10-K

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TABLE OF CONTENTS

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

Form 10-K

ý	ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 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 No. 1-13883

CALIFORNIA WATER SERVICE GROUP
(Exact name of registrant as specified in its charter)

Delaware (State or Other Jurisdiction of Incorporation or Organization)	77-0448994 (I.R.S. Employer Identification No.)
1720 North First Street,
San Jose, California (Address of Principal Executive Offices)	95112 (Zip Code)

(408) 367-8200
(Registrant's Telephone Number, including Area Code)

         Securities registered pursuant to Section 12(b) of the Act:

Title of Each Class:	Name of Each Exchange on Which Registered:
Common Stock, $0.01 par value per share	New York Stock Exchange

         Securities registered pursuant to Section 12(g) of the Act: None

         Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ý    No o

         Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 of Section 15(d) of the Act. Yes o    No ý

         Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the Registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ý    No o

         Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232,405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ý    No o

         Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. 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 the definitions of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer ý Accelerated filer o Non-accelerated filer o
(Do not check if a
smaller reporting company) Smaller reporting company o

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

         The aggregate market value of the voting and non-voting common stock held by non-affiliates of the registrant was $774 million on June 30, 2012, the last business day of the registrant's most recently completed second fiscal quarter. The valuation is based on the closing price of the registrant's common stock as traded on the New York Stock Exchange.

         Common stock outstanding at February 11, 2013, 41,908,218 shares.

DOCUMENTS INCORPORATED BY REFERENCE

         Portions of the definitive proxy statement for the California Water Service Group 2012 Annual Meeting are incorporated by reference into Part III hereof.

TABLE OF CONTENTS

		Page
PART I
Item 1.	Business		4
	Forward-Looking Statements		4
	Overview		5
	Regulated Business		6
	Non-Regulated Businesses		7
	Operating Segment		9
	Growth		9
	Geographical Service Areas and Number of Customers at Year-end		9
	Rates and Regulation		10
	Water Supply		16
	Seasonal Fluctuations		19
	Utility Plant Construction		19
	Sale of Surplus Real Properties		19
	Energy Reliability		20
	Impact of Climate Change Legislation		20
	Security at Company Facilities		20
	Quality of Water Supply		21
	Competition and Condemnation		21
	Environmental Matters		21
	Employees		22
	Executive Officers of the Registrant		22
Item 1A.	Risk Factors		25
Item 1B.	Unresolved Staff Comments		39
Item 2.	Properties		39
Item 3.	Legal Proceedings		39
Item 4.	Mine Safety Disclosures		39
PART II
Item 5.	Market for Registrant's Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities		40
Item 6.	Selected Financial Data		41
Item 7.	Management's Discussion and Analysis of Financial Condition and Results of Operations		43
	Overview		43
	Critical Accounting Policies and Estimates		43
	Results of Operations		47
	Rates and Regulation		53
	Water Supply		53
	Liquidity and Capital Resources		54
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk		60
Item 8.	Financial Statements and Supplementary Data		61
Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure		103
Item 9A.	Controls and Procedures		103
Item 9B.	Other Information		103

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		Page
PART III
Item 10.	Directors and Executive Officers and Corporate Governance		104
Item 11.	Executive Compensation		104
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters		104
Item 13.	Certain Relationships and Related Transactions and Director Independence		105
Item 14.	Principal Accountant Fees and Services		105
PART IV
Item 15.	Exhibits, Financial Statement Schedules		105
	Signatures		106
	Exhibit Index		108

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PART I

Item 1.    Business.

Forward-Looking Statements

        This annual report, including all documents incorporated by reference, contains forward-looking statements within the meaning established by the Private Securities Litigation Reform Act of 1995. Forward-looking statements in this annual report are based on currently available information, expectations, estimates, assumptions and projections, and our management's beliefs, assumptions, judgments and expectations about us, the water utility industry and general economic conditions. These statements are not statements of historical fact. When used in our documents, statements that are not historical in nature, including words like "expects," "intends," "plans," "believes," "may," "estimates," "assumes," "anticipates," "projects," "predicts," "forecasts," "should," "seeks," or variations of these words or similar expressions are intended to identify forward-looking statements. The forward- looking statements are not guarantees of future performance. They are based on numerous assumptions that we believe are reasonable, but they are open to a wide range of uncertainties and business risks. Consequently, actual results may vary materially from what is contained in a forward-looking statement.

        Factors which may cause actual results to be different than those expected or anticipated include, but are not limited to:

•

governmental and regulatory commissions' decisions, including decisions on proper disposition of property;

•

changes in regulatory commissions' policies and procedures;

•

the timeliness of regulatory commissions' actions concerning rate relief;

•

changes in the capital markets and access to sufficient capital on satisfactory terms;

•

new legislation;

•

changes in accounting valuations and estimates;

•

changes in accounting treatment for regulated companies, including adoption of International Financial Reporting Standards, if required;

•

electric power interruptions;

•

increases in suppliers' prices and the availability of supplies including water and power;

•

fluctuations in interest rates;

•

changes in environmental compliance and water quality requirements;

•

litigation that may result in damages or costs not recoverable from third parties;

•

acquisitions and the ability to successfully integrate acquired companies;

•

the ability to successfully implement business plans;

•

civil disturbances or terrorist threats or acts, or apprehension about the possible future occurrences of acts of this type;

•

the involvement of the United States in war or other hostilities;

•

our ability to attract and retain qualified employees;

•

labor relations matters as we negotiate with the unions;

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•

federal health care law changes that could result in increases to Company health care costs and additional income tax expenses in future years;

•

changes in federal and state income tax regulations and treatment of such by regulatory commissions;

•

implementation of new information technology systems;

•

changes in operations that result in an impairment to acquisition goodwill;

•

restrictive covenants in or changes to the credit ratings on current or future debt that could increase financing costs or affect the ability to borrow, make payments on debt, or pay dividends;

•

general economic conditions, including changes in customer growth patterns and our ability to collect billed revenue from customers;

•

changes in customer water use patterns and the effects of conservation;

•

the impact of weather on water sales and operating results;

•

the ability to satisfy requirements related to the Sarbanes-Oxley and Dodd-Frank Acts and other regulations on internal controls; and

•

the risks set forth in "Risk Factors" included elsewhere in this annual report.

        In light of these risks, uncertainties and assumptions, investors are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date of this annual report or as of the date of any document incorporated by reference in this annual report, as applicable. When considering forward-looking statements, investors should keep in mind the cautionary statements in this annual report and the documents incorporated by reference. We are not under any obligation, and we expressly disclaim any obligation, to update or alter any forward-looking statements, whether as a result of new information, future events or otherwise.

Overview

        California Water Service Group is a holding company incorporated in Delaware with six operating subsidiaries: California Water Service Company (Cal Water), New Mexico Water Service Company (New Mexico Water), Washington Water Service Company (Washington Water), Hawaii Water Service Company, Inc. (Hawaii Water), and CWS Utility Services and HWS Utility Services LLC (CWS Utility Services and HWS Utility Services LLC being referred to collectively in this annual report as Utility Services). Cal Water, New Mexico Water, Washington Water, and Hawaii Water are regulated public utilities. The regulated utility entities also provide some non-regulated services. Utility Services provides non-regulated services to private companies and municipalities. Cal Water was the original operating company and began operations in 1926.

        Our business is conducted through our operating subsidiaries. The bulk of the business consists of the production, purchase, storage, treatment, testing, distribution and sale of water for domestic, industrial, public and irrigation uses, and for fire protection. We also provide non-regulated water-related services under agreements with municipalities and other private companies. The non-regulated services include full water system operation, billing and meter reading services. Non-regulated operations also include the lease of communication antenna sites, lab services, and promotion of other non-regulated services. Earnings may be significantly affected by the sale of surplus real properties if and when they occur.

        During the year ended December 31, 2012, there were no significant changes in the kind of products produced or services rendered or those provided by our operating subsidiaries, or in the markets or methods of distribution.

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        Our mailing address and contact information is:

California Water Service Group
1720 North First Street
San Jose, California 95112-4598
telephone number: 408-367-8200
www.calwatergroup.com

        Annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to these reports are available free of charge through our website. The reports are available on our website as soon as reasonably practicable after such reports are filed with the SEC.

Regulated Business

        California water operations are conducted by the Cal Water and CWS Utility Services entities, which provide service to approximately 473,100 customers in 83 California communities through 25 separate districts. Of these 25 districts, 23 districts are regulated water systems, which are subject to regulation by the California Public Utilities Commission (CPUC). Cal Water operates two leased water systems, the City of Hawthorne and the City of Commerce, which are governed through their respective city councils and are outside of the CPUC's jurisdiction. California water operations account for approximately 94% of our total customers and approximately 94% of our total consolidated operating revenue.

        Hawaii Water provides service to approximately 4,200 water and wastewater customers on the islands of Maui and Hawaii, including several large resorts and condominium complexes. Hawaii's regulated operations are subject to the jurisdiction of the Hawaii Public Utilities Commission. Hawaii Water accounts for less than 1% of our total customers and approximately 3% of our total operating revenue. HWS Utility Services LLC was organized in 2007 and began non-regulated operations in January 2008.

        Washington Water provides domestic water service to approximately 15,800 customers in the Tacoma and Olympia areas. Washington Water's utility operations are regulated by the Washington Utilities and Transportation Commission. Washington Water accounts for approximately 3% of our total customers and approximately 2% of our total consolidated operating revenue.

        New Mexico Water provides service to approximately 7,600 water and wastewater customers in the Belen, Los Lunas and Elephant Butte areas in New Mexico. New Mexico's regulated operations are subject to the jurisdiction of the New Mexico Public Regulation Commission. New Mexico Water accounts for approximately 2% of our total customers and approximately 1% of our total consolidated operating revenue.

        The state regulatory bodies governing our regulated operations are referred to as the Commissions in this annual report. Rates and operations for regulated customers are subject to the jurisdiction of the respective state's regulatory commission. The Commissions require that water and wastewater rates for each regulated district be independently determined based on the cost of service. The Commissions are expected to authorize rates sufficient to recover normal operating expenses and allow the utility to earn a fair and reasonable return on invested capital.

        We distribute water in accordance with accepted water utility methods. Where applicable, we hold franchises and permits in the cities and communities where we operate. The franchises and permits allow us to operate and maintain facilities in public streets and right- of-ways as necessary.

        We operate the City of Hawthorne and the City of Commerce water systems under lease agreements. In accordance with the lease agreements, we receive all revenues from operating the systems and are responsible for paying the operating costs. The revenues and expenses for leased water systems are included in operating revenues and expenses. Rates for the City of Hawthorne and City of Commerce water systems are established in accordance with operating agreements and are subject to ratification by

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the respective city councils. The terms of other operating agreements range from one-year to three-year periods with provisions for renewals.

        In February 2011, our lease agreement for the operation of the City of Hawthorne water system expired. At the end of the lease term, the City of Hawthorne credited Cal Water $6.5 million for net capital improvements that we made to the City of Hawthorne's water system. Following the expiration of the lease agreement, we continued to operate the City of Hawthorne's water system on a month-to-month basis until October 2011, when we entered into a new 15-year capital lease agreement to operate the City of Hawthorne water system. The system, which is located near the Hermosa-Redondo district, serves about half of Hawthorne's population. The new lease agreement required us to make an up-front $8.1 million lease deposit to the city that is being amortized over the lease term. Additionally, annual lease payments of $0.9 million are made to the city and shall be increased or decreased each year on July 1, by the same percentage that the rates charged to customers served by the water system increased or decreased, exclusive of pass-through increases or decreases in the cost of water, power, and city-imposed fees, compared to the rates in effect on July 1 of the prior year, provided, that in no event will the annual lease payment be less than $0.9 million. Under the lease we are responsible for all aspects of system operation and capital improvements, although title to the system and system improvements reside with the city. Capital improvements are recorded as depreciable plant and equipment and depreciated per the asset lives set forth in the agreement. In exchange, we receive all revenue from the water system, which was $7.6 million, $7.5 million and $7.5 million in 2012, 2011, and 2010, respectively. At the end of the lease, the city is required to reimburse us for the unamortized value of capital improvements made during the term of the lease.

        In July 2003, an agreement was negotiated with the City of Commerce to lease and operate its water system. The lease requires us to pay $0.8 million per year in monthly installments and pay $200 per acre-foot for water usage exceeding 2,000 acre-feet per year plus a percentage of certain operational savings that may be realized. Under the lease agreement, we are responsible for all aspects of the system's operations. The city is responsible for capital expenditures, and title to the system and system improvements resides with the city. We bear the risks of operation and collection of amounts billed to customers. The agreement includes a procedure to request rate changes for cost changes outside of our control and other cost changes. In exchange, we receive all revenue from the system, which totaled $1.9 million in 2012 and $1.8 million in 2011 and 2010. The City of Commerce lease is a 15-year lease and expires in 2018.

        The City of Hawthorne and the City of Commerce lease revenues are governed through their respective city councils and are considered non-regulated because they are outside of the CPUC's jurisdiction. We report revenue and expenses for the City of Hawthorne and City of Commerce leases in operating revenues and operating expenses because we are entitled to retain all customer billings and are generally responsible for all operating expenses.

Non-Regulated Businesses

        Fees for non-regulated activities are based on contracts negotiated between the parties. Under other non-regulated contract arrangements, we operate municipally owned water systems, privately owned water systems, and recycled water distribution systems, but are not responsible for all operating costs. Non-regulated revenue received from water system operations is generally determined on a fee-per-customer basis.

        Non-regulated activities consist primarily of:

•

operating water and waste water systems, which are owned by other entities;

•

providing meter reading and billing services;

•

leasing communication antenna sites on our properties;

7

•

operating recycled water systems;

•

providing lab services for water quality testing;

•

billing of optional third-party insurance programs to our residential customers;

•

selling surplus property; and

•

other services as requested by the client.

        The revenues and expenses for leased water systems are included in operating revenues and operating expenses. All other non-regulated revenues and expenses are reported below net operating income on the income statement. Due to the variety of services provided and activities being outside of our core business, the number of customers is not tracked for these non-regulated activities, except customers for the City of Hawthorne and the City of Commerce. Effective June 30, 2011, the CPUC adopted new rules surrounding provision of unregulated services using utility assets and employees. As a result, nearly all California unregulated activities are now considered "nontariffed products and services (NTPS)." The prescribed accounting for these NTPS is incremental cost allocation plus revenue sharing with rate payers. Non-regulated services determined to be "active activities" require a 10% revenue sharing and "passive activities" require a 30% revenue sharing. The amount of non-regulated revenues subject to revenue sharing is the total billed revenues less any authorized pass through costs. Some examples of CPUC authorized pass through costs are purchased water, purchased power, and pump taxes. All of the non-regulated services listed above, except property leases, are "active activities" subject to a 10% revenue sharing. Property leases are "passive activities" subject to a 30% revenue sharing. The 2012 revenue sharing was $2.3 million. Any significant change in revenue sharing due to the new rules will be reflected in adopted rates after the next general rate case and will be accompanied by a change from full-cost allocation to incremental-cost allocation.

        We provide operating and maintenance, meter reading and customer billing services for several municipalities in California. We also provide sewer and refuse billing services to several municipalities. Revenues for these services were $11.2 million, $10.4 million, and $10.4 million in 2012, 2011, and 2010, respectively.

