10-Q

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

x Quarterly report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

for the quarterly period ended September 30, 2012

or

o Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

for the transition period from                    to                   

Commission file number   001-14431

American States Water Company

(Exact Name of Registrant as Specified in Its Charter)

California	95-4676679
(State or Other Jurisdiction of Incorporation or Organization)	(IRS Employer Identification No.)

630 E. Foothill Blvd, San Dimas, CA	91773-1212
(Address of Principal Executive Offices)	(Zip Code)

(909) 394-3600

(Registrant’s Telephone Number, Including Area Code)

Not Applicable

(Former Name, Former Address and Former Fiscal Year, if Changed Since Last Report)

Commission file number   001-12008

Golden State Water Company

(Exact Name of Registrant as Specified in Its Charter)

California	95-1243678
(State or Other Jurisdiction of Incorporation or Organization)	(IRS Employer Identification No.)

630 E. Foothill Blvd, San Dimas, CA	91773-1212
(Address of Principal Executive Offices)	(Zip Code)

(909) 394-3600

(Registrant’s Telephone Number, Including Area Code)

Not Applicable

(Former Name, Former Address and Former Fiscal Year, if Changed Since Last Report)

Indicate by check mark whether Registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that Registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

American States Water Company	Yes x No o
Golden State Water Company	Yes x No o

Indicate by check mark whether Registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or such shorter period that the Registrant was required to submit and post such files).

American States Water Company	Yes x No o
Golden State Water Company	Yes x No o

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

American States Water Company

Large accelerated filer o Accelerated filer x Non-accelerated filer o Smaller reporting company o

Golden State Water Company

Large accelerated filer o Accelerated filer o Non-accelerated filer x Smaller reporting company o

Indicate by check mark whether the Registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act)

American States Water Company	Yes ¨ Nox
Golden State Water Company	Yes ¨ Nox

As of November 2, 2012, the number of Common Shares outstanding, of American States Water Company was 19,216,427 shares. As of November 2, 2012, all of the 146 outstanding Common Shares of Golden State Water Company were owned by American States Water Company.

Golden State Water Company meets the conditions set forth in General Instruction (H)(1)(a) and (b) of Form 10-Q and is therefore filing this Form, in part, with the reduced disclosure format for Golden State Water Company.

AMERICAN STATES WATER COMPANY

and

GOLDEN STATE WATER COMPANY

FORM 10-Q

INDEX

Part I	Financial Information
Item 1:	Financial Statements	1
	Consolidated Balance Sheets of American States Water Company as of September 30, 2012 and December 31, 2011	4
	Consolidated Statements of Income of American States Water Company for the Three Months Ended September 30, 2012 and 2011	6
	Consolidated Statements of Income of American States Water Company for the Nine Months Ended September 30, 2012 and 2011	7
	Consolidated Statements of Cash Flow of American States Water Company for the Nine Months Ended September 30, 2012 and 2011	8
	Balance Sheets of Golden State Water Company as of September 30, 2012 and December 31, 2011	9
	Statements of Income of Golden State Water Company for the Three Months Ended September 30, 2012 and 2011	11
	Statements of Income of Golden State Water Company for the Nine Months Ended September 30, 2012 and 2011	12
	Statements of Cash Flow of Golden State Water Company for the Nine Months Ended September 30, 2012 and 2011	13
	Notes to Consolidated Financial Statements	14
Item 2:	Management’s Discussion and Analysis of Financial Condition and Results of Operations	28
Item 3:	Quantitative and Qualitative Disclosures About Market Risk	57
Item 4:	Controls and Procedures	57
Part II	Other Information
Item 1:	Legal Proceedings	58
Item 1A:	Risk Factors	58
Item 2:	Unregistered Sales of Equity Securities and Use of Proceeds	58
Item 3:	Defaults Upon Senior Securities	58
Item 4:	Mine Safety Disclosure	58
Item 5:	Other Information	58
Item 6:	Exhibits	59
	Signatures	62

PART I

Item 1. Financial Statements

General

The basic financial statements included herein have been prepared by Registrant, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission.

Certain information and footnote disclosures normally included in financial statements, prepared in accordance with accounting principles generally accepted in the United States of America, have been condensed or omitted pursuant to such rules and regulations. In the opinion of management, all adjustments consisting of normal recurring items and estimates necessary for a fair statement of results for the interim period have been made.

It is suggested that these financial statements be read in conjunction with the financial statements and notes thereto in the latest Annual Report on Form 10-K of American States Water Company and its wholly owned subsidiary, Golden State Water Company.

Filing Format

American States Water Company (hereinafter “AWR”) is the parent company of Golden State Water Company (hereinafter “GSWC”) and American States Utility Services, Inc. (hereinafter “ASUS”) and its subsidiaries.

This quarterly report on Form 10-Q is a combined report being filed by two separate Registrants: AWR and GSWC. For more information, please see Note 1 to the Notes to Consolidated Financial Statements and the heading entitled General in Item 2 - Management’s Discussion and Analysis of Financial Condition and Results of Operations. References in this report to “Registrant” are to AWR and GSWC collectively, unless otherwise specified. GSWC makes no representations as to the information contained in this report relating to AWR and its subsidiaries, other than GSWC.

Forward-Looking Statements

This Form 10-Q and the documents incorporated herein contain forward-looking statements intended to qualify for the “safe harbor” from liability established by the Private Securities Litigation Reform Act of 1995.  Forward-looking statements are based on current estimates, expectations and projections about future events and assumptions regarding these events and include statements regarding management’s goals, beliefs, plans or current expectations, taking into account the information currently available to management.  Forward-looking statements are not statements of historical facts.  For example, when we use words such as “anticipate,” “believe,” “plan,” “estimate,” “expect,” “intend,” “may” and other words that convey uncertainty of future events or outcomes, we are making forward-looking statements.  We are not able to predict all the factors that may affect future results.  We caution you that any forward-looking statements made by us are not guarantees of future performance and that actual results may differ materially from those in our forward-looking statements.  Some of the factors that could cause future results to differ materially from those expressed or implied by our forward-looking statements, or from historical results, include, but are not limited to:

·The outcome of pending and future regulatory, legislative or other proceedings, investigations or audits, including decisions in our general rate cases and the results of independent audits of our construction contracting procurement practices or other independent audits of our costs

·Changes in the policies and procedures of the California Public Utilities Commission (“CPUC”)

·Timeliness of CPUC action on rates

·Our ability to efficiently manage capital expenditures and operating and maintenance expenses within CPUC authorized levels and timely recovery of our costs through rates

·The impact of increasing opposition to rate increases on our ability to recover our costs through rates and on the size of our customer base

·Our ability to forecast the costs of maintaining GSWC’s aging water infrastructure

1

·Our ability to recover increases in permitting costs and in costs associated with negotiating and complying with the terms of our franchise agreements with cities and counties and other demands made upon us by the cities and counties in which GSWC operates

·Changes in accounting valuations and estimates, including changes resulting from changes in our assessment of anticipated recovery of regulatory assets, liabilities and revenues subject to refund or regulatory disallowances

·Changes in environmental laws and water and wastewater quality requirements and increases in costs associated with complying with these laws and requirements

·Availability of water supplies, which may be adversely affected by changes in weather patterns, contamination and court decisions or other governmental actions restricting use of water from the Colorado River, transportation of water to GSWC’s service areas through the California State Water Project or pumping of groundwater

·Our ability to obtain adequate, reliable and cost-effective supplies of chemicals, electricity, fuel, water and other raw materials that are needed for our water operations

·Our ability to recover the costs associated with the contamination of GSWC’s groundwater supplies from parties responsible for the contamination or through the ratemaking process and the time and expense incurred by us in obtaining recovery of such costs

·Adequacy of our power supplies and the extent to which we can manage and respond to the volatility of electric and natural gas prices

·Our ability to comply with the CPUC’s renewable energy procurement requirements

·Changes in GSWC customer demand due to unanticipated population growth or decline, changes in climate conditions, general economic and financial market conditions, cost increases and conservation

·Changes in accounting treatment for regulated utilities

·Changes in estimates used in ASUS’ revenue recognition under the percentage of completion method of accounting for our construction activities at our contracted services business

·Termination, in whole or in part, of our contracts to provide water and/or wastewater services at military bases for the convenience of the U.S. government or for default

·Delays in obtaining redetermination of prices or equitable adjustments to our prices on our contracts to provide water and/or wastewater services at military bases

·Disallowance of costs on our contracts to provide water and/or wastewater services at military bases as a result of audits, cost review or investigations by contracting agencies

·Inaccurate assumptions used in preparing bids in our contracted services business

·Failure of the collection or sewage systems that we operate on military bases resulting in untreated wastewater or contaminants spilling into nearby properties, streams or rivers

·Failure to comply with the terms of our military privatization contracts

·Failure of any of our subcontractors to perform services for us in accordance with the terms of our military privatization contracts

·Implementation, maintenance and upgrading of our information technology systems

·General economic conditions which may impact our ability to recover infrastructure investments and operating costs from customers

·Explosions, fires, accidents, mechanical breakdowns, the disruption of information technology and telecommunication systems, human error and similar events that may occur while operating and maintaining a water and electric system in California or operating and maintaining water and wastewater systems on military bases under varying geographic conditions

2

·The impact of storms, earthquakes, floods, mudslides, drought, wildfires, disease and similar natural disasters, or acts of terrorism or vandalism, that affect customer demand or that damage or disrupt facilities, operations or information technology systems owned by us, our customers or third parties on whom we rely

·Restrictive covenants in our debt instruments or changes to our credit ratings on current or future debt that may increase our financing costs or affect our ability to borrow or make payments on our debt

·Our ability to access capital markets and other sources of credit in a timely manner on acceptable terms

Please consider our forward-looking statements in light of these risks (which are more fully disclosed in our 2011 Annual Report on Form 10-K) as you read this Form 10-Q.  We qualify all of our forward-looking statement by these cautionary statements.

3

AMERICAN STATES WATER COMPANY

CONSOLIDATED BALANCE SHEETS

ASSETS

(Unaudited)

(in thousands)	September 30,2012			December 31, 2011
Property, Plant and Equipment
Regulated utility plant, at cost	$	1,346,064		$	1,302,589
Non utility property, at cost	8,687			7,747
Total	1,354,751			1,310,336
Less - Accumulated depreciation	(442,724		)	(413,836		)
Net property, plant and equipment	912,027			896,500
Other Property and Investments
Goodwill	1,116			1,116
Other property and investments	13,636			11,803
Total other property and investments	14,752			12,919
Current Assets
Cash and cash equivalents	43,066			1,315
Accounts receivable — customers (less allowance for doubtful accounts of $769 in 2012 and $715 in 2011)	28,792			20,399
Unbilled revenue	21,826			16,188
Receivable from the U.S. government (less allowance for doubtful accounts of $8 in 2012 and $0 in 2011)	4,287			7,584
Other accounts receivable (less allowance for doubtful accounts of $334 in 2012 and $333 in 2011)	7,920			12,181
Income taxes receivable	637			20,537
Materials and supplies, at average cost	6,578			3,070
Regulatory assets — current	25,525			36,362
Prepayments and other current assets	5,380			3,959
Costs and estimated earnings in excess of billings on uncompleted contracts	32,787			34,466
Deferred income taxes — current	10,292			9,540
Total current assets	187,090			165,601
Regulatory and Other Assets
Regulatory assets	151,195			143,595
Costs and estimated earnings in excess of billings on uncompleted contracts	4,323			598
Receivable from the U.S. government (less allowance for doubtful accounts of $0 in 2012 and 2011)	4,427			6,660
Deferred income taxes	11			15
Other	15,813			12,474
Total regulatory and other assets	175,769			163,342
Total Assets	$	1,289,638		$	1,238,362

The accompanying notes are an integral part of these consolidated financial statements

4

AMERICAN STATES WATER COMPANY

CONSOLIDATED BALANCE SHEETS

CAPITALIZATION AND LIABILITIES

(Unaudited)

(in thousands)	September 30, 2012		December 31, 2011
Capitalization
Common shares, no par value	$	247,030	$	233,306
Earnings reinvested in the business	201,822		175,360
Total common shareholders’ equity	448,852		408,666
Long-term debt	344,248		340,395
Total capitalization	793,100		749,061
Current Liabilities
Notes payable to banks	—		2,000
Long-term debt — current	178		291
Accounts payable	52,081		37,873
Income taxes payable	1,726		332
Accrued employee expenses	9,710		8,659
Accrued interest	6,423		3,938
Unrealized loss on purchased power contracts	2,719		7,611
Billings in excess of costs and estimated earnings on uncompleted contracts	19,346		26,973
Other	17,062		16,693
Total current liabilities	109,245		104,370
Other Credits
Advances for construction	73,451		75,353
Contributions in aid of construction - net	102,719		100,037
Deferred income taxes	133,651		128,963
Unamortized investment tax credits	1,904		1,972
Accrued pension and other postretirement benefits	68,550		68,353
Billings in excess of costs and estimated earnings on uncompleted contracts	—		3,272
Other	7,018		6,981
Total other credits	387,293		384,931
Commitments and Contingencies (Note 8)	—		—
Total Capitalization and Liabilities	$	1,289,638	$	1,238,362

The accompanying notes are an integral part of these consolidated financial statements

5

AMERICAN STATES WATER COMPANY

CONSOLIDATED STATEMENTS OF INCOME

FOR THE THREE MONTHS

ENDED SEPTEMBER 30, 2012 AND 2011

(Unaudited)

	Three Months Ended September 30,
(in thousands, except per share amounts)	2012			2011
Operating Revenues
Water	$	90,604		$	89,570
Electric	8,549			8,744
Contracted services	34,368			21,395
Total operating revenues	133,521			119,709
Operating Expenses
Water purchased	18,874			16,094
Power purchased for pumping	3,067			3,141
Groundwater production assessment	3,923			3,795
Power purchased for resale	2,854			3,038
Supply cost balancing accounts	1,960			5,050
Other operation expenses	7,394			7,398
Administrative and general expenses	17,362			18,022
Depreciation and amortization	10,230			9,554
Maintenance	4,232			4,346
Property and other taxes	3,878			3,682
ASUS construction expenses	23,332			13,169
Net gain on sale of property	(65		)	—
Total operating expenses	97,041			87,289
Operating Income	36,480			32,420
Other Income and Expenses
Interest expense	(6,018		)	(6,194		)
Interest income	419			202
Other	219			(170		)
Total other income and expenses	(5,380		)	(6,162		)
Income from continuing operations before income tax expense	31,100			26,258
Income tax expense	12,436			10,641
Income from continuing operations	18,664			15,617
Loss from discontinued operations, net of tax	—			(18		)
Net Income	$	18,664		$	15,599
Basic Earnings Per Common Share
Income from continuing operations	$	0.97		$	0.83
Income (loss) from discontinued operations	—			—
Net Income	$	0.97		$	0.83
Fully Diluted Earnings Per Share
Income from continuing operations	$	0.97		$	0.83
Income (loss) from discontinued operations	—			—
Net Income	$	0.97		$	0.83
Weighted Average Number of Shares Outstanding	19,059			18,701
Weighted Average Number of Diluted Shares	19,103			18,852
Dividends Declared Per Common Share	$	0.355		$	0.280

The accompanying notes are an integral part of these consolidated financial statements

6

AMERICAN STATES WATER COMPANY

CONSOLIDATED STATEMENTS OF INCOME

FOR THE NINE MONTHS

ENDED SEPTEMBER 30, 2012 AND 2011

(Unaudited)

	Nine Months Ended September 30,
(in thousands, except per share amounts)	2012			2011
Operating Revenues
Water	$	237,447		$	234,047
Electric	27,735			27,178
Contracted services	89,298			62,620
Total operating revenues	354,480			323,845
Operating Expenses
Water purchased	42,257			37,679
Power purchased for pumping	6,642			6,842
Groundwater production assessment	11,228			10,307
Power purchased for resale	8,725			9,767
Supply cost balancing accounts	9,560			14,374
Other operation expenses	21,671			21,261
Administrative and general expenses	51,739			54,181
Depreciation and amortization	31,127			28,829
Maintenance	11,415			12,695
Property and other taxes	11,699			10,640
ASUS construction expenses	58,513			37,844
Net gain on sale of property	(68		)	(128		)
Total operating expenses	264,508			244,291
Operating Income	89,972			79,554
Other Income and Expenses
Interest expense	(17,808		)	(18,807		)
Interest income	1,129			500
Other	435			(379		)
Total other income and expenses	(16,244		)	(18,686		)
Income from continuing operations before income tax expense	73,728			60,868
Income tax expense	29,871			25,568
Income from continuing operations	43,857			35,300
Income from discontinued operations, net of tax	—			3,850
Net Income	$	43,857		$	39,150
Basic Earnings Per Common Share
Income from continuing operations	$	2.30		$	1.88
Income from discontinued operations	—			0.20
Net Income	$	2.30		$	2.08
Fully Diluted Earnings Per Share
Income from continuing operations	$	2.30		$	1.88
Income from discontinued operations	—			0.20
Net Income	$	2.30		$	2.08
Weighted Average Number of Shares Outstanding	18,924			18,672
Weighted Average Number of Diluted Shares	19,038			18,816
Dividends Declared Per Common Share	$	0.915		$	0.820

The accompanying notes are an integral part of these consolidated financial statements

7

AMERICAN STATES WATER COMPANY

CONSOLIDATED STATEMENTS OF CASH FLOW

FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2012 AND 2011

(Unaudited)

	Nine Months Ended September 30,
(in thousands)	2012			2011
Cash Flows From Operating Activities:
Net income	$	43,857		$	39,150
Adjustments to reconcile net income to net cash provided by operating activities:
Gain on sale of CCWC, net of taxes, included in discontinued operations	—			(2,454		)
Depreciation and amortization	31,127			28,829
Provision for doubtful accounts	1,313			776
Deferred income taxes and investment tax credits	4,735			4,317
Stock-based compensation expense	1,477			1,245
Other — net	(359		)	1,179
Changes in assets and liabilities:
Accounts receivable — customers	(9,664		)	(8,241		)
Unbilled revenue	(5,638		)	(1,844		)
Other accounts receivable	3,967			(3,354		)
Receivable from the U.S. government	5,530			(6,732		)
Materials and supplies	(3,508		)	(656		)
Prepayments and other current assets	(1,421		)	1,261
Regulatory assets — supply cost balancing accounts	9,560			14,374
Costs and estimated earnings in excess of billings on uncompleted contracts	(2,046		)	4,163
Other assets (including other regulatory assets)	(17,698		)	(16,545		)
Accounts payable	12,981			2,075
Income taxes receivable/payable	21,294			(2,816		)
Billings in excess of costs and estimated earnings on uncompleted contracts	(10,899		)	4,569
Accrued pension and other postretirement benefits	3,079			(2,351		)
Other liabilities	3,892			5,692
Net cash provided	91,579			62,637
Cash Flows From Investing Activities:
Construction expenditures	(48,169		)	(63,574		)
Proceeds from the sale of CCWC	—			29,603
Other	69			(72		)
Net cash used	(48,100		)	(34,043		)
Cash Flows From Financing Activities:
Proceeds from issuance of Common Shares and stock option exercises	12,434			2,350
Receipt of advances for and contributions in aid of construction	5,101			6,149
Refunds on advances for construction	(3,216		)	(3,843		)
Repayments of long-term debt	(294		)	(22,304		)
Proceeds from issuance of long-term debt, net of issuance costs	4,034			61,911
Net change in notes payable to banks	(2,000		)	(56,400		)
Dividends paid	(17,307		)	(15,306		)
Other — net	(480		)	(133		)
Net cash used	(1,728		)	(27,576		)
Net increase in cash and cash equivalents	41,751			1,018
Cash and cash equivalents, beginning of period	1,315			4,197
Cash and cash equivalents, end of period	$	43,066		$	5,215

The accompanying notes are an integral part of these consolidated financial statements

8

GOLDEN STATE WATER COMPANY

BALANCE SHEETS

ASSETS

(Unaudited)

(in thousands)	September 30, 2012			December 31, 2011
Utility Plant
Utility plant, at cost	$	1,346,064		$	1,302,589
Less - Accumulated depreciation	(438,697		)	(410,644		)
Net utility plant	907,367			891,945
Other Property and Investments	11,468			9,626
Current Assets
Cash and cash equivalents	25,552			—
Accounts receivable-customers (less allowance for doubtful accounts of $769 in 2012 and $715 in 2011)	28,792			20,399
Unbilled revenue	21,826			16,188
Inter-company receivable	1,330			785
Other accounts receivable (less allowance for doubtful accounts of $257 in 2012 and $290 in 2011)	6,281			7,755
Income taxes receivable from Parent	—			19,914
Materials and supplies, at average cost	2,457			1,926
Regulatory assets — current	25,525			36,362
Prepayments and other current assets	5,058			3,710
Deferred income taxes — current	9,255			8,497
Total current assets	126,076			115,536
Regulatory and Other Assets
Regulatory assets	151,195			143,595
Other accounts receivable	2,090			1,838
Other	13,877			10,843
Total regulatory and other assets	167,162			156,276
Total Assets	$	1,212,073		$	1,173,383

The accompanying notes are an integral part of these financial statements

9

GOLDEN STATE WATER COMPANY

BALANCE SHEETS

CAPITALIZATION AND LIABILITIES

(Unaudited)

(in thousands)	September 30, 2012		December 31, 2011
Capitalization
Common shares, no par value	$	230,074	$	228,936
Earnings reinvested in the business	178,904		155,870
Total common shareholder’s equity	408,978		384,806
Long-term debt	344,248		340,395
Total capitalization	753,226		725,201
Current Liabilities
Long-term debt — current	178		291
Accounts payable	36,399		31,227
Income taxes payable to Parent	868		—
Accrued employee expenses	8,648		7,544
Accrued interest	6,423		3,938
Unrealized loss on purchased power contracts	2,719		7,611
Other	16,554		16,162
Total current liabilities	71,789		66,773
Other Credits
Advances for construction	73,451		75,353
Contributions in aid of construction — net	102,719		100,037
Deferred income taxes	133,503		128,815
Unamortized investment tax credits	1,904		1,972
Accrued pension and other postretirement benefits	68,550		68,353
Other	6,931		6,879
Total other credits	387,058		381,409
Commitments and Contingencies (Note 8)	—		—
Total Capitalization and Liabilities	$	1,212,073	$	1,173,383

The accompanying notes are an integral part of these financial statements

10

GOLDEN STATE WATER COMPANY

STATEMENTS OF INCOME

FOR THE THREE MONTHS

ENDED SEPTEMBER 30, 2012 AND 2011

(Unaudited)

	Three Months Ended September 30,
(in thousands)	2012			2011
Operating Revenues
Water	$	90,604		$	89,570
Electric	8,549			8,744
Total operating revenues	99,153			98,314
Operating Expenses
Water purchased	18,874			16,094
Power purchased for pumping	3,067			3,141
Groundwater production assessment	3,923			3,795
Power purchased for resale	2,854			3,038
Supply cost balancing accounts	1,960			5,050
Other operation expenses	6,859			6,933
Administrative and general expenses	14,621			15,398
Depreciation and amortization	9,941			9,334
Maintenance	3,801			3,765
Property and other taxes	3,357			3,366
Net gain on sale of property	(65		)	—
Total operating expenses	69,192			69,914
Operating Income	29,961			28,400
Other Income and Expenses
Interest expense	(5,959		)	(6,138		)
Interest income	384			149
Other	219			(171		)
Total other income and expenses	(5,356		)	(6,160		)
Income from operations before income tax expense	24,605			22,240
Income tax expense	10,030			9,212
Net Income	$	14,575		$	13,028

The accompanying notes are an integral part of these financial statements

11

GOLDEN STATE WATER COMPANY

STATEMENTS OF INCOME

FOR THE NINE MONTHS

ENDED SEPTEMBER 30, 2012 AND 2011
(Unaudited)

	Nine Months Ended September 30,
(in thousands)	2012			2011
Operating Revenues
Water	$	237,447		$	234,047
Electric	27,735			27,178
Total operating revenues	265,182			261,225
Operating Expenses
Water purchased	42,257			37,679
Power purchased for pumping	6,642			6,842
Groundwater production assessment	11,228			10,307
Power purchased for resale	8,725			9,767
Supply cost balancing accounts	9,560			14,374
Other operation expenses	19,710			18,489
Administrative and general expenses	43,472			45,182
Depreciation and amortization	30,283			28,171
Maintenance	10,098			10,755
Property and other taxes	10,454			9,638
Net gain on sale of property	(65		)	(128		)
Total operating expenses	192,364			191,076
Operating Income	72,818			70,149
Other Income and Expenses
Interest expense	(17,648		)	(18,436		)
Interest income	1,063			439
Other	434			(570		)
Total other income and expenses	(16,151		)	(18,567		)
Income from operations before income tax expense	56,667			51,582
Income tax expense	23,352			22,147
Net Income	$	33,315		$	29,435

The accompanying notes are an integral part of these financial statements

12

GOLDEN STATE WATER COMPANY

STATEMENTS OF CASH FLOW

FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2012 AND 2011

(Unaudited)

	Nine Months Ended September 30,
(in thousands)	2012			2011
Cash Flows From Operating Activities:
Net income	$	33,315		$	29,435
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	30,283			28,171
Provision for doubtful accounts	1,271			697
Deferred income taxes and investment tax credits	4,725			4,460
Stock-based compensation expense	1,241			1,099
Other — net	(389		)	800
Changes in assets and liabilities:
Accounts receivable — customers	(9,664		)	(8,241		)
Unbilled revenue	(5,638		)	(1,844		)
Other accounts receivable	1,222			111
Materials and supplies	(531		)	(197		)
Prepayments and other current assets	(1,348		)	995
Regulatory assets — supply cost balancing accounts	9,560			14,374
Other assets (including other regulatory assets)	(17,612		)	(16,571		)
Accounts payable	3,945			3,752
Inter-company receivable/payable	(545		)	452
Income taxes receivable/payable from/to Parent	20,782			(1,977		)
Accrued pension and other postretirement benefits	3,079			(2,351		)
Other liabilities	3,985			5,798
Net cash provided	77,681			58,963
Cash Flows From Investing Activities:
Construction expenditures	(47,230		)	(62,089		)
Proceeds from sale of property	65			144
Net cash used	(47,165		)	(61,945		)
Cash Flows From Financing Activities:
Receipt of advances for and contributions in aid of construction	5,101			6,149
Refunds on advances for construction	(3,216		)	(3,843		)
Proceeds from the issuance of long-term debt, net of issuance costs	4,034			61,911
Repayments of long-term debt	(294		)	(22,304		)
Net change in inter-company borrowings	—			(23,381		)
Dividends paid	(10,200		)	(15,000		)
Other — net	(389		)	(78		)
Net cash (used) provided	(4,964		)	3,454
Net increase in cash and cash equivalents	25,552			472
Cash and cash equivalents, beginning of period	—			1,541
Cash and cash equivalents, end of period	$	25,552		$	2,013

The accompanying notes are an integral part of these financial statements

13

AMERICAN STATES WATER COMPANY AND SUBSIDIARIES

AND

GOLDEN STATE WATER COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1 — Summary of Significant Accounting Policies:

Nature of Operations: American States Water Company (“AWR”) is the parent company of Golden State Water Company (“GSWC”) and American States Utility Services, Inc. (“ASUS”) (and its subsidiaries, Fort Bliss Water Services Company (“FBWS”), Terrapin Utility Services, Inc. (“TUS”), Old Dominion Utility Services, Inc. (“ODUS”), Palmetto State Utility Services, Inc. (“PSUS”) and Old North Utility Services, Inc. (“ONUS”)).  The subsidiaries of ASUS may be collectively referred to herein as the “Military Utility Privatization Subsidiaries.” AWR was also the parent company of Chaparral City Water Company (“CCWC”) until the sale of CCWC on May 31, 2011.

GSWC is a public utility engaged principally in the purchase, production, distribution and sale of water in California serving approximately 255,000 customers. GSWC also distributes electricity in several San Bernardino Mountain communities in California serving approximately 23,000 customers. The California Public Utilities Commission (“CPUC”) regulates GSWC’s water and electric businesses, including properties, rates, services, facilities and other matters, and transactions by GSWC with its affiliates.  AWR’s assets and operating income are primarily those of GSWC.

ASUS performs water and wastewater services, including the operation, maintenance, renewal and replacement of water and/or wastewater systems on a contract basis. Through its wholly owned subsidiaries, ASUS operates and maintains the water and/or wastewater systems at various military bases pursuant to 50-year firm, fixed-price contracts, which are subject to periodic price redeterminations and modifications for changes in circumstances, and changes in laws and regulations. There is no direct regulatory oversight by the CPUC over AWR or the operation, rates or services provided by ASUS or any of its wholly owned subsidiaries.

Basis of Presentation: The consolidated financial statements and notes thereto are being presented in a combined report being filed by two separate Registrants: AWR and GSWC. References in this report to “Registrant” are to AWR and GSWC, collectively, unless otherwise specified.  Certain prior period amounts have been reclassified to conform to the 2012 financial statement presentation.

The consolidated financial statements of AWR include the accounts of AWR and its subsidiaries, all of which are wholly owned. These financial statements are prepared in conformity with accounting principles generally accepted in the United States of America. Inter-company transactions and balances have been eliminated in the AWR consolidated financial statements. The operational results of CCWC for the periods presented are reported in discontinued operations, net of transaction costs.

The consolidated financial statements included herein have been prepared by Registrant, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”).  The December 31, 2011 condensed consolidated balance sheet data was derived from audited financial statements, but does not include all disclosures required by GAAP. The preparation of the consolidated financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. In the opinion of management, all adjustments, consisting of normal, recurring items and estimates necessary for a fair statement of the results for the interim periods, have been made. It is suggested that these consolidated financial statements be read in conjunction with the consolidated financial statements and the notes thereto included in the Form 10-K for the year ended December 31, 2011 filed with the SEC.

GSWC’s Related Party Transactions: GSWC and ASUS provide and receive various services to and from their parent, AWR.  Any transactions between GSWC and AWR or ASUS are governed by the CPUC’s affiliate transaction rules.  In addition, AWR has a $100.0 million syndicated credit facility. AWR borrows under this facility and provides funds to its subsidiaries, including GSWC, in support of their operations. Any amounts owed to AWR for borrowings under this facility are included in inter-company payables on GSWC’s balance sheet. The interest rate charged to GSWC and other affiliates is sufficient to cover AWR’s interest cost under the credit facility. GSWC also allocates certain corporate office administrative and general costs to its affiliate, ASUS, using allocation factors mandated by the CPUC.  Through May 31, 2011, GSWC also allocated costs to CCWC.

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Long-Term Debt:  On October 1, 2012, GSWC redeemed its $8,000,000, 7.55% Medium-Term Notes, Series B.  The Notes, which were due 2025, were redeemed at a price of 101.133% of the outstanding principal amount of the Notes, plus accrued and unpaid interest through October 1, 2012, for a total redemption price of $8.3 million.

Sales and Use Taxes:  GSWC bills certain sales and use taxes levied by state or local governments to its customers. Included in these sales and use taxes are franchise fees, which GSWC pays to various municipalities (based on ordinances adopted by these municipalities) in order to use public right of way for utility purposes. GSWC bills these franchise fees to its customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of GSWC’s ability to collect from the customer, are accounted for on a gross basis. GSWC’s franchise fees billed to customers and recorded as operating revenue were approximately $966,000 and $942,000 for the three months ended September 30, 2012 and 2011, respectively, and $2,600,000 and $2,423,000 for the nine months ended September 30, 2012 and 2011, respectively. When GSWC acts as an agent, and the tax is not required to be remitted if it is not collected from the customer, the taxes are accounted for on a net basis.

Depending on the state in which the operations are conducted, ASUS and its subsidiaries are also subject to certain state non-income tax assessments generally computed on a “gross receipts” or “gross revenues” basis.  These non-income tax assessments are required to be paid regardless of whether the subsidiary is reimbursed by the U.S. government for these assessments under its 50-year contracts with the U.S. government.  The non-income tax assessments are accounted for on a gross basis and totaled $222,000 and $168,000 during the three months ended September 30, 2012 and 2011, respectively, and $563,000 and $533,000 for the nine months ended September 30, 2012 and 2011, respectively.

Recently Adopted Accounting Pronouncements:  The following accounting standards did not or are not expected to have any impact on Registrant’s consolidated financial statements:

Accounting Standards Update No. 2011-05, Comprehensive Income (Topic 220): Presentation of Comprehensive Income (“ASU 2011-05”). Under ASU 2011-05, an entity has the option to present the total of comprehensive income, the components of net income, and the components of other comprehensive income either in a single continuous statement of comprehensive income or in two separate but consecutive statements. Under both options, an entity will be required to present each component of net income along with total net income, each component of other comprehensive income along with a total for other comprehensive income, and a total amount for comprehensive income.  ASU 2011-05 is effective for fiscal years beginning on or after December 15, 2011 and did not have a material impact on Registrant’s consolidated financial statements.

Accounting Standards Update No. 2011-08, Intangibles - Goodwill and Other (Topic 350): Testing Goodwill for Impairment (“ASU 2011-08”). Under ASU 2011-08, an entity has the option to first assess qualitative factors to determine whether the existence of events or circumstances leads to a determination that it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If, after assessing the totality of events or circumstances, an entity determines it is not more likely than not that the fair value of a reporting unit is less than its carrying amount, performing the two-step impairment test is not required. The guidance does not change how an entity measures a goodwill impairment loss, and is therefore not expected to affect the information reported to users of an entity’s financial statements.  The adoption of this update is not expected to have a significant impact on its results of operations, financial position or cash flows.

In December 2011, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2011-11, Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities (“ASU 2011-11”). The ASU 2011-11 amendments require companies to disclose information about offsetting and related arrangements to enable users of its financial statements to understand the effect of those arrangements on its financial position. ASU 2011-11 is required to be applied retrospectively for all prior periods presented and is effective for annual periods for fiscal years beginning on or after January 1, 2013, and interim periods within those annual fiscal years. Registrant does not expect adoption of this standard to have a material impact on its consolidated results of operations and financial condition.

Other accounting standards that have been issued by the FASB or other standards-setting bodies that do not require adoption until a future date are not expected to have a material impact on Registrant’s consolidated financial statements upon adoption.

15

Note 2 — Regulatory Matters:

In accordance with accounting principles for rate-regulated enterprises, Registrant records regulatory assets, which represent probable future recovery of costs from customers through the ratemaking process, and regulatory liabilities, which represent probable future refunds that are to be credited to customers through the ratemaking process. At September 30, 2012, Registrant had approximately $77.7 million of regulatory assets, net of regulatory liabilities not accruing carrying costs. Of this amount, $52.1 million relates to the underfunded positions of the pension and other post-retirement obligations, $16.2 million relates to deferred income taxes representing accelerated tax benefits flowed through to customers, which will be included in rates concurrently with recognition of the associated future tax expense, and $2.7 million relates to a memorandum account authorized by the CPUC to track unrealized gains and losses on GSWC’s purchase power contract over the life of the contract. The remainder relates to other items that do not provide for or incur carrying costs. Regulatory assets, less regulatory liabilities, included in the consolidated balance sheets are as follows:

(dollars in thousands)	September 30,2012			December 31, 2011
GSWC
Electric supply cost balancing account	$	5,937		$	8,347
Water Revenue Adjustment Mechanism, net of Modified Cost Balancing Account	43,638			39,112
Base Revenue Requirement Adjustment Mechanism	6,171			4,053
Costs deferred for future recovery on Aerojet case	16,310			17,173
Pensions and other post-retirement obligations	55,780			56,960
Derivative unrealized loss (Note 4)	2,719			7,611
Flow-through taxes, net (Note 6)	16,169			17,032
Electric transmission line abandonment costs	2,257			2,428
Asset retirement obligations	2,869			2,793
Low income rate assistance balancing accounts	8,305			6,194
General rate case memorandum accounts	6,610			12,922
Santa Maria adjudication memorandum accounts	3,561			3,662
Bay Point balancing accounts	5,242			5,752
Other regulatory assets, net	9,756			8,409
Various refunds to customers	(8,604		)	(12,491		)
Total	$	176,720		$	179,957

Regulatory matters are discussed in detail in the consolidated financial statements and the notes thereto included in the Form 10-K for the year ended December 31, 2011 filed with the SEC.  The discussion below focuses on significant matters and changes since December 31, 2011.

