $0.3​​​​​​​​​​​​​​ million of current capital lease obligations, which are included in Other​​​​​​​ Current Liabilities and $ million of noncurrent capital lease obligations, which are included in Other Noncurrent Liabilities, on the Company’s Consolidated Balance Sheets as of September 30, 2019. Lease Payments ($000’s) Year Ending December 31, Operating Leases Capital Leases Rest of 2019 $ 356 $ 80 2020 1,338 262 2021 1,168 161 2022 887 97 2023 587 55 2024-2028 400 — Total Payments 4,736 655 Less: Interest 507 35 Amount of Lease Obligations Recorded on Consolidated Balance Sheets $ 4,229 $ 620 The payment amounts in the following table, which are as of December 31, 2018, would not differ substantially from the payment amounts as of September 30, 2018. Lease Payments ($000’s) Year Ending December 31, Operating Leases Capital Leases 2019 $ 1,372 $ 3,069 2020 1,138 2,535 2021 969 93 2022 689 32 2023 390 14 2024-2028 120 — Total Payments $ 4,678 $ 5,743

COMMON STOCK AND PREFERRED ST_2

COMMON STOCK AND PREFERRED STOCK (Tables)	9 Months Ended
	Sep. 30, 2019
Table Text Block Supplement [Abstract]
Restricted Stock Units Issued	The equity portion of Restricted Stock Units activity during the nine months ended September 30, 2019 in conjunction with the Stock Plan is presented in the following table: Restricted Stock Units (Equity Portion) Units Weighted Average Stock Price Restricted Stock Units as of December 31, 2018 61,789 $ 38.25 Restricted Stock Units Granted — — Dividend Equivalents Earned 1,210 $ 57.08 Restricted Stock Units Settled — — Restricted Stock Units as of September 30, 2019 62,999 $ 38.61

ENVIRONMENTAL MATTERS (Tables)

ENVIRONMENTAL MATTERS (Tables)	9 Months Ended
	Sep. 30, 2019
Environmental Obligations Recognized by Company	The following table sets forth a summary of changes in the Company’s liability for the current and long-term portions of the Company’s environmental obligations, which are included in Other Current Liabilities and Other Noncurrent Liabilities, respectively, on the Company’s ​​​​​​​Consolidated Balance Sheets as of September 30, 2019 and 2018. Environmental Obligations ($ millions) Fitchburg Northern Total Nine months ended September 30, 2019 2018 2019 2018 2019 2018 Total Balance at Beginning of Period $ — $ 0.1 $ 2.0 $ 2.0 $ 2.0 $ 2.1 Additions — — 1.0 0.6 1.0 0.6 Less: Payments / Reductions — 0.1 0.2 0.5 0.2 0.6 Total Balance at End of Period — — 2.8 2.1 2.8 2.1 Less: Current Portion — — 0.6 0.6 0.6 0.6 Noncurrent Balance at End of Period $ — $ $ 2.2 $ 1.5 $ 2.2 $ 1.5

RETIREMENT BENEFIT OBLIGATIONS

RETIREMENT BENEFIT OBLIGATIONS (Tables)	9 Months Ended
	Sep. 30, 2019
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: Used to Determine Plan Costs 2019 2018 Discount Rate 4.25 % 3.60 % Rate of Compensation Increase 3.00 % 3.00 % Expected Long-term rate of return on plan assets 7.75 % 7.75 % Health Care Cost Trend Rate Assumed for Next Year 7.00 % 7.50 % Ultimate Health Care Cost Trend Rate 4.50 % 4.50 % Year that Ultimate Health Care Cost Trend Rate is reached 2024 2024
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 Plan Three Months Ended September 30, 2019 2018 2019 2018 2019 2018 Service Cost $ 776 $ 848 $ 576 $ 733 $ 62 $ 122 Interest Cost 1,621 1,469 857 852 142 101 Expected Return on Plan Assets (2,119 ) (1,946 ) (412 ) (409 ) — — Prior Service Cost Amortization 80 81 304 327 14 47 Actuarial Loss Amortization 1,081 1,447 56 346 157 121 Sub-total 1,439 1,899 1,381 1,849 375 391 Amounts Capitalized and Deferred (650 ) (962 ) (650 ) (930 ) (107 ) (113 ) Net Periodic Benefit Cost Recognized $ 789 $ 937 $ 731 $ 919 $ 268 $ 278 Pension Plan PBOP Plan SERP Plan Nine Months Ended September 30, 2019 2018 2019 2018 2019 2018 Service Cost $ 2,328 $ 2,544 $ 1,728 $ 2,199 $ 185 $ 366 Interest Cost 4,863 4,407 2,569 2,554 426 303 Expected Return on Plan Assets (6,356 ) (5,838 ) (1,234 ) (1,227 ) — — Prior Service Cost Amortization 240 243 910 981 42 141 Actuarial Loss Amortization 3,243 4,341 170 1,038 471 365 Sub-total 4,318 5,697 4,143 5,545 1,124 1,175 Amounts Capitalized and Deferred (1,659 ) (2,590 ) (1,730 ) (2,557 ) (322 ) (339 ) Net Periodic Benefit Cost Recognized $ 2,659 $ 3,107 $ 2,413 $ 2,988 $ 802 $ 836

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Additional Information (Detail) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2019USD ($)mi	Sep. 30, 2019USD ($)Subsidiary	Jan. 01, 2019USD ($)	Dec. 31, 2018USD ($)	Sep. 30, 2018USD ($)
Significant Accounting Policies [Line Items]
Length Of Pipeline | mi	86
Gain on divestiture of business, pretax		$ 13.4
Gain on divestiture of business, net		9.8
Provision for income taxes		3.6
Cost of removal obligation	$ 98.4	98.4		$ 90.7	$ 91.2
Recognition of lease assets			$ 4.2
Recognition of lease liabilities			$ 4.2
Regulatory assets	123.6	123.6		140.3	138
Investments in trading securities	5.9	$ 5.9		4.8	5.3
Utilities
Significant Accounting Policies [Line Items]
Number of Subsidiaries | Subsidiary		3
Unitil Service; Unitil Realty; and Unitil Resources
Significant Accounting Policies [Line Items]
Number of Subsidiaries | Subsidiary		3
Annual Electric Sales Volume
Significant Accounting Policies [Line Items]
Percentage of total sales volumes revenue subject to RDM		27.00%
Annual Natural Gas Sales Volume
Significant Accounting Policies [Line Items]
Percentage of total sales volumes revenue subject to RDM		11.00%
Environmental and Rate Case Costs and Other Expenditures | Recovered over the next seven years
Significant Accounting Policies [Line Items]
Regulatory assets	5.8	$ 5.8
ISO-NE Obligations
Significant Accounting Policies [Line Items]
Cash Deposits	$ 3.5	$ 3.5		3.5	3.2
Maximum
Significant Accounting Policies [Line Items]
Cash equivalents maturity period		3 months
Lease term	12 months	12 months
Deferred Compensation Plan [Member]
Significant Accounting Policies [Line Items]
Investments in trading securities	$ 0.1	$ 0.1		$ 0	$ 0