        We lease antenna sites to telecommunication companies, which place equipment at various Company-owned sites. Lease revenues totaled $2.0 million, $1.9 million, and $2.2 million in 2012, 2011 and 2010, respectively. The antennas are used in cellular phone and personal communication applications. We continue to negotiate new leases for similar uses.

        In 2006, we started an Extended Service Protection program (ESP) in California covering certain repairs to residential customer's water line between the meter and the home. The non-regulated program was operated by CWS Utility Services. Typically the utility is responsible for servicing and maintaining the water line up to and including the meter. The home owner is responsible for the water line from the meter to the house. In late 2007, we contracted with Home Service USA to replace the ESP program with an insurance product. Home Service USA now provides water line protection insurance, sewer line protection insurance, and internal plumbing protection insurance to Cal Water's customers who request it. Cal Water includes charges for these optional non-tariffed services on its bills. Revenues for these services were $2.0 million in 2012, 2011, and 2010. In September 2011 as part of a settlement with the Division of Ratepayer Advocates, we proposed to the CPUC a rate payer refund of $2.1 million relating to the ESP program sale proceeds as of December 31, 2012. The proposed settlement resolves the last open issue with the Division of Ratepayer Advocates regarding the revenue sharing with rate payers. The proposed settlement reduced 2011 operating revenues and was recorded as a regulatory liability on the balance sheet as of December 31, 2012.

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Operating Segment

        We operate in one reportable segment, the supply and distribution of water and providing water-related utility services.

Growth

        We intend to continue exploring opportunities to expand our regulated and non-regulated water and wastewater businesses in the western United States. The opportunities could include system acquisitions, lease arrangements similar to the City of Hawthorne and City of Commerce contracts, full service system operation and maintenance agreements, meter reading, billing contracts and other utility-related services. Management believes that a holding company structure facilitates providing non-regulated utility services, which are not subject to any Commission's jurisdiction.

Geographical Service Areas and Number of Customers at Year-end

        Our principal markets are users of water within our service areas. Most of the geographical service areas are regulated; however, the City of Hawthorne and City of Commerce are included due to similarities in structure and risk of operations. The approximate number of customers served in each district is as follows:

        Regulated Customers, City of Hawthorne and City of Commerce Customers at December 31, (rounded to the nearest hundred)

	2012		2011
SAN FRANCISCO BAY AREA
Bayshore (serving South San Francisco, Colma, Broadmoor, San Mateo and San Carlos)		53,200		53,300
Bear Gulch (serving portions of Menlo Park, Atherton, Woodside and Portola Valley)		18,800		18,800
Los Altos (including portions of Cupertino, Los Altos Hills, Mountain View and Sunnyvale)		18,400		18,800
Livermore		18,800		18,300
		109,200		109,200
SACRAMENTO VALLEY
Chico (including Hamilton City)		28,100		28,000
Oroville		3,500		3,600
Marysville		3,700		3,700
Dixon		2,900		2,900
Willows		2,400		2,400
		40,600		40,600
NORTH COAST
Redwood Valley (Lucerne, Duncans Mills, Guerneville, Dillon Beach, Noel Heights & portions of Santa Rosa)		1,900		1,900
		1,900		1,900
SALINAS VALLEY
Salinas		28,300		28,200
King City		2,500		2,600
		30,800		30,800

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	2012		2011
SAN JOAQUIN VALLEY
Bakersfield		69,100		68,500
Stockton		42,700		42,800
Visalia		41,200		40,700
Selma		6,200		6,100
Kern River Valley		4,200		4,200
		163,400		162,300
LOS ANGELES AREA
East Los Angeles (including portions of the City of Commerce service area)		26,700		26,700
Hermosa-Redondo (serving Hermosa Beach, Redondo Beach and a portion of Torrance)		26,700		26,600
Dominguez (Carson and portions of Compton, Harbor City, Long Beach, Los Angeles and Torrance)		33,900		33,800
Palos Verdes (including Palos Verdes Estates, Rancho Palos Verdes, Rolling Hills Estates and Rolling Hills)		24,100		24,100
Westlake (a portion of Thousand Oaks)		7,000		7,100
Antelope Valley (Fremont Valley, Lake Hughes, Lancaster & Leona Valley)		1,400		1,400
Hawthorne and Commerce (leased municipal systems)		7,400		7,400
		127,200		127,100
CALIFORNIA TOTAL		473,100		471,900
HAWAII		4,200		4,200
NEW MEXICO		7,600		7,700
WASHINGTON		15,800		15,700
COMPANY TOTAL		500,700		499,500

Rates and Regulation

        The state regulatory commissions have plenary powers setting rates and operating standards. As such, state commission decisions significantly impact the company's revenues, earnings, and cash flows. The amounts discussed herein are generally annual amounts, unless specifically stated, and the financial impact to recorded revenue is expected to occur over a 12-month period from the effective date of the decision. In California, water utilities are required to make several different types of filings. Most filings result in rate changes that remain in place until the next General Rate Case (GRC). As explained below, surcharges and surcredits to recover balancing and memorandum accounts as well as general rate case interim rate relief are temporary rate changes, which have specific time frames for recovery.

        GRCs, escalation rate increase filings, and offset filings change rates to amounts that will remain in effect until the next GRC. The CPUC follows a rate case plan, which requires Cal Water to file a GRC for each of its regulated operating districts every three years. In a GRC proceeding, the CPUC not only considers the utility's rate setting requests, but may also consider other issues that affect the utility's rates and operations. The CPUC is generally required to issue its GRC decision prior to the first day of the test year or authorize interim rates. In accordance with the rate case plan, the Commission issued a decision on Cal Water's 2009 general rate case filing in the fourth quarter of 2010 with rates effective on January 1, 2011. In accordance with the CPUC's rate case plan for Class A water utilities Cal Water filed a GRC on July 5, 2012, which is applicable to all of its California Districts. Any rate change as a result of that filing is expected to be effective on January 1, 2014.

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        Between GRC filings utilities may file escalation rate increases, which allow the utility to recover cost increases, primarily from inflation and incremental investment, during the second and third years of the rate case cycle. However, escalation rate increases are subject to a weather-normalized earnings test on a district-by-district basis. Under the earnings test, the CPUC may reduce the escalation rate increase if, in the most recent 12-month period, this earnings test reflects earnings in excess of what was authorized for that district.

        In addition, California water utilities are entitled to make offset filings. Offset filings may be filed to adjust revenues for construction projects authorized in GRCs when the plant is placed in service or for rate changes charged to the Company for purchased water, purchased power, and pump taxes (referred to as "offsettable expenses"). Such rate changes approved in offset filings remain in effect until the next GRC is approved.

        Cal Water's Water Revenue Adjustment Mechanisms (WRAMs) and Modified Cost Balancing Accounts (MCBAs) were authorized by the CPUC to remove the disincentive associated with lower water consumption levels caused by promoting water conservation programs. In order to maintain revenue neutrality, the CPUC de-coupled Cal Water's revenue requirement from ratepayer usage with the WRAM/MCBA. Under the WRAM/MCBA, Cal Water recovers the full quantity revenue amounts authorized by the CPUC by using advice letter filings for any unbilled quantity revenue amounts or refunds for overcollection, regardless of customer usage volumes.

        Advice letters, which implement surcharges and surcredits to amortize balances in the WRAM and MCBA accounts are filed between February and April of each year based on the district balances for the last calendar year. Based on current CPUC interpretations, most surcharges are amortized between 12 or 18 months. The WRAM and MCBA amounts are cumulative, so if they are not amortized in a given calendar year, the balance will be carried forward and included with the following year balance.

2012 Regulatory Activity

Changes in CPUC's Procedures for WRAM Amortization

        During 2011, Cal Water, along with four other investor-owned water utilities filed a joint application to change the 2011 and future amortization periods to 24 months or less. The CPUC issued its decision regarding the amortization periods on April 19, 2012. The decision shortened the amortization for undercollected balances for calendar years 2011, 2012, and 2013. Also, the decision authorized Cal Water to bill and collect all year-end undercollected balances. Cal Water anticipates most of the undercollected balances during calendar years 2011, 2012, and 2013 will be collected using 12 and 18- month amortization periods. The collection periods for calendar year 2014 and future years will be determined during the 2012 GRC.

        For metered customers, Cal Water recognizes revenue from rates which are designed and authorized by the California Public Utilities Commission (CPUC). Under the WRAM, Cal Water records the adopted level of volumetric revenues, which would include recovery of cost of service and a return on investments, as established by the CPUC for metered accounts (adopted volumetric revenues). In addition to volumetric-based revenues, the revenue requirements approved by the CPUC include service charges, flat rate charges, and other items not subject to the WRAM. The adopted volumetric revenue considers the seasonality of consumption of water based upon historical averages. The variance between adopted volumetric revenues and actual billed volumetric revenues for metered accounts is recorded as a component of revenue with an offsetting entry to a regulatory asset or liability balancing account (tracked individually for each Cal Water district) subject to certain criteria under the accounting for regulated operations being met. The variance amount may be positive or negative and represents amounts that will be billed or refunded to customers in the future.

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        Cost-recovery rates are designed to permit full recovery of certain costs allowed to be recovered by the Commissions. Cost- recovery rates such as the MCBA provides for recovery of adopted expense levels for purchased water, purchased power and pump taxes, as established by the CPUC. In addition, cost-recovery rates include recovery of cost related to water conservation programs and certain other operation expenses adopted by the CPUC. Variances (which include the effects of changes in both rate and volume for the MCBA) between adopted and actual costs are recorded as a component of revenue, as the amount of such variances will be recovered from or refunded to our customers at a later date. There is no markup for return or profit for cost-recovery expenses and they are generally recognized when expenses are incurred.

        The balances in the WRAM and MCBA assets and liabilities accounts will fluctuate on a monthly basis depending upon the variance between adopted and actual results. The recovery or refund of the WRAM is netted against the MCBA over- or under- recovery for the corresponding district and is interest bearing at the current 90 day commercial paper rate. Cal Water files with the CPUC to refund or collect the net WRAM and MCBA balances at the end of each year. On April 19, 2012, the CPUC issued a decision to shorten the amortization periods for Cal Water's undercollected net WRAM and MCBA receivable balances for calendar years 2011, 2012, and 2013. Most of Cal Water's undercollected net WRAM and MCBA receivable balances will be collected within 24 months of the respective reporting periods due to the shortened amortization periods. As of December 31, 2011 Cal Water deferred $12.9 million of net WRAM and MCBA revenues and $10.5 million of associated costs because these amounts were estimated to be collected more than 24 months after the respective reporting periods. In 2012, Cal Water recognized all of the 2011 deferred net WRAM and MCBA revenues and associated costs which increased income before income taxes by $2.4 million. As of December 31, 2012, $0.9 million of net WRAM and MCBA revenues and $0.7 million of associated costs were deferred because the Company concluded it would not be able to collect those amounts within 24 months of the respective reporting period.

Remaining Balances from Previously Authorized Balancing Accounts Recoveries/Refunds

        Prior to the adoption of the MCBA on July 1, 2008, the CPUC required incremental cost balancing accounts (ICBA) to track changes in costs for purchased electric power, purchased water, and pump taxes. Cal Water completed ICBA refunds and billings during 2012 which had been authorized in prior years. As of December 31, 2012, a $0.6 million regulatory asset and a $0.3 million regulatory liability were recorded for the remaining unbilled or un-refunded balances. Cal Water has requested to surcharge or refund the remaining balances as part of its current GRC.

California Cost of Capital Proceeding

        Cal Water, along with the three other large water utilities in California, filed an application with the CPUC in May of 2011 to review its cost of capital for 2012 through 2014. The Company and the other applicants reached a settlement with the Division of Ratepayer Advocates that was approved by the CPUC in Decision D.12-07-009. The decision adopted a 9.99% return on equity and 53.4% equity capital structure for rate setting purposes. Cal Water filed an advice letter to reflect this lower authorized return, resulting in a 2012 revenue decrease of $3.9 million. The decision also discontinued the Temporary Interest Rate Balancing Account (TIRBA) and required Cal Water to refund the balance of $1.1 million to customers via a 12-month surcredit. The TIRBA was recorded as a regulatory liability and reduction to revenue in 2011.

        The cost of capital proceeding was scheduled to set the authorized rate of return for the Company's investment starting on January 1, 2012 and a decision had not been issued at that time, the CPUC required Cal Water to file an advice letter to establish a Cost of Capital interim rate memorandum account (COCIRM). In August, Cal Water filed an advice letter to amortize the balance in the COCIRM, which will result in a refund to customers of $2.5 million over a 12 month period. The COCIRM was recorded as a regulatory liability and reduction to revenue in 2012.

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        The decision also continued the Water Cost of Capital Mechanism (WCCM), which requires an additional adjustment to equity returns if there is a large change in the Moody AA utility bond index. In October 2012, the change reflected in the Moody AA utility bond index exceeded the trigger. Cal Water filed Advice Letter 2088 on October 15, 2012, effective January 1, 2013, which reduced the authorized return on equity to 9.43%. Other components of the cost of capital including debt cost and capital structure did not change. The ROE reduction results in a $3.8 million decrease in authorized revenue requirement for 2013. The WCCM will be reviewed again in October 2013 to determine whether an adjustment up or down is required for 2014.

2012 California GRC filing

        On July 5, 2012, Cal Water filed its 2012 GRC application covering all district and general office revenue requirements. The GRC application requested an increase of $92.7 million or 19.4% in rates for 2014, $17.2 million or 3.0% in rates for 2015 and $16.9 million or 2.9% in rates for 2016. Additionally, the GRC includes a number of special requests. The Division of Ratepayer Advocates at the CPUC is currently reviewing the filing. There are also six intervening parties representing various ratepayer interests. Any rate change as a result of this filing is expected to be effective on January 1, 2014.

Low Income Ratepayer Assistance Program

        Cal Water currently administers a Low Income Ratepayer Assistance Program (LIRA) in accordance with decision D.06-11-053. This program provides qualifying low income customers with a 50% discount on their service charge (up to a maximum of $12 per month). It imposes a surcharge on non-qualifying customers on monthly water consumption and a set amount on flat rate services. Due to a successful enrollment of over 49,000 customers, this account had accumulated an under collection of approximately $7.7 million as of December 31, 2012, and is recorded in non-current regulatory assets. In early 2012, Cal Water filed a petition to modify D.06-11-053 to 1) increase surcharges to balance program expenses and revenues, 2) amortize the current balance in the program, and 3) establish an annual adjustment mechanism to reduce the potential of large balances in the future. In September 2012, the Commission approved D. 12-09-20, which approved a settlement between Cal Water and the Division of Ratepayer Advocates (DRA). The decision allows Cal Water to 1) raise its LIRA surcharge on non eligible customers from $0.01 per CCF to $0.06 per CCF to account for more eligible customers participating in the program, 2) adjust surcharges on an annual basis, and 3) put in place a temporary surcharge of $0.0182 per unit on all metered water sales to recover the accumulated balance in the program account. The temporary surcharge was designed to collect the under recovered balance over a three year period.

2010 Ka'anapali (Hawaii) GRC Filing

        On December 30, 2010, Hawaii Water filed its 2010 GRC application for the Ka'anapali Service Area. The Hawaii Public Utilities Commission (HPUC) requires a separate rate application for all service areas and uses a limited future test year. The Ka'anapali GRC requested additional revenue of $1.5 million or an increase of 38.2% over the prior year. Hawaii Water and the Consumer Advocate of the HPUC reached a settlement regarding the rate case issues. On January 11, 2012, the HPUC issued a Decision and Order approving the stipulated settlement. This resulted in a $1.2 million, or 30.8%, annual revenue increase that was effective March 2012.