Alternative-Revenue Programs:

GSWC records the difference between what it bills its water customers and that which is authorized by the CPUC using the Water Revenue Adjustment Mechanism (“WRAM”). GSWC also records the difference between adopted and actual expense levels for purchased water, purchased power and pump taxes, as established by the CPUC, using the Modified Cost Balancing Accounts (“MCBA”). GSWC has implemented surcharges to recover its WRAM balances, net of the MCBA.  For the three months ended September 30, 2012 and 2011, surcharges of $6.7 million and $5.2 million, respectively, were billed to customers to decrease previously incurred under-collections in the WRAM, net of MCBA accounts, and approximately $14.3 million and $10.8 million for the nine months ended September 30, 2012 and 2011, respectively. As of September 30, 2012, GSWC has a net aggregated regulatory asset of $43.6 million which is comprised of a $64.2 million under-collection in the WRAM accounts and $20.6 million over-collection in the MCBA accounts.

Based on CPUC guidelines, recovery periods relating to GSWC’s WRAM/MCBA balances range between 12 and 36 months, with the majority being 24 months.  As required by the accounting guidance for alternative revenue programs, GSWC is required to collect its WRAM, net of its MCBA, within 24 months following the year in which they are recorded.  In September 2010, GSWC, along with other California water utilities, filed an application with the CPUC to modify the recovery period of its WRAM and MCBA to 18 months or less.  In April 2012, the CPUC issued a final decision which, among other things, sets the recovery period for under-collection balances that are up to 15% of adopted annual revenues at 18 months or less.  For under-collection balances greater than 15%, the recovery period is 19 to 36 months. GSWC does not currently have any balances over 15% of adopted annual revenues.

16

In addition to adopting a new amortization schedule, the final decision sets a cap on total net WRAM/MCBA surcharges in any given calendar year of 10% of the last authorized revenue requirement. For GSWC, the cap will be applied to its 2013 WRAM balances to be filed for recovery in early 2014.  The cap requirement set forth in the final decision will not impact GSWC’s 2012 and prior year WRAM/MCBA balances.

In June 2012, the CPUC approved surcharges for recovery of BVES’ 2011 Base Revenue Requirement Adjustment Mechanism (“BRRAM”) balance. The CPUC approved a 36-month surcharge, with the amounts collected through December 2013 to be applied to the 2011 BRRAM under-collection.  Surcharges collected during the remainder of the 36-month period would be for recovery of a $1.6 million increase in the BVES revenue requirement representing the difference between the allocated general office costs authorized by the CPUC in its November 2010 decision on the Region II, Region III and general office rate case, and what is currently in BVES’ rates for allocated general office costs.  As authorized by the CPUC, the $1.6 million was included in the BRRAM for recovery through the surcharge; however, these costs are not considered an alternative revenue program.

CPUC Pending Rehearing Matter:

In July 2011, the CPUC issued an order granting the Division of Ratepayer Advocates (“DRA”) request to rehear certain issues from the Region II, Region III and general office rate case approved in November 2010.  Among the issues in the rehearing are the La Serena plant improvement project included in rate base totaling approximately $3.5 million and GSWC’s methodology for deferring rate case costs.  Final resolution of these matters is expected in 2013. The regulatory issues associated with these matters are further discussed below.

La Serena Plant Improvement Project:

In November 2010, as part of GSWC’s Region II, Region III and general office rate case decision, the CPUC disallowed a portion of the La Serena plant improvement project costs from utility customer rates.  As a result of the CPUC’s decision in 2010, GSWC recorded a charge of $2.2 million, which included the disallowance of these capital costs and the related revenues earned on those capital costs that will be refunded to customers.

In December 2010, DRA filed a motion for rehearing on this matter, contending that the CPUC erred in assigning a portion of the La Serena plant improvement costs to GSWC utility customers and requested that all of the capital costs related to the La Serena plant improvement project be disallowed. In July 2011, the CPUC granted DRA’s request for rehearing.  Hearings on these matters are expected in the fourth quarter of 2012. A proposed decision is expected in June 2013. In addition to granting a rehearing, the CPUC also directed the Division of Water and Audits (“DWA”) to undertake an audit of the La Serena project costs and to provide a confidential report to the CPUC with recommendations on whether an investigation should be conducted to determine whether any laws were broken related to the La Serena project.  Management does not believe it has violated any laws in regards to the La Serena project.  DWA issued its independent audit report, which found cost overruns for the La Serena plant improvement project to be lower than the amount of costs for rate recovery previously disallowed by the CPUC.

In October 2012, DRA issued a report on this matter recommending further disallowances of costs and refund of revenues earned on those costs. DRA’s recommendation is inconsistent with the independent audit report issued by DWA.  In addition, GSWC believes DRA’s recommendations are without merit and inconsistent with previous CPUC decisions on this matter.  However, if DRA prevails, GSWC may be required to write-off additional capital costs and provide refunds to customers of the revenues earned on those costs.  Based on DRA’s recommendation, additional disallowed costs and revenues earned on those costs through September 30, 2012 totaled approximately $2.5 million. GSWC intends to vigorously defend its position. However, at this time, management cannot predict the outcome of the rehearing, DWA’s and DRA’s recommendations, or determine the estimated additional loss or range of loss, if any.

Deferred rate case costs:

The rehearing is also re-addressing deferred rate case costs, which are direct costs consisting primarily of outside consulting services which have been incurred in connection with the preparation and processing of a general rate case. Historically, GSWC has deferred these costs as a regulatory asset which are then recovered in rates and amortized over the term of a rate case cycle once the new rates go into effect.  In the rehearing proceeding, DRA is again challenging GSWC’s historical practice of deferring these costs with subsequent recovery upon the effective date of the new rates. Instead, DRA believes that rate case costs should be projected for future periods and recovered prospectively.  Management believes that DRA’s rationale and recommendations are inconsistent with previous CPUC decisions on this matter and also with GSWC’s historical practice of deferring and recovering rate case expenses associated with the current general rate case, and continues to believe that the costs are probable for recovery.  However, if DRA prevails, GSWC may be required to write-off deferred rate case costs related to its current pending rate case, which total approximately $1.9 million as of September 30, 2012.  At this time, GSWC is unable to predict the outcome of this matter.

17

BVES Regulatory Matters:

BVES General Rate Case

In February 2012, GSWC filed its BVES general rate case (“GRC”) for rates in years 2013 through 2016.  In August 2012, DRA issued its report on the GRC.  Included in DRA’s recommendations is a $2.0 million retroactive ratemaking proposal to increase BVES’ accumulated depreciation balance to reflect adopted depreciation expense for the years 2009 through 2012 rather than actual depreciation expense as recorded in compliance with Generally Accepted Accounting Principles.  DRA also recommends that one-half of deferred rate case costs be borne by shareholders, rather than entirely by customers as has been authorized by the CPUC in prior rate cases.  As of September 30, 2012, GSWC has a $2.2 million regulatory asset representing deferred rate case costs for the current BVES general rate case, which are considered probable of recovery. Hearings on the GRC, including these matters, were held in September 2012.  If DRA prevails, GSWC may be required to record a charge to adjust accumulated depreciation and to write-off half of its deferred rate case costs. GSWC believes DRA’s recommendations are without merit and intends to vigorously defend its positions.  However, at this time, GSWC is unable to predict the final outcome of these matters which are expected to be resolved in the pending rate case.

Renewables Portfolio Standard

GSWC’s BVES division has been regularly filing compliance reports with the CPUC regarding its purchases of energy from renewable energy resources to meet California’s renewables portfolio standards (“RPS”).  Previous filings under prior RPS laws had indicated that BVES had not achieved annual target purchase levels of renewable energy resources and thus, on its face, might be subject to a potential penalty.  However, a new RPS law went into effect in December 2011 which changed, among other things, the prior RPS requirement based upon annual procurement targets to multi-year procurement targets.  Under the new RPS law, BVES must procure sufficient RPS-eligible resources to meet: (i) any RPS procurement requirement deficit for any year prior to 2011, and (ii) RPS procurement requirements for the 2011 — 2013 compliance period by no later than December 31, 2013.  BVES’ first RPS reports under the new law were submitted to the CPUC in March 2012 and August 2012, and did not reflect any RPS procurement deficiencies nor any potential or actual penalties.  Accordingly, no provision for loss has been recorded in the financial statements as of September 30, 2012.

In September 2009, GSWC negotiated a ten-year contract with the Los Angeles County Sanitation District (“LACSD”) to purchase renewable energy created from landfill gas. In February 2011, LACSD notified GSWC that it intended to shut down the landfill gas generator. In August 2011, GSWC and LACSD negotiated a settlement to resolve a dispute between the parties regarding certain terms of the contract.  Under the terms of the settlement, GSWC agreed to waive its right to a 14 month termination notice and LACSD agreed to sell renewable energy credits (“RECs”) to GSWC.

In November 2011, GSWC filed for CPUC approval for the purchase of these RECs.   In July 2012, the CPUC approved the purchase.  BVES intends to apply these RECs towards either its pre-2011 renewable energy requirements or its 2011-2013 requirements. The REC’s were purchased for approximately $325,000 during the third quarter of 2012 as an asset and will be included as part of BVES’ electric supply cost balancing account when the RECs are applied towards the RPS requirements.

In June 2011, GSWC’s BVES filed an application with the CPUC to recover $1.2 million in legal and outside service costs incurred during the period September 1, 2007 through March 31, 2011 in connection with seeking to procure renewable energy resources.  In March 2012, the CPUC approved the application.  Accordingly, a regulatory asset of $1.3 million, including accrued interest, was recorded in March 2012.  A 12-month surcharge was implemented in May 2012 for recovery of these costs.

Other Regulatory Matters:

Cost of Capital Proceeding for Water Regions:

In July 2012, the CPUC issued a final decision on GSWC’s water cost of capital proceeding filed in May 2011. The decision approves the settlement agreement entered into between GSWC, along with three other California water utilities, and DRA in November 2011.  The approved settlement authorizes a Return on Equity (“ROE”) of 9.99% and a rate-making capital structure for GSWC of 55% equity and 45% debt. The weighted cost of capital (return on rate base), with an updated embedded debt cost and the settlement ROE, is 8.64%. The new rate of return authorized by the CPUC’s final decision was implemented into water rates retroactive to January 1, 2012.

18

Among other things, the final decision required GSWC to refund to customers approximately $408,000, representing the settled amount included in the interest rate balancing account.  During the three months ended September 30, 2012, GSWC refunded the majority of this to customers through a one-time surcredit.

The CPUC decision also authorized GSWC to continue the Water Cost of Capital Mechanism (“WCCM”).  The WCCM adjusts ROE and rate of return on rate base between the three-year cost of capital proceedings only if there is a positive or negative change of more than 100 basis points in the average of Moody’s Aa utility bond rate as measured over the period October 1 through September 30.  If the average Moody’s rate for this period changes by over 100 basis points from the benchmark, the ROE will be adjusted by one half of the difference. For the period October 1, 2011 through September 30, 2012, Moody’s rate declined by 112 basis points from the benchmark. As a result, in October 2012, GSWC filed an advice letter to lower its water ROE by 56 basis points, from 9.99% to 9.43%, which will be incorporated in the new 2013 water rates.

Changes in Tax Law

The Small Business Jobs Act of 2010 and the Tax Relief, Unemployment Insurance Reauthorization and Job Creation Act of 2010 (“Tax Relief Acts”) extended 50% bonus depreciation for qualifying property through 2012 and created 100% bonus depreciation for qualifying property placed in service between September 9, 2010 and December 31, 2011.

In June 2011, the CPUC adopted a resolution that requires water utilities to file advice letters implementing a one-way memorandum account to track the revenue effects associated with the Tax Relief Acts. This may result in a reduction in revenue requirements in future rate case proceedings. The effective date of the memorandum account established by the resolution was April 14, 2011.  More specifically, the memorandum account established by the resolution tracks on a CPUC-jurisdictional, revenue-requirement basis: (a) decreases in each impacted utility’s revenue requirement resulting from increases in its deferred tax reserve; and (b) other direct changes in the revenue requirement resulting from taking advantage of the Tax Relief Acts. This resolution also authorizes impacted utilities to use savings from this new tax law to invest in certain additional, needed utility infrastructure, not otherwise funded in rates, within a time frame shorter than would be practicable through the formal application or advice letter processes. The establishment of a memorandum account does not change rates, nor guarantee that rates will be changed in the future. This mechanism simply allows the CPUC to determine at a future date whether rates should be changed. GSWC has evaluated the potential impact of this resolution and does not expect it to have a material impact on its consolidated financial statements. However, at this time, GSWC cannot predict the outcome of this resolution or determine its potential impact, if any, on future rates.

CPUC Subpoena

On December 15, 2011, the CPUC approved a settlement agreement reached between GSWC and DWA to resolve an investigation of certain work orders and charges paid to a specific contractor used previously for numerous construction projects over a period of 14 years.  The settlement provides for refunds to customers totaling $9.5 million to be made over a period of 12-36 months, as well as a reduction in rate-base and other rate adjustments totaling $3.0 million.  As a result of the settlement, management does not expect future increases in the reserve related to this specific contractor.  Refunds totaling $1.1 million and $2.2 million were made to customers during the three and nine months ended September 30, 2012, respectively.

As part of the settlement agreement, GSWC agreed to be subject to three separate independent audits of its procurement practices over a period of ten years from the date the settlement was approved by the CPUC.  The audits will cover GSWC’s procurement practices from 1994 forward and could result in further disallowances of costs.  The cost of the audits will be borne by shareholders and may not be recovered by GSWC in rates to customers. At this time, management cannot predict the outcome of these audits or determine the estimated loss or range of loss, if any, resulting from these audits.

19

Note 3 — Earnings per Share/Capital Stock:

In accordance with the accounting guidance for participating securities and earnings per share (“EPS”), AWR uses the “two-class” method of computing EPS. The “two-class” method is an earnings allocation formula that determines EPS for each class of common stock and participating security. AWR has participating securities related to stock options and restricted stock units that earn dividend equivalents on an equal basis with AWR’s Common Shares (the “Common Shares”) that have been issued under AWR’s 2000 Stock Incentive Plan and 2008 Stock Incentive Plan (the “2000 and 2008 Employee Plans”) and the 2003 Non-Employee Directors Plan (the “2003 Directors Plan”). In applying the “two-class” method, undistributed earnings are allocated to both common shares and participating securities.

The following is a reconciliation of AWR’s net income and weighted average Common Shares outstanding for calculating basic net income per share:

Basic		For The Three MonthsEnded September 30,					For The Nine MonthsEnded September 30,
(in thousands, except per share amounts)		2012		2011			2012		2011
Net income from continuing operations		$	18,664	$	15,617		$	43,857	$	35,300
Net income (loss) from discontinued operations		—		(18		)	—		3,850
Total net income		18,664		15,599			43,857		39,150
Less: (a)  Distributed earnings to common shareholders		6,766		5,236			17,316		15,311
Distributed earnings to participating securities		52		38			119		102
Undistributed earnings		11,846		10,325			26,422		23,737
(b)	Undistributed earnings allocated to common shareholders	11,755		10,250			26,242		23,580
	Undistributed earnings allocated to participating securities	91		75			180		157
Total income available to common shareholders, basic (a)+(b)		$	18,521	$	15,486		$	43,558	$	38,891
Weighted average Common Shares outstanding, basic		19,059		18,701			18,924		18,672
Basic earnings per Common Share:
Income from continuing operations		$	0.97	$	0.83		$	2.30	$	1.88
Income from discontinued operations		—		—			—		0.20
Net Income		$	0.97	$	0.83		$	2.30	$	2.08

Diluted EPS is based upon the weighted average number of Common Shares, including both outstanding shares and shares potentially issuable in connection with stock options granted under Registrant’s 2000 and 2008 Employee Plans, and the 2003 Directors Plan, and net income. At September 30, 2012 and 2011, there were 226,208 and 668,360 options outstanding, respectively, under these Plans. At September 30, 2012 and 2011, there were also 148,176 and 136,703 restricted stock units outstanding, respectively.

The following is a reconciliation of AWR’s net income and weighted average Common Shares outstanding for calculating diluted net income per share:

Diluted	For The Three MonthsEnded September 30,				For The Nine MonthsEnded September 30,
(in thousands, except per share amounts)	2012		2011		2012		2011
Common shareholders earnings, basic	$	18,521	$	15,486	$	43,558	$	38,891
Undistributed earnings for dilutive stock options	—		75		180		157
Total common shareholders earnings, diluted	$	18,521	$	15,561	$	43,738	$	39,048
Weighted average common shares outstanding, basic	19,059		18,701		18,924		18,672
Stock-based compensation (1)	44		151		114		144
Weighted average common shares outstanding, diluted	19,103		18,852		19,038		18,816
Diluted earnings per Common Share:
Income from continuing operations	$	0.97	$	0.83	$	2.30	$	1.88
Income from discontinued operations	—		—		—		0.20
Net Income	$	0.97	$	0.83	$	2.30	$	2.08

(1)In applying the treasury stock method of reflecting the dilutive effect of outstanding stock-based compensation in the calculation of diluted EPS, 182,932 and 425,839 stock options at September 30, 2012 and 2011, respectively, were deemed to be outstanding in accordance with accounting guidance on earnings per share.

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All of the 148,176 and 136,703 restricted stock units at September 30, 2012 and 2011, respectively, were included in the calculation of diluted EPS for the nine months ended September 30, 2012 and 2011.

Stock options of 43,276 and 241,921 were outstanding at September 30, 2012 and 2011, respectively, but not included in the computation of diluted EPS because the related option exercise price was greater than the average market price of AWR’s Common Shares for the nine months ended September 30, 2012 and 2011.  Stock options of 600 were outstanding at September 30, 2011, but not included in the computation of diluted EPS because they were anti-dilutive.

During the nine months ended September 30, 2012 and 2011, AWR issued 423,590 and 100,148 Common Shares, for approximately $12,434,000 and $2,350,000, respectively, under AWR’s Common Share Purchase and Dividend Reinvestment Plan, the 401(k) Plan, the 2000 and 2008 Employee Plans, and the 2003 Directors Plan. In addition, Registrant purchased 571,652 and 319,470 Common Shares on the open market during the nine months ended September 30, 2012 and 2011, respectively, under Registrant’s 401(k) Plan and the Common Share Purchase and Dividend Reinvestment Plan. The Common Shares purchased by Registrant were used to satisfy the requirements of these plans.

During the three months ended September 30, 2012 and 2011, AWR paid quarterly dividends of approximately $6.7 million, or $0.355 per share, and $5.2 million, or $0.28 per share, respectively.  During the nine months ended September 30, 2012 and 2011, AWR paid quarterly dividends to shareholders of approximately $17.3 million, or $0.915 per share, and $15.3 million, or $0.82 per share, respectively.

Note 4 — Derivative Instruments:

GSWC purchases certain power at a fixed cost, under a purchased power contract, depending on the amount of power and the period during which the power is purchased.  One of the products under this contract is an option to purchase energy of up to 15 megawatts per hour daily during winter peak months (November through March) and up to 5 megawatts per hour daily during nonpeak months (April through October). The contract is subject to the accounting guidance for derivatives and requires mark-to-market derivative accounting.

The CPUC has authorized GSWC to establish a regulatory asset and liability memorandum account to offset the entries required by the accounting guidance.  Accordingly, all unrealized gains and losses generated from the purchased power contract are deferred on a monthly basis into a non-interest bearing regulatory memorandum account that tracks the changes in fair value of the derivative throughout the term of the contract, having no impact on GSWC’s earnings. Upon expiration of the purchased power contract, the balance in this regulatory memorandum account will be zero.  As of September 30, 2012 there was a $2.7 million cumulative unrealized loss which has been included in the memorandum account.

On January 12, 2012, GSWC executed a new purchased power master agreement. The agreement is subject to CPUC approval, which GSWC plans to file for approval by the end of 2012. If approved, GSWC will be able to purchase 12 megawatts (“MWs”) of base load energy at a fixed price to be negotiated upon CPUC approval of the agreement. GSWC also intends to request CPUC approval of a regulatory asset and liability memorandum account for the new contract to offset the entries required by the accounting guidance on derivatives.

The accounting guidance for fair value measurements applies to all financial assets and financial liabilities that are being measured and reported on a fair value basis. Under the accounting guidance, GSWC makes fair value measurements that are classified and disclosed in one of the following three categories:

Level 1: Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities;

Level 2: Quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability, or

Level 3: Prices or valuation techniques that require inputs that are both significant to the fair value measurement and unobservable (i.e., supported by little or no market activity).

Registrant’s valuation model utilizes various inputs that include quoted market prices for energy over the duration of the contract. The market prices used to determine the fair value for this derivative instrument were estimated based on independent sources such as broker quotes and publications that are not observable in or corroborated by the market.  Registrant receives one broker quote to determine the fair value of its derivative instrument.  When such inputs have a significant impact on the measurement of fair value, the instrument is categorized in Level 3. Accordingly, the valuation of the derivative on Registrant’s purchased power contract has been classified as Level 3 for all periods presented.

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The following table presents changes in the fair value of the derivative for the three and nine months ended September 30, 2012 and 2011:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
(dollars in thousands)	2012			2011			2012			2011
Balance, at beginning of the period	$	(5,176	)	$	(7,475	)	$	(7,611	)	$	(6,850	)
Unrealized gain (loss) on purchased power contracts	2,457			(101		)	4,892			(726		)
Balance, at end of the period	$	(2,719	)	$	(7,576	)	$	(2,719	)	$	(7,576	)

Note 5 — Fair Value of Financial Instruments:

For cash and cash equivalents, accounts receivable, accounts payable and short-term debt, the carrying amount is assumed to approximate fair value due to the short-term nature of the amounts. The table below estimates the fair value of long-term debt held by GSWC. Rates available to GSWC at September 30, 2012 and December 31, 2011 for debt with similar terms and remaining maturities were used to estimate fair value for long-term debt. The interest rates used for the September 30, 2012 valuation decreased as compared to December 31, 2011, increasing the fair value of long-term debt as of September 30, 2012. Changes in the assumptions will produce differing results.

	September 30, 2012				December 31, 2011
(dollars in thousands)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Financial liabilities:
Long-term debt—GSWC	$	344,426	$	469,065	$	340,686	$	437,275

As previously discussed in Note 4, the accounting guidance for fair value measurements establishes a framework for measuring fair value and requires fair value measurements to be classified and disclosed in one of three levels. Publicly issued notes are measured using current U.S. corporate bond yields available for similar financial instruments and are classified as Level 1.  Private placement notes and other long-term debt are measured using current U.S. corporate bond yields for similar debt instruments and are classified as Level 2. The following tables set forth by level, within the fair value hierarchy, GSWC’s long-term debt measured at fair value as of September 30, 2012:

(dollars in thousands)	Level 1		Level 2		Level 3	Total
Long-term debt—GSWC	$	295,778	$	173,287	—	$	469,065

Note 6 — Income Taxes:

As a regulated utility, GSWC treats certain temporary differences as flow-through adjustments in computing its income tax provision consistent with the income tax approach approved by the CPUC for ratemaking purposes. Flow-through adjustments increase or decrease tax expense in one period, with an offsetting decrease or increase occurring in another period. Giving effect to these temporary differences as flow-through adjustments typically results in a greater variance between the effective income tax rate and the statutory federal income tax rate in any given period than would otherwise exist if GSWC were not required to account for its income taxes as a regulated enterprise.  GSWC’s effective income tax rate deviates from the statutory rate primarily due to state taxes and differences between book and taxable income that are treated as flow-through adjustments in accordance with regulatory requirements (principally plant-, rate-case- and compensation-related items).

Changes in Tax Law

The Tax Relief Acts extended bonus depreciation for qualifying property through 2012.  As a result, Registrant’s current tax expense for 2011 and 2012 reflects benefits from the Tax Relief Acts. Although these law changes reduce AWR’s current taxes payable, they do not reduce its total income tax expense or effective income tax rate.

In December 2011, the U.S. Treasury Department issued temporary regulations related to the tax treatment of tangible property, including guidance on expensing certain repairs and maintenance expenditures for which separate guidance has not been issued. These regulations are effective for tax years beginning on or after January 1, 2012.  The majority of GSWC’s assets consist of water pipelines. For these assets the regulations did not provide any new guidance. Registrant is evaluating its water-pipeline tax repair-cost method.  Registrant is also evaluating other tax-method changes provided for under the regulations; however, the effects on its tax expense and tax balances are not anticipated to be significant. Although these temporary regulations are expected to reduce AWR’s current taxes payable, they do not reduce its total effective income tax rate.

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Note 7 — Employee Benefit Plans:

The components of net periodic benefit costs, before allocation to the overhead pool, for Registrant’s pension plan, postretirement plan, and Supplemental Executive Retirement Plan (“SERP”) for the three and nine months ended September 30, 2012 and 2011 are as follows:

	For The Three Months Ended September 30,
	Pension Benefits						Other Postretirement Benefits						SERP
(dollars in thousands)	2012			2011			2012			2011			2012		2011
Components of Net Periodic Benefits Cost:
Service cost	$	1,670		$	1,406		$	112		$	107		$	183	$	150
Interest cost	1,663			1,631			136			153			122		116
Expected return on plan assets	(1,634		)	(1,587		)	(90		)	(74		)	—		—
Amortization of transition	—			—			105			105			—		—
Amortization of prior service cost (benefit)	31			30			(50		)	(50		)	40		40
Amortization of actuarial loss	759			310			—			—			77		34
Net periodic pension cost under accounting standards	2,489			1,790			213			241			422		340
Regulatory adjustment — deferred (1)	(596		)	(127		)	—			—			—		—
Total expense recognized, before allocation to overhead pool	$	1,893		$	1,663		$	213		$	241		$	422	$	340

	For The Nine Months Ended September 30,
	Pension Benefits						Other Postretirement Benefits						SERP
(dollars in thousands)	2012			2011			2012			2011			2012		2011
Components of Net Periodic Benefits Cost:
Service cost	$	5,007		$	4,218		$	336		$	321		$	549	$	450
Interest cost	4,992			4,893			408			459			366		348
Expected return on plan assets	(4,905		)	(4,761		)	(270		)	(221		)	—		—
Amortization of transition	—			—			315			315			—		—
Amortization of prior service cost (benefit)	90			89			(150		)	(150		)	120		121
Amortization of actuarial loss	2,277			931			—			—			231		101
Net periodic pension cost under accounting standards	7,461			5,370			639			724			1,266		1,020
Regulatory adjustment — deferred (1)	(1,794		)	(380		)	—			—			—		—
Total expense recognized, before allocation to overhead pool	$	5,667		$	4,990		$	639		$	724		$	1,266	$	1,020

(1)Regulatory Adjustment - In November 2010, the CPUC authorized GSWC to establish a two-way balancing account, effective January 1, 2010, to track differences between the forecasted annual pension expenses adopted in rates and the actual annual expense to be recorded by GSWC in accordance with the accounting guidance for pension costs.  As of September 30, 2012, GSWC has included a $3.7 million under-collection in the two-way pension balancing account recorded as a regulatory asset (Note 2).

During the three and nine months ended September 30, 2012, Registrant contributed $4.3 million and $6.1 million to the pension plan, respectively. Registrant expects to contribute approximately $500,000 to the postretirement medical plan during the fourth quarter of 2012.

Note 8 — Contingencies:

Water Quality-Related Litigation:

Perchlorate and/or Volatile Organic Compounds (“VOC”) have been detected in certain wells servicing GSWC’s South San Gabriel System. GSWC filed suit in federal court, along with two other affected water purveyors and the San Gabriel Basin Water Quality Authority, together known as the “Water Entities”, against some of those allegedly responsible for the contamination of two of GSWC’s wells and those of the other affected water purveyors. In response to the filing of the lawsuit, the Potentially Responsible Party (“PRP”) defendants filed motions to dismiss the suit or strike certain portions of the suit. The judge issued a ruling on April 1, 2003 granting in part and denying in part the PRP’s motions. A key ruling of the court was that the water purveyors, including GSWC, by virtue of their ownership of wells contaminated with hazardous chemicals are themselves PRPs under the Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”).

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GSWC has amended its suit to claim certain affirmative defenses as an “innocent” party under CERCLA. GSWC is presently unable to estimate a range of loss, if any, in the event that GSWC is deemed to be a PRP, or on GSWC’s ability to fully recover from the PRPs, past and future costs associated with the treatment of these wells.

On August 29, 2003, the US Environmental Protection Agency (“EPA”) issued Unilateral Administrative Orders (“UAO”) against 41 parties deemed responsible for polluting the groundwater in portions of the San Gabriel Valley from which those impacted GSWC wells draw water. GSWC was not named as a party to the UAO. The UAO requires these parties to remediate the contamination.

On October 12, 2004, the judge in the lawsuit stayed the matter in order to allow the parties to explore settlement and appointed a special master to oversee mandatory settlement discussions between the PRPs and the Water Entities. EPA has also conducted settlement discussions with several PRPs regarding the UAO. The Water Entities and EPA have worked closely to coordinate their settlement discussions under the auspices of the special master in order to arrive at a complete resolution of all issues affecting the lawsuit and the UAO. Settlements have been reached with a majority of the PRPs.

On March 28, 2011, the Court lifted the stay and the matter has proceeded in litigation. The EPA filed a separate complaint against the remaining PRPs and this matter was consolidated with those filed by the Water Entities.  Since October 17, 2011 several 30-day stays were granted to continue settlement discussions.  During these 30-day stays, EPA and the Water Entities have successfully reached settlements with most of the remaining PRPs.  On January 15, 2012, the stay was lifted and the case entered the discovery phase as settlement negotiations with the remaining few PRPs continued.  Registrant believes it will reach settlements with all the PRPs.  However, Registrant is presently unable to predict the ultimate outcome of this matter.

Condemnation of Properties:

The laws of the State of California provide for the acquisition of public utility property by governmental agencies through their power of eminent domain, also known as condemnation, where doing so is necessary and in the public interest. In addition, these laws provide: (i) that the owner of utility property may contest whether the condemnation is actually necessary and in the public interest, and (ii) that the owner is entitled to receive the fair market value of its property if the property is ultimately taken.

The City of Claremont (“Claremont”) located in GSWC’s Region III, has expressed various concerns to GSWC about rates charged by GSWC and the effectiveness of the CPUC’s rate-setting procedures. On January 5, 2012, the Claremont City council members directed staff to pursue analysis required for potential acquisition of the water system and allocated funds from its general reserve for such analysis. On June 27, 2012, Claremont notified GSWC of its intent to appraise the value of GSWC’s water system serving Claremont. Claremont’s City Council is currently reviewing its appraisal of GSWC’s water system in Claremont. GSWC serves approximately 11,000 customers in Claremont.

The Town of Apple Valley (the “Town”) had abandoned its activities related to a potential condemnation of GSWC’s water system serving the Town in 2007. However, in January 2011, the Town Council directed staff to update the previously prepared financial feasibility study for the acquisition of GSWC’s water systems. The Town also created a Blue Ribbon Water Commission (“BRWC”) to provide recommendations on the items pending before the CPUC associated with the water companies (including GSWC) serving the Town.  The BRWC recommended against acquisition at this time based on current economic conditions. The Town has not yet made a decision based on the recommendation.  GSWC’s Apple Valley water systems serve approximately 2,900 customers.

In April 2011, an organization called Ojai FLOW (Friends of Locally Owned Water) started a local campaign for the Casitas Municipal Water District to purchase GSWC’s Ojai water system. The Ojai City Council passed a resolution supporting the efforts of Ojai FLOW at their regular meeting on April 26, 2011. On July 25, 2012, the Casitas Municipal Water District hired a financial consultant to provide consulting services to the District for the establishment of a Community Facilities District (“CFD”) and the issuance of bonds within the CFD to provide funding for the potential acquisition of GSWC’s Ojai system.  GSWC serves approximately 3,000 customers in Ojai.

Except for the City of Claremont, Town of Apple Valley and the City of Ojai, Registrant is currently not involved in activities related to the potential condemnation of any of its water customer service areas or in its BVES customer service area. No formal condemnation proceedings have been filed against any of the Registrant’s service areas during the past three years.

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Santa Maria Groundwater Basin Adjudication:

In 1997, the Santa Maria Valley Water Conservation District (“plaintiff”) filed a lawsuit against multiple defendants, including GSWC, the City of Santa Maria, and several other public water purveyors. The plaintiff’s lawsuit sought an adjudication of the Santa Maria Groundwater Basin (the “Basin”). A stipulated settlement of the lawsuit has been reached, subject to CPUC approval.  The settlement, among other things, if approved by the CPUC, would preserve GSWC’s historical pumping rights and secure supplemental water rights for use in case of drought or other reductions in the natural yield of the Basin. GSWC, under the stipulation, has a right to 10,000 acre-feet of groundwater replenishment provided by the Twitchell Project, a storage and flood control reservoir project operated by the Santa Maria Valley Conservation District.  A monitoring and annual reporting program has been established to allow the parties to responsibly manage the Basin and to respond to shortage conditions.  If severe water shortage conditions are found over a period of five years, the management area engineer will make findings and recommendations to alleviate such shortages.  If the Basin experiences severe shortage conditions, the court has the authority to limit GSWC’s groundwater production to 10,248 acre-feet per year, based on developed water in the Basin.  Over the last five years, GSWC’s average groundwater production has been 10,140 acre-feet per year.

On February 11, 2008, the court issued its final judgment, which approved and incorporated the stipulation.  The judgment awarded GSWC prescriptive rights to groundwater against the non-stipulating parties.  In addition, the judgment granted GSWC the right to use the Basin for temporary storage and to recapture 45 percent of the return flows that are generated from its importation of State Water Project water.  Pursuant to this judgment, the court retained jurisdiction over all of the parties to make supplemental orders or to amend the judgment as necessary.  On March 20, 2008, the non-stipulating parties filed notices of appeal.  In August 2010, the appellants filed their opening briefs, and oral arguments were heard on September 11, 2012.  Registrant is unable to predict the outcome of the appeal.

Environmental Clean-Up and Remediation:

Chadron Plant: GSWC has been involved in environmental remediation and clean-up at a plant site (“Chadron Plant”) that contained an underground storage tank which was used to store gasoline for its vehicles. This tank was removed in July 1990 along with the dispenser and ancillary piping. Since then, GSWC has been involved in various remediation activities at this site.  After many years of remediation activities, the majority of the leaked gasoline product has been removed.  However, a sheen of gasoline still remains at the top of the groundwater.  Additional groundwater remediation will be required before soil remediation can be commenced.  Management at this time cannot estimate when additional soil remediation will commence, due to the persistence of gasoline product in the groundwater.   As of September 30, 2012, the total spent to clean-up and remediate GSWC’s plant facility was approximately $3.5 million, of which $1.5 million has been paid by the State of California Underground Storage Tank Fund. Amounts paid by GSWC have been included in rate-base and approved by the CPUC for recovery.

As of September 30, 2012, GSWC has an accrued liability for the estimated additional cost of $1.2 million to complete the clean-up at the site. The ultimate cost may vary as there are many unknowns in remediation of underground gasoline spills and this is an estimate based on currently available information. Management also believes it is probable that the estimated additional costs will be approved in rate base by the CPUC and has recorded a corresponding regulatory asset.

Other Litigation:

Registrant is also subject to other ordinary routine litigation incidental to its business. Management believes that rate recovery, proper insurance coverage and reserves are in place to insure against property, professional and general liability and workers’ compensation claims incurred in the ordinary course of business. Registrant is unable to predict an estimate of the loss, if any, resulting from any pending suits or administrative proceedings, but does not believe the impact, if any, would be material.

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Note 9 — Discontinued Operations:

On May 31, 2011, AWR sold CCWC to EPCOR Water (USA) Inc. for a total purchase price of $35.2 million, including the assumption of approximately $5.6 million of long-term debt. AWR received approximately $29.6 million in cash, which was primarily used to pay down short-term borrowings.  The completion of the sale generated a gain (net of taxes and transaction costs) of approximately $2.2 million during 2011.  A summary of discontinued operations presented in the consolidated statements of income for the three and nine months ended September 30, 2011 are as follows:

(dollars in thousands)	Three MonthsEnded September 30, 2011			Nine Months Ended September 30, 2011
Operating revenues	$	—		$	3,492
Operating expenses	—			660
Operating income	—			2,832
Interest expense, net	—			(142		)
Income before income taxes	—			2,690
Income tax expense	—			1,078
Income from the operations, net of tax	—			1,612
Gain on sale of business, net of tax	—			2,454
Transaction costs, net of tax	(18		)	(216		)
Net gain on sale and transaction costs	(18		)	2,238
Income (loss) from discontinued operations (1)	$	(18	)	$	3,850

(1)Corporate overhead costs allocated to CCWC have been excluded from discontinued operations and have been included in other operating expenses and administrative and general expenses as part of continuing operations as they continue to be incurred, primarily at GSWC.

Note 10 — Business Segments:

AWR has three reportable segments, water, electric and contracted services, whereas GSWC has two segments, water and electric. Within the segments, AWR has two principal business units: water and electric service utility operations conducted through GSWC, and one contracted services unit conducted through ASUS and its subsidiaries. AWR has no material assets other than its investments in its subsidiaries on a stand-alone basis.