Components of Gas and Electric

Components of Gas and Electric Operating Revenue (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	$ 85.3	$ 87.1	$ 320.9	$ 315
Billed and Unbilled Revenue
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	77.8	80.5	332.8	327.3
Rate Adjustment Mechanism Revenue
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	7.5	6.6	(11.9)	(12.3)
Gas Segment
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	24.9	25.7	143.9	147.4
Gas Segment | Billed and Unbilled Revenue
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	20.5	19.6	160	151.1
Gas Segment | Rate Adjustment Mechanism Revenue
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	4.4	6.1	(16.1)	(3.7)
Electric
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	60.4	61.4	177	167.6
Electric | Billed and Unbilled Revenue
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	57.3	60.9	172.8	176.2
Electric | Rate Adjustment Mechanism Revenue
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	3.1	0.5	4.2	(8.6)
Residential | Billed and Unbilled Revenue
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	38.2	40.2	156.2	153.9
Residential | Gas Segment | Billed and Unbilled Revenue
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	6.9	6.6	61.4	58.3
Residential | Electric | Billed and Unbilled Revenue
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	31.3	33.6	94.8	95.6
C&I | Billed and Unbilled Revenue
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	37	37.2	161.7	158.8
C&I | Gas Segment | Billed and Unbilled Revenue
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	12.5	11.9	89.5	84.7
C&I | Electric | Billed and Unbilled Revenue
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	24.5	25.3	72.2	74.1
Other | Billed and Unbilled Revenue
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	2.6	3.1	14.9	14.6
Other | Gas Segment | Billed and Unbilled Revenue
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	1.1	1.1	9.1	8.1
Other | Electric | Billed and Unbilled Revenue
Operating Revenues [Line Items]
Total Gas and Electric Operating Revenues	$ 1.5	$ 2	$ 5.8	$ 6.5

Allowance for Doubtful Accounts

Allowance for Doubtful Accounts Included in Accounts Receivable Net (Detail) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018
Valuation Allowance [Line Items]
Allowance for Doubtful Accounts	$ 1	$ 1.3	$ 1.2

Components of Accrued Revenue (

Components of Accrued Revenue (Detail) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018
Deferred Revenue Arrangement [Line Items]
Accrued Revenue	$ 35.3	$ 54.7	$ 36
Unbilled Revenues
Deferred Revenue Arrangement [Line Items]
Accrued Revenue	10.4	13.4	9.6
Regulatory Assets
Deferred Revenue Arrangement [Line Items]
Accrued Revenue	$ 24.9	$ 41.3	$ 26.4

Components of Exchange Gas Rece

Components of Exchange Gas Receivable (Detail) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018
Receivables [Line Items]
Total Exchange Gas Receivable	$ 8.6	$ 8.1	$ 10.1
Northern Utilities Inc
Receivables [Line Items]
Total Exchange Gas Receivable	8	7.5	9.5
Fitchburg
Receivables [Line Items]
Total Exchange Gas Receivable	$ 0.6	$ 0.6	$ 0.6

Components of Gas Inventory (De

Components of Gas Inventory (Detail) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018
Public Utilities, Inventory [Line Items]
Weighted average cost inventory amount	$ 0.8	$ 0.8	$ 0.9
Liquefied Natural Gas & Other
Public Utilities, Inventory [Line Items]
Weighted average cost inventory amount	0.1	0.1	0.1
Natural Gas
Public Utilities, Inventory [Line Items]
Weighted average cost inventory amount	0.4	0.3	0.4
Propane
Public Utilities, Inventory [Line Items]
Weighted average cost inventory amount	$ 0.3	$ 0.4	$ 0.4

Regulatory Assets (Detail)

Regulatory Assets (Detail) - USD ($) $ in Millions		Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018
Regulatory Assets [Line Items]
Regulatory assets		$ 123.6	$ 140.3	$ 138
Less: Current Portion of Regulatory Assets	[1]	24.9	41.3	26.4
Regulatory Assets - noncurrent		98.7	99	111.6
Environmental Matters
Regulatory Assets [Line Items]
Regulatory assets		8	7.9	8.9
Other
Regulatory Assets [Line Items]
Regulatory assets		11.7	10	4.1
Retirement Benefits
Regulatory Assets [Line Items]
Regulatory assets		74	72	88
Deferred Storm Charges
Regulatory Assets [Line Items]
Regulatory assets		5	6.3	6.3
Income Taxes
Regulatory Assets [Line Items]
Regulatory assets		4.3	5.7	5.9
Energy Supply & Other Rate Adjustment Mechanisms
Regulatory Assets [Line Items]
Regulatory assets		$ 20.6	$ 38.4	$ 24.8
[1]	Reflects amounts included in Accrued Revenue, discussed above, on the Company’s Consolidated Balance Sheets.