2011 Pukalani (Hawaii) GRC Filing

        In August 2011, Hawaii Water filed a general rate case for the Pukalani wastewater system requesting $1.3 million in additional annual revenues. Hawaii Water reached a comprehensive and conceptual settlement with the Consumer Advocate. This settlement would result in an increase of $0.3 million in 2013, another increase of $0.2 million in 2014, and another increase of $0.2 million in 2015 each increase is

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separated by one year. A Decision and Order from the Commission approving this stipulated settlement is currently pending.

2012 Waikoloa (Hawaii) GRC Filings

        In August 2012, Hawaii Water filed general rate cases for the Waikoloa water, wastewater, and irrigation systems in Waikoloa Village and Waikoloa Resort requesting $6.3 million in additional annual revenues. The cases are being processed at this time on separate schedules. Hawaii Water cannot determine the timing or final amount of rate relief these filings will generate.

2011 Washington Water GRC Filing

        In 2011, Washington Water filed a general rate case for its operation. It requested a $1.7 million, or 21.8%, increase in revenue. The WUTC approved a $1.6 million, or 20.0%, increase effective in the first quarter of 2012.

Federal Income Tax Bonus Depreciation

        In 2011, Cal Water filed for and received approval to track the benefits from federal income tax accelerated depreciation in a memorandum account due to the Tax Relief, Unemployment Insurance Reauthorization, and Job Creation Act of 2010. Additional federal income tax deductions for assets placed in service after September 8, 2010, and before December 31, 2011, were $0.1 million for 2010 and $12.2 million for 2011. The memorandum account may result in a surcredit because of the impact to Cal Water's revenue requirement for changes to working cash estimates, reductions to federal income tax qualified U.S. production activities deductions (QPAD), and changes to contributions-in-aid-of-construction. As of December 31, 2012, the estimated surcredit range is between $0.6 million and $1.1 million. The CPUC will determine the disposition of amounts recorded in the memorandum account in Cal Water's next GRC.

Request for MTBE regulatory treatment

        The CPUC in its Decision (D.) 10-10-018 issued rules for treating contamination proceeds generally. Subsequently, the CPUC's D.11-03-043 resolved Cal Water's separate application for treatment of MTBE proceeds by ordering continued tracking of the proceeds and expenditures until litigation and remediation are both complete. The new rules allow Cal Water to file an advice letter to move proceeds from this tracking account into Contributions in Aid of Construction ("CIAC") when remediation or replacement projects are complete. Cal Water has completed several such projects totaling $4.5 million and $16.7 million in 2012 and 2011, respectively. While the advice letters have not been filed for some of these projects, Cal Water believes it is probable the CPUC will treat the invested amounts as CIAC when the advice letters are filed. The Company reclassified $4.5 million and $16.7 million from regulatory and other liabilities to CIAC during 2012 and 2011, respectively. MTBE-related projects identified in the 2009 rate case were incorporated as CIAC in rates beginning in 2011. Cal Water anticipates the CPUC approving similar treatment in future rate cases, resulting in no rate impact as contributed funds are applied to projects. The CPUC's adopted rules would require all contamination proceeds to be used first to pay transactional expenses, then to make ratepayers whole for costs to ensure the water system complies with the CPUC's water quality standards. The rules allow for a risk-based consideration of proceeds which exceed the costs of the remediation described above and may result in some sharing of excess, or "net" proceeds. Because treatment or replacement of Cal Water's MTBE contaminated wells will occur over a number of years, a final disposition of Cal Water's memorandum account will occur at an unknown future date. Cal Water will continue to monitor proceeds and remediation and will report to the CPUC in its next GRC. Because of uncertainty surrounding eventual remediation capital and operating costs and the eventual ratemaking treatment of "net proceeds" as defined by the CPUC, Cal Water cannot predict the future disposition of its partial MTBE settlement proceeds at this time.

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Service Line Insurance Billing

        As a consequence of D.07-12-055 which resolved Cal Water's 2006 GRC, Cal Water was required to demonstrate that its non-regulated Extended Service Protection (ESP) business or its successor complies with CPUC rules. Cal Water made an administrative compliance filing in 2008 which was rejected. Cal Water subsequently filed A.08-05-019 requesting Commission confirmation that the interaction between Cal Water, CWS Utility Services, and Home Service USA complied with all applicable rules. During the proceeding, the CPUC established a memorandum account to record Cal Water's revenues and expenses related to the non-regulated service line insurance business. The application is being processed in 2011 and 2012 after the CPUC adopted comprehensive rules for the relationships between regulated utilities and their unregulated affiliates and the rules for offering non-tariffed products and services. These rules went into effect on June 30, 2011 as a result of D.10-10-019. The CPUC's ratepayer advocate testified that Cal Water's customers should receive some of the proceeds from the sale of the non-regulated ESP business as well as other program revenues. While Cal Water challenged these claims and presented its own testimony, the parties were able to reach a settlement on all issues in the case. The proposed settlement, which was filed in October 2011, describes the accounting and revenue sharing applicable to the non-regulated service line business after June 30, 2011, and proposes a monetary settlement of $2.1 million to ratepayers to resolve all issues related to non-regulated service line business activity from 2007 through June 30, 2011. Cal Water recorded a $2.1 million regulatory liability in 2011. The settlement is still subject to approval by the CPUC. Cal Water anticipates that the CPUC will approve the settlement in the first quarter of 2013.

Escalation Increase filings

        As a part of the decision of the 2009 General Rate Case, Cal Water is authorized to file annual escalation rate increases for 2012 and 2013. In January 2012, Cal Water implemented escalation rate increases in 17 districts. The annual gross revenue associated with these increases is $8.7 million. In January 2013, Ca Water implemented escalation rate increases in 19 districts. The annual gross revenue associated with these increases is $9.6 million.

2012 Expense Offset filings

        In 2012, Cal Water filed advice letters to offset increased purchased water and pump tax rates in nine of its regulated districts totaling $13.5 million in annual revenue. Expense offsets are dollar-for-dollar increases in revenue to match increased expenses and interact with the WRAM and MCBA mechanisms so that net operating income is not affected by an offset increase.

        In May 2012, Cal Water filed an advice letter to recover the cost relating to the expense of hiring six additional Cross Connection Control Inspectors. These positions were approved in the 2009 GRC and Cal Water was allowed to file for the recovery of the positions and associated equipment after the positions were hired. The annual revenue increase from this filing is $0.6 million. In the future, Cal Water plans to file advice letters to offset expected increases in purchased water and pump tax charges in some districts. Cal Water cannot predict the exact timing or dollar amount of the changes.

2012 Ratebase Offset filings

        In 2012, Cal Water filed advice letters to offset several infrastructure improvement projects in seven districts totaling $2.0 million in annual revenue. For some of these offsets, Cal Water also filed 12 month surcredits to the customers to account for the use of internal labor to complete the flat to meter projects. These surcredits total $1.2 million. Companies are allowed to file rate base offsets to increase revenues for construction projects authorized in GRCs when the plant is placed in service. The project for this filing was authorized in the 2009 GRC. The remaining advice letter projects from the 2009 GRC are scheduled to be completed during 2013 or later. Some projects, where approval for Advice Letters was granted in the 2009 GRC, may be canceled due to changes in operations since the approval.

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Water Supply

        Our source of supply varies among our operating districts. Certain districts obtain all of their supply from wells; some districts purchase all of their supply from wholesale suppliers; and other districts obtain supply from a combination of wells and wholesale suppliers. A small portion of supply comes from surface sources and is processed through Company-owned water treatment plants. During 2012, an estimated 126 billion gallons of water was produced to meet customer demand, up 4.6% from the estimated 120 billion gallons produced in 2011. The 2012 average daily water production was approximately 345 million gallons. Historically, approximately half of the Company's water supply is purchased from wholesale suppliers with the balance pumped from wells. In 2012, approximately 48 percent of the Company's supply was obtained from wells, 47 percent was purchased from wholesale suppliers and 5 percent was obtained from surface supplies. By comparison, in 2011, the average daily water production was approximately 330 million gallons. Well water is generally less expensive and the Company strives to maximize the use of its well sources in districts where there is an option between well or purchased supply sources.

        In California, we obtain our water supply from wells, surface runoff or diversion, and by purchase from public agencies and other wholesale suppliers. Our water supply has been adequate to meet customer demand; however, during periods of drought, some districts have experienced mandatory water rationing. California's rainy season usually begins in November and continues through March with the most rain typically falling in December, January and February. During winter months, reservoirs and underground aquifers are replenished by rainfall. Snow accumulated in the mountains provides an additional water source when spring and summer temperatures melt the snowpack, producing runoff into streams and reservoirs, and also replenishing underground aquifers. There are six California water treatment plants located in the Bakersfield, Bear Gulch, Kernville, Oroville and Redwood Valley districts. Water for operation of the Bakersfield plants, with a combined capacity of 28 million gallons per day, is drawn from the Kern River under a long-term contract with the City of Bakersfield. The other four plants have a combined capacity of 18 million gallons per day.

        Washington and Hawaii receive rain in all seasons with the majority falling during winter months. Washington Water and Hawaii Water draw all their water supply by pumping from wells. New Mexico Water's rainfall normally occurs in all seasons, but is heaviest in the summer monsoon season. New Mexico Water pumps all of its water supply from wells based on its water rights.

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        The following table shows the estimated quantity of water purchased and the percentage of purchased water to total water production in each California operating district that purchased water in 2012. Other than noted below, all other districts receive 100% of their water supply from wells.

District	Water Purchased (MG)		Percentage of Total Water Production			Source of Purchased Supply
SAN FRANCISCO BAY AREA
Bayshore		7,515		97	%	San Francisco Public Utilities Commission
Bear Gulch		4,189		95	%	San Francisco Public Utilities Commission
Los Altos		2,774		67	%	Santa Clara Valley Water District
Livermore		2,466		70	%	Alameda County Flood Control and Water Conservation District, Zone 7
SACRAMENTO VALLEY
Oroville		779		73	%	Pacific Gas and Electric Co. and County of Butte
NORTH COAST
Redwood Valley		110		75	%	Yolo County Flood Control & Water Conservation District
SAN JOAQUIN VALLEY
Bakersfield		11,694		44	%	Kern County Water Agency and City of Bakersfield
Stockton		7,609		83	%	Stockton East Water District
LOS ANGELES AREA
East Los Angeles		3,493		66	%	Central Basin Municipal Water District
Dominguez		10,397		80	%	West Basin Municipal Water District and City of Torrance
City of Commerce		37		6	%	Central Basin Municipal Water District
Hawthorne		1,073		74	%	West Basin Municipal Water District
Hermosa-Redondo		3,435		84	%	West Basin Municipal Water District
Palos Verdes		6,504		100	%	West Basin Municipal Water District
Westlake		2,749		100	%	Calleguas Municipal Water District
Antelope/Kern		121		18	%	Antelope Valley-East Kern Water Agency and City of Bakersfield

MG = million gallons

        The Bear Gulch district obtains a portion of its water supply from surface runoff from the local watershed. The Oroville and Redwood Valley districts in the Sacramento Valley and the Bakersfield and Kern River Valley districts in the San Joaquin Valley purchase water from a surface supply. Surface sources are processed through our water treatment plants before being delivered to the distribution system. The Bakersfield district also purchases treated water as a component of its water supply.

        The Chico, Marysville, Dixon, and Willows districts in the Sacramento Valley, the Salinas and King City districts in the Salinas Valley, and the Selma and Visalia districts in the San Joaquin Valley obtain their entire supply from wells. In the Salinas district, which solely depends upon ground water, several wells were taken out of service in the last four years, primarily due to poor water quality. Treatment systems have been installed on some of these wells to meet customer demand. Management believes water supply issues in the Salinas district will be adequately resolved in the future by seeking additional sources or additional treatment.

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        Purchases for the Los Altos, Livermore, Oroville, Redwood Valley, Stockton, and Bakersfield districts are pursuant to long-term contracts expiring on various dates after 2012. The water supplies purchased for the Dominguez, East Los Angeles, Hermosa-Redondo, Palos Verdes, and Westlake districts as well as the Hawthorne and Commerce systems are provided by public agencies pursuant to a statutory obligation of continued non- preferential service to purveyors within the agencies' boundaries. Purchases for the Bayshore and Bear Gulch districts are in accordance with long-term contracts with the San Francisco Public Utilities Commission (SFPUC) until June 30, 2034.

        Management anticipates water supply contracts will be renewed as they expire though the price of wholesale water purchases is subject to pricing changes imposed by the various wholesalers.

        Shown below are wholesaler price rates and increases that became effective in 2012 and estimated wholesaler price rates and percent changes for 2013. In 2012, several districts experienced significant purchased water cost increases resulting in a significant impact in the 2012 MCBA balance and the filing of several purchased water offsets.

		2012						2013
	Effective Month			Percent Change			Effective Month			Percent Change
District		Unit Cost						Unit Cost
Antelope	January	$	330.00 /af		8.55	%	January	$	349.00 /af		5.76	%
Bakersfield(1)	July	$	144.00 /af		(2.0)	%	July	$	144.00 /af		0.00	%
Bear Gulch(2)	July	$	2.93 /ccf		11.41	%	July	$	2.93 /ccf		0.00	%
Commerce(2)	January	$	915.00 /af		6.52	%	January	$	967.00 /af		5.68	%
Dominguez(2)	July	$	1,036.00 /af		7.47	%	January	$	1,089.00 /af		5.12	%
East Los Angeles(2)	January	$	915.00 /af		6.52	%	January	$	967.00 /af		5.68	%
Hawthorne(2)	July	$	1,036.00 /af		7.47	%	January	$	1,089.00 /af		5.12	%
Hermosa-Redondo(2)	July	$	1,036.00 /af		7.47	%	January	$	1,089.00 /af		5.12	%
Livermore	January	$	2.17 /ccf		4.83	%	January	$	2.17 /ccf		0.00	%
Los Altos	July	$	722.00 /af		7.92	%	July	$	722.00 /af		0.00	%
Oroville(2)	April	$	163,512.00 /yr		2.88	%	April	$	163,512.00 /yr		0.00	%
Palos Verdes(2)	July	$	1,036.00 /af		7.47	%	January	$	1,089.00 /af		5.12	%
Bayshore(2)	July	$	2.93 /ccf		11.41	%	July	$	2.93 /ccf		0.00	%
Redwood Valley	June	$	57.00 /af		3.64	%	June	$	57.00 /af		0.00	%
Stockton	April	$	546,474.00 /mo		(2.73	)%	April	$	546,474.00/mo		0.00	%
Westlake	January	$	1,056.00 /af		7.65	%	January	$	1,056.00 /af		0.00	%

af = acre foot;

ccf = hundred cubic feet;

yr = fixed annual cost;

mo = fixed monthly cost

(1)

untreated water

(2)

wholesaler price changes occur every six months

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        We work with all local suppliers and agencies responsible for water supply to insure adequate, long-term supply for each system.

        See Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations—Water Supply" concerning more information on adequacy of supplies.