All activities of GSWC are geographically located within California.  The operating activities of CCWC have been included in discontinued operations as described in Note 9.  All activities of CCWC were located in the state of Arizona. GSWC is, and CCWC was, a rate-regulated utility.

Activities of ASUS and its subsidiaries are conducted in California, Georgia, Maryland, New Mexico, North Carolina, South Carolina, Texas, and Virginia.  Each of ASUS’s wholly owned subsidiaries is regulated by the state in which the subsidiary primarily conducts water and/or wastewater operations.  Fees charged for operations and maintenance, and renewal and replacement services are based upon the terms of the contracts with the U.S. government which have been filed with the commissions in the states in which ASUS’s subsidiaries are incorporated.

The tables below set forth information relating to GSWC’s operating segments, ASUS and its subsidiaries, and other matters. The identifiable assets are net of respective accumulated provisions for depreciation. Capital additions reflect capital expenditures paid in cash and exclude property installed by developers and conveyed to GSWC and through May 31, 2011 for CCWC.

	As Of And For The Three Months Ended September 30, 2012
	GSWC				ASUS		AWR			Consolidated
(dollars in thousands)	Water		Electric		Contracts		Parent			AWR
Operating revenues	$	90,604	$	8,549	$	34,368	$	—		$	133,521
Operating income (loss)	28,355		1,606		6,545		(26		)	36,480
Interest expense, net	5,178		397		24		—			5,599
Utility plant	867,310		40,057		4,660		—			912,027
Depreciation and amortization expense	9,405		536		289		—			10,230
Capital additions	17,347		1,155		220		—			18,722

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	As Of And For The Three Months Ended September 30, 2011
	GSWC				CCWC		ASUS		AWR			Consolidated
(dollars in thousands)	Water		Electric		Water		Contracts		Parent			AWR
Operating revenues	$	89,570	$	8,744	$	—	$	21,395	$	—		$	119,709
Operating income (loss)	26,752		1,648		—		4,025		(5		)	32,420
Interest expense, net	5,588		401		—		84		(81		)	5,992
Utility plant	848,647		38,063		—		4,424		—			891,134
Depreciation and amortization expense	8,832		502		—		220		—			9,554
Loss from discontinued operations, net of tax (2)	—		—				—		(18		)	(18		)
Capital additions	24,690		684		—		905		—			26,279

	As Of And For The Nine Months Ended September 30, 2012
	GSWC				ASUS		AWR			Consolidated
(dollars in thousands)	Water		Electric		Contracts		Parent			AWR
Operating revenues	$	237,447	$	27,735	$	89,298	$	—		$	354,480
Operating income (loss)	65,872		6,946		17,275		(121		)	89,972
Interest expense, net	15,399		1,186		118		(24		)	16,679
Utility plant	867,310		40,057		4,660		—			912,027
Depreciation and amortization expense	28,527		1,756		844		—			31,127
Capital additions	44,831		2,399		939		—			48,169

	As Of And For The Nine Months Ended September 30, 2011
	GSWC				CCWC			ASUS		AWR			Consolidated
(dollars in thousands)	Water		Electric		Water			Contracts		Parent			AWR
Operating revenues	$	234,047	$	27,178	$	—		$	62,620	$	—		$	323,845
Operating income (loss) (1)	65,320		4,829		(356		)	9,820		(59		)	79,554
Interest expense, net	16,780		1,217		—			309		1			18,307
Utility plant	848,647		38,063		—			4,424		—			891,134
Depreciation and amortization expense	26,662		1,509		—			658		—			28,829
Income from discontinued operations, net of tax (2)	—		—		1,612			—		2,238			3,850
Capital additions	59,776		2,313		—			1,485		—			63,574

The following table reconciles total utility plant (a key figure for rate-making) to total consolidated assets (in thousands):

	September 30,
	2012		2011
Total utility plant	$	912,027	891,134
Other assets	377,611		304,714
Total consolidated assets	$	1,289,638	$	1,195,848

(1)Operating income (loss) include CCWC’s allocated corporate overhead costs that are now primarily at GSWC.

(2)In accordance with the accounting guidance relating to assets held for sale, Registrant did not record depreciation expense for CCWC in 2011.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

General

The following discussion and analysis provides information on AWR’s consolidated operations and assets and where necessary, includes specific references to AWR’s individual segments and/or other subsidiaries: GSWC, ASUS and its subsidiaries, and AWR’s former subsidiary, CCWC. Included in the following analysis is a discussion of water and electric gross margins.  Water and electric gross margins are computed by taking total revenues, less total supply costs.  Registrant uses these margins and related percentages as important measures in evaluating its operating results.  Registrant believes these measures are useful internal benchmarks in evaluating the performance of GSWC. The discussion and tables included in the following analysis also present Registrant’s operations in terms of earnings per share by business segment.  Registrant believes that the disclosure of earnings per share by business segment provides investors with clarity surrounding the performance of its differing services and information that could be indicative of future performance for each business segment.  Registrant reviews these measurements regularly and compares them to historical periods and to its operating budget as approved. However, these measures, which are not presented in accordance with Generally Accepted Accounting Principles (“GAAP”), may not be comparable to similarly titled measures used by other entities and should not be considered as an alternative to operating income or earnings per share, which are determined in accordance with GAAP. A reconciliation of water and electric gross margins to the most directly comparable GAAP measures are included in the table under the section titled “Operating Expenses: Supply Costs.”  Reconciliations to AWR’s diluted earnings per share are included in the discussions under the sections titled “Summary Results by Segment.”

Overview

Registrant’s revenues, operating income and cash flows are earned primarily: (i) through delivering potable water to homes and businesses in various parts of California, (ii) through its contracted services business for the operation and maintenance and renewal and replacement of water and/or wastewater systems for the U.S. government at various military bases, and (iii) through the delivery of electricity in the Big Bear area of San Bernardino County, California. Rates charged to GSWC customers are determined by the CPUC. These rates are intended to allow recovery of operating costs and a reasonable rate of return on capital.  Registrant plans to continue to seek additional rate increases in future years from the CPUC to recover operating and supply costs and receive reasonable returns on invested capital. Capital expenditures in future years at GSWC are expected to remain at much higher levels than depreciation expense. When necessary, Registrant obtains funds from external sources in the debt and equity capital markets and through bank borrowings.

All of the current operation and maintenance contracts with the U.S. government are 50-year firm, fixed-price contracts with prospective price redeterminations. Additional revenues generated by contract operations are primarily dependent on new construction activities under contract modifications.  As a result, ASUS is subject to risks that are different than those of GSWC.

Some of the factors that affect Registrant’s financial performance are described in Item 1. Financial Statements, Forward-Looking Statements.

Summary of Third Quarter Results by Segment

The table below sets forth the third quarter diluted earnings per share by business segment from continuing operations:

	Diluted Earnings per Share
	3 Months Ended
	9/30/2012		9/30/2011		CHANGE
Water	$	0.71	$	0.64	$	0.07
Electric	0.05		0.05		—
Contracted services	0.21		0.13		0.08
AWR (parent)	—		0.01		(0.01		)
Totals from continuing operations, as reported	$	0.97	$	0.83	$	0.14

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For the three months ended September 30, 2012, diluted earnings per share from water operations increased $0.07 to $0.71 per share as compared to $0.64 per share for the three months ended September 30, 2011.  Impacting the comparability of the two periods were the following items:

·      An increase in the water gross margin of approximately $1.3 million, or $0.04 per share, during the three months ended September 30, 2012 as compared to the same period in 2011 due primarily to rate increases in 2012 approved by the CPUC to recover infrastructure improvements and operating costs.

·      A decrease in operating expenses (other than supply costs) by approximately $268,000, or $0.01 per share, due primarily to a decrease in administrative and general expenses resulting from lower outside service costs, labor and other employee related costs.  These decreases were partially offset by an increase in depreciation expense resulting from additions to utility plant.

·      An overall decrease in interest expense (net of interest income and other non-operating items) of $800,000, or $0.02 per share, due primarily to: (i) a decrease in short-term bank borrowings; (ii) higher interest income earned on regulatory assets and a refund claim currently under review by the Internal Revenue Service; and (iii) gains recorded on one of GSWC’s investments.

For the three months ended September 30, 2012 and 2011, diluted earnings from electric operations remained flat at $0.05 per share.

For the three months ended September 30, 2012, fully diluted earnings from contracted services increased by $0.08 per share to $0.21 per share as compared to the same period in 2011 due primarily to a higher construction dollar margin at the Fort Bragg military base in North Carolina and the military bases in Virginia resulting from an increase in construction activities at these bases.

The tables below set forth summaries of the third quarter results of operations by business segment (dollars in thousands):

	Operating Revenues									Pretax Operating Income
	3 Months		3 Months							3 Months			3 Months
	Ended		Ended		$			%		Ended			Ended			$			%
	9/30/2012		9/30/2011		CHANGE			CHANGE		9/30/2012			9/30/2011			CHANGE			CHANGE
Water	$	90,604	$	89,570	$	1,034		1.2	%	$	28,355		$	26,752		$	1,603		6.0	%
Electric	8,549		8,744		(195		)	-2.2	%	1,606			1,648			(42		)	-2.5	%
Contracted services	34,368		21,395		12,973			60.6	%	6,545			4,025			2,520			62.6	%
AWR (parent)	—		—		—			—		(26		)	(5		)	(21		)	420.0	%
Totals from continuing operations	$	133,521	$	119,709	$	13,812		11.5	%	$	36,480		$	32,420		$	4,060		12.5	%

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Summary of Year-to-Date Results by Segment

The table below sets forth the year-to-date diluted earnings per share by business segment from continuing operations, as reported:

	Diluted Earnings per Share
	9 Months Ended
	9/30/2012		9/30/2011		CHANGE
Water	$	1.55	$	1.44	$	0.11
Electric	0.20		0.12		0.08
Contracted services	0.55		0.31		0.24
AWR (parent)	—		0.01		(0.01		)
Totals from continuing operations, as reported	$	2.30	$	1.88	$	0.42

For the nine months ended September 30, 2012, diluted earnings per share contributed by the water segment were $1.55 per share as compared to $1.44 per share for the same period in 2011. The significant items in the water segment between the two periods were:

·An increase in the water gross margin of $3.5 million, or $0.10 per share, during the nine months ended September 30, 2012 primarily as the result of CPUC-approved third year rate increases effective January 1, 2012 to recover infrastructure improvements and operating costs.

·      An increase in operating expenses (other than supply costs) by approximately $2.5 million, or $0.08 per share, due primarily to increases in: (i) depreciation expense resulting from additions to utility plant; (ii) other operation expenses due, in large part, to higher labor and other employee benefits, conservation costs and bad debt expense; and (iii) property and other taxes related to franchise fees.  These increases were partially offset by a decrease in administrative and general expenses resulting primarily from lower outside service costs.

·      An overall decrease in interest expense (net of interest income and other non-operating items) of approximately $2.4 million, or $0.07 per share, primarily due to lower short-term bank borrowing and the recording of a $381,000 reduction in interest expense in connection with the CPUC’s final decision issued in July 2012 on the water cost of capital proceeding.  In addition, included in the nine months ended September 30, 2011 results was an interest charge of $553,000 related to the redemption of $22.0 million of GSWC’s 7.65% Medium-Term Notes that did not recur in 2012.  This charge was reversed in the fourth quarter of 2011 and was capitalized to be amortized over the life of new notes pursuant to the cost of capital settlement at the time.

·A decrease in the effective income tax rate during the nine months ended September 30, 2012 as compared to the same period in 2011, increasing earnings by approximately $0.02 per share during the first nine months of 2012 primarily resulting from changes between book and taxable income that are treated as flow-through adjustments in accordance with regulatory requirements.

For the nine months ended September 30, 2012, fully diluted earnings from GSWC’s electric operations increased by $0.08 per share as compared to the same period in 2011, due primarily to: (i) the CPUC’s approval of GSWC’s application to recover $1.2 million, or $0.04 per share, in legal and outside service costs previously incurred in connection with our  efforts to procure renewable energy resources; (ii) an increase in the electric gross margin of $1.1 million, or $0.03 per share; and (iii) a decrease in the effective income tax rate increasing earnings by approximately $0.02 per share. These increases were partially offset by an increase in other operating expenses (excluding the $1.2 million recovery of legal costs discussed above), which decreased earnings by $0.01 per share.

For the nine months ended September 30, 2012, fully diluted earnings from contracted services increased by $0.24 per share as compared to the same period in 2011 due primarily to a higher construction dollar margin at the Fort Bragg military base in North Carolina, the military bases in Virginia and at Andrews Air Force Base in Maryland resulting from an increase in construction activities at these bases. At Fort Bragg, there continues to be significant progress made on a major water and wastewater pipeline replacement project estimated to be substantially completed by the end of 2013.

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The table below sets forth the year-to-date results by business segment for continuing operations (dollars in thousands):

	Operating Revenues								Pretax Operating Income
	9 Months		9 Months						9 Months			9 Months
	Ended		Ended		$		%		Ended			Ended			$			%
	9/30/2012		9/30/2011		CHANGE		CHANGE		9/30/2012			9/30/2011			CHANGE			CHANGE
Water	$	237,447	$	234,047	$	3,400	1.5	%	$	65,872		$	64,964		$	908		1.4	%
Electric	27,735		27,178		557		2.0	%	6,946			4,829			2,117			43.8	%
Contracted services	89,298		62,620		26,678		42.6	%	17,275			9,820			7,455			75.9	%
AWR (parent)	—		—		—		—		(121		)	(59		)	(62		)	105.1	%
Totals from continuing operations	$	354,480	$	323,845	$	30,635	9.5	%	$	89,972		$	79,554		$	10,418		13.1	%

Discontinued Operations:

Net income from discontinued operations for the nine months ended September 30, 2011 was $3.9 million, due primarily to the gain on sale of CCWC of $2.2 million, net of taxes and transaction costs, or $0.12 per share.   Excluding the gain on sale, there was also net income of $1.6 million from CCWC’s operations for the first five months of 2011.

The following discussion and analysis provides information on AWR’s consolidated operations and where necessary, includes specific references to AWR’s individual segments and/or other continuing subsidiaries: GSWC and ASUS and its subsidiaries, and the discontinued operations of CCWC.

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Consolidated Results of Operations — Three Months Ended September 30, 2012 and 2011 (dollars in thousands, except per share amounts):

	3 Months			3 Months
	Ended			Ended			$			%
	9/30/2012			9/30/2011			CHANGE			CHANGE
OPERATING REVENUES
Water	$	90,604		$	89,570		$	1,034		1.2	%
Electric	8,549			8,744			(195		)	-2.2	%
Contracted services	34,368			21,395			12,973			60.6	%
Total operating revenues	133,521			119,709			13,812			11.5	%
OPERATING EXPENSES
Water purchased	18,874			16,094			2,780			17.3	%
Power purchased for pumping	3,067			3,141			(74		)	-2.4	%
Groundwater production assessment	3,923			3,795			128			3.4	%
Power purchased for resale	2,854			3,038			(184		)	-6.1	%
Supply cost balancing accounts	1,960			5,050			(3,090		)	-61.2	%
Other operation expenses	7,394			7,398			(4		)	-0.1	%
Administrative and general expenses	17,362			18,022			(660		)	-3.7	%
Depreciation and amortization	10,230			9,554			676			7.1	%
Maintenance	4,232			4,346			(114		)	-2.6	%
Property and other taxes	3,878			3,682			196			5.3	%
ASUS construction expenses	23,332			13,169			10,163			77.2	%
Net gain on sale of property	(65		)	—			(65		)	100.0	%
Total operating expenses	97,041			87,289			9,752			11.2	%
OPERATING INCOME	36,480			32,420			4,060			12.5	%
OTHER INCOME AND EXPENSES
Interest expense	(6,018		)	(6,194		)	176			-2.8	%
Interest income	419			202			217			107.4	%
Other	219			(170		)	389			-228.8	%
Total other income and expenses	(5,380		)	(6,162		)	782			-12.7	%
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAX EXPENSE	31,100			26,258			4,842			18.4	%
Income tax expense	12,436			10,641			1,795			16.9	%
INCOME FROM CONTINUING OPERATIONS	18,664			15,617			3,047			19.5	%
LOSS FROM DISCONTINUED OPERATIONS, NET OF TAX	—			(18		)	18			-100.0	%
NET INCOME	$	18,664		$	15,599		$	3,065		19.6	%
Basic earnings from continuing operations	$	0.97		$	0.83		$	0.14		16.9	%
Basic earnings from discontinued operations	—			—			—			—
	$	0.97		$	0.83		$	0.14		16.9	%
Diluted earnings from continuing operations	$	0.97		$	0.83		$	0.14		16.9	%
Diluted earnings from discontinued operations	—			—			—			—
	$	0.97		$	0.83		$	0.14		16.9	%

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Operating Revenues

General

Registrant relies upon rate approvals by the CPUC to recover operating expenses and to provide for a return on invested and borrowed capital used to fund utility plant for GSWC. ASUS files price redeterminations and equitable adjustments with the U.S. government in order to recover operating expenses and provide profit margin for contracted services.  If adequate rate relief and price redeterminations and adjustments are not granted in a timely manner, operating revenues and earnings can be negatively impacted.  ASUS’s earnings can also be positively impacted by additional construction projects at each of the Military Utility Privatization Subsidiaries.

Water

For the three months ended September 30, 2012, revenues from water operations increased to $90.6 million, as compared to $89.6 million for the three months ended September 30, 2011.  The increase in water revenues is primarily due to CPUC-approved third year rate increases for Regions II and III effective January 1, 2012 to recover infrastructure improvements and operating costs.

GSWC’s revenue requirement and volumetric revenues are adopted as part of a general rate case (“GRC”) every three years. GSWC filed a GRC for all three water regions in July of 2011 with rates expected to be effective January 2013.  As further discussed in the Regulatory Matters section, in June 2012, GSWC filed a motion to adopt a settlement agreement resolving most issues between GSWC, the CPUC’s Division of Ratepayer Advocates and The Utility Reform Network in connection with this GRC.  The CPUC has not yet acted on this motion.

GSWC’s billed customer water usage increased by approximately 2.8% as compared to the third quarter of 2011 but was lower than adopted consumption.  Changes in consumption do not have a significant impact on earnings due to the CPUC-approved Water Revenue Adjustment Mechanism (“WRAM”) account in all three water regions. GSWC records the difference between what it bills its water customers and that which is authorized by the CPUC in the WRAM accounts.

Electric

For the three months ended September 30, 2012, revenues from electric operations decreased slightly to $8.5 million compared to $8.7 million for the same period in 2011 due to a decrease in electric usage and a decrease in electric supply costs of $138,000 during the three months ended September 30, 2012, which resulted in a corresponding decrease in electric revenues.

Billed electric usage decreased by 2.3% during the three months ended September 30, 2012 as compared to the three months ended September 30, 2011.  Due to the CPUC-approved Base Revenue Requirement Adjustment Mechanism, which adjusts certain revenues to adopted levels authorized by the CPUC, changes in usage did not have a significant impact on earnings.

Contracted Services

Revenues from contracted services are composed of construction revenues (including renewals and replacements) and management fees for operating and maintaining the water and/or wastewater systems at military bases.  For the three months ended September 30, 2012, revenues from contracted services increased by $13.0 million, or 61%, to $34.4 million as compared to $21.4 million for the three months ended September 30, 2011. This is due primarily to an increase in construction activities related to various projects at all military bases, particularly at Fort Bragg in North Carolina, where a major water and wastewater pipeline replacement project is underway.  This project is estimated to be substantially completed by the end of 2013.

Contracted services continues to receive U.S. government awarded contract modifications and agreements with third-party prime contractors for new construction projects at the Military Utility Privatization Subsidiaries. The majority of new construction activity is expected to be performed during the next twelve months.  Earnings and cash flows from amendments and modifications to the original 50-year contracts with the U.S. government and agreements with third-party prime contractors for additional construction projects may or may not continue in future periods.

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Operating Expenses:

Supply Costs

Supply costs for the water segment consist of purchased water, purchased power for pumping, groundwater production assessments and water supply cost balancing accounts. Supply costs for the electric segment consist of purchased power for resale (including the cost of natural gas used by BVES’s generating unit) and the electric supply cost balancing account. Water and electric gross margins are computed by taking total revenues, less total supply costs. Registrant uses these gross margins and related percentages as important measures in evaluating its operating results. Registrant believes these measures are useful internal benchmarks in evaluating the utility business performance within its water and electric segments. Registrant reviews these measurements regularly and compares them to historical periods and to its operating budget. However, these measures, which are not presented in accordance with Generally Accepted Accounting Principles (“GAAP”), may not be comparable to similarly titled measures used by other entities and should not be considered as alternatives to operating income, which is determined in accordance with GAAP.

Total supply costs comprise the largest segment of total operating expenses. Supply costs accounted for 31.6% and 35.7% of total operating expenses for the three months ended September 30, 2012 and 2011, respectively.

The table below provides the amount of increases (decreases), percent changes in supply costs, and gross margins during the three months ended September 30, 2012 and 2011 (dollars in thousands):

	3 Months			3 Months
	Ended			Ended			$			%
	9/30/2012			9/30/2011			CHANGE			CHANGE
WATER OPERATING REVENUES (1)	$	90,604		$	89,570		$	1,034		1.2	%
WATER SUPPLY COSTS:
Water purchased (1)	$	18,874		$	16,094		$	2,780		17.3	%
Power purchased for pumping (1)	3,067			3,141			(74		)	-2.4	%
Groundwater production assessment (1)	3,923			3,795			128			3.4	%
Water supply cost balancing accounts (1)	1,364			4,500			(3,136		)	-69.7	%
TOTAL WATER SUPPLY COSTS	$	27,228		$	27,530		$	(302	)	-1.1	%
WATER MARGIN (2)	$	63,376		$	62,040		$	1,336		2.2	%
PERCENT MARGIN - WATER	69.9		%	69.3		%
ELECTRIC OPERATING REVENUES (1)	$	8,549		$	8,744		$	(195	)	-2.2	%
ELECTRIC SUPPLY COSTS:
Power purchased for resale (1)	$	2,854		$	3,038		$	(184	)	-6.1	%
Electric supply cost balancing accounts (1)	596			550			46			8.4	%
TOTAL ELECTRIC SUPPLY COSTS	$	3,450		$	3,588		$	(138	)	-3.8	%
ELECTRIC MARGIN (2)	$	5,099		$	5,156		$	(57	)	-1.1	%
PERCENT MARGIN - ELECTRIC	59.6		%	59.0		%

(1)	As reported on AWR’s Consolidated Statements of Income, except for supply cost balancing accounts. The sum of water and electric supply cost balancing accounts in the table above are shown on AWR’s Consolidated Statements of Income and totaled $1,960,000 and $5,050,000 for the three months ended September 30, 2012 and 2011, respectively.
(2)	Water and electric margins do not include any depreciation and amortization, maintenance, administrative and general, property and other taxes, or other operation expenses.

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Two of the principal factors affecting water supply costs are the amount of water produced and the source of the water. Generally, the variable cost of producing water from wells is less than the cost of water purchased from wholesale suppliers. Under the modified cost balancing account (“MCBA”), GSWC tracks adopted and actual expense levels for purchased water, purchased power and pump taxes, as established by the CPUC. GSWC records the variances (which include the effects of changes in both rate and volume) between adopted and actual purchased water, purchased power, and pump tax expenses. GSWC recovers from or refunds to customers the amount of such variances.  GSWC tracks these variances individually for each water ratemaking area.

For the three months ended September 30, 2012, 39.2% of GSWC’s water supply mix was purchased as compared to 36.8% purchased for the three months ended September 30, 2011.  However, as noted above, the implementation of the MCBA for GSWC’s water regions eliminates the effects of changes in the water supply mix on earnings. The overall adopted percentages of purchased water for the three months ended September 30, 2012 was approximately 43.8% as compared to the overall actual purchased water of 39.2% as stated above.  The overall water margin percent was 69.9% in the third quarter of 2012 as compared to 69.3% in the same period of 2011.

Purchased water costs for the three months ended September 30, 2012 increased to $18.9 million as compared to $16.1 million in the same period of 2011. This increase was primarily due to higher water rates charged by wholesale suppliers and an increase in the amount of water purchased in all regions due to an increase in customers’ water consumption.

For the three months ended September 30, 2012, power purchased for pumping was consistent with the amount incurred for the third quarter of 2011.  Although there was an increase in electric power used as compared to the third quarter of 2011, these increases were offset by a decrease in rates charged by power suppliers.

For the three months ended September 30, 2012, groundwater production assessments increased by $128,000 due to an increase in pump tax rates levied against groundwater production effective July 2012.

A decrease of $3.1 million in the water supply cost balancing account provision during the three months ended September 30, 2012 as compared to the same period in 2011 was primarily due to an increase in the actual purchased water supply mix, causing a decrease in the MCBA account as compared to the third quarter of 2011.  In addition, certain surcharges related to supply cost balancing accounts in effect during the three months ended September 30, 2011, expired in early 2012.

For the three months ended September 30, 2012, the cost of power purchased for resale to customers in GSWC’s BVES division decreased slightly to $2.9 million compared to $3.0 million for the same period in 2011. In addition to lower customer usage, for the three months ended September 30, 2012, BVES purchased seasonal energy in the spot market at an average price of $39.29 per megawatt hour (“MWh”), as compared to an average price of $44.56 in the spot market for the same period of 2011. BVES also purchases power at $67.90 per MWh under an existing purchased power contract. The difference between the price of purchased power and $77 per MWh as authorized by the CPUC is reflected in the electric supply cost balancing account.

Other Operation Expenses

The primary components of other operation expenses for GSWC include payroll, materials and supplies, chemicals and water treatment costs, and outside service costs for operating the regulated water systems, including the costs associated with water transmission and distribution, pumping, water quality, meter reading, billing, and operation of district offices.  Registrant’s electric and contracted services operations incur many of the same types of costs as well.  For the three months ended September 30, 2012 and 2011, other operation expenses by segment consisted of the following (dollars in thousands):

	3 Months		3 Months
	Ended		Ended		$			%
	9/30/2012		9/30/2011		CHANGE			CHANGE
Water Services	$	6,244	$	6,379	$	(135	)	-2.1	%
Electric Services	615		554		61			11.0	%
Contracted Services	535		465		70			15.1	%
Total other operation expenses	$	7,394	$	7,398	$	(4	)	-0.1	%

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For the three months ended September 30, 2012, other operation expenses for water services decreased by $135,000 primarily due to a $117,000 decrease in costs related to conservation programs, a $235,000 decrease in water treatment costs, and a $21,000 decrease in miscellaneous other operation expenses.  These decreases were partially offset by an increase in bad debt expense of $150,000 and increases in labor and other employee related benefits of $88,000.

The increase in other operation expenses during the three months ended September 30, 2012 for electric services was primarily due to an increase in outside service costs as compared to the same period in 2011.

Other operation expenses for contracted services increased by $70,000 primarily due to an increase in labor costs partially offset by lower water treatment costs incurred at Fort Bragg in North Carolina.

Administrative and General Expenses

Administrative and general expenses include payroll related to administrative and general functions, the related employee benefits charged to expense accounts, insurance expenses, outside legal and consulting fees, regulatory utility commission expenses, expenses associated with being a public company, and general corporate expenses. For the three months ended September 30, 2012 and 2011, administrative and general expenses by segment, including AWR (parent), consisted of the following (dollars in thousands):

	3 Months		3 Months
	Ended		Ended		$			%
	9/30/2012		9/30/2011		CHANGE			CHANGE
Water Services	$	12,741	$	13,393	$	(652	)	-4.9	%
Electric Services	1,880		2,004		(124		)	-6.2	%
Contracted Services	2,715		2,620		95			3.6	%
AWR (parent)	26		5		21			420.0	%
Total administrative and general expenses	$	17,362	$	18,022	$	(660	)	-3.7	%

For the three months ended September 30, 2012, administrative and general expenses decreased by $652,000 in water services compared to the three months ended September 30, 2011 due to decreases in legal and outside service costs of $252,000, data transmission line costs of $152,000, labor costs and other employee related benefits of $133,000, and other miscellaneous administrative and general expenses of $115,000.

For the three months ended September 30, 2012, administrative and general expenses for electric services decreased by $124,000 due to lower legal and outside service costs of $311,000 as compared to the same period in 2011.  This decrease was partially offset by an increase in labor and other employee related benefits of $154,000 and an increase of $33,000 in other miscellaneous administrative and general expenses.

For the three months ended September 30, 2012, administrative and general expenses for contracted services increased by $95,000 due primarily to an increase in outside services, primarily at Fort Bliss in Texas.

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Depreciation and Amortization

For the three months ended September 30, 2012 and 2011 depreciation and amortization expense by segment consisted of the following (dollars in thousands):

	3 Months		3 Months
	Ended		Ended		$		%
	9/30/2012		9/30/2011		CHANGE		CHANGE
Water Services	$	9,405	$	8,832	$	573	6.5	%
Electric Services	536		502		34		6.8	%
Contracted Services	289		220		69		31.4	%
Total depreciation and amortization	$	10,230	$	9,554	$	676	7.1	%

For the three months ended September 30, 2012, depreciation and amortization expense for water and electric services increased by $607,000 to $9.9 million compared to $9.3 million for the same period in 2011 due primarily to approximately $93.1 million of additions to utility plant during 2011.  Registrant believes that depreciation expense related to property additions approved by the CPUC will be recovered through rates.

Maintenance

For the three months ended September 30, 2012 and 2011, maintenance expense by segment consisted of the following (dollars in thousands):

	3 Months		3 Months
	Ended		Ended		$			%
	9/30/2012		9/30/2011		CHANGE			CHANGE
Water Services	$	3,590	$	3,530	$	60		1.7	%
Electric Services	211		235		(24		)	-10.2	%
Contracted Services	431		581		(150		)	-25.8	%
Total maintenance	$	4,232	$	4,346	$	(114	)	-2.6	%

Maintenance expense for contracted services decreased by $150,000 due primarily to the need to perform capital work to renew and replace infrastructure in lieu of routine maintenance service. Such activity is reflected under construction expense.

Property and Other Taxes

For the three months ended September 30, 2012 and 2011, property and other taxes by segment consisted of the following (dollars in thousands):

	3 Months		3 Months
	Ended		Ended		$			%
	9/30/2012		9/30/2011		CHANGE			CHANGE
Water Services	$	3,108	$	3,153	$	(45	)	-1.4	%
Electric Services	249		213		36			16.9	%
Contracted Services	521		316		205			64.9	%
Total property and other taxes	$	3,878	$	3,682	$	196		5.3	%

Property and other taxes overall for contracted services increased by $205,000 for the three months ended September 30, 2012 due to an increase in payroll taxes.

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ASUS Construction Expenses

For the three months ended September 30, 2012, construction expenses for contracted services were $23.3 million, increasing $10.2 million compared to the same period in 2011, due primarily to additional construction activity at all military bases, particularly at Fort Bragg in North Carolina and the military bases in Virginia.

Interest Expense

For the three months ended September 30, 2012 and 2011, interest expense by segment, including AWR (parent) consisted of the following (dollars in thousands):

	3 Months		3 Months
	Ended		Ended			$			%
	9/30/2012		9/30/2011			CHANGE			CHANGE
Water Services	$	5,548	$	5,737		$	(189	)	-3.3	%
Electric Services	411		401			10			2.5	%
Contracted Services	56		85			(29		)	-34.1	%
AWR (parent)	3		(29		)	32			-110.3	%
Total interest expense	$	6,018	$	6,194		$	(176	)	-2.8	%

Overall, interest expense decreased by $176,000 during the third quarter of 2012 as compared to the same period in 2011 due, in part, to a decrease in short term borrowings under the Registrant’s revolving credit facility. There were no borrowings under the facility during the three months ended September 30, 2012.  The average bank loan balance outstanding under the facility was $9.5 million during the same period of 2011. The average interest rate on short-term borrowings for the three months ended September 30, 2011 was approximately 1.5%.

Interest Income

For the three months ended September 30, 2012 and 2011, interest income by segment, including AWR (parent) consisted of the following (dollars in thousands):

	3 Months		3 Months
	Ended		Ended		$			%
	9/30/2012		9/30/2011		CHANGE			CHANGE
Water Services	$	370	$	149	$	221		148.3	%
Electric Services	14		—		14			100	%
Contracted Services	32		1		31			3100.0	%
AWR (parent)	3		52		(49		)	-94.2	%
Total interest income	$	419	$	202	$	217		107.4	%

Interest income increased by $221,000 for water services during the three months ended September 30, 2012 primarily as a result of changes in the settlement of refund claims currently under review by the Internal Revenue Service. In addition, there was an increase in interest income related to regulatory assets as compared to the same period in 2011.

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Income Tax Expense

For the three months ended September 30, 2012 and 2011, income tax expense by segment, including AWR (parent), consisted of the following (dollars in thousands):

	3 Months			3 Months
	Ended			Ended			$			%
	9/30/2012			9/30/2011			CHANGE			CHANGE
Water Services	$	9,795		$	8,825		$	970		11.0	%
Electric Services	235			387			(152		)	-39.3	%
Contracted Services	2,493			1,508			985			65.3	%
AWR (parent)	(87		)	(79		)	(8		)	10.1	%
Total income tax expense	$	12,436		$	10,641		$	1,795		16.9	%

For the three months ended September 30, 2012, income tax expense for water and electric services increased to $10.0 million compared to $9.2 million for the three months ended September 30, 2011 due primarily to an increase in pretax income, partially offset by a decrease in the effective tax rate.  The effective income tax rate (“ETR”) for GSWC was 40.8% for the three months ended September 30, 2012 as compared to 41.4% applicable to the three months ended September 30, 2011. The ETR deviates from the federal statutory rate primarily due to state taxes and differences between book and taxable income that are treated as flow-through adjustments in accordance with regulatory requirements (principally plant-, rate-case- and compensation-related items), and changes in permanent items.  Flow-through adjustments increase or decrease tax expense in one period, with an offsetting decrease or increase occurring in another period.

For the three months ended September 30, 2012, income tax expense for contracted services increased to $2.5 million as compared to $1.5 million for the three months ended September 30, 2011 due to an increase in pretax income.  The ETR was 38.2% for the three months ended September 30, 2012 and 2011.

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Consolidated Results of Operations — Nine months ended September 30, 2012 and 2011 (dollars in thousands except per share amounts):

	9 Months			9 Months
	Ended			Ended			$			%
	9/30/2012			9/30/2011			CHANGE			CHANGE
OPERATING REVENUES
Water	$	237,447		$	234,047		$	3,400		1.5	%
Electric	27,735			27,178			557			2.0	%
Contracted services	89,298			62,620			26,678			42.6	%
Total operating revenues	354,480			323,845			30,635			9.5	%
OPERATING EXPENSES
Water purchased	42,257			37,679			4,578			12.2	%
Power purchased for pumping	6,642			6,842			(200		)	-2.9	%
Groundwater production assessment	11,228			10,307			921			8.9	%
Power purchased for resale	8,725			9,767			(1,042		)	-10.7	%
Supply cost balancing accounts	9,560			14,374			(4,814		)	-33.5	%
Other operation expenses	21,671			21,261			410			1.9	%
Administrative and general expenses	51,739			54,181			(2,442		)	-4.5	%
Depreciation and amortization	31,127			28,829			2,298			8.0	%
Maintenance	11,415			12,695			(1,280		)	-10.1	%
Property and other taxes	11,699			10,640			1,059			10.0	%
ASUS construction expenses	58,513			37,844			20,669			54.6	%
Gain on sale of property	(68		)	(128		)	60			-46.9	%
Total operating expenses	264,508			244,291			20,217			8.3	%
OPERATING INCOME	89,972			79,554			10,418			13.1	%
OTHER INCOME AND EXPENSES
Interest expense	(17,808		)	(18,807		)	999			-5.3	%
Interest income	1,129			500			629			125.8	%
Other	435			(379		)	814			-214.8	%
Total other income and expenses	(16,244		)	(18,686		)	2,442			-13.1	%
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAX EXPENSE	73,728			60,868			12,860			21.1	%
Income tax expense	29,871			25,568			4,303			16.8	%
INCOME FROM CONTINUING OPERATIONS	43,857			35,300			8,557			24.2	%
INCOME FROM DISCONTINUED OPERATIONS, NET OF TAX	—			3,850			(3,850		)	-100.0	%
NET INCOME	$	43,857		$	39,150		$	4,707		12.0	%
Basic earnings from continuing operations	$	2.30		$	1.88		$	0.42		22.3	%
Basic earnings from discontinued operations	—			0.20			(0.20		)	-100.0	%
	$	2.30		$	2.08		$	0.22		10.6	%
Diluted earnings from continuing operations	$	2.30		$	1.88		$	0.42		22.3	%
Diluted earnings from discontinued operations	—			0.20			(0.20		)	-100.0	%
	$	2.30		$	2.08		$	0.22		10.6	%

40

Operating Revenues

General

Registrant relies upon rate approvals by the CPUC to provide for a return on invested and borrowed capital used to fund utility plant, and price redeterminations and equitable adjustments by the U.S. government in order to recover operating expenses and profit margin. If adequate rate relief and price redeterminations and adjustments are not granted in a timely manner, operating revenues and earnings can be negatively impacted.  ASUS’ earnings can also be positively impacted by additional construction projects at the Military Utility Privatization Subsidiaries.