Regulatory Liabilities (Detail)

Regulatory Liabilities (Detail) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018	Dec. 31, 2017
Regulatory Liabilities [Line Items]
Regulatory Liabilities	$ 61.1	$ 58.5	$ 60.1
Less: Current Portion of Regulatory Liabilities	14.4	11.5	12.2
Regulatory Liabilities-noncurrent	46.7	47	47.9
Energy Supply & Other Rate Adjustment Mechanisms
Regulatory Liabilities [Line Items]
Regulatory Liabilities	13.5	11.5	12.2
Income Tax
Regulatory Liabilities [Line Items]
Regulatory Liabilities	$ 47.6	$ 47	$ 47.9	$ 48.9

Fair Value of Marketable Securi

Fair Value of Marketable Securities (Detail) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Trading Securities	$ 5.9	$ 4.8	$ 5.3
Deferred Compensation Plan [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Trading Securities	0.1	0	0
Fair Value, Inputs, Level 1
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Trading Securities	5.9	4.8	5.3
Fair Value, Inputs, Level 1 | Deferred Compensation Plan [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Trading Securities	0.1
Fair Value, Inputs, Level 1 | Equity Funds
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Trading Securities			3
Fair Value, Inputs, Level 1 | Fixed Income Funds
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Trading Securities			$ 2.3
Fair Value, Inputs, Level 1 | Money Market Funds
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Trading Securities	5.9	$ 4.8
Fair Value, Inputs, Level 1 | Money Market Funds | Deferred Compensation Plan [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Trading Securities	$ 0.1

Components of Energy Supply Obl

Components of Energy Supply Obligations (Detail) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018
Contractual Obligation [Line Items]
Energy Supply Obligations-Current	$ 12.5	$ 13.4	$ 15
Power Supply Contract Divestitures, Noncurrent	0.4	0.6	0.7
Total Energy Supply Obligations	12.9	14	15.7
Renewable Energy Portfolio Standards
Contractual Obligation [Line Items]
Energy Supply Obligations-Current	4.2	5.6	5.2
Power Supply Contract Divestitures
Contractual Obligation [Line Items]
Energy Supply Obligations-Current	0.3	0.3	0.3
Exchange Gas Obligation
Contractual Obligation [Line Items]
Energy Supply Obligations-Current	$ 8	$ 7.5	$ 9.5

Dividends Declared Per Share (D

Dividends Declared Per Share (Detail) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Dividends Payable [Line Items]
Dividend Amount	$ 0.370	$ 0.365	$ 1.11	$ 1.095
Group One
Dividends Payable [Line Items]
Declaration Date			Oct. 23, 2019
Date Paid (Payable)			Nov. 27, 2019
Shareholder of Record Date			Nov. 13, 2019
Dividend Amount			$ 0.370
Group Two
Dividends Payable [Line Items]
Declaration Date			Jul. 24, 2019
Date Paid (Payable)			Aug. 29, 2019
Shareholder of Record Date			Aug. 15, 2019
Dividend Amount			$ 0.370
Group Three
Dividends Payable [Line Items]
Declaration Date			Apr. 24, 2019
Date Paid (Payable)			May 29, 2019
Shareholder of Record Date			May 15, 2019
Dividend Amount			$ 0.370
Group Four
Dividends Payable [Line Items]
Declaration Date			Jan. 30, 2019
Date Paid (Payable)			Feb. 28, 2019
Shareholder of Record Date			Feb. 14, 2019
Dividend Amount			$ 0.370
Group Five
Dividends Payable [Line Items]
Declaration Date			Oct. 24, 2018
Date Paid (Payable)			Nov. 29, 2018
Shareholder of Record Date			Nov. 15, 2018
Dividend Amount			$ 0.365
Group Six
Dividends Payable [Line Items]
Declaration Date			Jul. 25, 2018
Date Paid (Payable)			Aug. 29, 2018
Shareholder of Record Date			Aug. 15, 2018
Dividend Amount			$ 0.365
Group Seven
Dividends Payable [Line Items]
Declaration Date			Apr. 25, 2018
Date Paid (Payable)			May 29, 2018
Shareholder of Record Date			May 15, 2018
Dividend Amount			$ 0.365
Group Eight
Dividends Payable [Line Items]
Declaration Date			Jan. 30, 2018
Date Paid (Payable)			Feb. 28, 2018
Shareholder of Record Date			Feb. 14, 2018
Dividend Amount			$ 0.365

Significant Segment Financial D

Significant Segment Financial Data (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Other Operating Revenue - Non-Regulated		$ 1.1	$ 0.9	$ 3.5
Total Operating Revenues	$ 85.3	88.2	321.8	318.5
Segment Profit (Loss)	2.3	2.8	32.8	22
Capital Expenditures	38	39.1	76.7	76.3
Segment Assets	1,309.7	1,264.5	1,309.7	1,264.5	$ 1,298.3
Billed and Unbilled Revenue
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Total Operating Revenues	77.8	80.5	332.8	327.3
Rate Adjustment Mechanism Revenue
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Total Operating Revenues	7.5	6.6	(11.9)	(12.3)
Gas Segment
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Total Operating Revenues	24.9	25.7	143.9	147.4
Segment Profit (Loss)	(3.9)	(3.2)	10.1	9.1
Capital Expenditures	26.9	30.9	48.3	53.1
Segment Assets	780.7	730	780.7	730
Gas Segment | Billed and Unbilled Revenue
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Total Operating Revenues	20.5	19.6	160	151.1
Gas Segment | Rate Adjustment Mechanism Revenue
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Total Operating Revenues	4.4	6.1	(16.1)	(3.7)
Electric
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Total Operating Revenues	60.4	61.4	177	167.6
Segment Profit (Loss)	4.4	4.5	9.7	10.2
Capital Expenditures	9.2	7.2	24.1	20.8
Segment Assets	507.6	485.7	507.6	485.7
Electric | Billed and Unbilled Revenue
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Total Operating Revenues	57.3	60.9	172.8	176.2
Electric | Rate Adjustment Mechanism Revenue
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Total Operating Revenues	3.1	0.5	4.2	(8.6)
All Other Segments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Segment Profit (Loss)	1.8	1.2	2.8	1.8
Capital Expenditures	1.9	1	4.3	2.4
Segment Assets	21.1	42.2	21.1	42.2
Unregulated Operation
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Other Operating Revenue - Non-Regulated		1.1	0.9	3.5
Total Operating Revenues		1.1	0.9	3.5
Segment Profit (Loss)		0.3	10.2	0.9
Segment Assets	$ 0.3	$ 6.6	$ 0.3	$ 6.6