Seasonal Fluctuations

        In California, our customers' consumption pattern of water varies with the weather, in terms of rainfall and temperature. In the WRAM and MCBA design, the CPUC considers the historical pattern in determining the adopted sales and production costs. With a majority of our sales being subject to the WRAM and production costs being covered by the MCBA, variations from the adopted pattern have been minimized. However, cash flows from operations and short-term borrowings on our credit facilities are significantly impacted by seasonal fluctuations including recovery of the WRAM and MCBA.

        Our water business is seasonal in nature. Weather conditions can have a material effect on customer usage. Customer demand for water generally is lower during the cooler and rainy, winter months. Demand increases in the spring when warmer weather returns and the rains end, and customer use more water for outdoor purposes, such as landscape irrigation. Warm temperatures during the generally dry summer months result in increased demand. Water usage declines during the fall as temperatures decrease and the rainy season begins. During years in which precipitation is especially heavy or extends beyond the spring into the early summer, customer demand can decrease from historic normal levels, generally due to reduced outdoor water usage. Likewise, an early start to the rainy season during the fall can cause a decline in customer usage. As a result, seasonality of water usage has a significant impact on our cash flows from operations and borrowing on our short-term facilities.

Utility Plant Construction

        We have continually extended, enlarged, and replaced our facilities as required to meet increasing demands and to maintain the water systems. We obtain construction financing using funds from operations, short-term bank borrowings, long-term financing, advances for construction and contributions in aid of construction that are funded by developers. Advances for construction are cash deposits from developers for construction of water facilities or water facilities deeded from developers. These advances are generally refundable without interest over a period of 40 years in equal annual payment amounts. Contributions in aid of construction consist of nonrefundable cash deposits or facilities transferred from developers, primarily for fire protection and relocation projects. We cannot control the amounts received from developers. This amount fluctuates from year-to-year as the level of construction activity carried on by developers varies. This activity is impacted by the demand for housing, commercial development, and general business conditions, including interest rates.

        See Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources" for additional information.

Sale of Surplus Real Properties

        When properties are no longer used and useful for public utility purposes, we are no longer allowed to earn a return on our investment in the property in the regulated business. The surplus property is transferred out of the regulated operations. From time to time, some properties have been sold or offered for sale. As these sales are subject to local real estate market conditions and can take several months or years to close, income from the sale of surplus properties may or may not be consistent from year-to-year.

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Energy Reliability

        We continue to use power efficiently to minimize the power expenses passed on to our customers, and maintain backup power systems to continue water service to our customers if the power companies' supplies are interrupted. Many of our well sites are equipped with emergency electric generators designed to produce electricity to keep the wells operating during power outages. Storage tanks also provide customers with water during blackout periods.

Impact of Climate Change Legislation

        Our operations depend on power provided by other public utilities and, in emergencies, power generated by our portable and fixed generators. If future legislation limits emissions from the power generation process, our cost of power may increase. Any increase in the cost of power will be passed along to our California rate payers through the MCBA or included in our cost of service paid by our rate payers as requested in our general rate case filings

        Approved in April 2009, the Low Carbon Fuel Standard Program, which went into effect January 1, 2011, requires diesel engines to use low carbon fuel such as biodiesel or other alternatives. This may increase the operating cost of our generators and vehicles.

        We maintain a fleet of vehicles to provide service to our customers, including a number of heavy duty diesel vehicles that we retrofitted by the end of 2010 to meet California emission standards. If future legislation further impacts the cost to operate the fleet or the fleet acquisition cost in order to meet certain emission standards, it will increase our cost of service and our rate base. Any increase in fleet operating costs associated with meeting emission standards will be included in our cost of service paid by our rate payers as requested in our general rate case filings. While recovery of these costs is not guaranteed, we would expect recovery in the regulatory process.

        Starting January 1, 2010, under the California Environmental Quality Act (CEQA), all capital projects of a certain type (primarily wells, tanks, major pipelines and treatment facilities) will require mitigation of green house gas emissions. The cost to prepare the CEQA documentation and permit is estimated to add tens of thousands of dollars to such capital projects. This cost will be included in our capital cost and added to our rate base, which will be requested to be paid for by our rate payers. Any increase in the operating cost of the facilities will also be included in our cost of service paid by our rate payers as requested in our general rate case filings. While recovery of these costs is not guaranteed, we would expect recovery in the regulatory process.

        Cap and trade regulations were implemented in 2012 with the goal of reducing emissions to 1990 levels by the year 2020. These regulations will be implemented over a three year period and will be fully implemented in 2015. Under such regulations in 2015, we will be required to determine our carbon footprint and evaluate our electricity and fuel usage (both diesel and gasoline). We will also be required to evaluate methane emissions from our primary processes in our wastewater plants. At this time we are unable to determine the cost impact of such regulations but any increase in operating costs associated with the cap and trade regulations will be included in our cost of service requested to be paid by our rate payers as requested in our general rate case filings. While recovery of these costs is not guaranteed, we would expect recovery in the regulatory process.

Security at Company Facilities

        Due to terrorism and other risks, we have heightened security at our facilities and have taken added precautions to protect our employees and the water delivered to customers. In 2002, federal legislation was enacted that resulted in new regulations concerning security of water facilities, including submitting vulnerability assessment studies to the federal government. We have complied with regulations issued by the Environmental Protection Agency (EPA) pursuant to our federal legislation concerning vulnerability

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assessments and have made filings to the EPA as required. In addition, communication plans have been developed as a component of our procedures. While we do not make public comments on our security programs, we have been in contact with federal, state, and local law enforcement agencies to coordinate and improve our water delivery systems' security.

Quality of Water Supply

        Our operating practices are designed to produce potable water in accordance with accepted water utility practices. Water entering the distribution systems from surface sources is treated in compliance with federal and state Safe Drinking Water Act (SDWA) standards. Most well supplies are chlorinated or chloraminated for disinfection. Water samples from each water system are analyzed on a regular, scheduled basis in compliance with regulatory requirements. We operate a state-certified water quality laboratory at the San Jose General Office that provides testing for most of our California operations. Certain tests in California are contracted with independent certified labs qualified under the Environmental Laboratory Accreditation Program. Local independent state certified labs provide water sample testing for the Washington, New Mexico and Hawaii operations.

        In recent years, federal and state water quality regulations have resulted in increased water sampling requirements. The SDWA continues to be amended to address public health concerns. We monitor water quality standard changes and upgrade our treatment capabilities to maintain compliance with the various regulations.

Competition and Condemnation

        Our principal operations are regulated by the Commission of each state. Under state laws, no privately owned public utility may compete within any service territory that we already serve without first obtaining a certificate of public convenience and necessity from the applicable Commission. Issuance of such a certificate would only be made upon finding that our service is deficient. To management's knowledge, no application to provide service to an area served by us has been made.

        State law provides that whenever a public agency constructs facilities to extend a utility system into the service area of a privately owned public utility, such an act constitutes the taking of property and requires reimbursement to the utility for its loss. State statutes allow municipalities, water districts and other public agencies to own and operate water systems. These agencies are empowered to condemn properties already operated by privately owned public utilities. The agencies are also authorized to issue bonds, including revenue bonds, for the purpose of acquiring or constructing water systems. However, if a public agency were to acquire utility property by eminent domain action, the utility would be entitled to just compensation for its loss. In Washington, annexation was approved in February 2008 for property served by us on Orcas Island; however, we continue to serve the customers in the annexed area and do not expect the annexation to impact our operations. To management's knowledge, other than the Orcas Island property, no municipality, water district, or other public agency is contemplating or has any action pending to acquire or condemn any of our systems.

        We intend to continue the pursuit of opportunities to expand our business in the western United States, which may include expansion through acquisitions or mergers with other companies.

Environmental Matters

        Our operations are subject to environmental regulation by various governmental authorities. Environmental health and safety programs have been designed to provide compliance with water discharge regulations, underground and aboveground fuel storage tank regulations, hazardous materials management plans, hazardous waste regulations, air quality permitting requirements, wastewater discharge limitations and employee safety issues related to hazardous materials. Also, we actively investigate

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alternative technologies for meeting environmental regulations and continue the traditional practices of meeting environmental regulations.

        For a description of the material effects that compliance with environmental regulations may have on us, see Item 1A. "Risk Factors—Risks Related to Our Regulatory Environment." We expect environmental regulation to increase, resulting in higher operating costs in the future, which may have a material adverse effect on earnings.

Employees

        At year-end 2012, we had 1,131 employees, including 54 at Washington Water, 56 at Hawaii Water, and 16 at New Mexico Water. In California, most non-supervisory employees are represented by the Utility Workers Union of America, AFL-CIO, except certain engineering and laboratory employees who are represented by the International Federation of Professional and Technical Engineers, AFL-CIO.

        At December 31, 2012, we had 734 union employees. In December 2012, we negotiated 2013 and 2014 wage increases with both of our unions of 2.0% and 3.0%, respectively. The current agreement with the unions is effective through 2014. Management believes that it maintains good relationships with the unions.

        Employees at Washington Water, New Mexico Water, and Hawaii Water are not represented by unions.

Executive Officers of the Registrant

Name	Positions and Offices with California Water Service Group	Age
Peter C. Nelson(1)	Chairman and Chief Executive Officer since May 22,2012, Formerly, President and Chief Executive Officer (1996-2012), served as Vice President, Division Operations (1994-1995) and Region Vice President (1989-1994), Pacific Gas & Electric Company, a gas and electric public utility		65
Martin A. Kropelnicki(2)	President and Chief Operating Officer since October 1, 2012, Formerly, Chief Financial Officer and Treasurer (2006-2012), served as Chief Financial Officer of Power Light Corporation (2005-2006), Chief Financial Officer and Executive Vice President of Corporate Services of Hall Kinion and Associates (1997-2004), Deloitte & Touche Consulting (1996-1997), held various positions with Pacific Gas & Electric (1989-1996)		46
Thomas F. Smegal III(3)	Vice President, Chief Financial Officer and Treasurer since October 1, 2012. Formerly, Vice President, Regulatory Matters and Corporate Relations (2008-2012), Manager of Rates (2002-2008), Regulatory Analyst (1997-2002), served as Utilities Engineer at the California Public Utilities Commission (1990-1997)		45

22

Name	Positions and Offices with California Water Service Group	Age
Helen Del Grosso(5)	Vice President, Human Resources since May 1, 2013. Formerly Director of Human Resources (2008 - 2012), served as Employee and Labor Relations Manager for City of Palo Alto (2001 - 2008), served as Human Resources Manager for County of Santa Clara (1998 - 2001) and Director of Human Resources for Coherent Inc. Medical Group (1988 - 1998)		56
Francis S. Ferraro(4)	Vice President of Corporate Development and Legal since October 1, 2005. Formerly, Vice President of Regulatory Affairs and Corporate Communications (1989-2005), held various positions with the California Public Utilities Commission, including Administrative Law Judge, project manager on major energy and water rate proceedings, and Manager of the Energy Rate Design and Economics Branch (1973-1989)		63
Robert R. Guzzetta(5)	Vice President of Operations since October 1, 2005. Formerly Vice President of Engineering and Water Quality (1996-2005), held various other positions with California Water Service Company since 1977		58
David R. Karraker(5)	Vice President, Customer Service and Information Technology since May 1, 2012. Formerly California Water Service Company District Manager, East Los Angeles (2000-2012), Assistant District Manager, East Los Angeles (1998-2000), and various positions with California Water Service Company since 1974		56
Christine L. McFarlane(6)	Vice President, Chief Administrative Officer since January 2009. Formerly Vice President, Human Resources (1996-2008), held various other positions with California Water Service Company since 1969		66
Michael J. Rossi(3)	Vice President, Engineering and Water Quality since October 1, 2005. Formerly Chief Engineer (1997-2005), Assistant Chief Engineer (1988-1997), held various other positions with California Water Service Company since 1977		59

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Name	Positions and Offices with California Water Service Group	Age
Paul G. Townsley(7)	Vice President, Regulatory Matters and Corporate Relations effective in March 2013. Formerly Divisional Vice President, Operations and Engineering for EPCOR Water USA (2012-2013), served as President of American Water Works Company subsidiaries in Arizona, New Mexico, and Hawaii (2007-2012), served as American Water Works Company's President, Western Region (2002-2007), and various positions with Citizens Utilities Company (1982-2002)		55
Lynne P. McGhee(3)	Corporate Secretary since July 25, 2007; Associate Corporate Counsel since May 2003. Formerly served as a Commissioner legal advisor and staff counsel at the California Public Utilities Commission		48
David B. Healey(8)	Corporate Controller and Assistant Secretary Since July 25, 2012. Formerly Director of Financial Reporting (2009-2012), served as Subsidiary Controller for SunPower Corporation (2005-2009), served as Corporate Controller for Hall, Kinion & Associates, Inc. (1997-2005), and various positions with Pacific Gas & Electric Company (1985-1997)		56

(1)

Holds the same position with California Water Service Company, CWS Utility Services, Hawaii Water Service Co., Inc.; New Mexico Water Service Company and Washington Water Service Company;

(2)

Holds the same position with California Water Service Company, CWS Utility Services, Hawaii Water Service Co., Inc., and New Mexico Water Service Company; Chief Operating Officer of Washington Water Service Company;

(3)

Holds the same position with California Water Service Company, CWS Utility Services, Hawaii Water Service Company, Inc., New Mexico Water Service Company, and Washington Water Service Company;

(4)

Holds position with California Water Service Company, New Mexico Water Service Company, Hawaii Water Service Company, Inc., and CWS Utility Services;

(5)

Holds position with California Water Service Company and CWS Utility Services;

(6)

Christine McFarlane, Vice President, Chief Administrative Officer, announced her intention to retire in 2013;

(7)

Holds the same position with California Water Service Company, Hawaii Water Service Company, Inc., New Mexico Water Service Company, and Washington Water Service Company

(8)

Holds the same position with California Water Service Company, CWS Utility Services, Washington Water Service Company, and Hawaii Water Service Company, Inc.; Assistant Secretary and Assistant Treasurer of New Mexico Water Service Company

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Item 1A.    Risk Factors.

        If any of the following risks actually occur, our financial condition and results of operations could be materially and adversely affected.

Risks Related to Our Regulatory Environment

Our business is heavily regulated by state and federal regulatory agencies and our financial viability depends upon our ability to recover costs from our customers through rates that must be approved by state public utility commissions.

        California Water Service Company, New Mexico Water Service Company, Washington Water Service Company and Hawaii Water Service Company, Inc., are regulated public utilities which provide water service to our customers. The rates that we charge our water customers are subject to the jurisdiction of the regulatory commissions in the states in which we operate. These commissions may set water rates for each operating district independently because the systems are not interconnected. The commissions authorize us to charge rates which they consider to be sufficient to recover normal operating expenses, to provide funds for adding new or replacing water infrastructure, and to allow us to earn what the commissions consider to be a fair and reasonable return on invested capital.

        Our revenues and consequently our ability to meet our financial objectives are dependent upon the rates we are authorized to charge our customers by the commissions and our ability to recover our costs in these rates. Our management uses forecasts, models and estimates in order to set rates that will provide a fair and reasonable return on our invested capital. While our rates must be approved by the commissions, no assurance can be given that our forecasts, models and estimates will be correct or that the commissions will agree with our forecasts, models and estimates. If our rates are set too low, our revenues may be insufficient to cover our operating expenses, capital expenditure requirements and desired dividend levels.