Water

For the nine months ended September 30, 2012, revenues from water operations increased by $3.4 million to $237.4 million as compared to $234.0 million for the nine months ended September 30, 2011.  The increase in water revenues is primarily due to CPUC-approved third year rate increases for Regions II and III effective January 1, 2012 to recover infrastructure improvements and operating costs.

GSWC’s revenue requirement and volumetric revenues are adopted as part of a general rate case (“GRC”) every three years. GSWC filed a GRC for all three water regions in July of 2011 with rates expected to be effective January 2013.  As further discussed in the Regulatory Matters section, in June 2012, GSWC filed a motion to adopt a settlement agreement resolving most issues between GSWC, the CPUC’s Division of Ratepayer Advocates and The Utility Reform Network in connection with this GRC. The CPUC has not yet acted on this motion.

GSWC’s billed customer water usage increased by approximately 4.5% as compared to the same period in 2011, but was lower than adopted consumption.  Changes in consumption do not have a significant impact on earnings due to the CPUC-approved Water Revenue Adjustment Mechanism (“WRAM”) account in all three water regions. GSWC records the difference between what it bills its water customers and that which is authorized by the CPUC in the WRAM accounts.

Electric

For the nine months ended September 30, 2012, revenues from electric operations increased by 2.0% to $27.7 million compared to $27.2 million for the same period in 2011 due primarily to increases in electric base rates approved by the CPUC effective January 1, 2012.

Billed electric usage for the nine months ended September 30, 2012 decreased 3.1% as compared to the same period in 2011.  Due to the CPUC approved Base Revenue Requirement Adjustment Mechanism, which adjusts certain revenues to adopted levels authorized by the CPUC, this change in usage did not have a significant impact on earnings.

Contracted Services

Revenues from contracted services are composed of construction revenues (including renewals and replacements) and management fees for operating and maintaining the water and/or wastewater systems at military bases.  For the nine months ended September 30, 2012, revenues from contracted services increased by $26.7 million, or 42.6%, to $89.3 million as compared to $62.6 million for the nine months ended September 30, 2011 primarily due to an increase in construction activities particularly at Fort Bragg in North Carolina, Andrews Air Force Base in Maryland and the military bases in Virginia.  At Fort Bragg, there is a major water and wastewater pipeline replacement project estimated to be substantially completed by the end of 2013.  The increase in construction activities was partially offset by a $2.9 million increase in revenues recorded during the second quarter of 2011 due to a change in estimated costs related to the pipeline project at Fort Bragg. Contracted services continues to receive contract modifications from the U.S. government and agreements with third-party prime contractors for new construction projects at the Military Utility Privatization Subsidiaries. The majority of new construction activity is expected to be performed during the next twelve months.  Earnings and cash flows from amendments and modifications to the original 50-year contracts with the U.S. government and agreements with third-party prime contractors for additional construction projects may or may not continue in future periods.

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Operating Expenses:

Supply Costs

Supply costs accounted for approximately 29.6% and 32.3% of total operating expenses for the nine months ended September 30, 2012 and 2011, respectively.

The table below provides the amount of increases (decreases), percent changes in supply costs, and gross margins during the nine months ended September 30, 2012 and 2011 (dollars in thousands):

	9 Months			9 Months
	Ended			Ended			$			%
	9/30/2012			9/30/2011			CHANGE			CHANGE
WATER OPERATING REVENUES (1)	$	237,447		$	234,047		$	3,400		1.5	%
WATER SUPPLY COSTS:
Water purchased (1)	$	42,257		$	37,679		$	4,578		12.2	%
Power purchased for pumping (1)	6,642			6,842			(200		)	-2.9	%
Groundwater production assessment (1)	11,228			10,307			921			8.9	%
Water supply cost balancing accounts (1)	6,969			12,323			(5,354		)	-43.4	%
TOTAL WATER SUPPLY COSTS	$	67,096		$	67,151		$	(55	)	-0.1	%
WATER MARGIN (2)	$	170,351		$	166,896		$	3,455		2.1	%
PERCENT MARGIN - WATER	71.7		%	71.3		%
ELECTRIC OPERATING REVENUES (1)	$	27,735		$	27,178		$	557		2.0	%
ELECTRIC SUPPLY COSTS:
Power purchased for resale (1)	$	8,725		$	9,767		$	(1,042	)	-10.7	%
Electric supply cost balancing accounts (1)	2,591			2,051			540			26.3	%
TOTAL ELECTRIC SUPPLY COSTS	$	11,316		$	11,818		$	(502	)	-4.2	%
ELECTRIC MARGIN (2)	$	16,419		$	15,360		$	1,059		6.9	%
PERCENT MARGIN - ELECTRIC	59.2		%	56.5		%

(1)           As reported on AWR’s Consolidated Statements of Income, except for supply cost balancing accounts. The sum of water and electric supply cost balancing accounts in the table above are shown on AWR’s Consolidated Statements of Income and totaled $9,560,000 and $14,374,000 for the nine months ended September 30, 2012 and 2011, respectively.

(2)           Water and electric margins do not include any depreciation and amortization, maintenance, administrative and general, property and other taxes, or other operation expenses.

For the nine months ended September 30, 2012, 35.5% of GSWC’s water supply mix was purchased as compared to 35.2% purchased for the nine months ended September 30, 2011.  However, GSWC implemented the MCBA for all its water regions which eliminates the effects of changes in the water supply mix on earnings.  The overall adopted percentages of purchased water for the nine months ended September 30, 2012 was approximately 42.1% as compared to overall actual purchased water of 35.5%.  The difference in actual mix compared to the mix approved by the CPUC resulted in an over-collection in the MCBA account. The overall water margin percent was 71.7% for the nine months ended September 30, 2012 as compared to 71.3% in the same period of 2011.

Purchased water costs for the nine months ended September 30, 2012 increased to $42.3 million as compared to $37.7 million in the same period of 2011 primarily due to higher water rates charged by wholesale suppliers and an overall increase in the amount of water purchased as a result of an increase in customers’ water consumption.

For the nine months ended September 30, 2012, power purchased for pumping decreased slightly to $6.6 million as compared to $6.8 million for the same period of 2011.  This was primarily due to lower electric supply rates and improved energy efficiency at GSWC’s pumping facilities.

42

For the nine months ended September 30, 2012, groundwater production assessments were $921,000 higher when compared to the same period in 2011 due to additional assessment rates levied.  Due to the MCBA account, these additional assessments do not impact the dollar water margin. The MCBA tracks the increases in pump tax rates for future recovery in water rates.

A decrease of $5.4 million in the water supply cost balancing account provision during the nine months ended September 30, 2012 as compared to the same period in 2011 was primarily due to a decrease in the over-collection in the MCBA account from higher water supply rates and an overall increase in customer demand.

For the nine months ended September 30, 2012, the cost of power purchased for resale to customers in GSWC’s BVES division decreased 10.7% to $8.7 million as compared $9.8 million for the same period of 2011 due primarily to lower energy prices purchased in the spot market in 2012 as compared to the same period of 2011. The difference between the price of purchased power and $77 per MWh as authorized by the CPUC is reflected in the electric supply cost balancing account.

Other Operation Expenses

The primary components of other operation expenses include payroll, materials and supplies, chemicals and water treatment, and outside service costs of operating the continuing regulated water systems, including the costs associated with water transmission and distribution, pumping, water quality, meter reading, billing, and operation of district offices.  Registrant’s electric and contracted services operations incur many of the same types of costs as well.  For the nine months ended September 30, 2012 and 2011, other operation expenses by segment consisted of the following (dollars in thousands):

	9 Months		9 Months
	Ended		Ended		$			%
	9/30/2012		9/30/2011		CHANGE			CHANGE
Water Services	$	17,932	$	16,850	$	1,082		6.4	%
Electric Services	1,778		1,659		119			7.2	%
Contracted Services	1,961		2,752		(791		)	-28.7	%
Total other operation expenses	$	21,671	$	21,261	$	410		1.9	%

For the nine months ended September 30, 2012, other operation expenses for water services increased by $1.1 million as compared to the same period in 2011 primarily due to: (i) an increase of $270,000 in costs related to conservation programs previously approved by the CPUC and included in rates; (ii) an increase of $576,000 in bad debt expense; (iii) a $400,000 increase in labor and related benefits costs; and (iv) an $87,000 increase in other miscellaneous operation expenses.  These increases were partially offset by a $251,000 decrease in water treatment expenses.

For the nine months ended September 30, 2012, other operation expenses for electric services increased by $119,000 primarily due to an increase in labor and related benefit costs.

For the nine months ended September 30, 2012, other operation expenses for contracted services decreased by $791,000 as compared to the same period in 2011, due largely to a decrease in precontract costs for design and engineering labor incurred for potential new construction projects primarily at Fort Bragg in North Carolina and Fort Bliss in Texas.

Administrative and General Expenses

Administrative and general expenses include payroll related to administrative and general functions, all employee benefits charged to expense accounts, insurance expenses, outside legal and consulting fees, regulatory utility commission expenses, expenses associated with being a public company, and general corporate expenses. For the nine months ended September 30, 2012 and 2011, administrative and general expenses by segment, including AWR (parent), consisted of the following (dollars in thousands):

43

	9 Months		9 Months
	Ended		Ended		$			%
	9/30/2012		9/30/2011		CHANGE			CHANGE
Water Services	$	38,772	$	39,452	$	(680	)	-1.7	%
Electric Services	4,700		6,066		(1,366		)	-22.5	%
Contracted Services	8,146		8,605		(459		)	-5.3	%
AWR (parent)	121		58		63			108.6	%
Total administrative and general expenses	$	51,739	$	54,181	$	(2,442	)	-4.5	%

For the nine months ended September 30, 2012, administrative and general expenses for water services decreased by $680,000 due primarily to a decrease in legal and other outside consulting costs.  These costs tend to fluctuate year-to-year and are expected to continue to fluctuate.

For the nine months ended September 30, 2012, administrative and general expenses for electric services decreased by $1.4 million compared to the nine months ended September 30, 2011 primarily due to the CPUC’s approval in March 2012 for BVES to recover $1.2 million of previously incurred legal and outside service costs in connection with its efforts to procure renewable energy resources.  As a result, in March 2012 BVES recorded a $1.2 million reduction in legal and outside service costs, which had previously been expensed as incurred.

Administrative and general expenses for contracted services decreased by $459,000 due primarily to an increase in the allocation of overhead expenses to construction costs as compared to the same period in 2011 as a result of increased construction activities primarily at Fort Bragg in North Carolina, Andrews Air Force Base in Maryland and the military bases in Virginia, partially offset by an increase in labor and related benefit costs and outside service costs.

Depreciation and Amortization

For the nine months ended September 30, 2012 and 2011, depreciation and amortization by segment consisted of the following (dollars in thousands):

	9 Months		9 Months
	Ended		Ended		$		%
	9/30/2012		9/30/2011		CHANGE		CHANGE
Water Services	$	28,527	$	26,662	$	1,865	7.0	%
Electric Services	1,756		1,509		247		16.4	%
Contracted Services	844		658		186		28.3	%
Total depreciation and amortization	$	31,127	$	28,829	$	2,298	8.0	%

For the nine months ended September 30, 2012, depreciation and amortization expense for water and electric services increased by $2.1 million to $30.3 million compared to $28.2 million for the nine months ended September 30, 2011 primarily due to approximately $93.1 million of additions to utility plant during 2011.  Registrant believes that depreciation expense related to property additions approved by the CPUC will be recovered through rates.

There was also an increase in depreciation and amortization expense for contracted services due to the addition of fixed assets.

44

Maintenance

For the nine months ended September 30, 2012 and 2011, maintenance expense by segment consisted of the following (dollars in thousands):

	9 Months		9 Months
	Ended		Ended		$			%
	9/30/2012		9/30/2011		CHANGE			CHANGE
Water Services	$	9,567	$	10,087	$	(520	)	-5.2	%
Electric Services	531		669		(138		)	-20.6	%
Contracted Services	1,317		1,939		(622		)	-32.1	%
Total maintenance	$	11,415	$	12,695	$	(1,280	)	-10.1	%

For the nine months ended September 30, 2012, maintenance expense for water services decreased $520,000 to $9.6 million compared to $10.1 million for the nine months ended September 30, 2011 primarily due to a decrease in both planned and unplanned maintenance at GSWC’s water facilities in Region II and Region III.

For the nine months ended September 30, 2012, maintenance expense for electric services decreased by $138,000 due primarily to a decrease in tree trimming maintenance as compared to the same period in 2011.

For the nine months ended September 30, 2012, maintenance expense for contracted services decreased by $622,000 due primarily to the need to perform capital work to renew and replace infrastructure in lieu of routine maintenance service. Such activity is reflected under construction expense.

Property and Other Taxes

For the nine months ended September 30, 2012 and 2011, property and other taxes by segment consisted of the following (dollars in thousands):

	9 Months		9 Months
	Ended		Ended		$		%
	9/30/2012		9/30/2011		CHANGE		CHANGE
Water Services	$	9,745	$	9,010	$	735	8.2	%
Electric Services	709		628		81		12.9	%
Contracted Services	1,245		1,002		243		24.3	%
Total property and other taxes	$	11,699	$	10,640	$	1,059	10.0	%

For the nine months ended September 30, 2012, property and other taxes for water services increased by $735,000 primarily due to increases in franchise fees and property taxes.

For the nine months ended September 30, 2012, property and other taxes for contracted services increased by $243,000 primarily due to an increase in payroll taxes.

ASUS Construction Expenses

For the nine months ended September 30, 2012, construction expenses for contracted services were $58.5 million, increasing by $20.7 million compared to the same period in 2011, due primarily to increased construction activity particularly at Fort Bragg, Andrews Air Force and the military bases in Virginia.

45

Interest Expense

For the nine months ended September 30, 2012 and 2011, interest expense by segment, including AWR (parent) consisted of the following (dollars in thousands):

	9 Months		9 Months
	Ended		Ended		$			%
	9/30/2012		9/30/2011		CHANGE			CHANGE
Water Services	$	16,425	$	17,219	$	(794	)	-4.6	%
Electric Services	1,223		1,217		6			0.5	%
Contracted Services	155		312		(157		)	-50.3	%
AWR (parent)	5		59		(54		)	-91.5	%
Total interest expense	$	17,808	$	18,807	$	(999	)	-5.3	%

Overall, interest expense decreased by $999,000 due primarily to costs totaling $553,000 incurred during the nine months ended September 30, 2011 related to the redemption of $22.0 million of GSWC’s 7.65% Medium-Term Notes. No such costs were incurred during 2012.  Also, in 2012 GSWC recorded a $381,000 reduction to interest expense in connection with the CPUC’s final decision on the water cost of capital proceeding. The decision ordered GSWC to refund $408,000 to customers, as compared to the $789,000 GSWC had estimated in its interest rate balancing account.  Finally, there was also a decrease in borrowings under Registrant’s revolving credit facility as compared to the same period in 2011. These decreases were partially offset by additional interest expense related to $62.0 million of 6% senior notes issued in April 2011. Average bank loan balances outstanding under Registrant’s revolving credit facility for the nine months ended September 30, 2012 were approximately $1.2 million, as compared to an average of $33.4 million during the same period of 2011. The average interest rates on short-term borrowings for the nine months ended September 30, 2012 and 2011 were approximately 1.5%.

Interest Income

For the nine months ended September 30, 2012 and 2011, interest income by segment, including AWR (parent) consisted of the following (dollars in thousands):

	9 Months		9 Months
	Ended		Ended		$			%
	9/30/2012		9/30/2011		CHANGE			CHANGE
Water Services	$	1,026	$	439	$	587		133.7	%
Electric Services	37		—		37			100.0	%
Contracted Services	37		3		34			1133.3	%
AWR (parent)	29		58		(29		)	-50.0	%
Total interest income	$	1,129	$	500	$	629		125.8	%

Interest income increased by $629,000 for the nine months ended September 30, 2012 primarily as a result of changes in the settlement of refund claims currently under review by the Internal Revenue Service. In addition, there was an increase in interest income related to regulatory assets as compared to the same period in 2011.

Other Income and Expenses

For the nine months ended September 30, 2012, Registrant recorded a gain of $435,000 on one of GSWC’s investments.  For the nine months ended September 30, 2011, Registrant recorded other expenses of $379,000 primarily related to a loss incurred on the same GSWC investment.

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Income Tax Expense

For the nine months ended September 30, 2012 and 2011, income tax expense by segment, including AWR (parent), consisted of the following (dollars in thousands):

	9 Months			9 Months
	Ended			Ended			$			%
	9/30/2012			9/30/2011			CHANGE			CHANGE
Water Services	$	21,358		$	20,566		$	792		3.9	%
Electric Services	1,994			1,436			558			38.9	%
Contracted Services	6,635			3,674			2,961			80.6	%
AWR (parent)	(116		)	(108		)	(8		)	7.4	%
Total income tax expense	$	29,871		$	25,568		$	4,303		16.8	%

For the nine months ended September 30, 2012, income tax expense for water and electric services increased to $23.4 million compared to $22.0 million for the nine months ended September 30, 2011 due primarily to an increase in pretax income, partially offset by a decrease in the effective tax rate.  The effective income tax rate (“ETR”) for GSWC for the nine months ended September 30, 2012 was 41.2% as compared to a 42.9% ETR applicable to the nine months ended September 30, 2011.  The ETR deviates from the federal statutory rate primarily due to state taxes and changes between book and taxable income that are treated as flow-through adjustments in accordance with regulatory requirements (principally plant-, rate-case- and compensation-related items), and changes in permanent items.  Flow-through adjustments increase or decrease tax expense in one period, with an offsetting decrease or increase occurring in another period.

Income tax expense for contracted services increased $2.9 million to $6.6 million compared to $3.7 million for the nine months ended September 30, 2011 due primarily to an increase in pretax income.  The ETR for contracted services for the nine months ended September 30, 2012 was 38.7% as compared to 38.6% for the same period in 2011.

Income from Discontinued Operations

Net income from discontinued operations for the nine months ended September 30, 2011 was $3.9 million, due primarily to the gain on sale of CCWC of $2.2 million, net of taxes and transaction costs, or $0.12 per share.  Excluding the gain on sale, there was also net income of $1.6 million from CCWC’s operations from the five months of operations in 2011 until the completion of the sale on May 31, 2011.

Critical Accounting Policies and Estimates

Critical accounting policies and estimates are those that are important to the portrayal of Registrant’s financial condition, results of operations and cash flows, and require the most difficult, subjective or complex judgments of Registrant’s management. The need to make estimates about the effect of items that are uncertain is what makes these judgments difficult, subjective and/or complex. Management makes subjective judgments about the accounting and regulatory treatment of many items. These judgments are based on Registrant’s historical experience, terms of existing contracts, Registrant’s observance of trends in the industry, and information available from other outside sources, as appropriate. Actual results may differ from these estimates under different assumptions or conditions.

The critical accounting policies used in the preparation of the Registrant’s financial statements that it believes affect the more significant judgments and estimates used in the preparation of its consolidated financial statements presented in this report are described in “Management’s Discussion and Analysis of Financial Condition and Results of Operation” included in Registrant’s Annual Report on Form 10-K for the year ended December 31, 2011. There have been no material changes to Registrant’s critical accounting policies.

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Liquidity and Capital Resources

AWR

Registrant’s regulated business is capital intensive and requires considerable capital resources. A portion of these capital resources are provided by internally generated cash flows from operations. When necessary, Registrant obtains funds from external sources in the capital markets and through bank borrowings. Access to external financing on reasonable terms depends on the credit ratings of AWR and GSWC and current business conditions, including that of the water utility industry in general as well as conditions in the debt or equity capital markets. Registrant also has access to a revolving credit facility that may be utilized to support operations.  Under the Third Amendment to the Amended and Restated Credit Agreement, which expires on May 27, 2013, the maximum amount that may be borrowed under this facility is $100.0 million.  AWR may, under the terms of the Amended and Restated Credit Agreement, elect to increase the aggregate bank commitments by up to $40.0 million.  The aggregate effective amount that may be outstanding under letters of credit is $25.0 million. As of September 30, 2012, there were no borrowings under this facility and $18.2 million of letters of credit were outstanding.  As of September 30, 2012, AWR had $81.8 million available to borrow under the credit facility.

In July 2012, Standard & Poor’s Ratings Services (“S&P”) affirmed the ‘A+’ corporate credit rating on AWR and GSWC with a stable outlook.  S&P debt ratings range from AAA (highest rating possible) to D (obligation is in default).  Securities ratings are not recommendations to buy, sell or hold a security and are subject to change or withdrawal at any time by the rating agency.  Pursuant to the revolving credit facility agreement, the “A+ stable” credit rating results in an interest rate spread on the facility of 120 basis points. Registrant believes that AWR’s sound capital structure and “A+ stable” credit rating, combined with its financial discipline, will enable AWR to access the debt and/or equity markets.  However, unpredictable financial market conditions in the future may limit its access or impact the timing of when to access the market, in which case, Registrant may choose to temporarily reduce its capital spending.  Registrant estimates capital expenditures for 2012 to be approximately $70 - $75 million.

AWR filed a Registration Statement in August 2012 with the Securities and Exchange Commission for the sale from time to time of debt and equity securities. As of September 30, 2012, $115.0 million was available for issuance under this Registration Statement. The Registration Statement expires in August 2015.

AWR funds its operating expenses and pays dividends on its outstanding common shares primarily through dividends from its subsidiaries and through proceeds from equity issuances not invested in subsidiaries.  The ability of GSWC and ASUS to pay dividends to AWR is restricted by California law. Under these restrictions, GSWC and ASUS had approximately $178.9 million and $13.0 million, respectively, available on September 30, 2012 to pay dividends to AWR.

Registrant has paid common dividends for over 75 consecutive years.  On October 30, 2012, AWR declared a regular quarterly dividend of $0.355 per Common Share. The dividend, totaling approximately $6.8 million, will be paid on or about December 1, 2012 to common shareholders of record at the close of business on November 12, 2012.  AWR’s ability to pay cash dividends on its Common Shares outstanding depends primarily upon cash flows from its subsidiaries. AWR presently intends to continue paying quarterly cash dividends in the future, on or about March 1, June 1, September 1 and December 1, subject to earnings and financial condition, regulatory requirements and such other factors as the Board of Directors may deem relevant.

AWR anticipates that interest costs will increase in future periods due to the need for additional external capital to fund its construction program. AWR believes that costs associated with capital used to fund construction projects at GSWC will continue to be recovered in water and electric rates charged to customers.

Cash Flows from Operating Activities:

Cash flows from operating activities have generally been sufficient to meet operating requirements and a portion of capital expenditure requirements. Registrant’s future cash flows from operating activities will be affected by a number of factors, including utility regulation; infrastructure investment; maintenance expenses; inflation; compliance with environmental, health and safety standards; production costs; customer growth; per customer usage of water and electricity; weather and seasonality; compliance with local governmental requirements and required cash contributions to pension and post-retirement plans.  In addition, future cash flows from non-regulated subsidiaries will depend on new business activities, including military base operations and the construction of new and/or replacement infrastructure at military bases, timely redetermination of prices and equitable adjustments of prices and timely collection of payments from the U.S. government.

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Cash flows from operating activities are primarily generated by net income, adjusted for non-cash expenses such as depreciation and amortization, and deferred income taxes.  Net cash provided by operating activities was $91.6 million for the nine months ended September 30, 2012 as compared to $62.6 million for the nine months ended September 30, 2011.  There has been an increase in cash flows from operations due to lower tax payments resulting from accelerated depreciation taken in 2011 and 2012 in connection with tax law changes. There was also an increase in cash flows from operating activities at ASUS due primarily to higher construction activity at Fort Bragg and the timely collection of amounts billed for construction work.  There was also an increase in GSWC’s operating cash flows due to rate increases approved by the CPUC, including surcharges to recover previously recorded regulatory assets. GSWC currently has surcharges in place to recover approximately $24.9 million included in its WRAM, net of MCBA accounts, as of September 30, 2012.  The timing of cash receipts and disbursements related to other working capital items also affected the changes in net cash provided by operating activities.

Cash Flows from Investing Activities:

Net cash used in investing activities was $48.1 million for the nine months ended September 30, 2012 as compared to $34.0 million for the same period in 2011. Cash flows from investing activities for the nine months ended September 30, 2011 included $29.6 million in cash received in connection with the sale of CCWC.

Registrant intends to invest in capital to provide essential services to its regulated customer base, while working with its regulators to have the opportunity to earn a fair rate of return on investment. Registrant’s infrastructure investment plan consists of both infrastructure renewal programs, where infrastructure is replaced, as needed, and major capital investment projects, where new water treatment and delivery facilities are constructed.  GSWC may also be required from time to time to relocate existing infrastructure in order to accommodate local infrastructure improvement projects.  Projected capital expenditures and other investments are subject to periodic review and revision to reflect changes in economic conditions and other factors.

Cash Flows from Financing Activities:

Registrant’s financing activities include primarily: (i) the issuance of common shares, and short-term and long-term debt; (ii) the repayment of long-term debt and notes payable to banks; (iii) proceeds from stock option exercises; and (iv) the payment of dividends on common shares.  In order to finance new infrastructure, Registrant also receives customer advances for and contributions in aid of construction (net of refunds).  Short-term borrowings are used to fund capital expenditures until long-term financing is arranged.

Net cash used in financing activities was $1.7 million for the nine months ended September 30, 2012 as compared to $27.6 million for the same period in 2011.  In 2011, Registrant used a portion of the cash proceeds from the sale of CCWC and cash proceeds from the issuance of new debt to pay down short-term borrowings and redeem certain long-term debt with higher rates. For the nine months ended September 30, 2012, Registrant paid $17.3 million in shareholder dividends, which was largely offset by cash proceeds from the Company’s stock incentive plan and from receipt of advances and contributions in aid of construction.  Because of the increase in cash generated from operations, Registrant did not have any short-term bank borrowings and was able to substantially increase its ending cash balance.

GSWC

GSWC funds the majority of its operating expenses, payments on its debt, and dividends on its outstanding common shares and a portion of its construction expenditures through internal sources. Internal sources of cash flow are provided primarily by retention of a portion of earnings from operating activities. Internal cash generation is influenced by factors such as weather patterns, environmental regulation, litigation, changes in supply costs and regulatory decisions affecting GSWC’s ability to recover these supply costs, timing of rate relief, increases in maintenance expenses and capital expenditures.  As of September 30, 2012, GSWC had $100.0 million available for issuance of debt securities under a Registration Statement filed with the Securities and Exchange Commission in November 2011.  During the nine months ended September 30, 2012, GSWC was able to fund its operations and its capital expenditures through cash generated from operating activities.

GSWC relies on external sources, including equity investments and short-term borrowings from AWR, and long-term debt from time to time to help fund a portion of its construction expenditures.  In addition, GSWC receives advances and contributions from customers, home builders and real estate developers to fund construction necessary to extend service to new areas. Advances for construction are generally refundable at a rate of 2.5% in equal annual installments over 40 years.  Amounts which are no longer refundable are reclassified to contributions in aid of construction. Utility plant funded by advances and contributions is excluded from rate base.

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Generally, GSWC depreciates contributed property and amortizes contributions in aid of construction at the composite rate of the related property.

As is often the case with public utilities, GSWC’s current liabilities may at times exceed its current assets.  Management believes that internally-generated funds along with the short-term borrowings under AWR’s existing credit facility and the proceeds from the issuance of long-term debt and common shares issuances to AWR will be adequate to provide sufficient working capital to enable GSWC to maintain normal operations and to meet its capital and financing requirements pending recovery of costs in rates.

Cash Flows from Operating Activities:

Net cash provided by operating activities was $77.7 million for the nine months ended September 30, 2012 as compared to $59.0 million for the same period in 2011.  As previously discussed, this increase was due primarily to higher rates in effect, surcharges in place to collect the WRAM under-collections in all of GSWC’s water regions, and lower tax payments resulting from accelerated depreciation taken in 2011 and 2012 in connection with tax law changes.  GSWC currently has surcharges in place to recover approximately $24.9 million included in its WRAM, net of MCBA, accounts as of September 30, 2012.  The timing of cash receipts and disbursements related to other working capital items also affected the changes in net cash provided by operating activities.

Cash Flows from Investing Activities:

Net cash used in investing activities was $47.2 million for the nine months ended September 30, 2012 as compared to $61.9 million for the same period in 2011, which is consistent with GSWC’s 2012 capital investment program. GSWC is expected to incur capital expenditures in 2012 of approximately $70 - $75 million primarily for upgrades to its water supply and distribution facilities.

Cash Flows from Financing Activities:

Net cash used in financing activities was $5.0 million for the nine months ended September 30, 2012 as compared to cash provided by financing activities of $3.5 million for the same period in 2011.  As a result of the increase in cash generated from operations, GSWC did not have any intercompany borrowings, was able to pay dividends to AWR and substantially increase its ending cash balance.

ASUS

ASUS funds its operating expenses primarily through internal operating sources and investments by, or loans from, AWR. ASUS, in turn, provides funding to its subsidiaries.

Contractual Obligations and Other Commitments

Registrant has various contractual obligations which are recorded as liabilities in the consolidated financial statements. Other items, such as certain purchase commitments and operating leases are not recognized as liabilities in the consolidated financial statements, but are required to be disclosed. In addition to contractual maturities, Registrant has certain debt instruments that contain annual sinking fund or other principal payments. Registrant believes that it will be able to refinance debt instruments at their maturity through public issuance, or private placement, of debt or equity. Annual principal and interest payments are generally made from cash flow from operations.

In October 2009, GSWC entered into an agreement with the California Department of Public Health (“CDPH”) whereby CDPH agreed to loan GSWC up to $9.0 million under the American Recovery and Reinvestment Act (“ARRA”).  Proceeds of the loan were used to reimburse GSWC for the costs of installing 6,228 water meters.  Pursuant to the agreement, as reimbursements were filed, GSWC issued letters of credit to CDPH equal to 80% of the amount loaned to GSWC (up to an aggregate of $7.2 million).  During 2012, GSWC received a total of $6.8 million in reimbursements from the CDPH, a portion of which was recorded as contributions and the remainder of which was recorded as long term debt. As of September 30, 2012, GSWC has issued a total of $7.2 million in letters of credit to CDPH.

There have been no other material changes to AWR’s contractual obligations and other commitments since December 31, 2011. See “Management’s Discussion and Analysis of Financial Condition and Results of Operation—Contractual Obligations, Commitments and Off Balance Sheet Arrangements” section of the Registrant’s Form 10-K for the year-ended December 31, 2011 for a detailed discussion of contractual obligations and other commitments.

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Contracted Services

The timely receipt of price redeterminations continues to be critical in order for ASUS to recover increasing costs of operating and maintaining, and renewing and replacing the water and/or wastewater systems at the military bases.  In addition, higher expenses from the corporate office and ASUS headquarters allocated to the Military Utility Privatization Subsidiaries were not contemplated at the time the contracts with the U.S. government were negotiated and are being addressed in current outstanding and future price redeterminations. Under the terms of these contracts, each contract price is subject to price redetermination two years after commencement of operations and every three years thereafter, unless otherwise agreed to by the parties.  In the event that ASUS is: (i) managing more assets at specific military bases than were included in the U.S. government’s request for proposal; (ii) managing assets that are in substandard condition as compared to what is disclosed in the request for proposal; or (iii) becomes subject to new regulatory requirements such as more stringent water quality standards, ASUS is permitted to file, and has filed, requests for equitable adjustment.

The timing of future filings of price redeterminations may be impacted by government actions, including audits by the Defense Contract Audit Agency (“DCAA”).  At times, our filing of price redetermination and requests for equitable adjustment may be postponed pending the outcomes of these audits.

Below is a summary of price redetermination and requests for equitable adjustment filings by subsidiaries of ASUS.

·FBWS — In connection with the inventory settlement with the U.S. government reached in January 2010, FBWS and the government agreed to waive the first and second price redeterminations for Fort Bliss required under the original 50-year contract. The third price redetermination, for the three-year period beginning October 1, 2012, was filed on July 16, 2012. The U.S. government has agreed in principle with FBWS’s revised proposal submission, which among other things provides for an annual increase of approximately $450,000 to the operations and maintenance fee compared to the amounts currently in effect.  Issuance of the contract modification is pending funding by the U.S. government.

·TUS —The first price redetermination for Andrews Air Force Base was filed in December 2007.  The U.S. government has agreed in principle with TUS’ settlement position for this redetermination, which would provide an increase of 7% to the operations and maintenance fee and an increase of 15% to the renewal and replacement fee compared to the interim adjustment in effect since August 2010 (and retroactive to February 2008).  Final modification for funding is pending government approval.

·ODUS — The second price redetermination for the Fort Lee privatization contract in Virginia, for the three-year period beginning February 2011, was filed in May 2012 and the second price redetermination for the other bases that ODUS operates in Virginia, for the three-year period beginning April 2011, was filed on July 30, 2012.  ODUS is awaiting commencement of negotiations on these filings.

·PSUS — In February 2012, PSUS filed the first price redetermination for Fort Jackson, to be effective beginning February 16, 2010.  Pending resolution of this filing, an interim increase of 3.4%, retroactive to February 2010, is currently in effect. PSUS is awaiting commencement of negotiations on these filings.

·ONUS - In March 2012, ONUS received a contract modification regarding installation of new water meters at Fort Bragg.  The contract modification provided for a reduction in the number of water meters to be installed, and the price associated with this revised scope. This $11.0 million project commenced during the second quarter and is being performed in conjunction with a backflow preventor installation project.  The two projects total $23 million in contract value and are expected to be completed by the end of 2013. In April 2012, ONUS received a contract modification affirming that ONUS will be able to retain the full amount of the cost savings from the use of an alternative pipe replacement technology. This modification and revision in cost estimates resulted in additional pretax operating income of $820,000. In September 2012, ONUS received a $17.6 million contract modification for construction of Patriot Point- Phase 1.  This project includes construction of all water and sewer infrastructure required to provide such services to a new area of Fort Bragg.  Construction is scheduled to start in the fourth quarter of 2012 with substantial completion expected by the first quarter of 2014. In December 2011, ONUS filed the first price redetermination for Fort Bragg, to be effective beginning March 1, 2010. Pending resolution of this filing, an interim increase of 3.6%, retroactive to March 2010, is currently in effect. Negotiations on this filing, including a DCAA audit on certain aspects of the filing, are underway with the government.

Price redeterminations and equitable adjustments, which include adjustments to reflect changes in operating conditions and infrastructure levels from that assumed at the time of the execution of the contracts, as well as inflation in costs, are expected to provide added revenues to help offset increased costs and provide Registrant the opportunity to continue to generate positive operating income at its Military Utility Privatization Subsidiaries.

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Regulatory Matters

Recent Changes in Rates

Rate changes in 2012:

In July 2012, the CPUC issued a final decision on GSWC’s cost of capital proceeding filed in May 2011. The decision approves the settlement agreement entered into between GSWC, along with three other California water utilities, and the CPUC’s Division of Ratepayer Advocates (“DRA”) in November 2011. The approved settlement authorizes a Return on Equity (“ROE”) of 9.99% and a rate-making capital structure for GSWC of 55% equity and 45% debt. The weighted cost of capital (return on rate base), with an updated embedded debt cost and the settlement ROE, is 8.64%. The new rate of return authorized by the CPUC’s final decision was implemented into water rates retroactive to January 1, 2012.

The CPUC decision also authorized GSWC to continue the Water Cost of Capital Mechanism (“WCCM”).  The WCCM adjusts ROE and rate of return on rate base between the three-year cost of capital proceedings only if there is a positive or negative change of more than 100 basis points in the average of the Moody’s Aa utility bond rate as measured over the period October 1 through September 30.  If the average Moody’s rate for this period changes by over 100 basis points from the benchmark, the ROE will be adjusted by one half of the difference. For the period October 1, 2011 through September 30, 2012, the Moody’s rate declined by 112 basis points from the benchmark. As a result, in October 2012, GSWC filed an advice letter to lower its water ROE by 56 basis points, from 9.99% to 9.43%, which will be incorporated in the new 2013 water rates.