Details on Long Term Debt (Deta

Details on Long Term Debt (Detail) - USD ($) $ in Millions		Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018
Debt Instrument [Line Items]
Total Long-Term Debt		$ 433.9	$ 409.3	$ 396
Less: Unamortized Debt Issuance Costs		3.5	3.5	3.1
Long-Term Debt		430.4	405.8	392.9
Less: Current Portion	[1]	19.5	18.4	31.8
Total Long-Term Debt, Less Current Portion		410.9	387.4	361.1
Long-Term Debt		430.4	405.8	392.9
6.33% Senior Notes, Due May 1, 2022
Debt Instrument [Line Items]
Total Long-Term Debt		20	20	20
3.70% Senior Notes, Due August 1, 2026
Debt Instrument [Line Items]
Total Long-Term Debt		30	30	30
Unitil Energy Systems Inc | First Mortgage Bonds 5.24% Senior Secured Notes, Due March 2, 2020
Debt Instrument [Line Items]
Total Long-Term Debt		5	10	10
Unitil Energy Systems Inc | First Mortgage Bonds 8.49% Senior Secured Notes, Due October 14, 2024
Debt Instrument [Line Items]
Total Long-Term Debt		6	6	7.5
Unitil Energy Systems Inc | First Mortgage Bonds 6.96% Senior Secured Notes, Due September 1, 2028
Debt Instrument [Line Items]
Total Long-Term Debt		18	20	20
Unitil Energy Systems Inc | First Mortgage Bonds 8.00% Senior Secured Notes, Due May 1, 2031
Debt Instrument [Line Items]
Total Long-Term Debt		15	15	15
Unitil Energy Systems Inc | First Mortgage Bonds 6.32% Senior Secured Notes, Due September 15, 2036
Debt Instrument [Line Items]
Total Long-Term Debt		15	15	15
Unitil Energy Systems Inc | First Mortgage Bonds 4.18% Senior Secured Notes Due November 30, 2048
Debt Instrument [Line Items]
Total Long-Term Debt		30	30
Fitchburg Gas and Electric Light Company | 6.75% Senior Notes, Due November 30, 2023
Debt Instrument [Line Items]
Total Long-Term Debt		5.7	5.7	7.6
Fitchburg Gas and Electric Light Company | 6.79% Senior Notes, Due October 15, 2025
Debt Instrument [Line Items]
Total Long-Term Debt		10	10	10
Fitchburg Gas and Electric Light Company | 3.52% Senior Notes, Due November 1, 2027
Debt Instrument [Line Items]
Total Long-Term Debt		10	10	10
Fitchburg Gas and Electric Light Company | 7.37% Notes, Due January 15, 2029
Debt Instrument [Line Items]
Total Long-Term Debt		12	12	12
Fitchburg Gas and Electric Light Company | 5.90% Notes, Due December 15, 2030
Debt Instrument [Line Items]
Total Long-Term Debt		15	15	15
Fitchburg Gas and Electric Light Company | 7.98% Notes, Due June 1, 2031
Debt Instrument [Line Items]
Total Long-Term Debt		14	14	14
Fitchburg Gas and Electric Light Company | 4.32% Senior Notes, Due November 1, 2047
Debt Instrument [Line Items]
Total Long-Term Debt		15	15	15
Northern Utilities Inc | 3.52% Senior Notes, Due November 1, 2027
Debt Instrument [Line Items]
Total Long-Term Debt		20	20	20
Northern Utilities Inc | 4.32% Senior Notes, Due November 1, 2047
Debt Instrument [Line Items]
Total Long-Term Debt		30	30	30
Northern Utilities Inc | 6.95% Senior Notes, Due December 3, 2018
Debt Instrument [Line Items]
Total Long-Term Debt				10
Northern Utilities Inc | 5.29% Senior Notes, Due March 2, 2020
Debt Instrument [Line Items]
Total Long-Term Debt		8.2	16.6	16.6
Northern Utilities Inc | 7.72% Senior Notes, Due December 3, 2038
Debt Instrument [Line Items]
Total Long-Term Debt		50	50	50
Northern Utilities Inc | 4.42% Senior Notes, Due October 15, 2044
Debt Instrument [Line Items]
Total Long-Term Debt		50	50	50
Northern Utilities Inc | 4.04% Senior Notes, Due September 12, 2049
Debt Instrument [Line Items]
Total Long-Term Debt		40
Granite State Gas Transmission Inc | 7.15% Senior Notes, Due December 15, 2018
Debt Instrument [Line Items]
Total Long-Term Debt				3.3
Granite State Gas Transmission Inc | 3.72% Senior Notes, Due November 1, 2027
Debt Instrument [Line Items]
Total Long-Term Debt		$ 15	$ 15	$ 15
[1]	The Current Portion of Long-Term Debt includes sinking fund payments.