        We periodically file rate increase applications with the commissions. The ensuing administrative and hearing process may be lengthy and costly. The decisions of the commissions are beyond our control and we can provide no assurances that our rate increase requests will be granted by the commissions. Even if approved, there is no guarantee that approval will be given in a timely manner or at a sufficient level to cover our expenses and provide a reasonable return on our investment. If the rate increase decisions are delayed, our earnings may be adversely affected.

Our evaluation of the probability of recovery of regulatory assets is subject to adjustment by regulatory agencies and any such adjustment could adversely affect our results of operations.

        Regulatory decisions may also impact prospective revenues and earnings, affect the timing of the recognition of revenues and expenses and may overturn past decisions used in determining our revenues and expenses. Our management continually evaluates the anticipated recovery of regulatory assets, liabilities, and revenues subject to refund and provides for allowances and/or reserves as deemed necessary. Current accounting procedures allow us to defer certain costs if we believe it is probable that we will be allowed to recover those costs by future rate increases. If a commission determined that a portion of our assets were not recoverable in customer rates, we may suffer an asset impairment which would require a write down in such asset's valuation which would be recorded through operations.

        If our assessment as to the probability of recovery through the ratemaking process is incorrect, the associated regulatory asset or liability would be adjusted to reflect the change in our assessment or any regulatory disallowances. A change in our evaluation of the probability of recovery of regulatory assets or a regulatory disallowance of all or a portion of our cost could have a material adverse effect on our financial results.

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Regulatory agencies may disagree with our valuation and characterization of certain of our assets.

        If we determine that assets are no longer used or useful for utility operations, we may remove them from our rate base and subsequently sell those assets. If the commission disagrees with our characterization, we could be subjected to penalties. Furthermore, there is a risk that the commission could determine that appreciation in property value should be awarded to the ratepayers rather than our stockholders.

Changes in laws, rules and policies of regulatory agencies can significantly affect our business.

        Regulatory agencies may change their rules and policies for various reasons, including changes in the local political environment. In some states, regulators are elected by popular vote or are appointed by elected officials, and the results of elections may change the long-established rules and policies of an agency dramatically. For example, in 2001 regulation regarding recovery of increases in electrical rates changed in California. For over 20 years prior to 2001, the California Public Utilities Commission allowed recovery of electric rate increases under its operating rules. However, in 2003, the commission reinstated its policy to allow utilities to adjust their rates for rate changes by the power companies. The original decision by the commission to change its policy, as well as its subsequent decision to reinstate that policy, affected our business.

        We rely on policies and regulations promulgated by the various state commissions in order to recover capital expenditures, maintain favorable treatment on gains from the sale of real property, offset certain production and operating costs, recover the cost of debt, maintain an optimal equity structure without over-leveraging, and have financial and operational flexibility to engage in non-regulated operations. If any of the commissions with jurisdiction over us implements policies and regulations that do not allow us to accomplish some or all of the items listed above, our future operating results may be adversely affected.

        In addition, legislatures may repeal, relax or tighten existing laws, or enact new laws that impact the regulatory agencies with jurisdiction over our business or affect our business directly. If changes in existing laws or the implementation of new laws limit our ability to accomplish some or all of our business objectives, our future operating results may be adversely affected.

We expect environmental regulation to increase, resulting in higher operating costs in the future.

        Our water and wastewater services are governed by various federal and state environmental protection, health and safety laws, and regulations. These provisions establish criteria for drinking water and for discharges of water, wastewater and airborne substances. The Environmental Protection Agency promulgates numerous nationally applicable standards, including maximum contaminant levels (MCLs) for drinking water. We believe we are currently in compliance with all of the MCLs promulgated to date but we can give no assurance that we will continue to comply with all water quality requirements. If we violate any federal or state regulations or laws governing health and safety, we could be subject to substantial fines or otherwise sanctioned.

        Environmental laws are complex and change frequently. They tend to become more stringent over time. As new or stricter standards are introduced, they could increase our operating costs. Although we would likely seek permission to recover these costs through rate increases, we can give no assurance that the commissions would approve rate increases to enable us to recover these additional compliance costs.

        We are required to test our water quality for certain chemicals and potential contaminants on a regular basis. If the test results indicate that we exceed allowable limits, we may be required either to commence treatment to remove the contaminant or to develop an alternate water source. Either of these results may be costly, and there can be no assurance that the commissions would approve rate increases to enable us to recover these additional compliance costs.

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Legislation regarding climate change may impact our operations

        Future legislation regarding climate change may restrict our operations or impose new costs on our business. Our operations depend on power provided by other public utilities and, in emergencies, power generated by our portable and fixed generators. If future legislation limits emissions from the power generation process, our cost of power may increase. Any increase in the cost of power will be passed along to our California rate payers through the MCBA or included in our cost of service paid by our rate payers as requested in our general rate case filings. While recovery of these costs is not guaranteed, we would expect recovery in the regulatory process.

        The Low Carbon Fuel Standard Program, which went into effect January 1, 2011, requires diesel engines to use low carbon fuel such as biodiesel or other alternatives. This may increase the operating cost of our generators and vehicles.

        We maintain a fleet of vehicles to provide service to our customers, including a number of heavy duty diesel vehicles that we retrofitted prior to the end of 2010 to meet California emission standards. If future legislation further impacts the cost to operate the fleet or the fleet acquisition cost in order to meet certain emission standards, it will increase our cost of service and our rate base. Any increase in fleet operating costs associated with meeting emission standards will be included in our cost of service paid by our rate payers as requested in our general rate case filings. While recovery of these costs is not guaranteed, we would expect recovery in the regulatory process.

        Starting January 1, 2010, under the California Environmental Quality Act (CEQA), all capital projects of a certain type (primarily wells, tanks, major pipelines and treatment facilities) will require mitigation of green house gas emissions. The cost to prepare the CEQA documentation and permit will add an estimated ten thousand dollars to such capital projects. This cost will be included in our capital cost and added to our rate base, which will be requested to be paid for by our rate payers. Any increase in the operating cost of the facilities will also be included in our cost of service paid by our rate payers as requested in our general rate case filings. While recovery of these costs is not guaranteed, we would expect recovery in the regulatory process.

        Cap and trade regulations were implemented in 2012 with the goal of reducing emissions to 1990 levels by the year 2020. These regulations will be implemented over a three year period and will be fully implemented in 2015. Under such regulations in 2015, we will be required to determine our carbon footprint and evaluate our electricity and fuel usage (both diesel and gasoline). We will also be required to evaluate methane emissions from our primary processes in our wastewater plants. At this time we are unable to determine the cost impact of such regulations but any increase in operating costs associated with the cap and trade regulations will be included in our cost of service requested to be paid by our rate payers as requested in our general rate case filings. While recovery of these costs is not guaranteed, we would expect recovery in the regulatory process.

We are party to a toxic contamination lawsuit which could result in our paying damages not covered by insurance.

        We have been and may be in the future, party to water contamination lawsuits, which may not be fully covered by insurance.

        The number of environmental and product-related lawsuits against other water utilities have increased in frequency in recent years. If we are subject to additional environmental or product-related lawsuits, we might incur significant legal costs and it is uncertain whether we would be able to recover the legal costs from ratepayers or other third parties. In addition, if current California law regarding California Public Utilities Commission's preemptive jurisdiction over regulated public utilities for claims about compliance with California Department of Health Services and United States Environmental Protection Agency water quality standards changes, our legal exposure may be significantly increased.

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Risks Related to Our Business Operations

Wastewater operations entail significant risks.

        While wastewater collection and treatment is not presently a major component of our revenues, wastewater collection and treatment involve many risks associated with damage to the surrounding environment. If collection or treatment systems fail or do not operate properly, untreated or partially treated wastewater could discharge onto property or into nearby streams and rivers, causing property damage or injury to aquatic life, or even human life. Liabilities resulting from such damage could materially and adversely affect our results of operations and financial condition.

Demand for our water is subject to various factors and is affected by seasonal fluctuations.

        Demand for our water during the warmer, dry months is generally greater than during cooler or rainy months due primarily to additional requirements for water in connection with irrigation systems, swimming pools, cooling systems and other outside water use. Throughout the year, and particularly during typically warmer months, demand will vary with temperature and rainfall levels. If temperatures during the typically warmer months are cooler than normal, or if there is more rainfall than normal, the demand for our water may decrease. Under the WRAM mechanism, lower water usage impacts our cash flows in the year of usage, but results in higher cash flows in the following years.

        In addition, governmental restrictions on water usage during drought conditions may result in a decreased demand for our water, even if our water reserves are sufficient to serve our customers during these drought conditions. However, during the drought of the late 1980's and early 1990's the California Public Utilities Commission beginning in 1992 allowed us to surcharge our customers to collect lost revenues caused by customers' conservation during the drought. Regardless of whether we may surcharge our customers during a conservation period, they may use less water even after a drought has passed because of conservation patterns developed during the drought. Furthermore, our customers may wish to use recycled water as a substitute for potable water. If rights are granted to others to serve our customers recycled water, there will likely be a decrease in demand for our water.

The adequacy of our water supplies depends upon a variety of factors beyond our control. Interruption in the water supply may adversely affect our earnings.

        We depend on an adequate water supply to meet the present and future needs of our customers. Whether we have an adequate supply varies depending upon a variety of factors, many of which are partially or completely beyond our control, including:

•

the amount of rainfall;

•

the amount of water stored in reservoirs;

•

underground water supply from which well water is pumped;

•

availability from water wholesalers;

•

changes in the amount of water used by our customers;

•

water quality;

•

legal limitations on water use such as rationing restrictions during a drought; and

•

population growth.

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        We purchase our water supply from various governmental agencies and others. Water supply availability may be affected by weather conditions, funding and other political and environmental considerations. In addition, our ability to use surface water is subject to regulations regarding water quality and volume limitations. If new regulations are imposed or existing regulations are changed or given new interpretations, the availability of surface water may be materially reduced. A reduction in surface water could result in the need to procure more costly water from other sources, thereby increasing our water production costs and adversely affecting our operating results.

        We have entered into long-term water supply agreements, which commit us to making certain minimum payments whether or not we purchase any water. Therefore, if demand is insufficient to use our required purchases we would have to pay for water we did not receive.

        From time to time, we enter into water supply agreements with third parties and our business is dependent upon such agreements in order to meet regional demand. For example, we have entered into a water supply contract with the San Francisco Public Utilities Commission that expires on June 30, 2034. We can give no assurance that the San Francisco Public Utilities Commission, or any of the other parties from whom we purchase water, will renew our contracts upon expiration, or that we will not be subject to significant price increases under any such renewed contracts.

        The parties from whom we purchase water maintain significant infrastructure and systems to deliver water to us. Maintenance of these facilities is beyond our control. If these facilities are not adequately maintained or if these parties otherwise default on their obligations to supply water to us, we may not have adequate water supplies to meet our customers' needs.

        If we are unable to access adequate water supplies we may be unable to satisfy all customer demand which could result in rationing. Rationing may have an adverse effect on cash flow from operations. We can make no guarantee that we will always have access to an adequate supply of water that will meet all required quality standards. Water shortages may affect us in a variety of ways. For example, shortages could:

•

adversely affect our supply mix by causing us to rely on more expensive purchased water;

•

adversely affect operating costs;

•

increase the risk of contamination to our systems due to our inability to maintain sufficient pressure; and

•

increase capital expenditures for building pipelines to connect to alternative sources of supply, new wells to replace those that are no longer in service or are otherwise inadequate to meet the needs of our customers and reservoirs and other facilities to conserve or reclaim water.

        We may or may not be able to recover increased operating and construction costs on a timely basis, or at all, for our regulated systems through the ratemaking process. Although we can give no assurance, we may also be able to recover certain of these costs from third parties that may be responsible, or potentially responsible, for groundwater contamination.

Changes in water supply costs impact our operations.

        The cost to obtain water for delivery to our customers varies depending on the sources of supply, wholesale suppliers' prices, the quality of water required to be treated and the quantity of water produced to fulfill customer water demand. Our source of supply varies among our operating districts. Certain districts obtain all of their supply from wells; some districts purchase all of the supply from wholesale suppliers; and other districts obtain the supply from a combination of wells and wholesale suppliers. A small portion of supply comes from surface sources and is processed through Company-owned water treatment plants. On average, slightly more than half of the water we deliver to our customers is pumped from wells or received from a surface supply with the remainder purchased from wholesale suppliers.

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Water purchased from suppliers usually costs us more than surface supplied or well pumped water. The cost of purchased water for delivery to customers represented 33.1% and 32.8% of our total operating costs in 2012 and 2011, respectively.

        Wholesale water suppliers may increase their prices for water delivered to us based on factors that affect their operating costs. Purchased water rate increases are beyond our control. In California, effective July 1, 2008, our ability to recover increases in the cost of purchased water changed with the adoption of the MCBA. With this change, actual purchased water costs are compared to authorized purchased water costs with variances, netted against variance in purchased power, pump tax, and metered revenue, recorded to revenue. The balance in the MCBA will be collected in the future by billing the net WRAM and MCBA accounts receivable balances over 12, 24, and 36 month periods, which may have a short-term negative impact on cash flow.

Dependency upon adequate supply of electricity and certain chemicals could adversely affect our results of operations.

        Purchased electrical power is required to operate the wells and pumps needed to supply water to our customers. Although there are back-up power generators to operate a number of wells and pumps in emergencies, an extended interruption in power could impact the ability to supply water. In the past, California has been subject to rolling power blackouts due to insufficient power supplies. There is no assurance we will not be subject to power blackouts in the future. Additionally, we require sufficient amounts of certain chemicals in order to treat the water we supply. There are multiple sources for these chemicals but an extended interruption of supply could adversely affect our ability to adequately treat our water.

        Purchased power is a significant operating expense. During 2012 and 2011, purchased power expense represented 6.4% and 6.9% of our total operating costs, respectively. These costs are beyond our control and can change unpredictably and substantially as occurred in California during 2001 when rates paid for electricity increased 48%. As with purchased water, purchased power costs are included in the MCBA. Cash flows between rate filings may be adversely affected until the commission authorizes a rate change but earnings will be minimally impacted. Cost of chemicals used in the delivery of water is not an element of the MCBA and therefore variances in quantity or cost could impact the results of operations.

Our ability to generate new operating contracts or renewal of existing operating contracts is affected by local politics.

        Our revenue and non-regulated revenue growth depends upon our ability to generate new as well as renew operating contracts with cities, other agencies and municipal utility districts. As our services are sold in a political environment, there is exposure to changing trends and municipal preferences. Terrorist acts have affected some political viewpoints relative to outsourcing of water or wastewater utility services. Municipalities own and municipal employees operate the majority of water and wastewater systems. Significant marketing and sales efforts are spent demonstrating the benefits of contract operations to elected officials and municipal authorities. The existing political environment means decisions affecting our business are based on many factors, not just economic factors.

Our business requires significant capital expenditures that are dependent on our ability to secure appropriate funding. If we are unable to obtain sufficient capital or if the rates at which we borrow increase, there would be a negative impact on our results of operations.

        The water utility business is capital-intensive. We invest significant funds to add or replace property, plant and equipment. In addition, water shortages may adversely affect us by causing us to rely on more purchased water. This could cause increases in capital expenditures needed to build pipelines to secure alternative water sources. In addition, we require capital to grow our business through acquisitions. We fund our short-term capital requirements from cash received from operations and funds received from

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developers. We also borrow funds from banks under short-term bank lending arrangements. We seek to meet our long-term capital needs by raising equity through common or preferred stock issues or issuing debt obligations. We cannot give any assurance that these sources will continue to be adequate or that the cost of funds will remain at levels permitting us to earn a reasonable rate of return. In the event we are unable to obtain sufficient capital, our expansion efforts could be curtailed, which may affect our growth and may affect our future results of operations.