In January 2012, GSWC implemented the rates previously approved by the CPUC in its last general rate case. The authorized rate increases represent increases of approximately $2.0 million for Region II and $3.0 million for Region III over 2011 adopted revenues. The rate increases for Region I are not material.

In January 2012, BVES implemented the rates previously approved by the CPUC in its last general rate case. The authorized rate increase is expected to provide GSWC with additional annual revenues of approximately $681,000, which includes BVES’ portion of the general office allocation.

Rate changes in 2011:

In January 2011, GSWC implemented the rates previously approved by the CPUC in its last general rate case.  The authorized rate increases represented increases of approximately $1.6 million for Region II, and approximately $2.4 million for Region III as compared to 2010 adopted revenues. These additional revenues were based upon normalized sales levels approved by the CPUC, effective January 1, 2011.

In January 2011, BVES implemented the rates previously approved by the CPUC in its last general rate case.  The authorized rate increase provided BVES with additional annual revenues of approximately $209,000.  In addition, the CPUC authorized rate increases to cover higher general office costs allocated to BVES.  This added additional revenues to BVES of $1.4 million in 2011 as compared to 2010.

In December 2010, the CPUC issued a final decision on GSWC’s Region I rate case, approving revenue increases for 2011 and 2012. On a year to year basis, the increase in 2011 revenues represented an increase of approximately $3.6 million over 2010 adopted revenues. The CPUC also authorized approximately $18.5 million of capital projects to be filed for revenue recovery with advice letters when those projects are completed. During the time that such projects are under development and construction, GSWC may accrue an allowance for funds used during construction on the accrued expenditures to offset the cost of financing project construction. A portion of these projects was completed in 2011. The remaining projects are expected to be completed during 2012 and 2013.

Pending General Rate Case Requests

GSWC

On June 21, 2012, GSWC filed a motion to adopt a settlement agreement between GSWC, the DRA, and The Utility Reform Network (“TURN”) in connection with the water General Rate Case (“GRC”) filing made in July 2011.  The proposed settlement, if approved by the CPUC, resolves almost all of the issues in the GRC application and would generate approximately $9.9 million in additional annual revenues starting in 2013 as compared to 2012 adopted revenues. The proposed rate increases for 2014 over 2013 are $8.1 million or 3%, and the 2015 proposed rate increases over 2014 amount to $7.2 million, or 2%, subject to an earnings test and fluctuations in market indices.  While the increase in 2013 revenues would be $9.9 million pursuant to the settlement agreement, the increase in the adopted water gross margin is approximately $13.4 million, or 6.2%, when compared to the 2012 adopted water gross margin. 

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In addition, the CPUC requested GSWC, DRA, and TURN to file additional testimony to justify the reasonableness of the Water Revenue Adjustment Mechanism (“WRAM”) and address the CPUC’s questions regarding the WRAM. In July 2012, all three parties filed additional testimony addressing the WRAM.  The settlement agreement for the GRC is subject to an acceptable resolution regarding the WRAM matter. Hearings on the WRAM were held in October 2012.

In February 2012, GSWC filed its BVES rate case for rates in years 2013 through 2016. If rates are approved as filed, the rate increases are expected to generate approximately $1.3 million in annual revenues starting in 2013. The proposed rate increases for 2014 over 2013 are $1.9 million, the 2015 proposed rate increases over 2014 amount to $1.3 million, and the 2016 proposed rate increases over 2015 amount to $1.3 million.

CPUC Pending Rehearing Matter

In July 2011, the CPUC issued an order granting DRA’s request to rehear certain issues from the Region II, Region III and general office rate case approved in November 2010.  Among the issues in the rehearing are the La Serena plant improvement project included in rate base totaling approximately $3.5 million, and GSWC’s methodology for deferring rate case costs.  Hearings and final resolution of these matters are expected in 2013. The regulatory issues associated with these two matters are further discussed below.

La Serena Plant Improvement Project:

In November 2010, as part of GSWC’s Region II, Region III and general office rate case decision, the CPUC disallowed a portion of the La Serena plant improvement project costs from utility customer rates.  As a result of the CPUC’s decision in 2010, GSWC recorded a charge of $2.2 million, which included the disallowance of these capital costs and the related revenues earned on those capital costs that will be refunded to customers.

In December 2010, DRA filed a motion for rehearing on this matter, contending that the CPUC erred in assigning a portion of the La Serena plant improvement costs to GSWC utility customers and requested that all of the capital costs related to the La Serena plant improvement project be disallowed. In July 2011, the CPUC granted DRA’s request for rehearing.  Hearings on these matters are expected in the fourth quarter of 2012. A proposed decision is expected in June 2013. In addition to granting a rehearing, the CPUC also directed the Division of Water and Audits (“DWA”) to undertake an audit of the La Serena project costs and to provide a confidential report to the CPUC with recommendations on whether an investigation should be conducted to determine whether any laws were broken related to the La Serena project.  Management does not believe it has violated any laws in regards to the La Serena project.  DWA issued its independent audit report, which found cost overruns for the La Serena plant improvement project to be lower than the amount of costs for rate recovery previously disallowed by the CPUC.

In October 2012, DRA issued a report on this matter recommending further disallowances of costs and refund of revenues earned on those costs. DRA’s recommendation is inconsistent with the independent audit report issued by DWA. In addition, GSWC believes DRA’s recommendations are without merit and inconsistent with previous CPUC decisions on this matter.  However, if DRA prevails, GSWC may be required to write-off additional capital costs and provide refunds to customers of the revenues earned on those costs.  Based on DRA’s recommendation, additional disallowed costs and revenues earned on those costs through September 30, 2012 totaled approximately $2.5 million. GSWC intends to vigorously defend its position.  However, at this time, management cannot predict the outcome of the rehearing, DWA’s and DRA’s recommendations, or determine the estimated additional loss or range of loss, if any.

Deferred rate case costs:

The rehearing granted by the CPUC in July of 2011 is also re-addressing deferred rate case costs, which are direct costs consisting primarily of outside consulting and legal services which have been incurred in connection with the preparation and processing of a general rate case. Historically, GSWC has deferred these costs as a regulatory asset which are then recovered in rates and amortized over the term of a rate case cycle once the new rates go into effect.  In the rehearing proceeding, DRA is again challenging GSWC’s historical practice of deferring these costs with subsequent recovery upon the effective date of the new rates. Instead, DRA believes that rate case costs should be projected for future periods and recovered prospectively.  Management believes that DRA’s rationale and recommendations are inconsistent with previous CPUC decisions on this matter and also with GSWC’s historical practice of deferring and recovering rate case expenses associated with the current general rate case.  However, if DRA prevails, GSWC may be required to write-off deferred rate case costs related to its current pending rate case, which total approximately $1.9 million as of September 30, 2012.  At this time, GSWC is unable to predict the outcome of this matter.

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Other Regulatory Matters

See “Management’s Discussion and Analysis of Financial Condition and Results of Operation—Regulatory Matters” section of the Registrant’s Form 10-K for the year-ended December 31, 2011 for a detailed discussion of other regulatory matters.

Finance Application

In July 2012, GSWC filed with the CPUC an application requesting authorization for it to issue, sell and deliver, by public offering or private placement, securities not exceeding $225.0 million in aggregate offering amount, consisting of, but not limited to, common shares and preferred shares, bonds, debentures, medium-term notes, loans and tax exempt debt. GSWC expects to use the net proceeds from the issuance of securities to first pay down all or a portion of its then outstanding short-term debt and fund its construction expenditures.  GSWC expects the CPUC will approve this application in 2012 or early 2013.

Alternative Revenue Mechanisms:

GSWC records the difference between what it bills its water customers and that which is authorized by the CPUC using the WRAM. GSWC also records the difference between adopted and actual expense levels for purchased water, purchased power and pump taxes, as established by the CPUC, using the Modified Cost Balancing Account (“MCBA”).  GSWC has implemented surcharges to recover its WRAM balances, net of the MCBA. For the three and nine months ended September 30, 2012, surcharges of $6.7 million and $14.3 million, respectively, were billed to customers to decrease previously incurred under-collections in the WRAM, net of MCBA accounts.  As of September 30, 2012, GSWC has a net aggregated regulatory asset of $43.6 million which is comprised of a $64.2 million under-collection in the WRAM accounts and $20.6 million over-collection in the MCBA accounts.

Based on CPUC guidelines, recovery periods relating to GSWC’s WRAM/MCBA balances range between 12 and 36 months, with the majority being 24 months.  As required by the accounting guidance for alternative revenue programs, GSWC is required to collect its WRAM, net of its MCBA, within 24 months following the year in which they are recorded.  In September 2010, GSWC, along with other California water utilities, filed an application with the CPUC to modify the recovery period of its WRAM and MCBA to 18 months or less.  In April 2012, the CPUC issued a final decision which, among other things, sets the recovery period for under-collection balances that are up to 15% of adopted annual revenues at 18 months or less.  For under-collection balances greater than 15%, the recovery period is 19 to 36 months. GSWC does not currently have any balances over 15% of adopted annual revenues. In addition to adopting a new amortization schedule, the final decision sets a cap on total net WRAM/MCBA surcharges in any given calendar year of 10% of the last authorized revenue requirement. The cap becomes effective following the first test year of each applicant’s pending or next general rate case.  For GSWC, the cap will be applied to its 2013 WRAM balances filed in early 2014.  The cap requirement set forth in the final decision will not impact GSWC’s 2012 and prior year WRAM/MCBA balances. Surcharges are currently in place to recover the WRAM/MCBA balances from 2009, 2010 and 2011.

In June 2012, the CPUC approved surcharges for recovery of BVES’ 2011 Base Revenue Requirement Adjustment Mechanism (“BRRAM”) balance. The CPUC approved a 36-month surcharge, with the amounts collected through December 2013 to be applied to the 2011 BRRAM under-collection.  Surcharges collected during the remainder of the 36-month period would be for recovery of a $1.6 million increase in the BVES revenue requirement representing the difference between the allocated general office costs authorized by the CPUC in its November 2010 decision on the Region II, Region III and general office rate case, and what is currently in BVES’ rates for allocated general office costs.  As authorized by the CPUC, the $1.6 million was included in the BRRAM for recovery through the surcharge; however, these costs are not considered an alternative revenue program.

Bear Valley Electric Service:

In February 2012, GSWC filed its BVES general rate case for rates in years 2013 through 2016.  In August 2012, DRA issued its report on the GRC.  Included in DRA’s recommendations is a $2.0 million retroactive ratemaking proposal to increase BVES’ accumulated depreciation balance to reflect adopted depreciation expense for the years 2009 through 2012 rather than actual depreciation expense as recorded in compliance with Generally Accepted Accounting Principles.  DRA also recommends that one-half of deferred rate case costs be borne by shareholders, rather than entirely by customers as has been authorized by the CPUC in prior rate cases.  As of September 30, 2012, GSWC has a $2.2 million regulatory asset representing deferred rate case costs for the current BVES general rate case. Hearings on the GRC, including these matters, were held in September 2012.  If DRA prevails, GSWC may be required to record a charge to adjust accumulated depreciation and to write-off half of its deferred rate case costs. GSWC believes DRA’s recommendations are without merit and intends to vigorously defend its positions. 

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However, at this time, GSWC is unable to predict the final outcome of these matters which are expected to be resolved in the pending rate case.

In January 2010, the City of Big Bear and surrounding areas of San Bernardino County experienced a series of snow storms, which damaged BVES power lines, poles, transformers, and other facilities and caused temporary interruption of service to some BVES customers.  As a result of these storms, BVES incurred additional operating costs to repair equipment and restore electric service to its customers, which were tracked in a catastrophic event memorandum account (“CEMA”).  In June 2011, GSWC filed for recovery of the CEMA account related to the storm damage and also for the remaining unrecovered balance for costs incurred from 2003 through 2005 related to a bark beetle infestation in its BVES service area.  In June 2012, the CPUC approved a 12-month surcharge to recover $796,000 recorded in BVES’s CEMA accounts.

GSWC’s BVES division has been regularly filing compliance reports with the CPUC regarding its purchases of energy from renewable energy resources to meet California’s renewables portfolio standard (“RPS”).  Previous filings under prior RPS laws had indicated that BVES had not achieved annual target purchase levels of renewable energy resources and thus, on its face, might be subject to a potential penalty.  However, a new RPS law went into effect in December 2011 which changed, among other things, the prior RPS requirement based upon annual procurement targets to multi-year procurement targets.  Under the new RPS law, BVES must procure sufficient RPS-eligible resources to meet: (i) any RPS procurement requirement deficit for any year prior to 2011, and; (ii) RPS procurement requirements for the 2011 — 2013 compliance period by no later than December 31, 2013.  BVES’ first RPS reports under the new law were submitted to the CPUC in March 2012 and August 2012 and did not reflect any RPS procurement deficiencies nor any potential or actual penalties.  Accordingly, no provision for loss has been recorded in the financial statements as of September 30, 2012.

In June 2011, BVES filed an application with the CPUC to recover $1.2 million in outside service costs incurred during the period September 1, 2007 through March 31, 2011 in connection with its efforts to procure renewable energy resources.  In March 2012, the CPUC approved the application.  Accordingly, a regulatory asset of $1.3 million, including accrued interest, was recorded in March 2012.  A 12-month surcharge was implemented in May 2012 for recovery of these costs.

In September 2009, GSWC negotiated a ten-year contract with the Los Angeles County Sanitation District (“LACSD”) to purchase renewable energy created from landfill gas. In February 2011, LACSD notified GSWC that it intended to shut down the landfill gas generator. In August 2011, GSWC and LACSD negotiated a settlement to resolve a dispute between the parties regarding certain terms of the contract.  Under the terms of the settlement, GSWC agreed to waive its right to a 14 month termination notice and LACSD agreed to sell renewable energy credits (“RECs”) to GSWC.

In November 2011, GSWC filed for CPUC approval for the purchase of these RECs. In July 2012, the CPUC approved the purchase of these RECs, which BVES intends to apply towards either its pre-2011 renewable energy requirements or its 2011-2013 requirements.  The REC’s were purchased for approximately $325,000 during the third quarter of 2012 as an asset and will be included as part of the supply cost balancing account when the RECs are applied towards the RPS requirements.

Changes in Tax Law:

The Small Business Jobs Act of 2010 and the Tax Relief, Unemployment Insurance Reauthorization and Job Creation Act of 2010 (“Tax Relief Acts”) extended 50% bonus depreciation for qualifying property through 2012 and created a 100% bonus depreciation for qualifying property placed in service between September 9, 2010 and December 31, 2011.

In June 2011, the CPUC adopted a resolution that requires water utilities to file advice letters implementing a one-way memorandum account to track the revenue effects associated with the Tax Relief Acts, which may reduce revenue requirements in future rate case proceedings.  The effective date of the memorandum account established by the resolution was April 14, 2011.  More specifically, the memorandum account established by the resolution will track on a CPUC-jurisdictional, revenue requirement basis: (a) decreases in each impacted utility’s revenue requirement resulting from increases in its deferred tax reserve; and (b) other direct changes in the revenue requirement resulting from taking advantage of the Tax Relief Acts. This resolution also authorizes impacted utilities to use savings from this new tax law to invest in certain additional, needed utility infrastructure, not otherwise funded in rates, within a time frame shorter than would be practicable through the formal application or advice letter processes. The establishment of a memorandum account does not change rates, nor guarantee that rates will be changed in the future. This mechanism simply allows the CPUC to determine at a future date whether rates should be changed. 

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GSWC has evaluated the potential impact of this resolution and does not expect it to have a material impact on its consolidated financial statements. However, at this time, GSWC cannot predict the outcome of this resolution or determine its potential impact, if any, on future rates.

CPUC Subpoena:

On December 15, 2011, the CPUC approved a settlement agreement reached between GSWC and DWA to resolve an investigation of certain work orders and charges paid to a specific contractor used previously for numerous construction projects over a period of 14 years. The settlement provides for refunds to customers totaling $9.5 million to be made over a period of 12-36 months, as well as a reduction in rate-base and other rate adjustments totaling $3.0 million. As a result of the settlement, management does not expect future increases in the reserve related to this specific contractor.  Refunds totaling $1.1 million and $2.2 million were made to customers during the three and nine months ended September 30, 2012, respectively.

Finally, as part of the settlement agreement, GSWC agreed to be subject to three separate independent audits of its procurement practices over a period of ten years from the date the settlement was approved by the CPUC.  The audits will cover GSWC’s procurement practices from 1994 forward and could result in further disallowances of costs.  The cost of the audits will be borne by shareholders and may not be recovered by GSWC in rates to customers. At this time, management cannot predict the outcome of these audits or determine the estimated loss or range of loss, if any.

Environmental Matters

AWR’s subsidiaries are subject to increasingly stringent environmental regulations, including the 1996 amendments to the Federal Safe Drinking Water Act; interim enhanced surface water treatment rules; regulation of disinfectant/disinfection by-products; the long-term enhanced surface water treatment rules; the ground water treatment rule; contaminant regulation of radon and arsenic; and unregulated contaminants monitoring rule.

There have been no material changes to AWR’s environmental matters since December 31, 2011. See “Management’s Discussion and Analysis of Financial Condition and Results of Operation-Environmental Matters” section of the Registrant’s Form 10-K for the year-ended December 31, 2011 for a detailed discussion of environmental matters.

Water Supply

See “Management’s Discussion and Analysis of Financial Condition and Results of Operation—Water Supply” section of the Registrant’s Form 10-K for the year-ended December 31, 2011 for a detailed discussion of water supply issues. The discussion below focuses on significant matters and changes since December 31, 2011.

Metropolitan Water District/ State Water Project

Water supplies available to the Metropolitan Water District of Southern California (“MWD”) through the State Water Project (“SWP”) vary from year to year based on weather.  However, MWD has generally been able to provide sufficient quantities of water to satisfy the needs of its member agencies and their customers.  Under its Integrated Resources Plan, MWD estimates that it can meet its member agencies’ demands over at least the next 20 years.

Every year, the California Department of Water Resources (“DWR”) establishes the SWP allocation for water deliveries to the state water contractors.  DWR generally establishes a percentage allocation of delivery requests based on a number of factors, including weather patterns, snow pack levels and reservoir levels.  The percent allocation given to state contractors can vary throughout the year as weather and other factors change. In April 2012, DWR announced an increase in its projected 2012 deliveries from 50% to 60% of delivery requests.

New Accounting Pronouncements

Registrant is subject to newly issued requirements as well as changes in existing requirements issued by the Financial Accounting Standards Board. Differences in financial reporting between periods for GSWC could occur unless and until the CPUC approves such changes for conformity through regulatory proceedings. See Note 1 of Unaudited Notes to Consolidated Financial Statements.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

Registrant is exposed to certain market risks, including fluctuations in interest rates, commodity price risk primarily relating to changes in the market price of electricity for BVES and economic conditions. Market risk is the potential loss arising from adverse changes in prevailing market rates and prices.

There have been no other material changes regarding Registrant’s market risk position from the information provided in its Annual Report on Form 10-K for the year ended December 31, 2011. The quantitative and qualitative disclosures about market risk are discussed in Item 7A-Quantitative and Qualitative Disclosures About Market Risk, contained in Registrant’s Annual Report on Form 10-K.

Item 4. Controls and Procedures

(a) Evaluation of Disclosure Controls and Procedures

As required by Rule 13a-15(b) under the Securities and Exchange Act of 1934 (the “Exchange Act”), Registrant has carried out an evaluation, under the supervision and with the participation of its management, including Registrant’s Chief Executive Officer (“CEO”) and its Chief Financial Officer (“CFO”), of the effectiveness, as of the end of the fiscal quarter covered by this report, of the design and operation of its “disclosure controls and procedures” as defined in Rule 13a-15(e) and 15d-15(e) promulgated by the Securities and Exchange Commission (“SEC”) under the Exchange Act. Based upon that evaluation, the CEO and the CFO concluded that disclosure controls and procedures, as of the end of such fiscal quarter, were adequate and effective to ensure that information required to be disclosed by Registrant in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and that such information is accumulated and communicated to Registrant’s management, including its CEO and CFO, as appropriate to allow timely decisions regarding required disclosure.

(b) Changes in Internal Controls over Financial Reporting

There has been no change in Registrant’s internal control over financial reporting during the quarter ended September 30, 2012, that has materially affected or is reasonably likely to materially affect its internal control over financial reporting.

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PART II

Item 1. Legal Proceedings

There have been no material developments in any of the legal proceedings described in our 2011 Annual Report on Form 10-K.

Registrant is subject to ordinary routine litigation incidental to its business. Other than those disclosed in Registrant’s Form 10-K for the year ended December 31, 2011, no other legal proceedings are pending, which are believed to be material. Management believes that rate recovery, proper insurance coverage and reserves are in place to insure against property, general liability and workers’ compensation claims incurred in the ordinary course of business.

Item 1A. Risk Factors

There have been no significant changes in the risk factors disclosed in our 2011 Annual Report on Form 10-K.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

The shareholders of AWR have approved the material features of all equity compensation plans under which AWR directly issues equity securities. AWR did not directly issue any unregistered equity securities during the third quarter of 2012.  The following table provides information about repurchases of common shares by AWR during the third quarter of 2012:

Period	Total Number of Shares Purchased		Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs (1)	Maximum Number of Shares That May Yet Be Purchased under the Plans or Programs
July 1 - 31, 2012	13,473		$	40.78	—	NA
August 1 - 31, 2012	65,167		$	41.07	—	NA
September 1 - 30, 2012	84,050		$	43.57	—	NA
Total	162,690	(2)	$	42.79	—	NA	(3)

(1)	None of the common shares were purchased pursuant to any publicly announced stock repurchase program.
(2)	Of this amount, 156,400 Common Shares were acquired on the open market for employees pursuant to the Company’s 401(k) Plan. The remainder of the Common Shares were acquired on the open market for participants in the Company’s Common Share Purchase and Dividend Reinvestment Plan.
(3)	None of these plans contain a maximum number of common shares that may be purchased in the open market under the plans.

Item 3. Defaults Upon Senior Securities

None

Item 4. Mine Safety Disclosure

Not applicable.

Item 5. Other Information

(a)	On October 30, 2012, the Board of Directors of AWR declared a regular quarterly dividend of $0.355 per Common Share. The dividend will be paid on or about December 1, 2012 to shareholders of record as of the close of business on November 12, 2012.
(b)	There have been no material changes during the third quarter of 2012 to the procedures by which shareholders may nominate persons to the Board of Directors of AWR.

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Item 6. Exhibits

(a)The following documents are filed as Exhibits to this report:

3.1	By-Laws of American States Water Company incorporated by reference to Exhibit 10.1 of Registrant’s Form 10-Q for the quarter ended June 30, 2012
3.2	By-laws of Golden State Water Company incorporated by reference to Exhibit 3.1 of Registrant’s Form 8-K filed May 13, 2011
3.3	Amended and Restated Articles of Incorporation of American States Water Company incorporated by reference to Exhibit 3.3 of Registrant’s Form 10-K/A for the year ended December 31, 2003
3.4	Restated Articles of Incorporation of Golden State Water Company, as amended, incorporated herein by reference to Exhibit 3.1 of Registrant’s Form 10-Q for the quarter ended September 30, 2005
4.1	Indenture, dated September 1, 1993 between Golden State Water Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee, as supplemented, incorporated herein by reference to Exhibit 4.01 of Golden State Water Company Form S-3 filed December 12, 2008
4.2	Note Purchase Agreement dated as of October 11, 2005 between Golden State Water Company and Co-Bank, ACB incorporated by reference to Exhibit 4.1 of Registrant’s Form 8-K filed October 13, 2005
4.3	Note Purchase Agreement dated as of March 10, 2009 between Golden State Water Company and Co-Bank, ACB, incorporated herein by reference to Exhibit 10.16 to Registrant’s Form 10-K filed on March 13, 2009
4.4	Indenture dated as of December 1, 1998 between American States Water Company and The Bank of New York Mellon Trust Company, N.A., as supplemented by the First Supplemental Indenture dated as of July 31, 2009 incorporated herein by reference to Exhibit 4.1 of American States Water Company’s Form 10-Q for the quarter ended June 30, 2009
10.1	Deferred Compensation Plan for Directors and Executives incorporated herein by reference to Registrant’s Registration Statement on Form S-2, Registration No. 33-5151 (2)
10.2	Second Sublease dated October 5, 1984 between Golden State Water Company and Three Valleys Municipal Water District incorporated herein by reference to Registrant’s Registration Statement on Form S-2, Registration No. 33-5151
10.3	Note Agreement dated as of May 15, 1991 between Golden State Water Company and Transamerica Occidental Life Insurance Company incorporated herein by reference to Registrant’s Form 10-Q with respect to the quarter ended June 30, 1991
10.4	Schedule of omitted Note Agreements, dated May 15, 1991, between Golden State Water Company and Transamerica Annuity Life Insurance Company, and Golden State Water Company and First Colony Life Insurance Company incorporated herein by reference to Registrant’s Form 10-Q with respect to the quarter ended June 30, 1991
10.5	Loan Agreement between California Pollution Control Financing Authority and Golden State Water Company, dated as of December 1, 1996 incorporated by reference to Exhibit 10.7 of Registrant’s Form 10-K for the year ended December 31, 1998
10.6	Agreement for Financing Capital Improvement dated as of June 2, 1992 between Golden State Water Company and Three Valleys Municipal Water District incorporated herein by reference to Registrant’s Form 10-K with respect to the year ended December 31, 1992
10.7	Water Supply Agreement dated as of June 1, 1994 between Golden State Water Company and Central Coast Water Authority incorporated herein by reference to Exhibit 10.15 of Registrant’s Form 10-K with respect to the year ended December 31, 1994
10.8	2003 Non-Employee Directors Stock Purchase Plan, as amended, incorporated herein by reference to Exhibit 10.1 to Registrant’s Form 8-K filed on January 30, 2009 (2)
10.9	Dividend Reinvestment and Common Share Purchase Plan incorporated herein by reference to American States Water Company Registrant’s Form S-3D filed November 12, 2008

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10.10	Form of Amended and Restated Change in Control Agreement between American States Water Company or a subsidiary and certain executives incorporated herein by reference to Exhibit 10.5 to Registrant’s Form 8-K filed on November 5, 2008(2)
10.11	Golden State Water Company Pension Restoration Plan, as amended, incorporated herein by reference to Exhibit 10.1 to the Registrant’s Form 8-K filed on May 21, 2009 (2)
10.12	American States Water Company 2000 Stock Incentive Plan, as amended, incorporated by reference to Exhibit 10.2 of Registrant’s Form 8-K filed May 23, 2008 (2)
10.13	Amended and Restated Credit Agreement between American States Water Company dated June 3, 2005 with Wells Fargo Bank, N.A., as Administrative Agent, as amended, incorporated by reference to Exhibit 10.1 to Registrant’s Form 8-K filed June 10, 2010
10.14	Form of Indemnification Agreement for executive officers and directors incorporated by reference to Exhibit 10.21 to Registrant’s Form 10-K for the year ended December 31, 2006 (2)
10.15	Form of Non-Qualified Stock Option Plan Agreement for officers and key employees for the 2000 Stock Incentive Plan incorporated by reference to Exhibit 10.1 to Registrant’s Form 8-K filed on January 7, 2005 (2)
10.16	Form of Non-Qualified Stock Option Plan Agreement for officers and key employees for the 2000 Stock Incentive Plan incorporated by reference to Exhibit 10.1 of Registrant’s Form 10-Q for the period ended March 31, 2006 (2)
10.17	Form of Director’s Non-Qualified Stock Option Agreement incorporated by reference to Exhibit 10.1 to Registrant’s Form 10-Q for the period ended September 30, 2006 (2)
10.18	Water Sale Agreement dated as of January 31, 2006 between Natomas Central Mutual Water Company and American States Utility Services, Inc. incorporated by reference to Exhibit 9.01 to Registrant’s Form 8-K filed February 3, 2006
10.19	Form of Restricted Stock Unit Award Agreement for officers and key employees under the 2000 Stock Incentive Plan incorporated by reference to Exhibit 10.3 of Registrant’s Form 8-K filed November 5, 2008 (2)
10.20	Form of Restricted Stock Unit Award Agreement for officers and key employees under the 2008 Stock Incentive Plan for restricted stock unit awards prior to January 1, 2011 incorporated by reference to Exhibit 10.4 of Registrant’s Form 8-K filed on November 5, 2008 (2)
10.21	Form of Amendment to Change in Control Agreement between American States Water Company or a subsidiary and certain executives incorporated herein by reference to Exhibit 10.6 to Registrant’s Form 8-K filed November 5, 2008 (2)
10.22	Amended and Restated 2008 Stock Incentive Plan incorporated by reference to Exhibit 10.1 to Registrant’s Form 8-K filed May 24, 2012 (2)
10.23	Form of Nonqualified Stock Option Agreement for officers and key employees for the 2008 Stock Incentive Plan incorporated for stock options granted prior to January 1, 2011 herein by reference to Exhibit 10.3 to Registrant’s Form 8-K filed May 23, 2008 (2)
10.24	2011 Short-Term Incentive Program incorporated herein by reference to Exhibit 10.1 to the Registrant’s Form 8-K filed on April 1, 2011(2)
10.25	Form of Award Agreement for Awards under the 2011 Short-Term Incentive Program incorporated herein by reference to Exhibit 10.2 to the Registrant’s Form 8-K filed on April 1, 2011(2)
10.26	Policy Regarding the Recoupment of Certain Performance-Based Compensation Payments incorporated herein by reference to Exhibit 10.3 to the Registrant’s Form 8-K filed on July 31, 2009(2)
10.27	Performance Incentive Plan incorporated herein by reference to Exhibit 10.4 to the Registrant’s Form 8-K filed on July 31, 2009(2)
10.28	Officer Relocation Policy incorporated herein by reference to Exhibit 10.5 to the Registrant’s Form 8-K filed on July 31, 2009(2)
10.29	Form of Non-Qualified Stock Option Award Agreement for officers and key employees under the 2008 Stock Incentive Plan for stock options granted after December 31, 2010 incorporated by reference to Exhibit 10.2 of Registrant’s Form 8-K filed on February 4, 2011 (2)

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10.30	Form of Restricted Stock Unit Award Agreement for officers and key employees under the 2008 Stock Incentive Plan for restricted stock unit awards after December 31, 2010 incorporated by reference to Exhibit 10.1 to Registrant’s Form 8-K filed on February 4, 2011 (2)
10.31	2012 Short-Term Incentive Program incorporated by reference to Exhibit 10.31 of Form 10-Q for the quarter ended June 30, 2012 (2)
10.32	Form of 2012 Short-Term Incentive Award Agreement incorporated by reference to Exhibit 10.32 of Form 10-Q for the quarter ended June 30, 2012 (2)
10.33	Performance Award Agreement for award of Performance Shares to Robert J. Sprowls incorporated by reference to Exhibit 10.1 of Form 8-K filed on June 4, 2012 (2)
31.1	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 for AWR (1)
31.1.1	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 for GSWC (1)
31.2	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 for AWR (1)
31.2.1	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 for GSWC (1)
32.1	Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (3)
32.2	Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (3)
101.INS	XBRL Instance Document (3)
101.SCH	XBRL Taxonomy Extension Schema (3)
101.CAL	XBRL Taxonomy Extension Calculation Linkbase (3)
101.DEF	XBRL Taxonomy Extension Definition Linkbase (3)
101.LAB	XBRL Taxonomy Extension Label Linkbase (3)
101.PRE	XBRL Taxonomy Extension Presentation Linkbase (3)

(1)	Filed concurrently herewith
(2)	Management contract or compensatory arrangement
(3)	Furnished concurrently herewith

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized and as its principal financial officer.

	AMERICAN STATES WATER COMPANY (“AWR”):
By:	/s/ EVA G. TANG
	Senior Vice President-Finance, Chief Financial
	Officer, Corporate Secretary and Treasurer
	GOLDEN STATE WATER COMPANY (“GSWC”):
By:	/s/ EVA G. TANG
	Senior Vice President-Finance, Chief Financial
	Officer and Secretary
Date:	November 5, 2012

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EX-31.1

Exhibit 31.1

Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 for AWR

I, Robert J. Sprowls, certify that:

1)I have reviewed this quarterly report on Form 10-Q for the period ended September 30, 2012 of American States Water Company (referred to as “the Registrant”);

2)Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3)Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the Registrant as of, and for, the periods presented in this report;

4)The Registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the Registrant and have:

a)designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the Registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)evaluated the effectiveness of the Registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d)disclosed in this report any change in the Registrant’s internal control over financial reporting that occurred during the Registrant’s most recent fiscal quarter (the Registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the Registrant’s internal control over financial reporting.

5)The Registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the Registrant’s auditors and the audit committee of Registrant’s board of directors (or persons performing the equivalent function):

a)all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the Registrant’s ability to record, process, summarize and report financial information; and

b)any fraud, whether or not material, that involves management or other employees who have a significant role in the Registrant’s internal controls over financial reporting.

Dated: November 5, 2012	By:	/s/ ROBERT J. SPROWLS
		Robert J. Sprowls
		President and Chief Executive Officer

EX-31.1.1

Exhibit 31.1.1

Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 for GSWC

I, Robert J. Sprowls, certify that:

1)I have reviewed this quarterly report on Form 10-Q for the period ended September 30, 2012 of Golden State Water Company (referred to as “GSWC”);

2)Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3)Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of GSWC as of, and for, the periods presented in this report;

4)GSWC’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for GSWC and have:

a)designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to GSWC is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)evaluated the effectiveness of GSWC’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d)disclosed in this report any change in GSWC’s internal control over financial reporting that occurred during GSWC’s most recent fiscal quarter (GSWC’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, GSWC’s internal control over financial reporting.

5)GSWC’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the GSWC’s auditors and the audit committee of GSWC’s board of directors (or persons performing the equivalent function):

a)all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the GSWC’s ability to record, process, summarize and report financial information; and

b)any fraud, whether or not material, that involves management or other employees who have a significant role in GSWC’s internal controls over financial reporting.

Dated: November 5, 2012	By:	/s/ ROBERT J. SPROWLS
		Robert J. Sprowls
		President and Chief Executive Officer

EX-31.2

Exhibit 31.2

Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 for AWR

I, Eva G. Tang, certify that:

1)I have reviewed this quarterly report on Form 10-Q for the period ended September 30, 2012 of American States Water Company (referred to as “the Registrant”);

2)Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3)Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the Registrant as of, and for, the periods presented in this report;

4)The Registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the Registrant and have:

a)designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the Registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)evaluated the effectiveness of the Registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d)disclosed in this report any change in the Registrant’s internal control over financial reporting that occurred during the Registrant’s most recent fiscal quarter (the Registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the Registrant’s internal control over financial reporting.

5)The Registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the Registrant’s auditors and the audit committee of Registrant’s board of directors (or persons performing the equivalent function):

a)all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the Registrant’s ability to record, process, summarize and report financial information; and

b)any fraud, whether or not material, that involves management or other employees who have a significant role in the Registrant’s internal controls over financial reporting.

Dated: November 5, 2012	By:	/s/ EVA G. TANG
		Eva G. Tang
		Senior Vice President-Finance, Chief Financial
		Officer, Corporate Secretary and Treasurer

1

EX-31.2.1

Exhibit 31.2.1

Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 for GSWC

I, Eva G. Tang, certify that:

1)I have reviewed this quarterly report on Form 10-Q for the period September 30, 2012 of Golden State Water Company (referred to as “GSWC”);

2)Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3)Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of GSWC as of, and for, the periods presented in this report;

4)GSWC’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for GSWC and have:

a)designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to GSWC is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)evaluated the effectiveness of GSWC’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d)disclosed in this report any change in GSWC’s internal control over financial reporting that occurred during GSWC’s most recent fiscal quarter (GSWC’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, GSWC’s internal control over financial reporting.

5)GSWC’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to GSWC’s auditors and the audit committee of GSWC’s board of directors (or persons performing the equivalent function):

a)all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect GSWC’s ability to record, process, summarize and report financial information; and

b)any fraud, whether or not material, that involves management or other employees who have a significant role in GSWC’s internal controls over financial reporting.

Dated: November 5, 2012	By:	/s/ EVA G. TANG
		Eva G. Tang
		Senior Vice President-Finance, Chief Financial
		Officer and Secretary

1

EX-32.1

Exhibit 32.1

Certification pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

(18 U.S.C. Section 1350)

In connection with the Quarterly Report of American States Water Company and Golden State Water Company (the “Registrant”) on Form 10-Q for the quarter ended September 30, 2012, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Robert J. Sprowls, Chief Executive Officer of the Registrant, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that, to the best of my knowledge:

(1)	The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Registrant.