Details on Long Term Debt (Pare

Details on Long Term Debt (Parenthetical) (Detail)	Sep. 12, 2019	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Debt Instrument [Line Items]
Debt instrument due date	Sep. 12, 2049
6.33% Senior Notes, Due May 1, 2022
Debt Instrument [Line Items]
Stated interest rate		6.33%	6.33%	6.33%
Debt instrument due date		May 1, 2022	May 1, 2022	May 1, 2022
3.70% Senior Notes, Due August 1, 2026
Debt Instrument [Line Items]
Stated interest rate		3.70%	3.70%	3.70%
Debt instrument due date		Aug. 1, 2026	Aug. 1, 2026	Aug. 1, 2026
First Mortgage Bonds 5.24% Senior Secured Notes, Due March 2, 2020 | Unitil Energy Systems Inc
Debt Instrument [Line Items]
Stated interest rate		5.24%	5.24%	5.24%
Debt instrument due date		Mar. 2, 2020	Mar. 2, 2020	Mar. 2, 2020
First Mortgage Bonds 8.49% Senior Secured Notes, Due October 14, 2024 | Unitil Energy Systems Inc
Debt Instrument [Line Items]
Stated interest rate		8.49%	8.49%	8.49%
Debt instrument due date		Oct. 14, 2024	Oct. 14, 2024	Oct. 14, 2024
First Mortgage Bonds 6.96% Senior Secured Notes, Due September 1, 2028 | Unitil Energy Systems Inc
Debt Instrument [Line Items]
Stated interest rate		6.96%	6.96%	6.96%
Debt instrument due date		Sep. 1, 2028	Sep. 1, 2028	Sep. 1, 2028
First Mortgage Bonds 8.00% Senior Secured Notes, Due May 1, 2031 | Unitil Energy Systems Inc
Debt Instrument [Line Items]
Stated interest rate		8.00%	8.00%	8.00%
Debt instrument due date		May 1, 2031	May 1, 2031	May 1, 2031
First Mortgage Bonds 6.32% Senior Secured Notes, Due September 15, 2036 | Unitil Energy Systems Inc
Debt Instrument [Line Items]
Stated interest rate		6.32%	6.32%	6.32%
Debt instrument due date		Sep. 15, 2036	Sep. 15, 2036	Sep. 15, 2036
First Mortgage Bonds 4.18% Senior Secured Notes Due November 30, 2048 | Unitil Energy Systems Inc
Debt Instrument [Line Items]
Stated interest rate		4.18%	4.18%	4.18%
Debt instrument due date		Nov. 30, 2048	Nov. 30, 2048	Nov. 30, 2048
6.75% Senior Notes, Due November 30, 2023 | Fitchburg Gas and Electric Light Company
Debt Instrument [Line Items]
Stated interest rate		6.75%	6.75%	6.75%
Debt instrument due date		Nov. 30, 2023	Nov. 30, 2023	Nov. 30, 2023
6.79% Senior Notes, Due October 15, 2025 | Fitchburg Gas and Electric Light Company
Debt Instrument [Line Items]
Stated interest rate		6.79%	6.79%	6.79%
Debt instrument due date		Oct. 15, 2025	Oct. 15, 2025	Oct. 15, 2025
3.52% Senior Notes, Due November 1, 2027 | Fitchburg Gas and Electric Light Company
Debt Instrument [Line Items]
Stated interest rate		3.52%	3.52%	3.52%
Debt instrument due date		Nov. 1, 2027	Nov. 1, 2027	Nov. 1, 2027
3.52% Senior Notes, Due November 1, 2027 | Northern Utilities Inc
Debt Instrument [Line Items]
Stated interest rate		3.52%	3.52%	3.52%
Debt instrument due date		Nov. 1, 2027	Nov. 1, 2027	Nov. 1, 2027
7.37% Notes, Due January 15, 2029 | Fitchburg Gas and Electric Light Company
Debt Instrument [Line Items]
Stated interest rate		7.37%	7.37%	7.37%
Debt instrument due date		Jan. 15, 2029	Jan. 15, 2029	Jan. 15, 2029
5.90% Notes, Due December 15, 2030 | Fitchburg Gas and Electric Light Company
Debt Instrument [Line Items]
Stated interest rate		5.90%	5.90%	5.90%
Debt instrument due date		Dec. 15, 2030	Dec. 15, 2030	Dec. 15, 2030
7.98% Notes, Due June 1, 2031 | Fitchburg Gas and Electric Light Company
Debt Instrument [Line Items]
Stated interest rate		7.98%	7.98%	7.98%
Debt instrument due date		Jun. 1, 2031	Jun. 1, 2031	Jun. 1, 2031
4.32% Senior Notes, Due November 1, 2047 | Fitchburg Gas and Electric Light Company
Debt Instrument [Line Items]
Stated interest rate		4.32%	4.32%	4.32%
Debt instrument due date		Nov. 1, 2047	Nov. 1, 2047	Nov. 1, 2047
4.32% Senior Notes, Due November 1, 2047 | Northern Utilities Inc
Debt Instrument [Line Items]
Stated interest rate		4.32%	4.32%	4.32%
Debt instrument due date		Nov. 1, 2047	Nov. 1, 2047	Nov. 1, 2047
6.95% Senior Notes, Due December 3, 2018 | Northern Utilities Inc
Debt Instrument [Line Items]
Stated interest rate		6.95%	6.95%	6.95%
Debt instrument due date		Dec. 3, 2018	Dec. 3, 2018	Dec. 3, 2018
5.29% Senior Notes, Due March 2, 2020 | Northern Utilities Inc
Debt Instrument [Line Items]
Stated interest rate		5.29%	5.29%	5.29%
Debt instrument due date		Mar. 2, 2020	Mar. 2, 2020	Mar. 2, 2020
7.72% Senior Notes, Due December 3, 2038 | Northern Utilities Inc
Debt Instrument [Line Items]
Stated interest rate		7.72%	7.72%	7.72%
Debt instrument due date		Dec. 3, 2038	Dec. 3, 2038	Dec. 3, 2038
4.42% Senior Notes, Due October 15, 2044 | Northern Utilities Inc
Debt Instrument [Line Items]
Stated interest rate		4.42%	4.42%	4.42%
Debt instrument due date		Oct. 15, 2044	Oct. 15, 2044	Oct. 15, 2044
4.04% Senior Notes, Due September 12, 2049 | Northern Utilities Inc
Debt Instrument [Line Items]
Stated interest rate	4.04%	4.04%	4.04%	4.04%
Debt instrument due date		Sep. 12, 2049	Sep. 12, 2049	Sep. 12, 2049
7.15% Senior Notes, Due December 15, 2018 | Granite State Gas Transmission Inc
Debt Instrument [Line Items]
Stated interest rate		7.15%	7.15%	7.15%
Debt instrument due date		Dec. 15, 2018	Dec. 15, 2018	Dec. 15, 2018
3.72% Senior Notes, Due November 1, 2027 | Granite State Gas Transmission Inc
Debt Instrument [Line Items]
Stated interest rate		3.72%	3.72%	3.72%
Debt instrument due date		Nov. 1, 2027	Nov. 1, 2027	Nov. 1, 2027

Estimated Fair Value of Long Te

Estimated Fair Value of Long Term Debt (Detail) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018
Fair Value, Inputs, Level 2
Debt Instrument [Line Items]
Estimated Fair Value of Long-Term Debt	$ 495.1	$ 422	$ 418.7