        Our ability to access the capital markets is affected by the ratings of certain of our debt securities. Standard & Poor's Rating Agency issues a rating on California Water Service Company's ability to repay certain debt obligations. The credit rating agency could downgrade our credit rating based on reviews of our financial performance and projections or upon the occurrence of other events that could impact our business outlook. Lower ratings by the agency could restrict our ability to access equity and debt capital. We can give no assurance that the rating agency will maintain ratings which allow us to borrow under advantageous conditions and at reasonable interest rates. A future downgrade by the agency could also increase our cost of capital by causing potential investors to require a higher interest rate due to a perceived risk related to our ability to repay outstanding debt obligations.

        While the majority of our debt is long term at fixed rates, we do have interest rate exposure in our short-term borrowings which have variable interest rates. We are also subject to interest rate risks on new financings. However, if interest rates were to increase on a long-term basis, our management believes that customer rates would increase accordingly, subject to approval by the appropriate commission. We can give no assurance that the commission would approve such an increase in customer rates.

        We are obligated to comply with specified debt covenants under certain of our loan and debt agreements. Failure to maintain compliance with these covenants could limit future borrowing, and we could face increased borrowing costs, litigation, acceleration of maturity schedules, and cross default issues. Such actions by our creditors could have a material adverse effect on our financial condition and results of operations.

Adverse changes to the national and world-wide financial system could result in disruptions in the financial and real estate markets availability and cost of short-term funds for our liquidity requirements, our ability to meet long-term commitments, and our customers' ability to pay for water services. Any of these could adversely affect our results of operations, cash flows and financial condition.

        We rely on our current credit facilities to fund short-term liquidity needs if internal funds are not available from operations. Specifically, given the seasonal fluctuations in demand for our water we commonly draw on our credit facilities to meet our cash requirements at times in the year when demand is relatively low. We also may occasionally use letters of credit issued under our revolving credit facilities. Disruptions in the capital and credit markets or further deterioration in the strength of financial institutions could adversely affect our ability to draw on our credit facilities. Our access to funds under our credit facilities is dependent on the ability of our banks to meet its funding commitments.

        Longer-term disruptions in the financial markets as a result of uncertainty, changing or increased regulation, reduced capital-raising alternatives, or failures of significant financial institutions or other factors could adversely affect our access to liquidity. Any disruption could require us to take measures to conserve cash until the markets stabilize or until alternative credit arrangements or other funding for business needs can be arranged. Such measures could include deferring capital expenditures, dividend payments or other discretionary uses of cash.

        Many of our customers and suppliers also have exposure to risks that could affect their ability to meet payment and supply commitments. We operate in geographic areas that may be particularly susceptible to declines in the price of real property, which could result in significant declines in demand for our products and services. In the event that any of our significant customers or suppliers, or a significant number of smaller customers and suppliers, are adversely affected by these risks, we may face disruptions in supply,

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significant reductions in demand for our products and services, inability of customers to pay invoices when due, and other adverse effects that could negatively affect our financial condition, results of operations and/or cash flows.

        Our operations and certain contracts for water distribution and treatment depend on the financial capability of state and local governments, and other municipal entities such as water districts. Major disruptions in the financial strength or operations of such entities, such as liquidity limitations, bankruptcy or insolvency, could have an adverse effect on our ability to conduct our business and/or enforce our rights under contracts to which such entities are a party.

We are a holding company that depends on cash flow from our subsidiaries to meet our obligations and to pay dividends on our common stock.

        As a holding company, we conduct substantially all of our operations through our subsidiaries and our only significant assets are investments in those subsidiaries. 94% of our revenues are derived from the operations of California Water Service Company. As a result, we are dependent on cash flow from our subsidiaries, and California Water Service Company in particular, to meet our obligations and to pay dividends on our common stock.

        We can make dividend payments only from our surplus (the excess, if any, of our net assets over total paid-in capital) or if there is no surplus, the net profits for the current fiscal year or the fiscal year before which the dividend is declared. In addition, we can pay cash dividends only if after paying those dividends we would be able to pay our liabilities as they become due. Owners of our capital stock cannot force us to pay dividends and dividends will only be paid if and when declared by our board of directors. Our board of directors can elect at any time, and for an indefinite duration, not to declare dividends on our capital stock.

        Our subsidiaries are separate and distinct legal entities and generally have no obligation to pay any amounts due on California Water Service Group's debt or to provide California Water Service Group with funds for dividends. Although there are no contractual or regulatory restrictions on the ability of our subsidiaries to transfer funds to us, the reasonableness of our capital structure is one of the factors considered by state and local regulatory agencies in their ratemaking determinations. Therefore, transfer of funds from our subsidiaries to us for the payment of our obligations or dividends may have an adverse effect on ratemaking determinations. Furthermore, our right to receive cash or other assets upon the liquidation or reorganization of a subsidiary is generally subject to the prior claims of creditors of that subsidiary. If we are unable to obtain funds from our subsidiaries in a timely manner, we may be unable to meet our obligations or pay dividends.

An important element of our growth strategy is the acquisition of water and wastewater systems. Risks associated with potential acquisitions, divestitures or restructurings may adversely affect us.

        We may seek to acquire or invest in other companies, technologies, services or products that complement our business. The execution of our growth strategy may expose us to different risks than those associated with our utility operations. We can give no assurance that we will succeed in finding attractive acquisition candidates or investments, or that we would be able to reach mutually agreeable terms with such parties. In addition, as consolidation becomes more prevalent in the water and wastewater industries, the prices for suitable acquisition candidates may increase to unacceptable levels and limit our ability to grow through acquisitions. If we are unable to find acquisition candidates or investments, our ability to grow may be limited.

        Acquisition and investment transactions may result in the issuance of our equity securities that could be dilutive if the acquisition or business opportunity does not develop in accordance with our business plan. They may also result in significant write-offs and an increase in our debt. The occurrence of any of these events could have a material adverse effect on our business, financial condition and results of operations.

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        Any of these transactions could involve numerous additional risks, including one or more of the following:

•

problems integrating the acquired operations, personnel, technologies or products with our existing businesses and products;

•

liabilities inherited from the acquired companies' prior business operations;

•

diversion of management time and attention from our core business to the acquired business;

•

failure to retain key technical, management, sales and other personnel of the acquired business;

•

difficulty in retaining relationships with suppliers and customers of the acquired business; and

•

difficulty in getting required regulatory approvals.

        In addition, the businesses and other assets we acquire may not achieve the sales and profitability expected. The occurrence of one or more of these events may have a material adverse effect on our business. There can be no assurance that we will be successful in overcoming these or any other significant risks encountered.

We may not be able to increase or sustain our recent growth rate, and we may not be able to manage our future growth effectively.

        We may be unable to continue to expand our business or manage future growth. To successfully manage our growth and handle the responsibilities of being a public company, we believe we must effectively:

•

hire, train, integrate and manage additional qualified engineers for engineering design and construction activities, new business personnel, and financial and information technology personnel;

•

retain key management, augment our management team, and retain qualified and certified water and wastewater system operators;

•

implement and improve additional and existing administrative, financial and operations systems, procedures and controls;

•

expand and upgrade our technological capabilities; and

•

manage multiple relationships with our customers, regulators, suppliers and other third parties.

        If we are unable to manage our growth effectively, we may not be able to take advantage of market opportunities, satisfy customer requirements, execute our business plan or respond to competitive pressures.

We have a number of large-volume commercial and industrial customers and a significant decrease in consumption by one or more of these customers could have an adverse effect on our operating results and cash flows.

        Our billed revenues will decrease, and such decrease may be material, if a significant business or industrial customer terminates or materially reduces its use of our water. Approximately $132.1 million, or 23.6%, of our 2012 water utility revenues was derived from business and industrial customers. If any of our large business or industrial customers in California reduce or cease its consumption of our water, the impact to net operating income would be minimal to our operations due to the WRAM and MCBA, but could impact our cash flows. In Hawaii, we serve a number of large resorts which if their water usage was reduced or ceased could have a material impact to our Hawaii operation. The delay between such date and the effective date of the rate relief may be significant and could adversely affect our operating results and cash flows.

33

Our operating cost and costs of providing services may rise faster than our revenues.

        Our ability to increase rates over time is dependent upon approval of such rate increases by state commissions, or in the case of the City of Hawthorne and the City of Commerce, the City Council, which may be inclined, for political or other reasons, to limit rate increases. However, our costs are subject to market conditions and other factors, which may increase significantly. The second largest component of our operating costs after water production is made up of salaries and wages. These costs are affected by the local supply and demand for qualified labor. Other large components of our costs are general insurance, workers compensation insurance, employee benefits and health insurance costs. These costs may increase disproportionately to rate increases authorized by state commissions and may have a material adverse effect on our future results of operations.

Our non-regulated business operates in a competitive market.

        While a majority of our business is regulated, our non-regulated business participates in a competitive market. We compete with several larger companies whose size, financial resources, customer base and technical expertise may restrict our ability to compete successfully for certain operations and maintenance contracts. Due to the nature of our contract operations business, and to the very competitive nature of the market, we must accurately estimate the cost and profitability of each project while, at the same time, maintaining prices at a level low enough to compete with other companies. Our inability to achieve this balance could adversely impact our results of operations.

Demand for our stock may fluctuate due to circumstances beyond our control.

        We believe that stockholders invest in public utility stocks, in part, because they seek reliable dividend payments. If there is an over-supply of stock of public utilities in the market relative to demand by such investors, the trading price of our securities could decrease. Additionally, if interest rates rise above the dividend yield offered by our equity securities, demand for our stock, and consequently its market price, may also decrease. A decline in demand for our stock may have a negative impact on our ability to finance capital projects.

The price of our common stock may be volatile and may be affected by market conditions beyond our control.

        The trading price of our common stock may fluctuate in the future because of the volatility of the stock market and a variety of other factors, many of which are beyond our control. Factors that could cause fluctuations in the trading price of our common stock include: regulatory developments; general economic conditions and trends; price and volume fluctuations in the overall stock market from time to time; actual or anticipated changes or fluctuations in our results of operations; actual or anticipated changes in the expectations of investors or securities analysts; actual or anticipated developments in our competitors' businesses or the competitive landscape generally; litigation involving us or our industry; and major catastrophic events or sales of large blocks of our stock.

        Equity markets in general can experience extreme price and volume fluctuations. Such price and volume fluctuations may continue to adversely affect the market price of our common stock for reasons unrelated to our business or operating results.

Adverse investment returns and other factors may increase our pension liability and pension funding requirements.

        A substantial number of our employees are covered by a defined benefit pension plan. At present, the pension plan is underfunded because our projected pension benefit obligation exceeds the aggregate fair value of plan assets. Under applicable law, we are required to make cash contributions to the extent necessary to comply with minimum funding levels imposed by regulatory requirements. The amount of such required cash contribution is based on an actuarial valuation of the plan. The funded status of the plan can be affected by investment returns on plan assets, discount rates, mortality rates of plan

34

participants, pension reform legislation and a number of other factors. There can be no assurance that the value of our pension plan assets will be sufficient to cover future liabilities. Although we have made contributions to our pension plan in recent years, it is possible that we could incur a pension liability adjustment, or could be required to make additional cash contributions to our pension plan, which would reduce the cash available for business and other needs.

Work stoppages and other labor relations matters could adversely affect our operating results.

        At December 31, 2012, 734 of our 1,131 total employees were union employees. Most of our unionized employees are represented by the Utility Workers Union of America, AFL-CIO, except certain engineering and laboratory employees who are represented by the International Federation of Professional and Technical Engineers, AFL-CIO.

        We believe our labor relations are good, but in light of rising costs for healthcare and pensions, contract negotiations in the future may be difficult. Furthermore, changes in applicable law or regulations could have an adverse effect on management's negotiating position with respect to our currently unionized employees and/or employees that decide to unionize in the future. We are subject to a risk of work stoppages and other labor relations matters as we negotiate with the unions to address these issues, which could affect our results of operations and financial condition. We can give no assurance that issues with our labor forces will be resolved favorably to us in the future or that we will not experience work stoppages.

We depend significantly on the services of the members of our management team, and the departure of any of those persons could cause our operating results to suffer.

        Our success depends significantly on the continued individual and collective contributions of our management team. The loss of the services of any member of our management team could have a material adverse effect on our business as our management team has knowledge of our industry and customers and would be difficult to replace.

Our operations are geographically concentrated in California and this lack of diversification may negatively impact our operations.

        Although we own facilities in a number of states, over 94% of our operations are located in California. As a result, we are largely subject to weather, political, water supply, labor, utility cost, regulatory and economic risks affecting California.

        We are also affected by the real property market in California. In order to grow our business, we may need to acquire additional real estate or rights to use real property owned by third parties, the cost of which tends to be higher and more volatile in California relative to other states. The value of our assets in California may decline if there is a decline in the California real estate market which results in a significant decrease in real property values.

        In 2008 and 2009, we experienced higher than normal uncollectible accounts activity which, we believe, were attributable in part to the significant declines in real estate values and rising unemployment experienced by our customers in a number of our districts in California due to the economic recession. We may experience higher than normal uncollectible accounts activity if real estate values decline and unemployment rates continue to increase.

The effects of natural disasters, terrorist activity, pandemics, or poor water quality or contamination to our water supply may result in disruption in our services and litigation which could adversely affect our business, operating results and financial condition.

        We operate in areas that are prone to earthquakes, fires, mudslides and other natural disasters. A significant seismic event or other natural disaster in California where our operations are concentrated

35

could adversely impact our ability to deliver water and adversely affect our costs of operations. A major disaster could damage or destroy substantial capital assets. The California Public Utilities Commission has historically allowed utilities to establish a catastrophic event memorandum account as another possible mechanism to recover costs. However, we can give no assurance that the CPUC or any other commission would allow any such cost recovery mechanism in the future.

        Our water supplies are subject to contamination, including contamination from the development of naturally-occurring compounds, chemicals in groundwater systems, pollution resulting from man-made sources, such as MTBE, sea water incursion and possible terrorist attacks. If our water supply is contaminated, we may have to interrupt the use of that water supply until we are able to substitute the flow of water from an uncontaminated water source. In addition, we may incur significant costs in order to treat the contaminated source through expansion of our current treatment facilities, or development of new treatment methods. If we are unable to substitute water supply from an uncontaminated water source, or to adequately treat the contaminated water source in a cost-effective manner, there may be an adverse effect on our revenues, operating results and financial condition. The costs we incur to decontaminate a water source or an underground water system could be significant and could adversely affect our business, operating results and financial condition and may not be recoverable in rates. We could also be held liable for consequences arising out of human exposure to hazardous substances in our water supplies or other environmental damage. For example, private plaintiffs have the right to bring personal injury or other toxic tort claims arising from the presence of hazardous substances in our drinking water supplies. Our insurance policies may not be sufficient to cover the costs of these claims.

        We operate a dam. If the dam were to fail for any reason, we would lose a water supply and flooding likely would occur. Whether or not we were responsible for the dam's failure, we could be sued. We can give no assurance that we would be able to successfully defend such a suit.