/s/ ROBERT J. SPROWLS

Robert J. Sprowls

President and Chief Executive Officer

Date: November 5, 2012

EX-32.2

Exhibit 32.2

Certification pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

(18 U.S.C. Section 1350)

In connection with the Quarterly Report of American States Water Company and Golden State Water Company (the “Registrant”) on Form 10-Q for the quarter ended September 30, 2012, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Eva G. Tang, Chief Financial Officer of the Registrant, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that, to the best of my knowledge:

(1)	The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Registrant.

/s/ EVA G. TANG

Eva G. Tang

Senior Vice President-Finance, Chief Financial Officer,

Corporate Secretary and Treasurer

Date: November 5, 2012

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Business Segments (Details 2) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2011
Business Segments:
Total utility plant	$ 912,027	$ 896,500	$ 891,134
Other assets	377,611		304,714
Total Assets	$ 1,289,638	$ 1,238,362	$ 1,195,848

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Regulatory Matters: (Details) (USD $)					9 Months Ended	16 Months Ended					1 Months Ended			3 Months Ended		1 Months Ended	3 Months Ended	9 Months Ended							1 Months Ended	3 Months Ended		9 Months Ended			1 Months Ended	9 Months Ended	1 Months Ended		9 Months Ended				1 Months Ended																					1 Months Ended	9 Months Ended			1 Months Ended	3 Months Ended	12 Months Ended			3 Months Ended	1 Months Ended		9 Months Ended	3 Months Ended
	Sep. 30, 2012	Sep. 30, 2012 Pension and other post-retirement obligations	Sep. 30, 2012 Deferred income taxes representing accelerated tax benefits	Sep. 30, 2012 Memorandum account to track unrealized gains and losses on purchase power contracts	Sep. 30, 2012 Other regulatory assets, net	Dec. 31, 2011 Other regulatory assets, net	Sep. 30, 2012 GSWC	Dec. 31, 2011 GSWC	Sep. 30, 2012 GSWC Various refunds to customers	Dec. 31, 2011 GSWC Various refunds to customers	May 31, 2012 GSWC Renewables Portfolio Standard	Jun. 30, 2011 GSWC Renewables Portfolio Standard	Sep. 30, 2009 GSWC Renewables Portfolio Standard	Sep. 30, 2012 GSWC Renewables Portfolio Standard	Mar. 31, 2012 GSWC Renewables Portfolio Standard	Dec. 31, 2011 GSWC CPUC Subpoena audit	Sep. 30, 2012 GSWC CPUC Subpoena	Sep. 30, 2012 GSWC CPUC Subpoena	Sep. 30, 2012 GSWC CPUC Subpoena Minimum	Sep. 30, 2012 GSWC CPUC Subpoena Maximum	Sep. 30, 2012 GSWC Pension and other post-retirement obligations	Dec. 31, 2011 GSWC Pension and other post-retirement obligations	Sep. 30, 2012 GSWC Electric supply cost balancing account	Dec. 31, 2011 GSWC Electric supply cost balancing account	Apr. 30, 2012 GSWC WRAM, net of MCBA	Sep. 30, 2012 GSWC WRAM, net of MCBA	Sep. 30, 2011 GSWC WRAM, net of MCBA	Sep. 30, 2012 GSWC WRAM, net of MCBA	Sep. 30, 2011 GSWC WRAM, net of MCBA	Dec. 31, 2011 GSWC WRAM, net of MCBA	Apr. 30, 2012 GSWC WRAM, net of MCBA Minimum	Sep. 30, 2012 GSWC WRAM, net of MCBA Minimum	Apr. 30, 2012 GSWC WRAM, net of MCBA Maximum	Sep. 30, 2010 GSWC WRAM, net of MCBA Maximum	Sep. 30, 2012 GSWC WRAM, net of MCBA Maximum	Sep. 30, 2012 GSWC WRAM, net of MCBA Majority	Sep. 30, 2012 GSWC Water Revenue Adjustment Mechanism	Sep. 30, 2012 GSWC Modified Cost Balancing Account	Jun. 30, 2012 GSWC Base revenue requirement adjustment mechanism	Sep. 30, 2012 GSWC Base revenue requirement adjustment mechanism	Dec. 31, 2011 GSWC Base revenue requirement adjustment mechanism	Sep. 30, 2012 GSWC Costs deferred for future recovery on Aerojet case	Dec. 31, 2011 GSWC Costs deferred for future recovery on Aerojet case	Sep. 30, 2012 GSWC Derivative unrealized loss	Dec. 31, 2011 GSWC Derivative unrealized loss	Sep. 30, 2012 GSWC Flow-through taxes, net	Dec. 31, 2011 GSWC Flow-through taxes, net	Sep. 30, 2012 GSWC Electric transmission line abandonment costs	Dec. 31, 2011 GSWC Electric transmission line abandonment costs	Sep. 30, 2012 GSWC Asset retirement obligations	Dec. 31, 2011 GSWC Asset retirement obligations	Sep. 30, 2012 GSWC Low income rate assistance balancing accounts	Dec. 31, 2011 GSWC Low income rate assistance balancing accounts	Sep. 30, 2012 GSWC General rate case memorandum accounts	Dec. 31, 2011 GSWC General rate case memorandum accounts	Sep. 30, 2012 GSWC Santa Maria adjudication memorandum accounts	Dec. 31, 2011 GSWC Santa Maria adjudication memorandum accounts	Sep. 30, 2012 GSWC Bay Point balancing accounts	Dec. 31, 2011 GSWC Bay Point balancing accounts	Aug. 31, 2012 GSWC BVES General Rate Case	Sep. 30, 2012 GSWC BVES General Rate Case	Sep. 30, 2012 GSWC Other regulatory assets, net	Dec. 31, 2011 GSWC Other regulatory assets, net	Nov. 30, 2011 GSWC Cost of Capital Proceeding for Water Regions item	Sep. 30, 2012 GSWC Cost of Capital Proceeding for Water Regions	Sep. 30, 2012 GSWC Cost of Capital Proceeding for Water Regions	Jan. 02, 2012 GSWC Cost of Capital Proceeding for Water Regions	Oct. 02, 2012 GSWC Cost of Capital Proceeding for Water Regions Subsequent Event [Member] Scenario, Forecast [Member]	Sep. 30, 2012 GSWC Cost of Capital Proceeding for Water Regions Minimum	Nov. 30, 2010 GSWC La Serena Plant Improvement Project	Jan. 31, 2008 GSWC La Serena Plant Improvement Project	Sep. 30, 2012 GSWC La Serena Plant Improvement Project	Sep. 30, 2012 GSWC Deferred rate case costs
Regulatory matters:
Regulatory asset not accruing carrying costs	$ 77,700,000	$ 52,100,000	$ 16,200,000	$ 2,700,000
Total							176,720,000	179,957,000													55,780,000	56,960,000	5,937,000	8,347,000		43,638,000		43,638,000		39,112,000										6,171,000	4,053,000	16,310,000	17,173,000	2,719,000	7,611,000	16,169,000	17,032,000	2,257,000	2,428,000	2,869,000	2,793,000	8,305,000	6,194,000	6,610,000	12,922,000	3,561,000	3,662,000	5,242,000	5,752,000		2,200,000	9,756,000	8,409,000
Total																																																																							3,500,000
Disallowed costs and revenue, if DRA prevails																																																																								2,500,000
Amount billed to customers as surcharges																										6,700,000	5,200,000	14,300,000	10,800,000
Under-collection amount															1,300,000																						64,200,000
Total									(8,604,000)	(12,491,000)						(9,500,000)																						(20,600,000)
Recovery periods											12 months																					12 months			36 months	24 months
Alternative revenue program																																				24 months
Modified recovery period as per application filed with CPUC with whom the decision is pending																																		18 months
Under-collection balances as a percentage of adopted annual revenues																									15.00%
Recovery period for under-collection balances that are up to 15% of adopted annual revenues																																	18 months
Recovery period for under-collection balances greater than 15% of adopted annual revenues																															19 months		36 months
Annual surcharges as a percentage of the last authorized revenue requirement																									10.00%
Period of surcharge approved																																							36 months
Increase in revenue requirement recoverable through surcharges collected																																							1,600,000
Term of contract with LACSD to purchase renewable energy created from landfill gas													10 years
Amount of retroactive ratemaking proposal included in DRA's recommendation to increase accumulated depreciation																																																												2,000,000
Period of right to terminate notice waived under the settlement													14 months
Portion of deferred rate case cost borne by shareholders																																																													50.00%
Purchase cost of REC's														325,000
Portion of deferred rate case costs required to be written off, if DRA prevails																																																													50.00%
Application filed with the CPUC for recovery of legal and outside service costs incurred												1,200,000
Settlement agreement, number of other California water utilities																																																																3
Amount of deferred rate case costs written off related to current pending rate case, if DRA prevails																																																																									1,900,000
Authorized ROE under settlement agreement (as a percent)																																																																			9.99%
Settlement agreement, percentage of equity in rate-making capital structure																																																																			55.00%
Proposed authorized ROE under the settlement agreement (as a percent)																																																																				9.43%
Settlement agreement, percentage of debt in rate-making capital structure																																																																			45.00%
Weighted cost of capital (return on rate base), with an updated embedded debt cost and the settlement ROE (as a percent)																																																																			8.64%
Refunds provided to customers																	1,100,000	2,200,000																																															408,000					2,200,000
Period of cost of capital proceedings for adjustment in ROE and rate of return																																																																	3 years
Change in average of the Moody's Aa utility bond rate (as a percent)																																																																					1.00%
Difference adjustment in ROE (as a percent)																																																																	50.00%
Decrease in Moody's rate from benchmark (as a percent)																																																																		1.12%
Decrease in ROE (as a percent)																																																																	0.56%
Bonus depreciation for qualifying property as extended under the Tax Relief Acts (as a percent)					50.00%
Newly created bonus depreciation for qualifying property, placed in service between September 9, 2010 and December 31, 2011, under the Tax Relief Acts (as a percent)						100.00%
Period of construction of numerous projects																14 years
Period of refunds to customers																			12 months	36 months
Reduction in rate-base and other adjustments as per the settlement																$ 3,000,000
Number of separate independent audits of procurement practices agreed as a part of the settlement agreement																3
Period of separate independent audits of procurement practices agreed as a part of settlement agreement																10 years

XML

Derivative Instruments:

9 Months Ended

Sep. 30, 2012

Derivative Instruments:

Derivative Instruments:

Note 4 — Derivative Instruments:

GSWC purchases certain power at a fixed cost, under a purchased power contract, depending on the amount of power and the period during which the power is purchased.  One of the products under this contract is an option to purchase energy of up to 15 megawatts per hour daily during winter peak months (November through March) and up to 5 megawatts per hour daily during nonpeak months (April through October). The contract is subject to the accounting guidance for derivatives and requires mark-to-market derivative accounting.

The CPUC has authorized GSWC to establish a regulatory asset and liability memorandum account to offset the entries required by the accounting guidance.  Accordingly, all unrealized gains and losses generated from the purchased power contract are deferred on a monthly basis into a non-interest bearing regulatory memorandum account that tracks the changes in fair value of the derivative throughout the term of the contract, having no impact on GSWC’s earnings. Upon expiration of the purchased power contract, the balance in this regulatory memorandum account will be zero.  As of September 30, 2012 there was a $2.7 million cumulative unrealized loss which has been included in the memorandum account.

On January 12, 2012, GSWC executed a new purchased power master agreement. The agreement is subject to CPUC approval, which GSWC plans to file for approval by the end of 2012. If approved, GSWC will be able to purchase 12 megawatts (“MWs”) of base load energy at a fixed price to be negotiated upon CPUC approval of the agreement. GSWC also intends to request CPUC approval of a regulatory asset and liability memorandum account for the new contract to offset the entries required by the accounting guidance on derivatives.

The accounting guidance for fair value measurements applies to all financial assets and financial liabilities that are being measured and reported on a fair value basis. Under the accounting guidance, GSWC makes fair value measurements that are classified and disclosed in one of the following three categories:

Level 1: Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities;

Level 2: Quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability, or

Level 3: Prices or valuation techniques that require inputs that are both significant to the fair value measurement and unobservable (i.e., supported by little or no market activity).

Registrant’s valuation model utilizes various inputs that include quoted market prices for energy over the duration of the contract. The market prices used to determine the fair value for this derivative instrument were estimated based on independent sources such as broker quotes and publications that are not observable in or corroborated by the market.  Registrant receives one broker quote to determine the fair value of its derivative instrument.  When such inputs have a significant impact on the measurement of fair value, the instrument is categorized in Level 3. Accordingly, the valuation of the derivative on Registrant’s purchased power contract has been classified as Level 3 for all periods presented.

The following table presents changes in the fair value of the derivative for the three and nine months ended September 30, 2012 and 2011:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
(dollars in thousands)	2012			2011			2012			2011
Balance, at beginning of the period	$	(5,176	)	$	(7,475	)	$	(7,611	)	$	(6,850	)
Unrealized gain (loss) on purchased power contracts	2,457			(101		)	4,892			(726		)
Balance, at end of the period	$	(2,719	)	$	(7,576	)	$	(2,719	)	$	(7,576	)

XML

Employee Benefit Plans: (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Pension Benefits
Components of Net Periodic Benefits Cost:
Service cost	$ 1,670,000	$ 1,406,000	$ 5,007,000	$ 4,218,000
Interest cost	1,663,000	1,631,000	4,992,000	4,893,000
Expected return on plan assets	(1,634,000)	(1,587,000)	(4,905,000)	(4,761,000)
Amortization of prior service cost (benefit)	31,000	30,000	90,000	89,000
Amortization of actuarial loss	759,000	310,000	2,277,000	931,000
Net periodic pension cost under accounting standards	2,489,000	1,790,000	7,461,000	5,370,000
Regulatory adjustment - deferred	(596,000)	(127,000)	(1,794,000)	(380,000)
Total expense recognized, before allocation to overhead pool	1,893,000	1,663,000	5,667,000	4,990,000
Employer's contribution and fair value of plan assets
Contributed to the pension plan	4,300,000		6,100,000
Pension Benefits | GSWC
Regulatory Adjustment:
Under-collection in the two-way pension balancing account	3,700,000		3,700,000
Other Postretirement Benefits
Components of Net Periodic Benefits Cost:
Service cost	112,000	107,000	336,000	321,000
Interest cost	136,000	153,000	408,000	459,000
Expected return on plan assets	(90,000)	(74,000)	(270,000)	(221,000)
Amortization of transition	105,000	105,000	315,000	315,000
Amortization of prior service cost (benefit)	(50,000)	(50,000)	(150,000)	(150,000)
Net periodic pension cost under accounting standards	213,000	241,000	639,000	724,000
Total expense recognized, before allocation to overhead pool	213,000	241,000	639,000	724,000
Employer's contribution and fair value of plan assets
Expected contribution during the fourth quarter			500,000
SERP
Components of Net Periodic Benefits Cost:
Service cost	183,000	150,000	549,000	450,000
Interest cost	122,000	116,000	366,000	348,000
Amortization of prior service cost (benefit)	40,000	40,000	120,000	121,000
Amortization of actuarial loss	77,000	34,000	231,000	101,000
Net periodic pension cost under accounting standards	422,000	340,000	1,266,000	1,020,000
Total expense recognized, before allocation to overhead pool	$ 422,000	$ 340,000	$ 1,266,000	$ 1,020,000

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Fair Value of Financial Instruments: (Details) (GSWC, USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Level 1
Financial liabilities:
Long-term debt-GSWC	$ 295,778
Level 2
Financial liabilities:
Long-term debt-GSWC	173,287
Carrying Amount
Financial liabilities:
Long-term debt-GSWC	344,426	340,686
Fair Value
Financial liabilities:
Long-term debt-GSWC	$ 469,065	$ 437,275

XML

Contingencies: (Details) (GSWC, USD $) In Millions, unless otherwise specified	1 Months Ended		9 Months Ended						1 Months Ended	9 Months Ended
	Oct. 31, 2011 Water Quality-Related Litigation	Aug. 31, 2003 Water Quality-Related Litigation party	Sep. 30, 2012 Water Quality-Related Litigation purveyor well	Sep. 30, 2012 Condemnation of Properties	Sep. 30, 2012 Environmental Clean-Up and Remediation	Sep. 30, 2012 City of Claremont Condemnation of Properties customer	Sep. 30, 2012 Town of Apple Valley Condemnation of Properties customer	Sep. 30, 2012 Ojai FLOW Condemnation of Properties customer	Feb. 29, 2008 Santa Maria Valley Water Conservation District	Sep. 30, 2012 Santa Maria Valley Water Conservation District acrefeet	Sep. 30, 2012 Santa Maria Valley Water Conservation District Maximum acrefeet
Contingencies
Number of other affected water purveyors that filed suit against those responsible for well contamination			2
Number of contaminated wells for which suit was filed			2
Number of parties deemed responsible for polluting groundwater		41
Number of days for which stays were granted to continue settlement discussions	30 days
Number of customers served through water systems						11,000	2,900	3,000
Period during which no formal condemnation proceedings were filed				3 years
Area of groundwater replenishment provided (in acre-feet)										10,000
Period of severe water shortage condition										5 years
Area per year to which groundwater production can be limited by the court (in acre-feet)											10,248
Period considered for deriving average groundwater production										5 years
Average groundwater production per year (in acre-feet)										10,140
Percentage of the return flows generated from importation of state water project to be recaptured									45.00%
Amount spent in clean-up and remediation activities					$ 3.5
Amount paid by the State of California Underground Storage Tank Fund for clean-up and remediation of plant facilities					1.5
Accrued liability for the estimated additional cost to complete the clean-up at the site					$ 1.2

XML

Discontinued Operations: (Details) (USD $)	1 Months Ended	3 Months Ended	9 Months Ended
	May 31, 2011	Sep. 30, 2011	Sep. 30, 2011
Discontinued operations
Proceeds from sale of discontinued operations			$ 29,603,000
Income statement and other disclosures
Gain on sale of business, net of taxes			2,454,000
Income (loss) from discontinued operations		(18,000)	3,850,000
CCWC
Discontinued operations
Total purchase price	35,200,000
Long debt assumed as part of purchase price	5,600,000
Proceeds from sale of discontinued operations	29,600,000
Income statement and other disclosures
Operating revenues			3,492,000
Operating expenses			660,000
Operating income			2,832,000
Interest expense, net			(142,000)
Income before income taxes			2,690,000
Income tax expense			1,078,000
Income from operations, net of tax			1,612,000
Gain on sale of business, net of taxes			2,454,000
Transaction costs, net of taxes		(18,000)	(216,000)
Net gain on sale and transaction costs		(18,000)	2,238,000
Income (loss) from discontinued operations		$ (18,000)	$ 3,850,000

XML

Earnings per Share/Capital Stock:

9 Months Ended

Sep. 30, 2012

Earnings per Share/Capital Stock:

Earnings per Share/Capital Stock:

Note 3 — Earnings per Share/Capital Stock:

In accordance with the accounting guidance for participating securities and earnings per share (“EPS”), AWR uses the “two-class” method of computing EPS. The “two-class” method is an earnings allocation formula that determines EPS for each class of common stock and participating security. AWR has participating securities related to stock options and restricted stock units that earn dividend equivalents on an equal basis with AWR’s Common Shares (the “Common Shares”) that have been issued under AWR’s 2000 Stock Incentive Plan and 2008 Stock Incentive Plan (the “2000 and 2008 Employee Plans”) and the 2003 Non-Employee Directors Plan (the “2003 Directors Plan”). In applying the “two-class” method, undistributed earnings are allocated to both common shares and participating securities.

The following is a reconciliation of AWR’s net income and weighted average Common Shares outstanding for calculating basic net income per share:

Basic		For The Three MonthsEnded September 30,					For The Nine MonthsEnded September 30,
(in thousands, except per share amounts)		2012		2011			2012		2011
Net income from continuing operations		$	18,664	$	15,617		$	43,857	$	35,300
Net income (loss) from discontinued operations		—		(18		)	—		3,850
Total net income		18,664		15,599			43,857		39,150
Less: (a)  Distributed earnings to common shareholders		6,766		5,236			17,316		15,311
Distributed earnings to participating securities		52		38			119		102
Undistributed earnings		11,846		10,325			26,422		23,737
(b)	Undistributed earnings allocated to common shareholders	11,755		10,250			26,242		23,580
	Undistributed earnings allocated to participating securities	91		75			180		157
Total income available to common shareholders, basic (a)+(b)		$	18,521	$	15,486		$	43,558	$	38,891
Weighted average Common Shares outstanding, basic		19,059		18,701			18,924		18,672
Basic earnings per Common Share:
Income from continuing operations		$	0.97	$	0.83		$	2.30	$	1.88
Income from discontinued operations		—		—			—		0.20
Net Income		$	0.97	$	0.83		$	2.30	$	2.08

Diluted EPS is based upon the weighted average number of Common Shares, including both outstanding shares and shares potentially issuable in connection with stock options granted under Registrant’s 2000 and 2008 Employee Plans, and the 2003 Directors Plan, and net income. At September 30, 2012 and 2011, there were 226,208 and 668,360 options outstanding, respectively, under these Plans. At September 30, 2012 and 2011, there were also 148,176 and 136,703 restricted stock units outstanding, respectively.

The following is a reconciliation of AWR’s net income and weighted average Common Shares outstanding for calculating diluted net income per share:

Diluted	For The Three MonthsEnded September 30,				For The Nine MonthsEnded September 30,
(in thousands, except per share amounts)	2012		2011		2012		2011
Common shareholders earnings, basic	$	18,521	$	15,486	$	43,558	$	38,891
Undistributed earnings for dilutive stock options	—		75		180		157
Total common shareholders earnings, diluted	$	18,521	$	15,561	$	43,738	$	39,048
Weighted average common shares outstanding, basic	19,059		18,701		18,924		18,672
Stock-based compensation (1)	44		151		114		144
Weighted average common shares outstanding, diluted	19,103		18,852		19,038		18,816
Diluted earnings per Common Share:
Income from continuing operations	$	0.97	$	0.83	$	2.30	$	1.88
Income from discontinued operations	—		—		—		0.20
Net Income	$	0.97	$	0.83	$	2.30	$	2.08

(1)In applying the treasury stock method of reflecting the dilutive effect of outstanding stock-based compensation in the calculation of diluted EPS, 182,932 and 425,839 stock options at September 30, 2012 and 2011, respectively, were deemed to be outstanding in accordance with accounting guidance on earnings per share.  All of the 148,176 and 136,703 restricted stock units at September 30, 2012 and 2011, respectively, were included in the calculation of diluted EPS for the nine months ended September 30, 2012 and 2011.

Stock options of 43,276 and 241,921 were outstanding at September 30, 2012 and 2011, respectively, but not included in the computation of diluted EPS because the related option exercise price was greater than the average market price of AWR’s Common Shares for the nine months ended September 30, 2012 and 2011.  Stock options of 600 were outstanding at September 30, 2011, but not included in the computation of diluted EPS because they were anti-dilutive.

During the nine months ended September 30, 2012 and 2011, AWR issued 423,590 and 100,148 Common Shares, for approximately $12,434,000 and $2,350,000, respectively, under AWR’s Common Share Purchase and Dividend Reinvestment Plan, the 401(k) Plan, the 2000 and 2008 Employee Plans, and the 2003 Directors Plan. In addition, Registrant purchased 571,652 and 319,470 Common Shares on the open market during the nine months ended September 30, 2012 and 2011, respectively, under Registrant’s 401(k) Plan and the Common Share Purchase and Dividend Reinvestment Plan. The Common Shares purchased by Registrant were used to satisfy the requirements of these plans.

During the three months ended September 30, 2012 and 2011, AWR paid quarterly dividends of approximately $6.7 million, or $0.355 per share, and $5.2 million, or $0.28 per share, respectively.  During the nine months ended September 30, 2012 and 2011, AWR paid quarterly dividends to shareholders of approximately $17.3 million, or $0.915 per share, and $15.3 million, or $0.82 per share, respectively.

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Business Segments (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011	Dec. 31, 2011
Details of reportable segment
Operating revenues	$ 133,521	$ 119,709	$ 354,480	$ 323,845
Operating income (loss)	36,480	32,420	89,972	79,554
Interest expense, net	5,599	5,992	16,679	18,307
Utility Plant	912,027	891,134	912,027	891,134	896,500
Depreciation and amortization expense	10,230	9,554	31,127	28,829
Income (loss) from discontinued operations		(18)		3,850
Capital additions	18,722	26,279	48,169	63,574
GSWC
Details of reportable segment
Number of reportable segments			2
Operating revenues	99,153	98,314	265,182	261,225
Operating income (loss)	29,961	28,400	72,818	70,149
Utility Plant	907,367		907,367		891,945
Depreciation and amortization expense	9,941	9,334	30,283	28,171
GSWC | Water
Details of reportable segment
Operating revenues	90,604	89,570	237,447	234,047
Operating income (loss)	28,355	26,752	65,872	65,320
Interest expense, net	5,178	5,588	15,399	16,780
Utility Plant	867,310	848,647	867,310	848,647
Depreciation and amortization expense	9,405	8,832	28,527	26,662
Capital additions	17,347	24,690	44,831	59,776
GSWC | Electric
Details of reportable segment
Operating revenues	8,549	8,744	27,735	27,178
Operating income (loss)	1,606	1,648	6,946	4,829
Interest expense, net	397	401	1,186	1,217
Utility Plant	40,057	38,063	40,057	38,063
Depreciation and amortization expense	536	502	1,756	1,509
Capital additions	1,155	684	2,399	2,313
CCWC | Water
Details of reportable segment
Operating income (loss)				(356)
Income (loss) from discontinued operations				1,612
ASUS | Contracts
Details of reportable segment
Operating revenues	34,368	21,395	89,298	62,620
Operating income (loss)	6,545	4,025	17,275	9,820
Interest expense, net	24	84	118	309
Utility Plant	4,660	4,424	4,660	4,424
Depreciation and amortization expense	289	220	844	658
Capital additions	220	905	939	1,485
AWR Parent
Details of reportable segment
Number of principal business units			3
Number of continuing principal business units			2
Number of contracted services			1
Operating income (loss)	(26)	(5)	(121)	(59)
Interest expense, net		(81)	(24)	1
Income (loss) from discontinued operations		$ (18)		$ 2,238

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CONSOLIDATED BALANCE SHEETS (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Property, Plant and Equipment
Regulated utility plant, at cost	$ 1,346,064	$ 1,302,589
Non utility property, at cost	8,687	7,747
Total	1,354,751	1,310,336
Less - Accumulated depreciation	(442,724)	(413,836)
Net property, plant and equipment	912,027	896,500
Other Property and Investments
Goodwill	1,116	1,116
Other property and investments	13,636	11,803
Total other property and investments	14,752	12,919
Current Assets
Cash and cash equivalents	43,066	1,315
Accounts receivable - customers (less allowance for doubtful accounts of $769 in 2012 and $715 in 2011)	28,792	20,399
Unbilled revenue	21,826	16,188
Receivable from the U.S. government (less allowance for doubtful accounts of $8 in 2012 and $0 in 2011)	4,287	7,584
Other accounts receivable, less allowance for doubtful accounts	7,920	12,181
Income taxes receivable	637	20,537
Materials and supplies, at average cost	6,578	3,070
Regulatory assets - current	25,525	36,362
Prepayments and other current assets	5,380	3,959
Costs and estimated earnings in excess of billings on uncompleted contracts	32,787	34,466
Deferred income taxes - current	10,292	9,540
Total current assets	187,090	165,601
Regulatory and Other Assets
Regulatory assets	151,195	143,595
Costs and estimated earnings in excess of billings on uncompleted contracts	4,323	598
Receivable from the U.S. government, less allowance for doubtful accounts	4,427	6,660
Deferred income taxes	11	15
Other	15,813	12,474
Total regulatory and other assets	175,769	163,342
Total Assets	1,289,638	1,238,362
Capitalization
Common shares, no par value	247,030	233,306
Earnings reinvested in the business	201,822	175,360
Total common shareholders' equity	448,852	408,666
Long-term debt	344,248	340,395
Total capitalization	793,100	749,061
Current Liabilities
Notes payable to banks		2,000
Long-term debt - current	178	291
Accounts payable	52,081	37,873
Income taxes payable	1,726	332
Accrued employee expenses	9,710	8,659
Accrued interest	6,423	3,938
Unrealized loss on purchased power contracts	2,719	7,611
Billings in excess of costs and estimated earnings on uncompleted contracts	19,346	26,973
Other	17,062	16,693
Total current liabilities	109,245	104,370
Other Credits
Advances for construction	73,451	75,353
Contributions in aid of construction - net	102,719	100,037
Deferred income taxes	133,651	128,963
Unamortized investment tax credits	1,904	1,972
Accrued pension and other postretirement benefits	68,550	68,353
Billings in excess of costs and estimated earnings on uncompleted contracts		3,272
Other	7,018	6,981
Total other credits	387,293	384,931
Commitments and Contingencies (Note 8)
Total Capitalization and Liabilities	1,289,638	1,238,362
GOLDEN STATE WATER COMPANY
Property, Plant and Equipment
Total	1,346,064	1,302,589
Less - Accumulated depreciation	(438,697)	(410,644)
Net property, plant and equipment	907,367	891,945
Other Property and Investments
Total other property and investments	11,468	9,626
Current Assets
Cash and cash equivalents	25,552
Accounts receivable - customers (less allowance for doubtful accounts of $769 in 2012 and $715 in 2011)	28,792	20,399
Unbilled revenue	21,826	16,188
Inter-company receivable	1,330	785
Other accounts receivable, less allowance for doubtful accounts	6,281	7,755
Income taxes receivable from Parent		19,914
Materials and supplies, at average cost	2,457	1,926
Regulatory assets - current	25,525	36,362
Prepayments and other current assets	5,058	3,710
Deferred income taxes - current	9,255	8,497
Total current assets	126,076	115,536
Regulatory and Other Assets
Regulatory assets	151,195	143,595
Other accounts receivable	2,090	1,838
Other	13,877	10,843
Total regulatory and other assets	167,162	156,276
Total Assets	1,212,073	1,173,383
Capitalization
Common shares, no par value	230,074	228,936
Earnings reinvested in the business	178,904	155,870
Total common shareholders' equity	408,978	384,806
Long-term debt	344,248	340,395
Total capitalization	753,226	725,201
Current Liabilities
Long-term debt - current	178	291
Accounts payable	36,399	31,227
Income taxes payable to Parent	868
Accrued employee expenses	8,648	7,544
Accrued interest	6,423	3,938
Unrealized loss on purchased power contracts	2,719	7,611
Other	16,554	16,162
Total current liabilities	71,789	66,773
Other Credits
Advances for construction	73,451	75,353
Contributions in aid of construction - net	102,719	100,037
Deferred income taxes	133,503	128,815
Unamortized investment tax credits	1,904	1,972
Accrued pension and other postretirement benefits	68,550	68,353
Other	6,931	6,879
Total other credits	387,058	381,409
Commitments and Contingencies (Note 8)
Total Capitalization and Liabilities	$ 1,212,073	$ 1,173,383

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Summary of Significant Accounting Policies:

9 Months Ended

Sep. 30, 2012

Summary of Significant Accounting Policies:

Summary of Significant Accounting Policies:

Note 1 — Summary of Significant Accounting Policies:

Nature of Operations: American States Water Company (“AWR”) is the parent company of Golden State Water Company (“GSWC”) and American States Utility Services, Inc. (“ASUS”) (and its subsidiaries, Fort Bliss Water Services Company (“FBWS”), Terrapin Utility Services, Inc. (“TUS”), Old Dominion Utility Services, Inc. (“ODUS”), Palmetto State Utility Services, Inc. (“PSUS”) and Old North Utility Services, Inc. (“ONUS”)).  The subsidiaries of ASUS may be collectively referred to herein as the “Military Utility Privatization Subsidiaries.” AWR was also the parent company of Chaparral City Water Company (“CCWC”) until the sale of CCWC on May 31, 2011.

GSWC is a public utility engaged principally in the purchase, production, distribution and sale of water in California serving approximately 255,000 customers. GSWC also distributes electricity in several San Bernardino Mountain communities in California serving approximately 23,000 customers. The California Public Utilities Commission (“CPUC”) regulates GSWC’s water and electric businesses, including properties, rates, services, facilities and other matters, and transactions by GSWC with its affiliates.  AWR’s assets and operating income are primarily those of GSWC.

ASUS performs water and wastewater services, including the operation, maintenance, renewal and replacement of water and/or wastewater systems on a contract basis. Through its wholly owned subsidiaries, ASUS operates and maintains the water and/or wastewater systems at various military bases pursuant to 50-year firm, fixed-price contracts, which are subject to periodic price redeterminations and modifications for changes in circumstances, and changes in laws and regulations. There is no direct regulatory oversight by the CPUC over AWR or the operation, rates or services provided by ASUS or any of its wholly owned subsidiaries.

Basis of Presentation: The consolidated financial statements and notes thereto are being presented in a combined report being filed by two separate Registrants: AWR and GSWC. References in this report to “Registrant” are to AWR and GSWC, collectively, unless otherwise specified.  Certain prior period amounts have been reclassified to conform to the 2012 financial statement presentation.

The consolidated financial statements of AWR include the accounts of AWR and its subsidiaries, all of which are wholly owned. These financial statements are prepared in conformity with accounting principles generally accepted in the United States of America. Inter-company transactions and balances have been eliminated in the AWR consolidated financial statements. The operational results of CCWC for the periods presented are reported in discontinued operations, net of transaction costs.

The consolidated financial statements included herein have been prepared by Registrant, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”).  The December 31, 2011 condensed consolidated balance sheet data was derived from audited financial statements, but does not include all disclosures required by GAAP. The preparation of the consolidated financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. In the opinion of management, all adjustments, consisting of normal, recurring items and estimates necessary for a fair statement of the results for the interim periods, have been made. It is suggested that these consolidated financial statements be read in conjunction with the consolidated financial statements and the notes thereto included in the Form 10-K for the year ended December 31, 2011 filed with the SEC.

GSWC’s Related Party Transactions: GSWC and ASUS provide and receive various services to and from their parent, AWR.  Any transactions between GSWC and AWR or ASUS are governed by the CPUC’s affiliate transaction rules.  In addition, AWR has a $100.0 million syndicated credit facility. AWR borrows under this facility and provides funds to its subsidiaries, including GSWC, in support of their operations. Any amounts owed to AWR for borrowings under this facility are included in inter-company payables on GSWC’s balance sheet. The interest rate charged to GSWC and other affiliates is sufficient to cover AWR’s interest cost under the credit facility. GSWC also allocates certain corporate office administrative and general costs to its affiliate, ASUS, using allocation factors mandated by the CPUC.  Through May 31, 2011, GSWC also allocated costs to CCWC.

Long-Term Debt:  On October 1, 2012, GSWC redeemed its $8,000,000, 7.55% Medium-Term Notes, Series B.  The Notes, which were due 2025, were redeemed at a price of 101.133% of the outstanding principal amount of the Notes, plus accrued and unpaid interest through October 1, 2012, for a total redemption price of $8.3 million.

Sales and Use Taxes:  GSWC bills certain sales and use taxes levied by state or local governments to its customers. Included in these sales and use taxes are franchise fees, which GSWC pays to various municipalities (based on ordinances adopted by these municipalities) in order to use public right of way for utility purposes. GSWC bills these franchise fees to its customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of GSWC’s ability to collect from the customer, are accounted for on a gross basis. GSWC’s franchise fees billed to customers and recorded as operating revenue were approximately $966,000 and $942,000 for the three months ended September 30, 2012 and 2011, respectively, and $2,600,000 and $2,423,000 for the nine months ended September 30, 2012 and 2011, respectively. When GSWC acts as an agent, and the tax is not required to be remitted if it is not collected from the customer, the taxes are accounted for on a net basis.

Depending on the state in which the operations are conducted, ASUS and its subsidiaries are also subject to certain state non-income tax assessments generally computed on a “gross receipts” or “gross revenues” basis.  These non-income tax assessments are required to be paid regardless of whether the subsidiary is reimbursed by the U.S. government for these assessments under its 50-year contracts with the U.S. government.  The non-income tax assessments are accounted for on a gross basis and totaled $222,000 and $168,000 during the three months ended September 30, 2012 and 2011, respectively, and $563,000 and $533,000 for the nine months ended September 30, 2012 and 2011, respectively.