Debt and Financing Arrangemen_3

Debt and Financing Arrangements - Additional Information (Detail) - USD ($)	Sep. 12, 2019	Nov. 30, 2018	Jul. 25, 2018	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Oct. 30, 2015
Line of Credit Facility [Line Items]
Weighted average interest rate on short term borrowings				3.40%	3.30%	3.60%	3.20%	3.30%
Gain on divestiture of business, net						$ 9,800,000
Capital lease obligation, total capitalized cost				$ 620,000	$ 6,500,000	620,000	$ 6,500,000	$ 5,800,000
Capital lease obligation, current				300,000	3,100,000	300,000	3,100,000	3,100,000
Capital lease obligation, noncurrent				300,000	3,400,000	300,000	3,400,000	2,700,000
Accounts Payable				22,900,000	27,400,000	22,900,000	27,400,000	42,600,000
Guarantee outstanding				4,300,000		4,300,000
Total rental expense under operating leases				400,000	400,000	1,100,000	1,400,000
Operating lease obligations						1,100,000
Net Utility Plant				1,083,900,000	1,022,300,000	1,083,900,000	1,022,300,000	1,036,800,000
Other current operating lease obligation				1,200,000		1,200,000
Other noncurrent operating lease obligation				$ 3,000,000		$ 3,000,000
Long-term debt, maturity date	Sep. 12, 2049
Operating lease, weighted average remaining lease term				4 years		4 years
Operating lease, weighted average discount rate percentage				5.30%		5.30%
Credit Facility [Member] | Amended Credit Facility [Member]
Line of Credit Facility [Line Items]
Revolving credit facility			$ 120,000,000
Sublimit for the issuance of standby letters of credit			$ 25,000,000
Revolving credit facility termination date			Jul. 25, 2023
Increase in borrowing limit			$ 50,000,000
Credit Facility [Member] | London Interbank Offered Rate | Amended Credit Facility [Member]
Line of Credit Facility [Line Items]
Credit facility, daily fluctuating rate of interest			1.125%
Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Revolving credit facility				$ 120,000,000	120,000,000	$ 120,000,000	120,000,000	120,000,000
Proceeds from lines of credit						187,100,000
Repayments of lines of credit						$ 220,700,000
Revolving Credit Facility [Member] | Credit Facility [Member]
Line of Credit Facility [Line Items]
Percentage of capitalization						The affirmative and negative covenants under the Credit Facility shall apply until the Credit Facility terminates and all amounts borrowed under the Credit Facility are paid in full (or with respect to letters of credit, they are cash collateralized). The only financial covenant in the Credit Facility provides that Funded Debt to Capitalization (as each term is defined in the Credit Facility) cannot exceed 65%, tested on a quarterly basis. At September 30, 2019, September 30, 2018 and December 31, 2018, the Company was in compliance with the covenants contained in the Credit Facility in effect on that date.
Unitil Service Corp [Member]
Line of Credit Facility [Line Items]
Capital lease obligation, total capitalized cost									$ 13,400,000
Northern Utilities Inc
Line of Credit Facility [Line Items]
Accounts Payable				100,000	100,000	$ 100,000	100,000	900,000
Natural gas storage inventory				$ 8,100,000	$ 9,600,000	$ 8,100,000	$ 9,600,000	$ 8,400,000
Northern Utilities Inc | 4.04% Senior Notes, Due September 12, 2049
Line of Credit Facility [Line Items]
Long-term debt, aggregate principal amount	$ 40,000,000
Long-term debt, stated interest rate	4.04%			4.04%	4.04%	4.04%	4.04%	4.04%
Long-term debt, maturity date						Sep. 12, 2049	Sep. 12, 2049	Sep. 12, 2049
Issuance of long-term debt	$ 200,000
Unitil Energy [Member] | 4.18% First Mortgage Bonds, Due November 30, 2048
Line of Credit Facility [Line Items]
Long-term debt, aggregate principal amount		$ 30,000,000
Long-term debt, stated interest rate		4.18%
Long-term debt, maturity date		Nov. 30, 2048
Issuance of long-term debt		$ 500,000
Assets under Capital Leases [Member]
Line of Credit Facility [Line Items]
Net Utility Plant				$ 1,300,000	$ 15,000,000	$ 1,300,000	$ 15,000,000	$ 15,000,000
Net Utility Plant, accumulated amortization				$ 600,000	$ 2,100,000	$ 600,000	$ 2,100,000	$ 1,700,000

Borrowing Limits Amounts Outsta

Borrowing Limits Amounts Outstanding and Amounts Available under Revolving Credit Facility (Detail) - USD ($)	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018
Debt Instrument [Line Items]
Short-Term Borrowings Outstanding	$ 49,200,000	$ 82,800,000	$ 69,100,000
Revolving Credit Facility
Debt Instrument [Line Items]
Revolving credit facility, limit	120,000,000	120,000,000	120,000,000
Short-Term Borrowings Outstanding	49,200,000	82,800,000	69,100,000
Letters of Credit Outstanding	100,000
Available revolving credit facility	$ 70,700,000	$ 37,200,000	$ 50,900,000

Debt and Financing Arrangemen_4

Debt and Financing Arrangements - Classification of the Company Lease Obligations (Detail) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018
Operating Lease Obligations:
Other Current Liabilities (current portion)	$ 1,200
Other Noncurrent Liabilities (long-term portion)	3,000
Total Operating Lease Obligations	4,229
Capital Lease Obligations:
Other Current Liabilities (current portion)	300	$ 3,100	$ 3,100
Other Noncurrent Liabilities (long-term portion)	300	2,700	3,400
Total Capital Lease Obligations	620	5,800	6,500
Total Lease Obligations	$ 4,800	$ 5,800	$ 6,500

Future Operating Lease Payment

Future Operating Lease Payment Obligations and Future Minimum Lease Payments under Capital Leases (Detail) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018
Operating leases
Rest of 2019	$ 356
2019		$ 1,372
2020	1,338	1,138
2021	1,168	969
2022	887	689
2023	587	390
2024-2028	400	120
Total Payments	4,736	4,678
Less: Interest	507
Amount of Lease Obligations Recorded on Consolidated Balance Sheets	4,229
Capital lease
Rest of 2019	80
2019		3,069
2020	262	2,535
2021	161	93
2022	97	32
2023	55	14
Total Payments	655	5,743
Less: Interest	35
Amount of Lease Obligations Recorded on Consolidated Balance Sheets	$ 620	$ 5,800	$ 6,500