        In light of the threats to the nation's health and security ensuing in the wake of the September 11, 2001 terrorist attacks, we have taken steps to increase security measures at our facilities and heighten employee awareness of threats to our water supply. We have also tightened our security measures regarding the delivery and handling of certain chemicals used in our business. We have and will continue to bear increased costs for security precautions to protect our facilities, operations and supplies. These costs may be significant. Despite these tightened security measures, we may not be in a position to control the outcome of terrorist events should they occur.

        We depend upon our skilled and trained workforce to ensure water delivery. Were a pandemic to occur, we can give no assurance that we would be able to maintain sufficient manpower to ensure uninterrupted service in all of the districts that we serve.

We retain certain risks not covered by our insurance policies.

        We evaluate our risks and insurance coverage annually. Our evaluation considers the costs, risks and benefits of retaining versus insuring various risks as well as the availability of certain types of insurance coverage. Furthermore, we are also affected by increases in prices for insurance coverage; in particular, we have been, and will continue to be, affected by rising health insurance costs. Retained risks are associated with deductible limits, partial self-insurance programs and insurance policy coverage ceilings. If we suffer an uninsured loss, we may be unable to pass all, or any portion, of the loss on to customers because our rates are regulated by regulatory commissions. Consequently, uninsured losses may negatively affect our financial condition, liquidity and results of operations. There can be no assurance that we will not face uninsured losses pertaining to the risks we have retained.

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We rely on our information technology and a number of complex business systems that could malfunction and result in negative impacts on our profitability and cash flow.

        Our business is dependent on several complex business systems, certain of which are owned by third parties. The business systems must function reliably in order for us to operate effectively. Among other things, system malfunctions and security breaches could prevent us from operating or monitoring our facilities, billing accurately and timely analysis of financial results. Our profitability and cash flow could be affected negatively in the event these systems do not operate effectively or are circumvented.

The accuracy of our judgments and estimates about financial and accounting matters will impact our operating results and financial condition.

        We make certain estimates and judgments in preparing our financial statements regarding, among others:

•

the useful life of intangible rights;

•

the number of years to depreciate certain assets;

•

amounts to set aside for uncollectible accounts receivable, inventory obsolescence and uninsured losses;

•

our legal exposure and the appropriate accrual for claims, including medical claims and workers' compensation claims;

•

future costs and assumptions for pensions and other post-retirement benefits;

•

regulatory recovery of deferred items;

•

possible tax uncertainties; and

•

projected collections of WRAM/MCBA receivables.

        The quality and accuracy of those estimates and judgments will have an impact on our operating results and financial condition.

        In addition, we must estimate unbilled revenues and costs as of the end of each accounting period. If our estimates are not accurate, we will be required to make an adjustment in a future period. Accounting rules permit us to use expense balancing accounts and memorandum accounts that include input cost changes to us that are different from amounts incorporated into the rates approved by the commissions. These accounts result in expenses and revenues being recognized in periods other than in which they occurred.

Our controls and procedures may fail or be circumvented.

        Management regularly reviews and updates our internal control over financial reporting, disclosure controls and procedures, and corporate governance policies and procedures. Any system of controls and procedures, however well designed and operated, is based in part on certain assumptions and can provide only reasonable, not absolute, assurances that the objectives of the system are met. Any failure or circumvention of our controls and procedures or failure to comply with regulations related to controls and procedures could result in lack of compliance with contractual agreements, misstatements in our financial statements in amounts that could be material or could cause investors to lose confidence in our reported financial information, either of which could have a negative effect on the trading price of our stock and may negatively affect our ability to raise future capital.

        Further, if we or our independent registered public accounting firm discover a material weakness in our internal control over financial reporting, the disclosure of that fact, even if quickly remedied, could reduce the market's confidence in our financial statements and harm our stock price. In addition,

37

non-compliance with Section 404 of the Sarbanes-Oxley Act of 2002 could subject us to a variety of administrative sanctions, including the suspension or delisting of our common stock from the New York Stock Exchange and the inability of registered broker-dealers to make a market in our common stock, which would further reduce our stock price.

We may be required to adopt International Financial Reporting Standards (IFRS), or other accounting or financial reporting standards, the ultimate adoption of which could negatively impact our business, financial condition or results of operations.

        We could be required to adopt IFRS or other accounting or financial reporting standards different from Generally Accepted Accounting Principles (GAAP) in the United States of America, which is currently applicable to our accounting and financial reporting. In 2008 the SEC released a proposed roadmap for the adoption of IFRS according to which we could be required to adopt IFRS in the future. Under GAAP we are subject to the accounting procedures for accounting for the effects of certain types of regulation, which, among other things, allows us to defer certain costs if we believe it is probable that we will be allowed to recover those costs by future rate increases. Currently, IFRS does not contain provisions equivalent to the current GAAP accounting procedures. The implementation and adoption of new accounting or financial reporting standards could affect our reported performance, which in turn could favorably or unfavorably impact our business, financial condition or results of operations. Furthermore, the transition to and application of new accounting or financial reporting standards could result in increased administrative costs. The SEC is expected to make a final determination regarding the adoption of IFRS at a later date.

Municipalities, water districts and other public agencies may condemn our property by eminent domain action.

        State statutes allow municipalities, water districts and other public agencies to own and operate water systems. These agencies are empowered to condemn properties already operated by privately owned public utilities. However, whenever a public agency constructs facilities to extend a utility system into the service area of a privately owned public utility, such an act constitutes the taking of property and requires reimbursement to the utility for its loss. If a public agency were to acquire our utility property by eminent domain action, we would be entitled to just compensation for our loss, but we would no longer have access to the condemned property nor would we be entitled to any portion of revenue generated from the use of such asset going forward.

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Item 1B.    Unresolved Staff Comments.

None

Item 2.    Properties.

        Our physical properties consist of offices and water facilities to accomplish the production, storage, treatment, and distribution of water. These properties are located in or near the geographic service areas listed above in Item 1, "Business—Geographical Service Areas and Number of Customers at Year-end." Our headquarters, which houses accounting, engineering, information systems, human resources, purchasing, regulatory, water quality, and executive staff, is located in San Jose, California.

        The real properties owned are held in fee simple title. Properties owned by Cal Water are subject to the lien of an Indenture of Mortgage and Deed of Trust dated April 17, 2009 (the California Indenture), securing Cal Water's first mortgage bonds, of which $459.2 million was outstanding at December 31, 2012. The California Indenture contains certain restrictions common to such types of instruments regarding the disposition of property and includes various covenants and restrictions. At December 31, 2012, our California utility was in compliance with the covenants of the California Indenture.

        Cal Water owns 629 wells and operates 4 leased wells. There are 434 owned storage tanks with a capacity of 492 million gallons, 3 leased storage tanks with a capacity of 0.7 million gallons, 36 managed storage tanks with a capacity of 30 million gallons, and 3 reservoirs with a capacity of 250 million gallons. Cal Water owns and operates 6 surface water treatment plants with a combined capacity of 46 million gallons per day. There are 5,759 miles of supply and distribution mains in the various systems.

        Hawaii Water owns 20 wells and manages 5 irrigation wells. There are 24 storage tanks with a storage capacity of 20 million gallons. There are 70 miles of supply and distribution lines. Hawaii Water operates 5 wastewater treatment facilities with a combined capacity to process approximately 1.7 million gallons per day. There are 26 miles of sewer collection mains.

        Washington Water owns 341 wells and manages 113 wells. There are 127 owned storage tanks and 41 managed storage tanks with a storage capacity of 9 million gallons. There are 328 miles of supply and distribution lines.

        New Mexico Water owns 17 wells. There are 12 storage tanks with a storage capacity of 4 million gallons. There are 134 miles of supply and distribution lines. New Mexico operates 2 waste water treatment facilities with a combined capacity to process 0.5 million gallons per day. There are 34 miles of sewer collection mains.

        Washington Water has long-term bank loans that are secured primarily by utility plant owned by Washington Water. New Mexico Water has a long-term loan that is secured by utility plant owned by New Mexico Water.

        In the leased City of Hawthorne and City of Commerce systems or in systems that are operated under contract for municipalities or private companies, title to the various properties is held exclusively by the municipality or private company.

Item 3.    Legal Proceedings.

        Information with respect to this item may be found under the subheading "Contingencies" in Note 14 to the consolidated Financial Statements in Item 8, which is incorporated herein by reference.

Item 4.    Mine Safety Disclosures.

        Not applicable.

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PART II

Item 5.    Market for Registrant's Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

        Our common stock is traded on the New York Stock Exchange under the symbol "CWT." At December 31, 2012, there were 41,908,218 common shares outstanding. There were 2,337 common stockholders of record as of February 11, 2013.

        During 2012, we paid a cash dividend of $0.630 per common share, or $0.15750 per quarter. During 2011, we paid a cash dividend of $0.615 per common share, or $0.15375 per quarter. In January 2013, our Board of Directors declared a quarterly cash dividend of $0.1600 per common share payable on February 22, 2013, to stockholders of record on February 11, 2013. This represents our 46th consecutive year of increasing the annual dividend and marks the 272nd consecutive quarterly dividend.

        We presently intend to pay quarterly cash dividends in the future consistent with past practices, subject to our earnings and financial condition, restrictions set forth in our debt instruments, regulatory requirements and such other factors as our Board of Directors may deem relevant.

        During 2012 and 2011, the common stock market price range and dividends per share for each quarter were as follows:

2012	First		Second		Third		Fourth
Common stock market price range:
High	$	19.25	$	18.60	$	19.05	$	18.90
Low		17.67		17.14		17.93		16.84
Dividends paid per common share		0.15750		0.15750		0.15750		0.15750

2011	First		Second		Third		Fourth
Common stock market price range:
High	$	19.18	$	19.16	$	19.37	$	19.20
Low		17.28		18.06		16.65		16.81
Dividends paid per common share		0.15375		0.15375		0.15375		0.15375

        Amounts above have been restated to reflect the 2 for 1 stock split effective June 10, 2011, which was retroactively applied to our financial statements.

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Five-Year Performance Graph

        The following performance graph compares the changes in the cumulative shareholder return on California Water Service Group's common stock with the cumulative total return on the Robert W. Baird Water Utility Index and the Standard & Poor's 500 Index during the last five years ended December 31, 2012. The comparison assumes $100 was invested on December 31, 2007, in California Water Service Group's common stock and in each of the forgoing indices and assumes reinvestment of dividends.

Performance Graph Data

        The following descriptive data is supplied in accordance with Rule 304(d) of Regulations S-T:

	2007		2008		2009		2010		2011		2012
California Water Service Group		100		130		106		111		112		117
S &P 500		100		63		80		92		94		109
RW Baird Water Utility Index		100		93		99		114		121		142

        An initial $10,000 investment in the common stock of California Water Service Group on December 31, 2007 including reinvestment of dividends would be worth $11,700 at the end of the 5-year period ending December 31, 2012.

Item 6.    Selected Financial Data.

        The following selected consolidated financial data should be read in conjunction with our Consolidated Financial Statements and the Notes thereto and the information contained in Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations."

        Historical results are not necessarily indicative of future results.

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FIVE YEAR FINANCIAL REVIEW

	2012			2011			2010			2009			2008
	(Dollars in thousands, except common share and other data)
Summary of Operations
Operating revenue
Residential	$	394,736		$	375,703		$	335,833		$	315,617		$	284,913
Business		106,674			100,050			90,992			86,766			75,620
Industrial		25,467			24,612			20,733			18,963			18,932
Public authorities		29,568			28,278			23,904			22,408			21,042
Other		26,567			(3,033	)		11,666			14,798			12,745
MCBA net adjustment to reduce adopted revenue		(23,046	)		(23,796	)		(22,729	)		(9,180	)		(2,940	)
Total operating revenue		559,966			501,814			460,399			449,372			410,312
Operating expenses		486,123			434,647			398,586			391,253			352,843
Interest expense, other income and expenses, net		25,015			29,455			24,157			17,565			17,664
Net income	$	48,828		$	37,712		$	37,656		$	40,554		$	39,805
Common Share Data
Earnings per share—diluted	$	1.17		$	0.90		$	0.90		$	0.98		$	0.95
Dividend paid		0.630			0.615			0.595			0.590			0.585
Dividend payout ratio		54	%		68	%		66	%		61	%		62	%
Book value per share	$	11.30		$	10.76		$	10.45		$	10.13		$	9.72
Market price at year-end		18.35			18.26			18.64			18.41			23.22
Common shares outstanding at year-end (in thousands)		41,908			41,817			41,667			41,531			41,446
Return on average common stockholders' equity		10.6	%		8.5	%		9.0	%		9.8	%		10.2	%
Long-term debt interest coverage		3.45			3.11			3.59			4.04			4.72
Balance Sheet Data
Net utility plant	$	1,457,056		$	1,381,119		$	1,294,297		$	1,198,077		$	1,112,367
Total assets		1,995,924			1,854,587			1,692,066			1,525,581			1,418,107
Long-term debt including current portion		481,250			488,165			481,561			387,222			290,316
Capitalization ratios:
Common stockholders' equity		49.6	%		48.0	%		47.5	%		52.1	%		58.1	%
Preferred stock		—			—			—			—			—
Long-term debt		50.4	%		52.0	%		52.5	%		47.9	%		41.9	%
Other Data
Estimated water production (million gallons)
Wells and surface supply		66,184			64,100			65,288			71,266			72,228
Purchased		59,708			56,253			56,654			60,292			65,529
Total estimated water production		125,892			120,353			121,942			131,558			137,757
Metered customers		458,400			451,900			438,600			426,600			417,208
Flat-rate customers		42,300			47,600			59,300			68,100			73,285
Customers at year-end**		500,700			499,500			497,900			494,700			490,493
New customers added		1,200			1,600			3,200			4,207			2,938
Revenue per customer	$	1,118		$	1,005		$	925		$	908		$	837
Utility plant per customer		4,187			3,925			3,706			3,455			3,228
Employees at year-end		1,131			1,132			1,127			1,013			929

**

Includes customers of the City of Hawthorne and City of Commerce

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Item 7.    Management's Discussion and Analysis of Financial Condition and Results of Operations.

Overview

        In 2012 and 2011, net income was $48.8 million and $37.7 million, respectively. Diluted earnings per share increased $0.27 to $1.17 or 30% from 2011 to 2012. The increase in net income was primarily attributable to a one-time income tax benefit of $6.2 million related to 2011 and prior years for state income tax repairs and maintenance deductions that we recognized in 2012, an unrealized pre-tax gain of $2.5 million on our benefit plan insurance investments, a one-time benefit of 2011 deferred WRAM operating revenues of $12.9 million and associated costs of $10.5 million that we recognized in 2012, a decrease in the current year income tax provision due to the repairs and maintenance deductions, and lower financing costs for short-term borrowings, which was partially offset by a $3.9 million reduction to operating revenues due to the cost of capital adjustment mechanism and cost increases for employee wages and benefits, water production costs, and depreciation on plant placed into service during 2011.

        Net income was $37.7 million in 2011 and 2010. Diluted earnings per common share were $0.90 in 2011 and 2010. The weighted average number of common shares outstanding used in the diluted earnings per share calculation was 41,772,000 in 2011 and 41,638,000 in 2010. Net income was the same in 2011 and 2010 because rate increases from the 2009 GRC and corresponding approved rates were offset by increases to operating expenses, long-term debt interest expense, and a reduction in net other income.