Recently Adopted Accounting Pronouncements:  The following accounting standards did not or are not expected to have any impact on Registrant’s consolidated financial statements:

Accounting Standards Update No. 2011-05, Comprehensive Income (Topic 220): Presentation of Comprehensive Income (“ASU 2011-05”). Under ASU 2011-05, an entity has the option to present the total of comprehensive income, the components of net income, and the components of other comprehensive income either in a single continuous statement of comprehensive income or in two separate but consecutive statements. Under both options, an entity will be required to present each component of net income along with total net income, each component of other comprehensive income along with a total for other comprehensive income, and a total amount for comprehensive income.  ASU 2011-05 is effective for fiscal years beginning on or after December 15, 2011 and did not have a material impact on Registrant’s consolidated financial statements.

Accounting Standards Update No. 2011-08, Intangibles - Goodwill and Other (Topic 350): Testing Goodwill for Impairment (“ASU 2011-08”). Under ASU 2011-08, an entity has the option to first assess qualitative factors to determine whether the existence of events or circumstances leads to a determination that it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If, after assessing the totality of events or circumstances, an entity determines it is not more likely than not that the fair value of a reporting unit is less than its carrying amount, performing the two-step impairment test is not required. The guidance does not change how an entity measures a goodwill impairment loss, and is therefore not expected to affect the information reported to users of an entity’s financial statements.  The adoption of this update is not expected to have a significant impact on its results of operations, financial position or cash flows.

In December 2011, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2011-11, Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities (“ASU 2011-11”). The ASU 2011-11 amendments require companies to disclose information about offsetting and related arrangements to enable users of its financial statements to understand the effect of those arrangements on its financial position. ASU 2011-11 is required to be applied retrospectively for all prior periods presented and is effective for annual periods for fiscal years beginning on or after January 1, 2013, and interim periods within those annual fiscal years. Registrant does not expect adoption of this standard to have a material impact on its consolidated results of operations and financial condition.

Other accounting standards that have been issued by the FASB or other standards-setting bodies that do not require adoption until a future date are not expected to have a material impact on Registrant’s consolidated financial statements upon adoption.

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Discontinued Operations: (Tables)

9 Months Ended

Sep. 30, 2012

Discontinued Operations:

Summary of discontinued operations presented in the consolidated statements of income

(dollars in thousands)	Three MonthsEnded September 30, 2011			Nine Months Ended September 30, 2011
Operating revenues	$	—		$	3,492
Operating expenses	—			660
Operating income	—			2,832
Interest expense, net	—			(142		)
Income before income taxes	—			2,690
Income tax expense	—			1,078
Income from the operations, net of tax	—			1,612
Gain on sale of business, net of tax	—			2,454
Transaction costs, net of tax	(18		)	(216		)
Net gain on sale and transaction costs	(18		)	2,238
Income (loss) from discontinued operations (1)	$	(18	)	$	3,850

(1)Corporate overhead costs allocated to CCWC have been excluded from discontinued operations and have been included in other operating expenses and administrative and general expenses as part of continuing operations as they continue to be incurred, primarily at GSWC.

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Summary of Significant Accounting Policies: (Details) (USD $)	3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		0 Months Ended	9 Months Ended		3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012 registrant	Sep. 30, 2011	Sep. 30, 2012 GSWC	Sep. 30, 2011 GSWC	Sep. 30, 2012 GSWC	Sep. 30, 2011 GSWC	Oct. 02, 2012 GSWC 7.55% Medium-Term Notes, Series B	Sep. 30, 2012 GSWC Purchase, production, distribution and sale of water customer	Sep. 30, 2012 GSWC Electricity distribution customer	Sep. 30, 2012 ASUS	Sep. 30, 2011 ASUS	Sep. 30, 2012 ASUS	Sep. 30, 2011 ASUS	Sep. 30, 2012 ASUS Contracts	Sep. 30, 2012 AWR Syndicated Credit Facility
Nature of Operations:
Number of customers served										255,000	23,000
Period of fixed price contracts to operate and maintain the water and/or wastewater systems at various military bases																50 years
Basis of Presentation:
Number of registrants filing combined report			2
GSWC's Related Party Transactions:
Maximum borrowing capacity on line of credit																	$ 100,000,000
Long-Term Debt:
Principal amount of long-term debt									8,000,000
Interest rate per annum (as a percent)									7.55%
Redemption price of debt instrument, as a percentage of principal amount									101.133%
Principal amount of notes redeemed									8,300,000
Sales and Use Taxes:
Franchise fees billed to customers and recorded as operating revenue					966,000	942,000	2,600,000	2,423,000
Non-income tax assessments accounted on a gross basis	$ 3,878,000	$ 3,682,000	$ 11,699,000	$ 10,640,000	$ 3,357,000	$ 3,366,000	$ 10,454,000	$ 9,638,000				$ 222,000	$ 168,000	$ 563,000	$ 533,000

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Regulatory Matters:

9 Months Ended

Sep. 30, 2012

Regulatory Matters:

Regulatory Matters:

Note 2 — Regulatory Matters:

In accordance with accounting principles for rate-regulated enterprises, Registrant records regulatory assets, which represent probable future recovery of costs from customers through the ratemaking process, and regulatory liabilities, which represent probable future refunds that are to be credited to customers through the ratemaking process. At September 30, 2012, Registrant had approximately $77.7 million of regulatory assets, net of regulatory liabilities not accruing carrying costs. Of this amount, $52.1 million relates to the underfunded positions of the pension and other post-retirement obligations, $16.2 million relates to deferred income taxes representing accelerated tax benefits flowed through to customers, which will be included in rates concurrently with recognition of the associated future tax expense, and $2.7 million relates to a memorandum account authorized by the CPUC to track unrealized gains and losses on GSWC’s purchase power contract over the life of the contract. The remainder relates to other items that do not provide for or incur carrying costs. Regulatory assets, less regulatory liabilities, included in the consolidated balance sheets are as follows:

(dollars in thousands)	September 30,2012			December 31, 2011
GSWC
Electric supply cost balancing account	$	5,937		$	8,347
Water Revenue Adjustment Mechanism, net of Modified Cost Balancing Account	43,638			39,112
Base Revenue Requirement Adjustment Mechanism	6,171			4,053
Costs deferred for future recovery on Aerojet case	16,310			17,173
Pensions and other post-retirement obligations	55,780			56,960
Derivative unrealized loss (Note 4)	2,719			7,611
Flow-through taxes, net (Note 6)	16,169			17,032
Electric transmission line abandonment costs	2,257			2,428
Asset retirement obligations	2,869			2,793
Low income rate assistance balancing accounts	8,305			6,194
General rate case memorandum accounts	6,610			12,922
Santa Maria adjudication memorandum accounts	3,561			3,662
Bay Point balancing accounts	5,242			5,752
Other regulatory assets, net	9,756			8,409
Various refunds to customers	(8,604		)	(12,491		)
Total	$	176,720		$	179,957

Regulatory matters are discussed in detail in the consolidated financial statements and the notes thereto included in the Form 10-K for the year ended December 31, 2011 filed with the SEC.  The discussion below focuses on significant matters and changes since December 31, 2011.

Alternative-Revenue Programs:

GSWC records the difference between what it bills its water customers and that which is authorized by the CPUC using the Water Revenue Adjustment Mechanism (“WRAM”). GSWC also records the difference between adopted and actual expense levels for purchased water, purchased power and pump taxes, as established by the CPUC, using the Modified Cost Balancing Accounts (“MCBA”). GSWC has implemented surcharges to recover its WRAM balances, net of the MCBA.  For the three months ended September 30, 2012 and 2011, surcharges of $6.7 million and $5.2 million, respectively, were billed to customers to decrease previously incurred under-collections in the WRAM, net of MCBA accounts, and approximately $14.3 million and $10.8 million for the nine months ended September 30, 2012 and 2011, respectively. As of September 30, 2012, GSWC has a net aggregated regulatory asset of $43.6 million which is comprised of a $64.2 million under-collection in the WRAM accounts and $20.6 million over-collection in the MCBA accounts.

Based on CPUC guidelines, recovery periods relating to GSWC’s WRAM/MCBA balances range between 12 and 36 months, with the majority being 24 months.  As required by the accounting guidance for alternative revenue programs, GSWC is required to collect its WRAM, net of its MCBA, within 24 months following the year in which they are recorded.  In September 2010, GSWC, along with other California water utilities, filed an application with the CPUC to modify the recovery period of its WRAM and MCBA to 18 months or less.  In April 2012, the CPUC issued a final decision which, among other things, sets the recovery period for under-collection balances that are up to 15% of adopted annual revenues at 18 months or less.  For under-collection balances greater than 15%, the recovery period is 19 to 36 months. GSWC does not currently have any balances over 15% of adopted annual revenues.

In addition to adopting a new amortization schedule, the final decision sets a cap on total net WRAM/MCBA surcharges in any given calendar year of 10% of the last authorized revenue requirement. For GSWC, the cap will be applied to its 2013 WRAM balances to be filed for recovery in early 2014.  The cap requirement set forth in the final decision will not impact GSWC’s 2012 and prior year WRAM/MCBA balances.

In June 2012, the CPUC approved surcharges for recovery of BVES’ 2011 Base Revenue Requirement Adjustment Mechanism (“BRRAM”) balance. The CPUC approved a 36-month surcharge, with the amounts collected through December 2013 to be applied to the 2011 BRRAM under-collection.  Surcharges collected during the remainder of the 36-month period would be for recovery of a $1.6 million increase in the BVES revenue requirement representing the difference between the allocated general office costs authorized by the CPUC in its November 2010 decision on the Region II, Region III and general office rate case, and what is currently in BVES’ rates for allocated general office costs.  As authorized by the CPUC, the $1.6 million was included in the BRRAM for recovery through the surcharge; however, these costs are not considered an alternative revenue program.

CPUC Pending Rehearing Matter:

In July 2011, the CPUC issued an order granting the Division of Ratepayer Advocates (“DRA”) request to rehear certain issues from the Region II, Region III and general office rate case approved in November 2010.  Among the issues in the rehearing are the La Serena plant improvement project included in rate base totaling approximately $3.5 million and GSWC’s methodology for deferring rate case costs.  Final resolution of these matters is expected in 2013. The regulatory issues associated with these matters are further discussed below.

La Serena Plant Improvement Project:

In November 2010, as part of GSWC’s Region II, Region III and general office rate case decision, the CPUC disallowed a portion of the La Serena plant improvement project costs from utility customer rates.  As a result of the CPUC’s decision in 2010, GSWC recorded a charge of $2.2 million, which included the disallowance of these capital costs and the related revenues earned on those capital costs that will be refunded to customers.

In December 2010, DRA filed a motion for rehearing on this matter, contending that the CPUC erred in assigning a portion of the La Serena plant improvement costs to GSWC utility customers and requested that all of the capital costs related to the La Serena plant improvement project be disallowed. In July 2011, the CPUC granted DRA’s request for rehearing.  Hearings on these matters are expected in the fourth quarter of 2012. A proposed decision is expected in June 2013. In addition to granting a rehearing, the CPUC also directed the Division of Water and Audits (“DWA”) to undertake an audit of the La Serena project costs and to provide a confidential report to the CPUC with recommendations on whether an investigation should be conducted to determine whether any laws were broken related to the La Serena project.  Management does not believe it has violated any laws in regards to the La Serena project.  DWA issued its independent audit report, which found cost overruns for the La Serena plant improvement project to be lower than the amount of costs for rate recovery previously disallowed by the CPUC.

In October 2012, DRA issued a report on this matter recommending further disallowances of costs and refund of revenues earned on those costs. DRA’s recommendation is inconsistent with the independent audit report issued by DWA.  In addition, GSWC believes DRA’s recommendations are without merit and inconsistent with previous CPUC decisions on this matter.  However, if DRA prevails, GSWC may be required to write-off additional capital costs and provide refunds to customers of the revenues earned on those costs.  Based on DRA’s recommendation, additional disallowed costs and revenues earned on those costs through September 30, 2012 totaled approximately $2.5 million. GSWC intends to vigorously defend its position. However, at this time, management cannot predict the outcome of the rehearing, DWA’s and DRA’s recommendations, or determine the estimated additional loss or range of loss, if any.

Deferred rate case costs:

The rehearing is also re-addressing deferred rate case costs, which are direct costs consisting primarily of outside consulting services which have been incurred in connection with the preparation and processing of a general rate case. Historically, GSWC has deferred these costs as a regulatory asset which are then recovered in rates and amortized over the term of a rate case cycle once the new rates go into effect.  In the rehearing proceeding, DRA is again challenging GSWC’s historical practice of deferring these costs with subsequent recovery upon the effective date of the new rates. Instead, DRA believes that rate case costs should be projected for future periods and recovered prospectively.  Management believes that DRA’s rationale and recommendations are inconsistent with previous CPUC decisions on this matter and also with GSWC’s historical practice of deferring and recovering rate case expenses associated with the current general rate case, and continues to believe that the costs are probable for recovery.  However, if DRA prevails, GSWC may be required to write-off deferred rate case costs related to its current pending rate case, which total approximately $1.9 million as of September 30, 2012.  At this time, GSWC is unable to predict the outcome of this matter.

BVES Regulatory Matters:

BVES General Rate Case

In February 2012, GSWC filed its BVES general rate case (“GRC”) for rates in years 2013 through 2016.  In August 2012, DRA issued its report on the GRC.  Included in DRA’s recommendations is a $2.0 million retroactive ratemaking proposal to increase BVES’ accumulated depreciation balance to reflect adopted depreciation expense for the years 2009 through 2012 rather than actual depreciation expense as recorded in compliance with Generally Accepted Accounting Principles.  DRA also recommends that one-half of deferred rate case costs be borne by shareholders, rather than entirely by customers as has been authorized by the CPUC in prior rate cases.  As of September 30, 2012, GSWC has a $2.2 million regulatory asset representing deferred rate case costs for the current BVES general rate case, which are considered probable of recovery. Hearings on the GRC, including these matters, were held in September 2012.  If DRA prevails, GSWC may be required to record a charge to adjust accumulated depreciation and to write-off half of its deferred rate case costs. GSWC believes DRA’s recommendations are without merit and intends to vigorously defend its positions.  However, at this time, GSWC is unable to predict the final outcome of these matters which are expected to be resolved in the pending rate case.

Renewables Portfolio Standard

GSWC’s BVES division has been regularly filing compliance reports with the CPUC regarding its purchases of energy from renewable energy resources to meet California’s renewables portfolio standards (“RPS”).  Previous filings under prior RPS laws had indicated that BVES had not achieved annual target purchase levels of renewable energy resources and thus, on its face, might be subject to a potential penalty.  However, a new RPS law went into effect in December 2011 which changed, among other things, the prior RPS requirement based upon annual procurement targets to multi-year procurement targets.  Under the new RPS law, BVES must procure sufficient RPS-eligible resources to meet: (i) any RPS procurement requirement deficit for any year prior to 2011, and (ii) RPS procurement requirements for the 2011 — 2013 compliance period by no later than December 31, 2013.  BVES’ first RPS reports under the new law were submitted to the CPUC in March 2012 and August 2012, and did not reflect any RPS procurement deficiencies nor any potential or actual penalties.  Accordingly, no provision for loss has been recorded in the financial statements as of September 30, 2012.

In September 2009, GSWC negotiated a ten-year contract with the Los Angeles County Sanitation District (“LACSD”) to purchase renewable energy created from landfill gas. In February 2011, LACSD notified GSWC that it intended to shut down the landfill gas generator. In August 2011, GSWC and LACSD negotiated a settlement to resolve a dispute between the parties regarding certain terms of the contract.  Under the terms of the settlement, GSWC agreed to waive its right to a 14 month termination notice and LACSD agreed to sell renewable energy credits (“RECs”) to GSWC.

In November 2011, GSWC filed for CPUC approval for the purchase of these RECs.   In July 2012, the CPUC approved the purchase.  BVES intends to apply these RECs towards either its pre-2011 renewable energy requirements or its 2011-2013 requirements. The REC’s were purchased for approximately $325,000 during the third quarter of 2012 as an asset and will be included as part of BVES’ electric supply cost balancing account when the RECs are applied towards the RPS requirements.

In June 2011, GSWC’s BVES filed an application with the CPUC to recover $1.2 million in legal and outside service costs incurred during the period September 1, 2007 through March 31, 2011 in connection with seeking to procure renewable energy resources.  In March 2012, the CPUC approved the application.  Accordingly, a regulatory asset of $1.3 million, including accrued interest, was recorded in March 2012.  A 12-month surcharge was implemented in May 2012 for recovery of these costs.

Other Regulatory Matters:

Cost of Capital Proceeding for Water Regions:

In July 2012, the CPUC issued a final decision on GSWC’s water cost of capital proceeding filed in May 2011. The decision approves the settlement agreement entered into between GSWC, along with three other California water utilities, and DRA in November 2011.  The approved settlement authorizes a Return on Equity (“ROE”) of 9.99% and a rate-making capital structure for GSWC of 55% equity and 45% debt. The weighted cost of capital (return on rate base), with an updated embedded debt cost and the settlement ROE, is 8.64%. The new rate of return authorized by the CPUC’s final decision was implemented into water rates retroactive to January 1, 2012.  Among other things, the final decision required GSWC to refund to customers approximately $408,000, representing the settled amount included in the interest rate balancing account.  During the three months ended September 30, 2012, GSWC refunded the majority of this to customers through a one-time surcredit.

The CPUC decision also authorized GSWC to continue the Water Cost of Capital Mechanism (“WCCM”).  The WCCM adjusts ROE and rate of return on rate base between the three-year cost of capital proceedings only if there is a positive or negative change of more than 100 basis points in the average of Moody’s Aa utility bond rate as measured over the period October 1 through September 30.  If the average Moody’s rate for this period changes by over 100 basis points from the benchmark, the ROE will be adjusted by one half of the difference. For the period October 1, 2011 through September 30, 2012, Moody’s rate declined by 112 basis points from the benchmark. As a result, in October 2012, GSWC filed an advice letter to lower its water ROE by 56 basis points, from 9.99% to 9.43%, which will be incorporated in the new 2013 water rates.

Changes in Tax Law

The Small Business Jobs Act of 2010 and the Tax Relief, Unemployment Insurance Reauthorization and Job Creation Act of 2010 (“Tax Relief Acts”) extended 50% bonus depreciation for qualifying property through 2012 and created 100% bonus depreciation for qualifying property placed in service between September 9, 2010 and December 31, 2011.

In June 2011, the CPUC adopted a resolution that requires water utilities to file advice letters implementing a one-way memorandum account to track the revenue effects associated with the Tax Relief Acts. This may result in a reduction in revenue requirements in future rate case proceedings. The effective date of the memorandum account established by the resolution was April 14, 2011.  More specifically, the memorandum account established by the resolution tracks on a CPUC-jurisdictional, revenue-requirement basis: (a) decreases in each impacted utility’s revenue requirement resulting from increases in its deferred tax reserve; and (b) other direct changes in the revenue requirement resulting from taking advantage of the Tax Relief Acts. This resolution also authorizes impacted utilities to use savings from this new tax law to invest in certain additional, needed utility infrastructure, not otherwise funded in rates, within a time frame shorter than would be practicable through the formal application or advice letter processes. The establishment of a memorandum account does not change rates, nor guarantee that rates will be changed in the future. This mechanism simply allows the CPUC to determine at a future date whether rates should be changed. GSWC has evaluated the potential impact of this resolution and does not expect it to have a material impact on its consolidated financial statements. However, at this time, GSWC cannot predict the outcome of this resolution or determine its potential impact, if any, on future rates.

CPUC Subpoena

On December 15, 2011, the CPUC approved a settlement agreement reached between GSWC and DWA to resolve an investigation of certain work orders and charges paid to a specific contractor used previously for numerous construction projects over a period of 14 years.  The settlement provides for refunds to customers totaling $9.5 million to be made over a period of 12-36 months, as well as a reduction in rate-base and other rate adjustments totaling $3.0 million.  As a result of the settlement, management does not expect future increases in the reserve related to this specific contractor.  Refunds totaling $1.1 million and $2.2 million were made to customers during the three and nine months ended September 30, 2012, respectively.

As part of the settlement agreement, GSWC agreed to be subject to three separate independent audits of its procurement practices over a period of ten years from the date the settlement was approved by the CPUC.  The audits will cover GSWC’s procurement practices from 1994 forward and could result in further disallowances of costs.  The cost of the audits will be borne by shareholders and may not be recovered by GSWC in rates to customers. At this time, management cannot predict the outcome of these audits or determine the estimated loss or range of loss, if any, resulting from these audits.

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CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Accounts receivable - customers, allowance for doubtful accounts	$ 769	$ 715
Receivable from the U.S. government, allowance for doubtful accounts	8	0
Other accounts receivable, allowance for doubtful accounts	334	333
Receivable from the U.S. government, allowance for doubtful accounts	0	0
GOLDEN STATE WATER COMPANY
Accounts receivable - customers, allowance for doubtful accounts	769	715
Other accounts receivable, allowance for doubtful accounts	$ 257	$ 290

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Regulatory Matters: (Tables)

9 Months Ended

Sep. 30, 2012

Regulatory Matters:

Schedule of regulatory assets, less regulatory liabilities in the consolidated balance sheets for continuing operations

(dollars in thousands)	September 30,2012			December 31, 2011
GSWC
Electric supply cost balancing account	$	5,937		$	8,347
Water Revenue Adjustment Mechanism, net of Modified Cost Balancing Account	43,638			39,112
Base Revenue Requirement Adjustment Mechanism	6,171			4,053
Costs deferred for future recovery on Aerojet case	16,310			17,173
Pensions and other post-retirement obligations	55,780			56,960
Derivative unrealized loss (Note 4)	2,719			7,611
Flow-through taxes, net (Note 6)	16,169			17,032
Electric transmission line abandonment costs	2,257			2,428
Asset retirement obligations	2,869			2,793
Low income rate assistance balancing accounts	8,305			6,194
General rate case memorandum accounts	6,610			12,922
Santa Maria adjudication memorandum accounts	3,561			3,662
Bay Point balancing accounts	5,242			5,752
Other regulatory assets, net	9,756			8,409
Various refunds to customers	(8,604		)	(12,491		)
Total	$	176,720		$	179,957

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Document and Entity Information	9 Months Ended
	Sep. 30, 2012	Nov. 02, 2012
Document and Entity Information
Entity Registrant Name	AMERICAN STATES WATER CO
Entity Central Index Key	0001056903
Document Type	10-Q
Document Period End Date	Sep. 30, 2012
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		19,216,427
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q3

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Earnings per Share/Capital Stock: (Tables)

9 Months Ended

Sep. 30, 2012

Earnings per Share/Capital Stock:

Schedule of reconciliation of AWR's net income and weighted average Common Shares outstanding for calculating basic net income per share

Basic		For The Three MonthsEnded September 30,					For The Nine MonthsEnded September 30,
(in thousands, except per share amounts)		2012		2011			2012		2011
Net income from continuing operations		$	18,664	$	15,617		$	43,857	$	35,300
Net income (loss) from discontinued operations		—		(18		)	—		3,850
Total net income		18,664		15,599			43,857		39,150
Less: (a)  Distributed earnings to common shareholders		6,766		5,236			17,316		15,311
Distributed earnings to participating securities		52		38			119		102
Undistributed earnings		11,846		10,325			26,422		23,737
(b)	Undistributed earnings allocated to common shareholders	11,755		10,250			26,242		23,580
	Undistributed earnings allocated to participating securities	91		75			180		157
Total income available to common shareholders, basic (a)+(b)		$	18,521	$	15,486		$	43,558	$	38,891
Weighted average Common Shares outstanding, basic		19,059		18,701			18,924		18,672
Basic earnings per Common Share:
Income from continuing operations		$	0.97	$	0.83		$	2.30	$	1.88
Income from discontinued operations		—		—			—		0.20
Net Income		$	0.97	$	0.83		$	2.30	$	2.08

Schedule of reconciliation of AWR's net income and weighted average Common Shares outstanding for calculating diluted net income per share

Diluted	For The Three MonthsEnded September 30,				For The Nine MonthsEnded September 30,
(in thousands, except per share amounts)	2012		2011		2012		2011
Common shareholders earnings, basic	$	18,521	$	15,486	$	43,558	$	38,891
Undistributed earnings for dilutive stock options	—		75		180		157
Total common shareholders earnings, diluted	$	18,521	$	15,561	$	43,738	$	39,048
Weighted average common shares outstanding, basic	19,059		18,701		18,924		18,672
Stock-based compensation (1)	44		151		114		144
Weighted average common shares outstanding, diluted	19,103		18,852		19,038		18,816
Diluted earnings per Common Share:
Income from continuing operations	$	0.97	$	0.83	$	2.30	$	1.88
Income from discontinued operations	—		—		—		0.20
Net Income	$	0.97	$	0.83	$	2.30	$	2.08

(1)In applying the treasury stock method of reflecting the dilutive effect of outstanding stock-based compensation in the calculation of diluted EPS, 182,932 and 425,839 stock options at September 30, 2012 and 2011, respectively, were deemed to be outstanding in accordance with accounting guidance on earnings per share. 

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CONSOLIDATED STATEMENTS OF INCOME (USD $) Share data in Thousands, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Operating Revenues
Water	$ 90,604,000	$ 89,570,000	$ 237,447,000	$ 234,047,000
Electric	8,549,000	8,744,000	27,735,000	27,178,000
Contracted services	34,368,000	21,395,000	89,298,000	62,620,000
Total operating revenues	133,521,000	119,709,000	354,480,000	323,845,000
Operating Expenses
Water purchased	18,874,000	16,094,000	42,257,000	37,679,000
Power purchased for pumping	3,067,000	3,141,000	6,642,000	6,842,000
Groundwater production assessment	3,923,000	3,795,000	11,228,000	10,307,000
Power purchased for resale	2,854,000	3,038,000	8,725,000	9,767,000
Supply cost balancing accounts	1,960,000	5,050,000	9,560,000	14,374,000
Other operation expenses	7,394,000	7,398,000	21,671,000	21,261,000
Administrative and general expenses	17,362,000	18,022,000	51,739,000	54,181,000
Depreciation and amortization	10,230,000	9,554,000	31,127,000	28,829,000
Maintenance	4,232,000	4,346,000	11,415,000	12,695,000
Property and other taxes	3,878,000	3,682,000	11,699,000	10,640,000
ASUS construction expenses	23,332,000	13,169,000	58,513,000	37,844,000
Net (gain) loss on sale of property	(65,000)		(68,000)	(128,000)
Total operating expenses	97,041,000	87,289,000	264,508,000	244,291,000
Operating Income	36,480,000	32,420,000	89,972,000	79,554,000
Other Income and Expenses
Interest expense	(6,018,000)	(6,194,000)	(17,808,000)	(18,807,000)
Interest income	419,000	202,000	1,129,000	500,000
Other	219,000	(170,000)	435,000	(379,000)
Total other income and expenses	(5,380,000)	(6,162,000)	(16,244,000)	(18,686,000)
Income from continuing operations before income tax expense	31,100,000	26,258,000	73,728,000	60,868,000
Income tax expense	12,436,000	10,641,000	29,871,000	25,568,000
Income from continuing operations	18,664,000	15,617,000	43,857,000	35,300,000
Income (loss) from discontinued operations, net of tax		(18,000)		3,850,000
Net Income	18,664,000	15,599,000	43,857,000	39,150,000
Basic Earnings Per Common Share
Income from continuing operations (in dollars per share)	$ 0.97	$ 0.83	$ 2.30	$ 1.88
Income (loss) from discontinued operations (in dollars per share)				$ 0.20
Net Income (in dollars per share)	$ 0.97	$ 0.83	$ 2.30	$ 2.08
Fully Diluted Earnings Per Share
Income from continuing operations (in dollars per share)	$ 0.97	$ 0.83	$ 2.30	$ 1.88
Income (loss) from discontinued operations (in dollars per share)				$ 0.20
Net Income (in dollars per share)	$ 0.97	$ 0.83	$ 2.30	$ 2.08
Weighted Average Number of Shares Outstanding (in shares)	19,059	18,701	18,924	18,672
Weighted Average Number of Diluted Shares (in shares)	19,103	18,852	19,038	18,816
Dividends Declared Per Common Share (in dollars per share)	$ 0.355	$ 0.280	$ 0.915	$ 0.820
GOLDEN STATE WATER COMPANY
Operating Revenues
Water	90,604,000	89,570,000	237,447,000	234,047,000
Electric	8,549,000	8,744,000	27,735,000	27,178,000
Total operating revenues	99,153,000	98,314,000	265,182,000	261,225,000
Operating Expenses
Water purchased	18,874,000	16,094,000	42,257,000	37,679,000
Power purchased for pumping	3,067,000	3,141,000	6,642,000	6,842,000
Groundwater production assessment	3,923,000	3,795,000	11,228,000	10,307,000
Power purchased for resale	2,854,000	3,038,000	8,725,000	9,767,000
Supply cost balancing accounts	1,960,000	5,050,000	9,560,000	14,374,000
Other operation expenses	6,859,000	6,933,000	19,710,000	18,489,000
Administrative and general expenses	14,621,000	15,398,000	43,472,000	45,182,000
Depreciation and amortization	9,941,000	9,334,000	30,283,000	28,171,000
Maintenance	3,801,000	3,765,000	10,098,000	10,755,000
Property and other taxes	3,357,000	3,366,000	10,454,000	9,638,000
Net (gain) loss on sale of property	(65,000)		(65,000)	(128,000)
Total operating expenses	69,192,000	69,914,000	192,364,000	191,076,000
Operating Income	29,961,000	28,400,000	72,818,000	70,149,000
Other Income and Expenses
Interest expense	(5,959,000)	(6,138,000)	(17,648,000)	(18,436,000)
Interest income	384,000	149,000	1,063,000	439,000
Other	219,000	(171,000)	434,000	(570,000)
Total other income and expenses	(5,356,000)	(6,160,000)	(16,151,000)	(18,567,000)
Income from continuing operations before income tax expense	24,605,000	22,240,000	56,667,000	51,582,000
Income tax expense	10,030,000	9,212,000	23,352,000	22,147,000
Net Income	$ 14,575,000	$ 13,028,000	$ 33,315,000	$ 29,435,000

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Employee Benefit Plans:

9 Months Ended

Sep. 30, 2012

Employee Benefit Plans:

Employee Benefit Plans:

Note 7 — Employee Benefit Plans:

The components of net periodic benefit costs, before allocation to the overhead pool, for Registrant’s pension plan, postretirement plan, and Supplemental Executive Retirement Plan (“SERP”) for the three and nine months ended September 30, 2012 and 2011 are as follows:

	For The Three Months Ended September 30,
	Pension Benefits						Other Postretirement Benefits						SERP
(dollars in thousands)	2012			2011			2012			2011			2012		2011
Components of Net Periodic Benefits Cost:
Service cost	$	1,670		$	1,406		$	112		$	107		$	183	$	150
Interest cost	1,663			1,631			136			153			122		116
Expected return on plan assets	(1,634		)	(1,587		)	(90		)	(74		)	—		—
Amortization of transition	—			—			105			105			—		—
Amortization of prior service cost (benefit)	31			30			(50		)	(50		)	40		40
Amortization of actuarial loss	759			310			—			—			77		34
Net periodic pension cost under accounting standards	2,489			1,790			213			241			422		340
Regulatory adjustment — deferred (1)	(596		)	(127		)	—			—			—		—
Total expense recognized, before allocation to overhead pool	$	1,893		$	1,663		$	213		$	241		$	422	$	340

	For The Nine Months Ended September 30,
	Pension Benefits						Other Postretirement Benefits						SERP
(dollars in thousands)	2012			2011			2012			2011			2012		2011
Components of Net Periodic Benefits Cost:
Service cost	$	5,007		$	4,218		$	336		$	321		$	549	$	450
Interest cost	4,992			4,893			408			459			366		348
Expected return on plan assets	(4,905		)	(4,761		)	(270		)	(221		)	—		—
Amortization of transition	—			—			315			315			—		—
Amortization of prior service cost (benefit)	90			89			(150		)	(150		)	120		121
Amortization of actuarial loss	2,277			931			—			—			231		101
Net periodic pension cost under accounting standards	7,461			5,370			639			724			1,266		1,020
Regulatory adjustment — deferred (1)	(1,794		)	(380		)	—			—			—		—
Total expense recognized, before allocation to overhead pool	$	5,667		$	4,990		$	639		$	724		$	1,266	$	1,020

(1)Regulatory Adjustment - In November 2010, the CPUC authorized GSWC to establish a two-way balancing account, effective January 1, 2010, to track differences between the forecasted annual pension expenses adopted in rates and the actual annual expense to be recorded by GSWC in accordance with the accounting guidance for pension costs.  As of September 30, 2012, GSWC has included a $3.7 million under-collection in the two-way pension balancing account recorded as a regulatory asset (Note 2).

During the three and nine months ended September 30, 2012, Registrant contributed $4.3 million and $6.1 million to the pension plan, respectively. Registrant expects to contribute approximately $500,000 to the postretirement medical plan during the fourth quarter of 2012.

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Income Taxes:

9 Months Ended

Sep. 30, 2012

Income Taxes:

Income Taxes:

Note 6 — Income Taxes:

As a regulated utility, GSWC treats certain temporary differences as flow-through adjustments in computing its income tax provision consistent with the income tax approach approved by the CPUC for ratemaking purposes. Flow-through adjustments increase or decrease tax expense in one period, with an offsetting decrease or increase occurring in another period. Giving effect to these temporary differences as flow-through adjustments typically results in a greater variance between the effective income tax rate and the statutory federal income tax rate in any given period than would otherwise exist if GSWC were not required to account for its income taxes as a regulated enterprise.  GSWC’s effective income tax rate deviates from the statutory rate primarily due to state taxes and differences between book and taxable income that are treated as flow-through adjustments in accordance with regulatory requirements (principally plant-, rate-case- and compensation-related items).

Changes in Tax Law

The Tax Relief Acts extended bonus depreciation for qualifying property through 2012.  As a result, Registrant’s current tax expense for 2011 and 2012 reflects benefits from the Tax Relief Acts. Although these law changes reduce AWR’s current taxes payable, they do not reduce its total income tax expense or effective income tax rate.

In December 2011, the U.S. Treasury Department issued temporary regulations related to the tax treatment of tangible property, including guidance on expensing certain repairs and maintenance expenditures for which separate guidance has not been issued. These regulations are effective for tax years beginning on or after January 1, 2012.  The majority of GSWC’s assets consist of water pipelines. For these assets the regulations did not provide any new guidance. Registrant is evaluating its water-pipeline tax repair-cost method.  Registrant is also evaluating other tax-method changes provided for under the regulations; however, the effects on its tax expense and tax balances are not anticipated to be significant. Although these temporary regulations are expected to reduce AWR’s current taxes payable, they do not reduce its total effective income tax rate.

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Business Segments: (Tables)

9 Months Ended

Sep. 30, 2012

Business Segments:

Schedule of reporting segments information

	As Of And For The Three Months Ended September 30, 2012
	GSWC				ASUS		AWR			Consolidated
(dollars in thousands)	Water		Electric		Contracts		Parent			AWR
Operating revenues	$	90,604	$	8,549	$	34,368	$	—		$	133,521
Operating income (loss)	28,355		1,606		6,545		(26		)	36,480
Interest expense, net	5,178		397		24		—			5,599
Utility plant	867,310		40,057		4,660		—			912,027
Depreciation and amortization expense	9,405		536		289		—			10,230
Capital additions	17,347		1,155		220		—			18,722

	As Of And For The Three Months Ended September 30, 2011
	GSWC				CCWC		ASUS		AWR			Consolidated
(dollars in thousands)	Water		Electric		Water		Contracts		Parent			AWR
Operating revenues	$	89,570	$	8,744	$	—	$	21,395	$	—		$	119,709
Operating income (loss)	26,752		1,648		—		4,025		(5		)	32,420
Interest expense, net	5,588		401		—		84		(81		)	5,992
Utility plant	848,647		38,063		—		4,424		—			891,134
Depreciation and amortization expense	8,832		502		—		220		—			9,554
Loss from discontinued operations, net of tax (2)	—		—				—		(18		)	(18		)
Capital additions	24,690		684		—		905		—			26,279

	As Of And For The Nine Months Ended September 30, 2012
	GSWC				ASUS		AWR			Consolidated
(dollars in thousands)	Water		Electric		Contracts		Parent			AWR
Operating revenues	$	237,447	$	27,735	$	89,298	$	—		$	354,480
Operating income (loss)	65,872		6,946		17,275		(121		)	89,972
Interest expense, net	15,399		1,186		118		(24		)	16,679
Utility plant	867,310		40,057		4,660		—			912,027
Depreciation and amortization expense	28,527		1,756		844		—			31,127
Capital additions	44,831		2,399		939		—			48,169

	As Of And For The Nine Months Ended September 30, 2011
	GSWC				CCWC			ASUS		AWR			Consolidated
(dollars in thousands)	Water		Electric		Water			Contracts		Parent			AWR
Operating revenues	$	234,047	$	27,178	$	—		$	62,620	$	—		$	323,845
Operating income (loss) (1)	65,320		4,829		(356		)	9,820		(59		)	79,554
Interest expense, net	16,780		1,217		—			309		1			18,307
Utility plant	848,647		38,063		—			4,424		—			891,134
Depreciation and amortization expense	26,662		1,509		—			658		—			28,829
Income from discontinued operations, net of tax (2)	—		—		1,612			—		2,238			3,850
Capital additions	59,776		2,313		—			1,485		—			63,574

Schedule of reconciliation of total utility plant (a key figure for rate-making) to total consolidated assets

The following table reconciles total utility plant (a key figure for rate-making) to total consolidated assets (in thousands):

	September 30,
	2012		2011
Total utility plant	$	912,027	891,134
Other assets	377,611		304,714
Total consolidated assets	$	1,289,638	$	1,195,848

(1)Operating income (loss) include CCWC’s allocated corporate overhead costs that are now primarily at GSWC.