Common Stock And Preferred St_3

Common Stock And Preferred Stock - Additional Information (Detail) - USD ($)	Oct. 01, 2019	Jan. 29, 2019	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Class of Stock [Line Items]
Common stock, shares outstanding			14,925,898	14,872,011	14,925,898	14,872,011	14,876,955
Common stock, shares issued			4,727	5,423	15,793	19,700
Proceeds from Issuance of Common Stock					$ 900,000	$ 900,000
Restricted stock weighted average grant date fair value					$ 46.41	$ 41.96
Share based compensation expense					$ 2,200,000	$ 2,100,000
Percentage of fully-vested restricted stock units that directors will receive in common shares when settled					70.00%
Fair value of liabilities associated with fully vested RSUs that will be settled in cash			$ 1,700,000	$ 1,200,000	$ 1,700,000	1,200,000	$ 1,300,000
Percentage of fully-vested restricted stock units that directors will receive in cash when settled					30.00%
Preferred Stock			200,000	200,000	$ 200,000	200,000	$ 200,000
Maximum
Class of Stock [Line Items]
Dividend declared			$ 100,000	$ 100,000	$ 100,000	$ 100,000
Restricted Stock
Class of Stock [Line Items]
Restricted stock vesting period					4 years
Restricted stock non-vested			50,917	49,581	50,917	49,581
Unrecognized share based compensation			$ 800,000		$ 800,000
Share compensation recognition period					2 years 8 months 12 days
Restricted Stock Units Granted		33,150
Aggregate Market Value					$ 1,600,000
Forfeitures under the stock plan					0
Cancellations under the stock plan					0
Restricted Stock | Maximum
Class of Stock [Line Items]
Restricted stock available for awards			677,500		677,500
Restricted stock that may be awarded in any one calendar year to any one participant			20,000		20,000
Restricted Stock | Vesting Annually
Class of Stock [Line Items]
Restricted stock vesting percentage annually					25.00%
Restricted Stock Units (RSUs)
Class of Stock [Line Items]
Restricted Stock Units Granted	9,918				0
Restricted stock units outstanding				53,454		53,454
Weighted-Average Stock Price				$ 36.47		$ 36.47
Series 6 | Unitil Energy Systems Inc
Class of Stock [Line Items]
Preferred stock, outstanding			1,887	1,893	1,887	1,893	1,893
Preferred Stock			$ 200,000	$ 200,000	$ 200,000	$ 200,000	$ 200,000
Dividend rate					6.00%	6.00%	6.00%
Dividend and Distribution Reinvestment and Share Purchase Plan
Class of Stock [Line Items]
Proceeds from Issuance of Common Stock					$ 889,000
Dividend and Distribution Reinvestment and Share Purchase Plan | Average
Class of Stock [Line Items]
Common stock price per share			$ 56.29		$ 56.29
Dividend and Distribution Reinvestment and Share Purchase Plan | Common Stock
Class of Stock [Line Items]
Common stock, shares issued					15,793

Restricted Stock Units Issued (

Restricted Stock Units Issued (Detail) - Restricted Stock Units (RSUs) - $ / shares	Oct. 01, 2019	Sep. 30, 2019
Restricted Stock Units
Beginning Restricted Stock Units	62,999	61,789
Restricted Stock Units Granted	9,918	0
Dividend Equivalents Earned		1,210
Restricted Stock Units Settled		0
Ending Restricted Stock Units		62,999
Weighted-Average Stock Price
Beginning Restricted Stock Units	$ 38.61	$ 38.25
Restricted Stock Units Granted		0
Dividend Equivalents Earned		57.08
Restricted Stock Units Settled		0
Ending Restricted Stock Units		$ 38.61

Regulatory Matters - Additional

Regulatory Matters - Additional Information (Detail)

Nov. 01, 2017USD ($)

Jun. 28, 2019USD ($)

May 01, 2019USD ($)

Feb. 28, 2019USD ($)

May 07, 2018USD ($)

May 02, 2018USD ($)

Dec. 31, 2017

Apr. 20, 2017USD ($)

Jun. 30, 2017MW

Sep. 30, 2019

Jun. 30, 2027MW

Dec. 31, 2022MWh

Jun. 25, 2019

Apr. 30, 2019USD ($)

Jul. 31, 2018MWh

Jul. 31, 2018

Jul. 31, 2018MW

Regulatory Assets [Line Items]

Annual revenue adjustment

$ 1,400,000

Power generation facility | MW

1,600

Pro rata percentage share of contracts

1

Tax Year 2018

Regulatory Assets [Line Items]

Corporate income tax rate

21.00%

21.00%

Unitil Energy Systems Inc | New Hampshire

Regulatory Assets [Line Items]

Permanent rate increase

$ 4,100,000

Increase (decrease) in annual revenue

$ 340,000

Fitchburg Gas and Electric Light Company

Regulatory Assets [Line Items]

Increase (decrease) in annual revenue

$ 900,000

1,000,000

Recovery amount

$ 600,000

$ 1,600,000

Annual revenue adjustment

$ 400,000

Amendment effective date

Nov. 1, 2018

Fitchburg Gas and Electric Light Company | Offshore Wind Energy

Regulatory Assets [Line Items]

Power generation facility | MWh

400

Remuneration Percentage

2.75

2.75

Fitchburg Gas and Electric Light Company | Offshore Wind Energy | First Solicitation [Member]

Regulatory Assets [Line Items]

Power generation facility | MWh

800

Fitchburg Gas and Electric Light Company | Offshore Wind Energy | Second Solicitation [Member]

Regulatory Assets [Line Items]

Power generation facility

800

400

Fitchburg Gas and Electric Light Company | Qualified Clean Energy

Regulatory Assets [Line Items]

Power Generation Capacity | MWh

9,554,940

Fitchburg Gas and Electric Light Company | Minimum [Member] | Offshore Wind Energy

Regulatory Assets [Line Items]

Power generation facility | MW

400

Fitchburg Gas and Electric Light Company | Scenario Forecast

Regulatory Assets [Line Items]

Power Generation Capacity | MWh

9,450,000

Northern Utilities Inc

Regulatory Assets [Line Items]

Increase (decrease) in annual revenue

$ 7,000,000

$ 3,200,000

Increase In Annual Base Rate

2.1

2.4

Annual TIRA Adjustment

$ 1,000,000

$ 1,100,000

Percentage Of Increase In Test Year Operating Revenue

7.00%

Northern Utilities Inc | Maine

Regulatory Assets [Line Items]

TIRA extended term

8 years

Environmental Matters - Additio

Environmental Matters - Additional Information (Detail) - Environmental Restoration Costs $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)
Maine
Site Contingency [Line Items]
Amortization period for environmental costs	5 years
New Hampshire
Site Contingency [Line Items]
Amortization period for environmental costs	7 years
Northern Utilities Manufactured Gas Plant Sites
Site Contingency [Line Items]
Estimated Costs Accrued For Remediation	$ 0.7

Company's Liability for Environ

Company's Liability for Environmental Obligations (Detail) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Environmental Exit Cost [Line Items]
Total Balance at Beginning of Period	$ 2	$ 2.1
Additions	1	0.6
Less: Payments / Reductions	0.2	0.6
Total Balance at End of Period	2.8	2.1
Less: Current Portion	0.6	0.6
Noncurrent Balance at End of Period	2.2	1.5
Fitchburg Gas and Electric Light Company
Environmental Exit Cost [Line Items]
Total Balance at Beginning of Period		0.1
Less: Payments / Reductions		0.1
Northern Utilities Inc
Environmental Exit Cost [Line Items]
Total Balance at Beginning of Period	2	2
Additions	1	0.6
Less: Payments / Reductions	0.2	0.5
Total Balance at End of Period	2.8	2.1
Less: Current Portion	0.6	0.6
Noncurrent Balance at End of Period	$ 2.2	$ 1.5

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($) $ in Millions	1 Months Ended	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2019	Sep. 30, 2019	Dec. 31, 2020	Dec. 31, 2018	Dec. 31, 2017	Sep. 30, 2018
Income Taxes [Line Items]
Regulatory Liability			$ 61.1		$ 58.5		$ 60.1
Regulatory liability, expected flow back to customers			47.1			$ 48.9
Tax provision					$ 2.4
NOL carryforward assets expiration date					2029
Alternative minimum tax credit carryforwards					$ 3.1
Scenario Forecast
Income Taxes [Line Items]
Regulatory liability, expected pass back to ratepayers		$ 0.4		$ 1.6
Reconciling Mechanisms
Income Taxes [Line Items]
Regulatory liability, expected pass back to ratepayers						1.8
Net Operating Loss Carryforward Assets
Income Taxes [Line Items]
Regulatory liability, expected pass back to ratepayers						5.8
Tax Cuts And Jobs Act Of 2017 Change In Tax Rate Regulatory Liability recognized			$ 1.4
Minimum
Income Taxes [Line Items]
Average Rate Assumption Method estimated flow back period			15 years
Maximum
Income Taxes [Line Items]
Average Rate Assumption Method estimated flow back period			20 years
Fitchburg Gas and Electric Light Company
Income Taxes [Line Items]
Average Rate Assumption Method estimated flow back period			15 years
Income Tax Related Liabilities
Income Taxes [Line Items]
Regulatory Liability	$ 48.9		$ 47.6		$ 47	$ 48.9	$ 47.9
Electric Ratepayers | Fitchburg Gas and Electric Light Company
Income Taxes [Line Items]
Regulatory liability, expected flow back to customers			10.1
Gas Ratepayers | Fitchburg Gas and Electric Light Company
Income Taxes [Line Items]
Regulatory liability, expected flow back to customers			$ 10.4
Tax Year 2018
Income Taxes [Line Items]
Corporate federal income tax	21.00%		21.00%
Internal Revenue Service [Member] | Tax Year 2018
Income Taxes [Line Items]
Net Operating Loss Carryforwards Utilized For Income Taxes			$ 5.7
Federal, Maine, Massachusetts, and New Hampshire Tax Authorities
Income Taxes [Line Items]
Tax examination description			The Company remains subject to examination by Maine, Massachusetts, and New Hampshire tax authorities for the tax periods ended December 31, 2016; December 31, 2017; and December 31, 2018.
Domestic Country And State Jurisdiction [Member]
Income Taxes [Line Items]
Net Operating Loss Carryforwards			$ 11.9

Key Weighted Average Assumption

Key Weighted Average Assumptions Used in Determining Benefit Plan Costs and Obligations (Detail) - Benefit Plan Costs	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Discount Rate	4.25%	3.60%
Rate of Compensation Increase	3.00%	3.00%
Expected Long-term rate of return on plan assets	7.75%	7.75%
Health Care Cost Trend Rate Assumed for Next Year	7.00%	7.50%
Ultimate Health Care Cost Trend Rate	4.50%	4.50%
Year that Ultimate Health Care Cost Trend Rate is reached	2024	2024

Components of Retirement Plan C

Components of Retirement Plan Costs (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Service Cost	$ 776	$ 848	$ 2,328	$ 2,544
Interest Cost	1,621	1,469	4,863	4,407
Expected Return on Plan Assets	(2,119)	(1,946)	(6,356)	(5,838)
Prior Service Cost Amortization	80	81	240	243
Actuarial Loss Amortization	1,081	1,447	3,243	4,341
Sub-total	1,439	1,899	4,318	5,697
Amounts Capitalized and Deferred	(650)	(962)	(1,659)	(2,590)
Net Periodic Benefit Cost Recognized	789	937	2,659	3,107
Other Postretirement Benefit Plans, Defined Benefit
Defined Benefit Plan Disclosure [Line Items]
Service Cost	576	733	1,728	2,199
Interest Cost	857	852	2,569	2,554
Expected Return on Plan Assets	(412)	(409)	(1,234)	(1,227)
Prior Service Cost Amortization	304	327	910	981
Actuarial Loss Amortization	56	346	170	1,038
Sub-total	1,381	1,849	4,143	5,545
Amounts Capitalized and Deferred	(650)	(930)	(1,730)	(2,557)
Net Periodic Benefit Cost Recognized	731	919	2,413	2,988
Supplemental Employee Retirement Plans, Defined Benefit
Defined Benefit Plan Disclosure [Line Items]
Service Cost	62	122	185	366
Interest Cost	142	101	426	303
Prior Service Cost Amortization	14	47	42	141
Actuarial Loss Amortization	157	121	471	365
Sub-total	375	391	1,124	1,175
Amounts Capitalized and Deferred	(107)	(113)	(322)	(339)
Net Periodic Benefit Cost Recognized	$ 268	$ 278	$ 802	$ 836

Retirement Benefit Obligation_2

Retirement Benefit Obligations - Additional Information (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Contributions to benefit plan	$ 6.9
Other Postretirement Benefit Plans, Defined Benefit
Defined Benefit Plan Disclosure [Line Items]
Contributions to benefit plan	2.8
Supplemental Employee Retirement Plans, Defined Benefit
Defined Benefit Plan Disclosure [Line Items]
Benefit payments under SERP Plan	0.4
Expected additional benefit payments for the remainder of 2019	$ 0.2