(2)In accordance with the accounting guidance relating to assets held for sale, Registrant did not record depreciation expense for CCWC in 2011.

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Derivative Instruments: (Tables) (GSWC)

9 Months Ended

Sep. 30, 2012

GSWC

Derivative instruments

Schedule of changes in the fair value of the derivative

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
(dollars in thousands)	2012			2011			2012			2011
Balance, at beginning of the period	$	(5,176	)	$	(7,475	)	$	(7,611	)	$	(6,850	)
Unrealized gain (loss) on purchased power contracts	2,457			(101		)	4,892			(726		)
Balance, at end of the period	$	(2,719	)	$	(7,576	)	$	(2,719	)	$	(7,576	)

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Business Segments:

9 Months Ended

Sep. 30, 2012

Business Segments:

Business Segments:

Note 10 — Business Segments:

AWR has three reportable segments, water, electric and contracted services, whereas GSWC has two segments, water and electric. Within the segments, AWR has two principal business units: water and electric service utility operations conducted through GSWC, and one contracted services unit conducted through ASUS and its subsidiaries. AWR has no material assets other than its investments in its subsidiaries on a stand-alone basis.

All activities of GSWC are geographically located within California.  The operating activities of CCWC have been included in discontinued operations as described in Note 9.  All activities of CCWC were located in the state of Arizona. GSWC is, and CCWC was, a rate-regulated utility.

Activities of ASUS and its subsidiaries are conducted in California, Georgia, Maryland, New Mexico, North Carolina, South Carolina, Texas, and Virginia.  Each of ASUS’s wholly owned subsidiaries is regulated by the state in which the subsidiary primarily conducts water and/or wastewater operations.  Fees charged for operations and maintenance, and renewal and replacement services are based upon the terms of the contracts with the U.S. government which have been filed with the commissions in the states in which ASUS’s subsidiaries are incorporated.

The tables below set forth information relating to GSWC’s operating segments, ASUS and its subsidiaries, and other matters. The identifiable assets are net of respective accumulated provisions for depreciation. Capital additions reflect capital expenditures paid in cash and exclude property installed by developers and conveyed to GSWC and through May 31, 2011 for CCWC.

	As Of And For The Three Months Ended September 30, 2012
	GSWC				ASUS		AWR			Consolidated
(dollars in thousands)	Water		Electric		Contracts		Parent			AWR
Operating revenues	$	90,604	$	8,549	$	34,368	$	—		$	133,521
Operating income (loss)	28,355		1,606		6,545		(26		)	36,480
Interest expense, net	5,178		397		24		—			5,599
Utility plant	867,310		40,057		4,660		—			912,027
Depreciation and amortization expense	9,405		536		289		—			10,230
Capital additions	17,347		1,155		220		—			18,722

	As Of And For The Three Months Ended September 30, 2011
	GSWC				CCWC		ASUS		AWR			Consolidated
(dollars in thousands)	Water		Electric		Water		Contracts		Parent			AWR
Operating revenues	$	89,570	$	8,744	$	—	$	21,395	$	—		$	119,709
Operating income (loss)	26,752		1,648		—		4,025		(5		)	32,420
Interest expense, net	5,588		401		—		84		(81		)	5,992
Utility plant	848,647		38,063		—		4,424		—			891,134
Depreciation and amortization expense	8,832		502		—		220		—			9,554
Loss from discontinued operations, net of tax (2)	—		—				—		(18		)	(18		)
Capital additions	24,690		684		—		905		—			26,279

	As Of And For The Nine Months Ended September 30, 2012
	GSWC				ASUS		AWR			Consolidated
(dollars in thousands)	Water		Electric		Contracts		Parent			AWR
Operating revenues	$	237,447	$	27,735	$	89,298	$	—		$	354,480
Operating income (loss)	65,872		6,946		17,275		(121		)	89,972
Interest expense, net	15,399		1,186		118		(24		)	16,679
Utility plant	867,310		40,057		4,660		—			912,027
Depreciation and amortization expense	28,527		1,756		844		—			31,127
Capital additions	44,831		2,399		939		—			48,169

	As Of And For The Nine Months Ended September 30, 2011
	GSWC				CCWC			ASUS		AWR			Consolidated
(dollars in thousands)	Water		Electric		Water			Contracts		Parent			AWR
Operating revenues	$	234,047	$	27,178	$	—		$	62,620	$	—		$	323,845
Operating income (loss) (1)	65,320		4,829		(356		)	9,820		(59		)	79,554
Interest expense, net	16,780		1,217		—			309		1			18,307
Utility plant	848,647		38,063		—			4,424		—			891,134
Depreciation and amortization expense	26,662		1,509		—			658		—			28,829
Income from discontinued operations, net of tax (2)	—		—		1,612			—		2,238			3,850
Capital additions	59,776		2,313		—			1,485		—			63,574

The following table reconciles total utility plant (a key figure for rate-making) to total consolidated assets (in thousands):

	September 30,
	2012		2011
Total utility plant	$	912,027	891,134
Other assets	377,611		304,714
Total consolidated assets	$	1,289,638	$	1,195,848

(1)Operating income (loss) include CCWC’s allocated corporate overhead costs that are now primarily at GSWC.

(2)In accordance with the accounting guidance relating to assets held for sale, Registrant did not record depreciation expense for CCWC in 2011.

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Contingencies:

9 Months Ended

Sep. 30, 2012

Contingencies:

Contingencies:

Note 8 — Contingencies:

Water Quality-Related Litigation:

Perchlorate and/or Volatile Organic Compounds (“VOC”) have been detected in certain wells servicing GSWC’s South San Gabriel System. GSWC filed suit in federal court, along with two other affected water purveyors and the San Gabriel Basin Water Quality Authority, together known as the “Water Entities”, against some of those allegedly responsible for the contamination of two of GSWC’s wells and those of the other affected water purveyors. In response to the filing of the lawsuit, the Potentially Responsible Party (“PRP”) defendants filed motions to dismiss the suit or strike certain portions of the suit. The judge issued a ruling on April 1, 2003 granting in part and denying in part the PRP’s motions. A key ruling of the court was that the water purveyors, including GSWC, by virtue of their ownership of wells contaminated with hazardous chemicals are themselves PRPs under the Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”).  GSWC has amended its suit to claim certain affirmative defenses as an “innocent” party under CERCLA. GSWC is presently unable to estimate a range of loss, if any, in the event that GSWC is deemed to be a PRP, or on GSWC’s ability to fully recover from the PRPs, past and future costs associated with the treatment of these wells.

On August 29, 2003, the US Environmental Protection Agency (“EPA”) issued Unilateral Administrative Orders (“UAO”) against 41 parties deemed responsible for polluting the groundwater in portions of the San Gabriel Valley from which those impacted GSWC wells draw water. GSWC was not named as a party to the UAO. The UAO requires these parties to remediate the contamination.

On October 12, 2004, the judge in the lawsuit stayed the matter in order to allow the parties to explore settlement and appointed a special master to oversee mandatory settlement discussions between the PRPs and the Water Entities. EPA has also conducted settlement discussions with several PRPs regarding the UAO. The Water Entities and EPA have worked closely to coordinate their settlement discussions under the auspices of the special master in order to arrive at a complete resolution of all issues affecting the lawsuit and the UAO. Settlements have been reached with a majority of the PRPs.

On March 28, 2011, the Court lifted the stay and the matter has proceeded in litigation. The EPA filed a separate complaint against the remaining PRPs and this matter was consolidated with those filed by the Water Entities.  Since October 17, 2011 several 30-day stays were granted to continue settlement discussions.  During these 30-day stays, EPA and the Water Entities have successfully reached settlements with most of the remaining PRPs.  On January 15, 2012, the stay was lifted and the case entered the discovery phase as settlement negotiations with the remaining few PRPs continued.  Registrant believes it will reach settlements with all the PRPs.  However, Registrant is presently unable to predict the ultimate outcome of this matter.

Condemnation of Properties:

The laws of the State of California provide for the acquisition of public utility property by governmental agencies through their power of eminent domain, also known as condemnation, where doing so is necessary and in the public interest. In addition, these laws provide: (i) that the owner of utility property may contest whether the condemnation is actually necessary and in the public interest, and (ii) that the owner is entitled to receive the fair market value of its property if the property is ultimately taken.

The City of Claremont (“Claremont”) located in GSWC’s Region III, has expressed various concerns to GSWC about rates charged by GSWC and the effectiveness of the CPUC’s rate-setting procedures. On January 5, 2012, the Claremont City council members directed staff to pursue analysis required for potential acquisition of the water system and allocated funds from its general reserve for such analysis. On June 27, 2012, Claremont notified GSWC of its intent to appraise the value of GSWC’s water system serving Claremont. Claremont’s City Council is currently reviewing its appraisal of GSWC’s water system in Claremont. GSWC serves approximately 11,000 customers in Claremont.

The Town of Apple Valley (the “Town”) had abandoned its activities related to a potential condemnation of GSWC’s water system serving the Town in 2007. However, in January 2011, the Town Council directed staff to update the previously prepared financial feasibility study for the acquisition of GSWC’s water systems. The Town also created a Blue Ribbon Water Commission (“BRWC”) to provide recommendations on the items pending before the CPUC associated with the water companies (including GSWC) serving the Town.  The BRWC recommended against acquisition at this time based on current economic conditions. The Town has not yet made a decision based on the recommendation.  GSWC’s Apple Valley water systems serve approximately 2,900 customers.

In April 2011, an organization called Ojai FLOW (Friends of Locally Owned Water) started a local campaign for the Casitas Municipal Water District to purchase GSWC’s Ojai water system. The Ojai City Council passed a resolution supporting the efforts of Ojai FLOW at their regular meeting on April 26, 2011. On July 25, 2012, the Casitas Municipal Water District hired a financial consultant to provide consulting services to the District for the establishment of a Community Facilities District (“CFD”) and the issuance of bonds within the CFD to provide funding for the potential acquisition of GSWC’s Ojai system.  GSWC serves approximately 3,000 customers in Ojai.

Except for the City of Claremont, Town of Apple Valley and the City of Ojai, Registrant is currently not involved in activities related to the potential condemnation of any of its water customer service areas or in its BVES customer service area. No formal condemnation proceedings have been filed against any of the Registrant’s service areas during the past three years.

Santa Maria Groundwater Basin Adjudication:

In 1997, the Santa Maria Valley Water Conservation District (“plaintiff”) filed a lawsuit against multiple defendants, including GSWC, the City of Santa Maria, and several other public water purveyors. The plaintiff’s lawsuit sought an adjudication of the Santa Maria Groundwater Basin (the “Basin”). A stipulated settlement of the lawsuit has been reached, subject to CPUC approval.  The settlement, among other things, if approved by the CPUC, would preserve GSWC’s historical pumping rights and secure supplemental water rights for use in case of drought or other reductions in the natural yield of the Basin. GSWC, under the stipulation, has a right to 10,000 acre-feet of groundwater replenishment provided by the Twitchell Project, a storage and flood control reservoir project operated by the Santa Maria Valley Conservation District.  A monitoring and annual reporting program has been established to allow the parties to responsibly manage the Basin and to respond to shortage conditions.  If severe water shortage conditions are found over a period of five years, the management area engineer will make findings and recommendations to alleviate such shortages.  If the Basin experiences severe shortage conditions, the court has the authority to limit GSWC’s groundwater production to 10,248 acre-feet per year, based on developed water in the Basin.  Over the last five years, GSWC’s average groundwater production has been 10,140 acre-feet per year.

On February 11, 2008, the court issued its final judgment, which approved and incorporated the stipulation.  The judgment awarded GSWC prescriptive rights to groundwater against the non-stipulating parties.  In addition, the judgment granted GSWC the right to use the Basin for temporary storage and to recapture 45 percent of the return flows that are generated from its importation of State Water Project water.  Pursuant to this judgment, the court retained jurisdiction over all of the parties to make supplemental orders or to amend the judgment as necessary.  On March 20, 2008, the non-stipulating parties filed notices of appeal.  In August 2010, the appellants filed their opening briefs, and oral arguments were heard on September 11, 2012.  Registrant is unable to predict the outcome of the appeal.

Environmental Clean-Up and Remediation:

Chadron Plant: GSWC has been involved in environmental remediation and clean-up at a plant site (“Chadron Plant”) that contained an underground storage tank which was used to store gasoline for its vehicles. This tank was removed in July 1990 along with the dispenser and ancillary piping. Since then, GSWC has been involved in various remediation activities at this site.  After many years of remediation activities, the majority of the leaked gasoline product has been removed.  However, a sheen of gasoline still remains at the top of the groundwater.  Additional groundwater remediation will be required before soil remediation can be commenced.  Management at this time cannot estimate when additional soil remediation will commence, due to the persistence of gasoline product in the groundwater.   As of September 30, 2012, the total spent to clean-up and remediate GSWC’s plant facility was approximately $3.5 million, of which $1.5 million has been paid by the State of California Underground Storage Tank Fund. Amounts paid by GSWC have been included in rate-base and approved by the CPUC for recovery.

As of September 30, 2012, GSWC has an accrued liability for the estimated additional cost of $1.2 million to complete the clean-up at the site. The ultimate cost may vary as there are many unknowns in remediation of underground gasoline spills and this is an estimate based on currently available information. Management also believes it is probable that the estimated additional costs will be approved in rate base by the CPUC and has recorded a corresponding regulatory asset.

Other Litigation:

Registrant is also subject to other ordinary routine litigation incidental to its business. Management believes that rate recovery, proper insurance coverage and reserves are in place to insure against property, professional and general liability and workers’ compensation claims incurred in the ordinary course of business. Registrant is unable to predict an estimate of the loss, if any, resulting from any pending suits or administrative proceedings, but does not believe the impact, if any, would be material.

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Discontinued Operations:

9 Months Ended

Sep. 30, 2012

Discontinued Operations:

Discontinued Operations:

Note 9 — Discontinued Operations:

On May 31, 2011, AWR sold CCWC to EPCOR Water (USA) Inc. for a total purchase price of $35.2 million, including the assumption of approximately $5.6 million of long-term debt. AWR received approximately $29.6 million in cash, which was primarily used to pay down short-term borrowings.  The completion of the sale generated a gain (net of taxes and transaction costs) of approximately $2.2 million during 2011.  A summary of discontinued operations presented in the consolidated statements of income for the three and nine months ended September 30, 2011 are as follows:

(dollars in thousands)	Three MonthsEnded September 30, 2011			Nine Months Ended September 30, 2011
Operating revenues	$	—		$	3,492
Operating expenses	—			660
Operating income	—			2,832
Interest expense, net	—			(142		)
Income before income taxes	—			2,690
Income tax expense	—			1,078
Income from the operations, net of tax	—			1,612
Gain on sale of business, net of tax	—			2,454
Transaction costs, net of tax	(18		)	(216		)
Net gain on sale and transaction costs	(18		)	2,238
Income (loss) from discontinued operations (1)	$	(18	)	$	3,850

(1)Corporate overhead costs allocated to CCWC have been excluded from discontinued operations and have been included in other operating expenses and administrative and general expenses as part of continuing operations as they continue to be incurred, primarily at GSWC.

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Summary of Significant Accounting Policies: (Policies)

9 Months Ended

Sep. 30, 2012

Summary of Significant Accounting Policies:

Nature of Operations and Basis of Presentation

Nature of Operations: American States Water Company (“AWR”) is the parent company of Golden State Water Company (“GSWC”) and American States Utility Services, Inc. (“ASUS”) (and its subsidiaries, Fort Bliss Water Services Company (“FBWS”), Terrapin Utility Services, Inc. (“TUS”), Old Dominion Utility Services, Inc. (“ODUS”), Palmetto State Utility Services, Inc. (“PSUS”) and Old North Utility Services, Inc. (“ONUS”)).  The subsidiaries of ASUS may be collectively referred to herein as the “Military Utility Privatization Subsidiaries.” AWR was also the parent company of Chaparral City Water Company (“CCWC”) until the sale of CCWC on May 31, 2011.

GSWC is a public utility engaged principally in the purchase, production, distribution and sale of water in California serving approximately 255,000 customers. GSWC also distributes electricity in several San Bernardino Mountain communities in California serving approximately 23,000 customers. The California Public Utilities Commission (“CPUC”) regulates GSWC’s water and electric businesses, including properties, rates, services, facilities and other matters, and transactions by GSWC with its affiliates.  AWR’s assets and operating income are primarily those of GSWC.

ASUS performs water and wastewater services, including the operation, maintenance, renewal and replacement of water and/or wastewater systems on a contract basis. Through its wholly owned subsidiaries, ASUS operates and maintains the water and/or wastewater systems at various military bases pursuant to 50-year firm, fixed-price contracts, which are subject to periodic price redeterminations and modifications for changes in circumstances, and changes in laws and regulations. There is no direct regulatory oversight by the CPUC over AWR or the operation, rates or services provided by ASUS or any of its wholly owned subsidiaries.

Basis of Presentation: The consolidated financial statements and notes thereto are being presented in a combined report being filed by two separate Registrants: AWR and GSWC. References in this report to “Registrant” are to AWR and GSWC, collectively, unless otherwise specified.  Certain prior period amounts have been reclassified to conform to the 2012 financial statement presentation.

The consolidated financial statements of AWR include the accounts of AWR and its subsidiaries, all of which are wholly owned. These financial statements are prepared in conformity with accounting principles generally accepted in the United States of America. Inter-company transactions and balances have been eliminated in the AWR consolidated financial statements. The operational results of CCWC for the periods presented are reported in discontinued operations, net of transaction costs.

The consolidated financial statements included herein have been prepared by Registrant, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”).  The December 31, 2011 condensed consolidated balance sheet data was derived from audited financial statements, but does not include all disclosures required by GAAP. The preparation of the consolidated financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. In the opinion of management, all adjustments, consisting of normal, recurring items and estimates necessary for a fair statement of the results for the interim periods, have been made. It is suggested that these consolidated financial statements be read in conjunction with the consolidated financial statements and the notes thereto included in the Form 10-K for the year ended December 31, 2011 filed with the SEC.

GSWC's Related Party Transactions:

GSWC’s Related Party Transactions: GSWC and ASUS provide and receive various services to and from their parent, AWR.  Any transactions between GSWC and AWR or ASUS are governed by the CPUC’s affiliate transaction rules.  In addition, AWR has a $100.0 million syndicated credit facility. AWR borrows under this facility and provides funds to its subsidiaries, including GSWC, in support of their operations. Any amounts owed to AWR for borrowings under this facility are included in inter-company payables on GSWC’s balance sheet. The interest rate charged to GSWC and other affiliates is sufficient to cover AWR’s interest cost under the credit facility. GSWC also allocates certain corporate office administrative and general costs to its affiliate, ASUS, using allocation factors mandated by the CPUC.  Through May 31, 2011, GSWC also allocated costs to CCWC.

Long-Term Debt:

Long-Term Debt:  On October 1, 2012, GSWC redeemed its $8,000,000, 7.55% Medium-Term Notes, Series B.  The Notes, which were due 2025, were redeemed at a price of 101.133% of the outstanding principal amount of the Notes, plus accrued and unpaid interest through October 1, 2012, for a total redemption price of $8.3 million.

Sales and Use Taxes:

Sales and Use Taxes:  GSWC bills certain sales and use taxes levied by state or local governments to its customers. Included in these sales and use taxes are franchise fees, which GSWC pays to various municipalities (based on ordinances adopted by these municipalities) in order to use public right of way for utility purposes. GSWC bills these franchise fees to its customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of GSWC’s ability to collect from the customer, are accounted for on a gross basis. GSWC’s franchise fees billed to customers and recorded as operating revenue were approximately $966,000 and $942,000 for the three months ended September 30, 2012 and 2011, respectively, and $2,600,000 and $2,423,000 for the nine months ended September 30, 2012 and 2011, respectively. When GSWC acts as an agent, and the tax is not required to be remitted if it is not collected from the customer, the taxes are accounted for on a net basis.

Depending on the state in which the operations are conducted, ASUS and its subsidiaries are also subject to certain state non-income tax assessments generally computed on a “gross receipts” or “gross revenues” basis.  These non-income tax assessments are required to be paid regardless of whether the subsidiary is reimbursed by the U.S. government for these assessments under its 50-year contracts with the U.S. government.  The non-income tax assessments are accounted for on a gross basis and totaled $222,000 and $168,000 during the three months ended September 30, 2012 and 2011, respectively, and $563,000 and $533,000 for the nine months ended September 30, 2012 and 2011, respectively.

Recently Adopted Accounting Pronouncements:

Recently Adopted Accounting Pronouncements:  The following accounting standards did not or are not expected to have any impact on Registrant’s consolidated financial statements:

Accounting Standards Update No. 2011-05, Comprehensive Income (Topic 220): Presentation of Comprehensive Income (“ASU 2011-05”). Under ASU 2011-05, an entity has the option to present the total of comprehensive income, the components of net income, and the components of other comprehensive income either in a single continuous statement of comprehensive income or in two separate but consecutive statements. Under both options, an entity will be required to present each component of net income along with total net income, each component of other comprehensive income along with a total for other comprehensive income, and a total amount for comprehensive income.  ASU 2011-05 is effective for fiscal years beginning on or after December 15, 2011 and did not have a material impact on Registrant’s consolidated financial statements.

Accounting Standards Update No. 2011-08, Intangibles - Goodwill and Other (Topic 350): Testing Goodwill for Impairment (“ASU 2011-08”). Under ASU 2011-08, an entity has the option to first assess qualitative factors to determine whether the existence of events or circumstances leads to a determination that it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If, after assessing the totality of events or circumstances, an entity determines it is not more likely than not that the fair value of a reporting unit is less than its carrying amount, performing the two-step impairment test is not required. The guidance does not change how an entity measures a goodwill impairment loss, and is therefore not expected to affect the information reported to users of an entity’s financial statements.  The adoption of this update is not expected to have a significant impact on its results of operations, financial position or cash flows.

In December 2011, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2011-11, Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities (“ASU 2011-11”). The ASU 2011-11 amendments require companies to disclose information about offsetting and related arrangements to enable users of its financial statements to understand the effect of those arrangements on its financial position. ASU 2011-11 is required to be applied retrospectively for all prior periods presented and is effective for annual periods for fiscal years beginning on or after January 1, 2013, and interim periods within those annual fiscal years. Registrant does not expect adoption of this standard to have a material impact on its consolidated results of operations and financial condition.

Other accounting standards that have been issued by the FASB or other standards-setting bodies that do not require adoption until a future date are not expected to have a material impact on Registrant’s consolidated financial statements upon adoption.

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Employee Benefit Plans: (Tables)

9 Months Ended

Sep. 30, 2012

Employee Benefit Plans:

Schedule of components of net periodic benefit costs, before allocation to the overhead pool, for Registrant's pension plan, postretirement plan, and SERP

	For The Three Months Ended September 30,
	Pension Benefits						Other Postretirement Benefits						SERP
(dollars in thousands)	2012			2011			2012			2011			2012		2011
Components of Net Periodic Benefits Cost:
Service cost	$	1,670		$	1,406		$	112		$	107		$	183	$	150
Interest cost	1,663			1,631			136			153			122		116
Expected return on plan assets	(1,634		)	(1,587		)	(90		)	(74		)	—		—
Amortization of transition	—			—			105			105			—		—
Amortization of prior service cost (benefit)	31			30			(50		)	(50		)	40		40
Amortization of actuarial loss	759			310			—			—			77		34
Net periodic pension cost under accounting standards	2,489			1,790			213			241			422		340
Regulatory adjustment — deferred (1)	(596		)	(127		)	—			—			—		—
Total expense recognized, before allocation to overhead pool	$	1,893		$	1,663		$	213		$	241		$	422	$	340

	For The Nine Months Ended September 30,
	Pension Benefits						Other Postretirement Benefits						SERP
(dollars in thousands)	2012			2011			2012			2011			2012		2011
Components of Net Periodic Benefits Cost:
Service cost	$	5,007		$	4,218		$	336		$	321		$	549	$	450
Interest cost	4,992			4,893			408			459			366		348
Expected return on plan assets	(4,905		)	(4,761		)	(270		)	(221		)	—		—
Amortization of transition	—			—			315			315			—		—
Amortization of prior service cost (benefit)	90			89			(150		)	(150		)	120		121
Amortization of actuarial loss	2,277			931			—			—			231		101
Net periodic pension cost under accounting standards	7,461			5,370			639			724			1,266		1,020
Regulatory adjustment — deferred (1)	(1,794		)	(380		)	—			—			—		—
Total expense recognized, before allocation to overhead pool	$	5,667		$	4,990		$	639		$	724		$	1,266	$	1,020

(1)Regulatory Adjustment - In November 2010, the CPUC authorized GSWC to establish a two-way balancing account, effective January 1, 2010, to track differences between the forecasted annual pension expenses adopted in rates and the actual annual expense to be recorded by GSWC in accordance with the accounting guidance for pension costs.  As of September 30, 2012, GSWC has included a $3.7 million under-collection in the two-way pension balancing account recorded as a regulatory asset (Note 2).

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Earnings per Share/Capital Stock: (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Basic
Net income from continuing operations	$ 18,664,000	$ 15,617,000	$ 43,857,000	$ 35,300,000
Net income (loss) from discontinued operations		(18,000)		3,850,000
Net Income	18,664,000	15,599,000	43,857,000	39,150,000
Less: Distributed earnings to common shareholders	6,766,000	5,236,000	17,316,000	15,311,000
Less: Distributed earnings to participating securities	52,000	38,000	119,000	102,000
Undistributed earnings	11,846,000	10,325,000	26,422,000	23,737,000
Undistributed earnings allocated to common shareholders	11,755,000	10,250,000	26,242,000	23,580,000
Undistributed earnings allocated to participating securities	91,000	75,000	180,000	157,000
Total income available to common shareholders, basic	18,521,000	15,486,000	43,558,000	38,891,000
Weighted average Common Shares outstanding, basic	19,059,000	18,701,000	18,924,000	18,672,000
Basic earnings per Common Share:
Income from continuing operations (in dollars per share)	$ 0.97	$ 0.83	$ 2.30	$ 1.88
Income (loss) from discontinued operations (in dollars per share)				$ 0.20
Net Income (in dollars per share)	$ 0.97	$ 0.83	$ 2.30	$ 2.08
Stock option and restricted stock option outstanding
Options outstanding (in shares)	226,208	668,360	226,208	668,360
Diluted
Common shareholders earnings, basic	18,521,000	15,486,000	43,558,000	38,891,000
Undistributed earnings for dilutive stock options		75,000	180,000	157,000
Total common shareholders earnings, diluted	18,521,000	15,561,000	43,738,000	39,048,000
Weighted average Common Shares outstanding, basic	19,059,000	18,701,000	18,924,000	18,672,000
Stock-based compensation (in shares)	44,000	151,000	114,000	144,000
Weighted average common shares outstanding, diluted	19,103,000	18,852,000	19,038,000	18,816,000
Diluted earnings per Common Share:
Income from continuing operations (in dollars per share)	$ 0.97	$ 0.83	$ 2.30	$ 1.88
Income (loss) from discontinued operations (in dollars per share)				$ 0.20
Net Income (in dollars per share)	$ 0.97	$ 0.83	$ 2.30	$ 2.08
Additional disclosure
Stock options included in the calculation of diluted EPS (in shares)			182,932	425,839
Stock options not included in the calculation of diluted EPS (in shares)	43,276	241,921	43,276	241,921
Anti-dilutive stock options not included in the computation of diluted EPS (in shares)				600
Common Shares issued under Common Share Purchase and Dividend Reinvestment Plan, the 401(k) Plan, and the stock incentive plans			423,590	100,148
Value of Common Shares issued under Common Share Purchase and Dividend Reinvestment Plan, the 401(k) Plan, and the stock incentive plans			12,434,000	2,350,000
Common Shares purchased on the open market under 401(k) Plan and the Common Share Purchase and Dividend Reinvestment Plan			571,652	319,470
Quarterly dividends paid	$ 6,700,000	$ 5,200,000	$ 17,307,000	$ 15,306,000
Quarterly dividends paid, per share of common stock (in dollars per share)	$ 0.355	$ 0.28	$ 0.915	$ 0.82
Restricted Stock Units Member
Share based compensation arrangement
Restricted stock units outstanding (in shares)	148,176	136,703	148,176	136,703

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CONSOLIDATED STATEMENTS OF CASH FLOW (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011
Cash Flows From Operating Activities:
Net income	$ 43,857	$ 39,150
Adjustments to reconcile net income to net cash provided by operating activities:
Gain on sale of CCWC, net of taxes, included in discontinued operations		(2,454)
Depreciation and amortization	31,127	28,829
Provision for doubtful accounts	1,313	776
Deferred income taxes and investment tax credits	4,735	4,317
Stock-based compensation expense	1,477	1,245
Other - net	(359)	1,179
Changes in assets and liabilities:
Accounts receivable - customers	(9,664)	(8,241)
Unbilled revenue	(5,638)	(1,844)
Other accounts receivable	3,967	(3,354)
Receivable from the U.S. government	5,530	(6,732)
Materials and supplies	(3,508)	(656)
Prepayments and other current assets	(1,421)	1,261
Regulatory assets - supply cost balancing accounts	9,560	14,374
Costs and estimated earnings in excess of billings on uncompleted contracts	(2,046)	4,163
Other assets (including other regulatory assets)	(17,698)	(16,545)
Accounts payable	12,981	2,075
Income taxes receivable/payable	21,294	(2,816)
Billings in excess of costs and estimated earnings on uncompleted contracts	(10,899)	4,569
Accrued pension and other postretirement benefits	3,079	(2,351)
Other liabilities	3,892	5,692
Net cash provided	91,579	62,637
Cash Flows From Investing Activities:
Construction expenditures	(48,169)	(63,574)
Proceeds from the sale of CCWC		29,603
Other	69	(72)
Net cash used	(48,100)	(34,043)
Cash Flows From Financing Activities:
Proceeds from issuance of Common Shares and stock option exercises	12,434	2,350
Receipt of advances for and contributions in aid of construction	5,101	6,149
Refunds on advances for construction	(3,216)	(3,843)
Repayments of long-term debt	(294)	(22,304)
Proceeds from issuance of long-term debt, net of issuance costs	4,034	61,911
Net change in notes payable to banks	(2,000)	(56,400)
Dividends paid	(17,307)	(15,306)
Other - net	(480)	(133)
Net cash (used) provided	(1,728)	(27,576)
Net increase (decrease) in cash and cash equivalents	41,751	1,018
Cash and cash equivalents, beginning of period	1,315	4,197
Cash and cash equivalents, end of period	43,066	5,215
GOLDEN STATE WATER COMPANY
Cash Flows From Operating Activities:
Net income	33,315	29,435
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	30,283	28,171
Provision for doubtful accounts	1,271	697
Deferred income taxes and investment tax credits	4,725	4,460
Stock-based compensation expense	1,241	1,099
Other - net	(389)	800
Changes in assets and liabilities:
Accounts receivable - customers	(9,664)	(8,241)
Unbilled revenue	(5,638)	(1,844)
Other accounts receivable	1,222	111
Materials and supplies	(531)	(197)
Prepayments and other current assets	(1,348)	995
Regulatory assets - supply cost balancing accounts	9,560	14,374
Other assets (including other regulatory assets)	(17,612)	(16,571)
Accounts payable	3,945	3,752
Inter-company receivable/payable	(545)	452
Income taxes receivable/payable from/to Parent	20,782	(1,977)
Accrued pension and other postretirement benefits	3,079	(2,351)
Other liabilities	3,985	5,798
Net cash provided	77,681	58,963
Cash Flows From Investing Activities:
Construction expenditures	(47,230)	(62,089)
Proceeds from sale of property	65	144
Net cash used	(47,165)	(61,945)
Cash Flows From Financing Activities:
Receipt of advances for and contributions in aid of construction	5,101	6,149
Refunds on advances for construction	(3,216)	(3,843)
Repayments of long-term debt	(294)	(22,304)
Proceeds from issuance of long-term debt, net of issuance costs	4,034	61,911
Net change in inter-company borrowings		(23,381)
Dividends paid	(10,200)	(15,000)
Other - net	(389)	(78)
Net cash (used) provided	(4,964)	3,454
Net increase (decrease) in cash and cash equivalents	25,552	472
Cash and cash equivalents, beginning of period		1,541
Cash and cash equivalents, end of period	$ 25,552	$ 2,013

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Fair Value of Financial Instruments:

9 Months Ended

Sep. 30, 2012

Fair Value of Financial Instruments:

Fair Value of Financial Instruments:

Note 5 — Fair Value of Financial Instruments:

For cash and cash equivalents, accounts receivable, accounts payable and short-term debt, the carrying amount is assumed to approximate fair value due to the short-term nature of the amounts. The table below estimates the fair value of long-term debt held by GSWC. Rates available to GSWC at September 30, 2012 and December 31, 2011 for debt with similar terms and remaining maturities were used to estimate fair value for long-term debt. The interest rates used for the September 30, 2012 valuation decreased as compared to December 31, 2011, increasing the fair value of long-term debt as of September 30, 2012. Changes in the assumptions will produce differing results.

	September 30, 2012				December 31, 2011
(dollars in thousands)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Financial liabilities:
Long-term debt—GSWC	$	344,426	$	469,065	$	340,686	$	437,275

As previously discussed in Note 4, the accounting guidance for fair value measurements establishes a framework for measuring fair value and requires fair value measurements to be classified and disclosed in one of three levels. Publicly issued notes are measured using current U.S. corporate bond yields available for similar financial instruments and are classified as Level 1.  Private placement notes and other long-term debt are measured using current U.S. corporate bond yields for similar debt instruments and are classified as Level 2. The following tables set forth by level, within the fair value hierarchy, GSWC’s long-term debt measured at fair value as of September 30, 2012:

(dollars in thousands)	Level 1		Level 2		Level 3	Total
Long-term debt—GSWC	$	295,778	$	173,287	—	$	469,065

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Derivative Instruments: (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012 item	Sep. 30, 2011
Derivative instruments
Regulatory asset not accruing carrying costs	$ 77,700,000		$ 77,700,000
Purchase power contract
Derivative instruments
Number of broker quotes received in order to determine the fair value of derivative instrument			1
GSWC | Purchase power contract
Derivative instruments
Number of megawatts of base load energy that the entity will be able to purchase under the new agreement			12
Changes in the fair value of the derivative
Balance, at beginning of the period	(5,176,000)	(7,475,000)	(7,611,000)	(6,850,000)
Unrealized gain (loss) on purchased power contracts	2,457,000	(101,000)	4,892,000	(726,000)
Balance, at end of the period	(2,719,000)	(7,576,000)	(2,719,000)	(7,576,000)
GSWC | Purchase power contract | Maximum
Derivative instruments
Megawatts per hour daily during winter peak months that the entity has an option to purchase as one of the products under the purchase power contract			15
Megawatts per hour daily during nonpeak months that the entity has an option to purchase as one of the products under the purchase power contract			5
Memorandum account to track unrealized gains and losses on purchase power contracts
Derivative instruments
Regulatory asset not accruing carrying costs	$ 2,700,000		$ 2,700,000

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Fair Value of Financial Instruments: (Tables) (GSWC)

9 Months Ended

Sep. 30, 2012

GSWC

Fair value of financial instruments

Schedule of estimates of the fair value of long-term debt

	September 30, 2012				December 31, 2011
(dollars in thousands)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Financial liabilities:
Long-term debt—GSWC	$	344,426	$	469,065	$	340,686	$	437,275

Schedule of long-term debt measured at fair value

(dollars in thousands)	Level 1		Level 2		Level 3	Total
Long-term debt—GSWC	$	295,778	$	173,287	—	$	469,065