        The 2009 GRC and corresponding approved rates, and GRCs filed in Hawaii will increase 2013 authorized operating revenues. The cost of capital adjustment mechanism (CCAM) required a reduction to 2013 authorized operating revenues of $3.8 million due to a decrease in the Moody AA utility bond index as of September 30, 2012 compared to September 30, 2011. The CCAM 2013 adjustment will reduce the authorized rate of return. The 2012 GRC will not increase authorized operating revenues until 2014. (see discussion in Regulatory Matters section of this annual report).

        We plan to continue to seek rate relief to recover our operating cost increases and receive reasonable returns on invested capital. We expect to fund our long-term capital needs through a combination of debt, common stock offerings, and cash flow from operations.

Critical Accounting Policies and Estimates

        We maintain our accounting records in accordance with accounting principles generally accepted in the United States of America and as directed by the Commissions to which our operations are subject. The process of preparing financial statements requires the use of estimates on the part of management. The estimates used by management are based on historic experience and an understanding of current facts and circumstances. A summary of our significant accounting policies is listed in Note 2 of the Notes to Consolidated Financial Statements. The following sections describe those policies where the level of subjectivity, judgment, and variability of estimates could have a material impact on the financial condition, operating performance, and cash flows of the business.

Revenue Recognition

        Revenue generally includes monthly cycle customer billings for regulated water and wastewater services at rates authorized by regulatory Commissions (plus an estimate for water used between the customer's last meter reading and the end of the accounting period) and billings to certain non-regulated customers at rates authorized by contract with government agencies.

        The Company's regulated water and waste water revenue requirements are authorized by the Commissions in the states in which we operate. The revenue requirements are intended to provide the Company a reasonable opportunity to recover its cost of service and earn a return on investments.

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        For metered customers, Cal Water recognizes revenue from rates which are designed and authorized by the CPUC. Under the Water Revenue Adjustment Mechanism (WRAM), Cal Water records the adopted level of volumetric revenues, which would include recovery of cost of service and a return on investments as established by the CPUC for metered accounts (adopted volumetric revenues). In addition to volumetric-based revenues, the revenue requirements approved by the CPUC include service charges, flat rate charges, and other items not subject to the WRAM. The adopted volumetric revenue considers the seasonality of consumption of water based upon historical averages. The variance between adopted volumetric revenues and actual billed volumetric revenues for metered accounts is recorded as a component of revenue with an offsetting entry to a regulatory asset or liability balancing account (tracked individually for each Cal Water district) subject to certain criteria under the accounting for regulated operations being met. The variance amount may be positive or negative and represents amounts that will be billed or refunded to customers in the future.

        Cost-recovery rates are designed to permit full recovery of certain costs allowed to be recovered by the commissions. Cost-recovery rates such as the Modified Cost Balancing Account (MCBA) provides for recovery of adopted expense levels for purchased water, purchased power and pump taxes, as established by the CPUC. In addition, cost-recovery rates include recovery of cost related to water conservation programs and certain other operation expenses adopted by the CPUC. Variances (which include the effects of changes in both rate and volume for the MCBA) between adopted and actual costs are recorded as a component of revenue, as the amount of such variances will be recovered from or refunded to our customers at a later date. There is no profit associated with cost-recovery expenses which are generally recognized when the expenses are incurred.

        The balances in the WRAM and MCBA assets and liabilities accounts will fluctuate on a monthly basis depending upon the variance between adopted and actual results. The recovery or refund of the WRAM is netted against the MCBA over- or under-recovery for the corresponding district and is interest bearing at the current 90 day commercial paper rate. At the end of the calendar year, Cal Water files with the CPUC to refund or collect the balance in the accounts. On April 19, 2012, the CPUC issued a decision to shorten the amortization periods for Cal Water's undercollected net WRAM and MCBA receivable balances. As a result of the decision, most balances are collected over 12 and 18 months. Cal Water defers any net WRAM and MCBA revenues and associated costs whenever the net receivable balances are estimated to be collected more than 24 months after the respective reporting period in which it was recorded. Cal Water excluded net WRAM and MCBA revenues of $0.9 million, associated costs of $0.7 million, and the related $0.2 million of net operating income before income taxes as of December 31, 2012 due to the net receivable balances estimated to be collected more than 24 months. The deferred net WRAM and MCBA revenue and associated costs were determined using forecasts of rate payer consumption trends in future reporting periods and the timing of when the CPUC will authorize Cal Water's filings to recover unbilled balances. Deferred revenues and associated costs are recorded in future periods as the collection becomes within 24 months of the respective reporting period.

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        The net WRAM and MCBA balances included in regulatory assets and liabilities as of December 31, 2012 and 2011 are:

	2012		2011
	Dollars in millions
Net short-term receivable	$	34.0	$	19.4
Net long-term receivable		12.1		30.2
Total receivable	$	46.1	$	49.6
Net short-term payable	$	0.4	$	0.5
Net long-term payable		0.1		0.2
Total payable	$	0.5	$	0.7

        Flat rate customers are billed in advance at the beginning of the service period. The revenue is prorated so that the portion of revenue applicable to the current period is included in that period's revenue, with the balance recorded as unearned revenue on the balance sheet and recognized as revenue when earned in the subsequent accounting period. Our unearned revenue liability was $1.7 million and $1.9 million as of December 31, 2012 and 2011, respectively. This liability is included in "other accrued liabilities" on our consolidated balance sheets.

Regulated Utility Accounting

        Because we operate extensively in a regulated business, we are subject to the accounting standards for regulated utilities. The Commissions in the states in which we operate establish rates that are designed to permit the recovery of the cost of service and a return on investment. We capitalize and record regulatory assets for costs that would otherwise be charged to expense if it is probable that the incurred costs will be recovered in future rates. Regulatory assets are amortized over the future periods that the costs are expected to be recovered. If costs expected to be incurred in the future are currently being recovered through rates, we record those expected future costs as regulatory liabilities. In addition, we record regulatory liabilities when the Commissions require a refund to be made to our customers over future periods.

        Determining probability requires significant judgment by management and includes, but is not limited to, consideration of testimony presented in regulatory hearings, proposed regulatory decisions, final regulatory orders, and the strength or status of applications for rehearing or state court appeals. We also record a regulatory asset when a mechanism is in place to recover current expenditures and historical experience indicates that recovery of incurred costs is probable, such as the regulatory assets for pension benefits; and deferred income tax.

        If we determine that a portion of our assets used in utility operations is not recoverable in customer rates, we would be required to impair an asset and write-down the assets' valuation. The 2010 Hawaii Water GRC for the Ka'anapali District included a $0.3 million asset impairment which was recorded during 2011 and the 2009 Cal Water GRC settlement included a $0.6 million asset impairment which was recorded during 2010.

Goodwill Accounting and Evaluation for Impairment

        In November of 2012 and 2011, we performed annual impairment tests of the remaining goodwill balance of $2.6 million by comparing the fair value of Hawaii Water, the reporting unit, with its carrying amount, including goodwill and no impairment was recorded. Our analysis considered the approval of future rate case proceedings for the various operations of Hawaii Water based on historical rate of return filings allowed by the Hawaii Public Utilities Commission. To the extent the approved rate of return filings

45

allowed by the Hawaii Public Utilities Commission are less than expected, an impairment of the recorded goodwill may occur.

Income Taxes

        We account for income taxes using the asset and liability method. Deferred tax assets and liabilities are recognized for future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. We measure deferred tax assets and liabilities at enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. We recognize the effect on the deferred tax assets and liabilities of a change in tax rate in the period that includes the enactment date. We must also assess the likelihood that deferred tax assets will be recovered in future taxable income and, to the extent recovery is not probable, a valuation allowance would be recorded. If a valuation allowance were required, it could significantly increase income tax expense. In management's view, a valuation allowance was not required at December 31, 2012 or December 31, 2011.

        We anticipate that future rate actions by the regulatory commissions will reflect revenue requirements for the tax effects of temporary differences recognized, which have previously been passed through to customers. The regulatory commissions have granted us rate increases to reflect the normalization of the tax benefits of the federal accelerated methods and available Investment Tax Credits (ITCs) for all assets placed in service after 1980. ITCs are deferred and amortized over the lives of the related properties for book purposes.

        During 2012, the Company filed an application for a change in accounting method (section 481 adjustment) with the Internal Revenue Service (IRS) to implement the new repairs and maintenance deduction. The new deduction is for qualified tangible property placed into service during 2012 and prior years. The new tax regulations allow the Company to deduct a significant amount of costs previously capitalized for book and tax purposes. The Company completed its analysis of the federal repairs maintenance deduction related to 2011 and prior years in the third quarter of 2012. The Company's federal repairs and maintenance deductions for qualified tangible property placed into service during 2011 and prior years was $86.7 million and created a $30.4 million deferred tax liability for the temporary timing difference between book and tax treatments as of September 30, 2012. The 2011 and prior years federal repairs and maintenance deduction eliminated the Company's 2010 and 2011 previously filed federal qualified U.S. production activities deductions (QPAD) and was recorded as a $0.8 million federal income tax expense in the quarter ended September 30, 2012. The Company's state repairs deduction for qualified tangible property deductions placed into service during 2011 and prior years was $122.2 million and was recorded as a $7.0 million reduction to state income tax expense in the quarter ended September 30, 2012. The 2012 federal and state income tax repairs and maintenance deduction was estimated at $14.0 million. The estimated deduction increased the Company's federal deferred tax liability $4.9 million and reduced state income tax expenses $0.8 million in the quarter ended December 31, 2012. The 2012 federal income tax QPAD deduction was eliminated by the repairs and maintenance deduction.

        The 2012 repairs and maintenance deductions resulted in a federal net operating loss (NOL) of $26.0 million and a state NOL of $55.7 million. The NOL carry-forward amounts are more likely than not to be recovered and therefore require no valuation allowance. The NOL carry-forward does not begin to expire until 2033.

        During 2010, the Company filed an application for a change in accounting method (Section 481 adjustment) with the State of California to change its plant-in-service state tax depreciation method from the double- declining method to the straight line method at the respective assets mid-life. The Company's application was approved by the State of California during the first quarter of 2011. California uses the flow-through method of accounting for income tax depreciation. As a result, the Company reduced its 2010 income tax obligation by $1.6 million, net of federal income taxes in the quarter ended March 31, 2011.

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        The Tax Relief, Unemployment Insurance Reauthorization and Job Creation Act of 2010 will provide the Company with additional federal income tax deductions for assets placed in service after September 8, 2010 and before December 31, 2011. The federal income tax deduction was $6.6 million in 2010, $12.6 million in 2011, and is estimated at $1.6 million in 2012. The 2012 estimate will be finalized when we file the 2012 tax returns in the third quarter of 2013.

        The IRS is presently auditing the Company's 2010 and 2011 federal income tax returns. It is uncertain when the IRS will complete its audit. The Company believes that the final resolution of the IRS audit will not have a material adverse impact on its financial condition or results of operations. During 2012, the California Franchise Tax Board completed an audit of the Company's 2008 and 2009 state income tax returns without any adjustments. The Company is not under audit by any other jurisdiction.

Pension Benefits

        We incur costs associated with our pension and postretirement health care benefits plans. To measure the expense of these benefits, our management must estimate compensation increases, mortality rates, future health cost increases and discount rates used to value related liabilities and to determine appropriate funding. Different estimates used by our management could result in significant variances in the cost recognized for pension benefit plans. The estimates used are based on historical experience, current facts, future expectations, and recommendations from independent advisors and actuaries. We use an investment advisor to provide advice in managing the plan's investments. With the 2009 GRC settlement, we anticipate any increases in funding for the pension benefits plans will be recovered in future rate filings, thereby mitigating the financial impact. We believe it is probable that future costs will be recovered in future rates and therefore have recorded a regulatory asset in accordance with generally accepted accounting principles.

Workers' Compensation and Other Claims

        We are self-insured for a portion of workers' compensation and other claims. Excess amounts are covered by insurance policies. For workers' compensation, we work with an independent actuary firm to estimate the discounted liability associated with claims submitted and claims not yet submitted based on historical data. These estimates could vary significantly from actual claims paid, which could impact earnings and cash flows. For other claims, management estimates the cost incurred but not yet paid using historical information. Actual costs could vary from these estimates. Management believes actual costs incurred would be allowed in future rates, mitigating the financial impact.

Results of Operations

Earnings

        Net income was $48.8 and $37.7 million in 2012 and 2011, respectively. Diluted earnings per common share were $1.17 in 2012 and $0.90 in 2011. The weighted average number of common shares outstanding used in the diluted earnings per common share calculation was 41,892,000 in 2012 and 41,772,000 in 2011. Net income increase $11.1 million in 2012, or $0.27 per diluted common share, mostly due to a one-time income tax benefit of $6.2 million related to 2011 and prior years for state income tax repairs and maintenance deductions that we recognized in 2012, an unrealized pre-tax gain of $2.5 million on our benefit plan insurance investments, a one-time benefit of 2011 deferred WRAM revenues of $12.9 million and associated costs of $10.5 million that we recognized in 2012, a decrease in the current year income tax provision due to the repairs and maintenance deductions which included $1.0 million of prior years deductions which were recognized in 2012, and lower financing costs for short-term borrowings, which was partially offset by a $3.9 million reduction to operating revenues due to the cost of capital adjustment mechanism and cost increases for employee wages and benefits, water production costs, and depreciation on plant placed into service during 2011.

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        During 2012, the cost of capital adjustment mechanism required a reduction to 2013 authorized operating revenues of $3.8 million due to a decrease in the Moody AA utility bond index as of September 30, 2012 compared to September 30, 2011.

        Net income was $37.7 million in 2011 and 2010. Diluted earnings per common share were $0.90 in 2011 and 2010. The weighted average number of common shares outstanding used in the diluted earnings per share calculation was 41,772,000 in 2011 and 41,638,000 in 2010. Net income was the same in 2011 and 2010 because rate increases from the 2009 GRC and corresponding approved rates were offset by increases to operating expenses, long-term debt interest expense, and a reduction in net other income.

Dividends

        At the January 2013 meeting, the Board of Directors declared the quarterly dividend, increasing it for the 46th consecutive year. The quarterly dividend was raised from $0.1575 to $0.1600 per common share, or an annual rate of $0.64 per common share. Dividends have been paid for 68 consecutive years. The annual dividends paid per common share in 2012, 2011, and 2010 were $0.630, $0.615, and $0.595, respectively. Earnings not paid as dividends are reinvested in the business for the benefit of stockholders. The dividend payout ratio was 54% in 2012, 68% in 2011, and 66% in 2010, for an average of 62% over the three-year period. Our long-term targeted dividend payout ratio is 60%

Operating Revenue

        Operating revenue in 2012 was $560.0 million, an increase of $58.2 million, or 11.6%, over 2011. Operating revenue in 2011 was $501.8 million, an increase of $41.4 million, or 9.0%, over 2010. The estimated sources of changes in operating revenue were:

	2012		2011			2010
	Dollars in millions
Rate increases	$	28.9	$	53.2		$	28.5
Deferred WRAM revenue(1)		12.0		(12.9	)		—
Usage by new customers		1.2		2.9			2.3
Net change due to actual versus adopted results, usage, and other(2)		16.1		(1.8	)		(19.8	)
Net change	$	58.2	$	41.4		$	11.0

(1)

2012 deferred WRAM revenue was $(0.9) million of the $12.0 million amount shown above. Also, $12.9 million of 2011 deferred WRAM revenue was recognized as revenue in 2012. 2011 deferred WRAM revenue was $(12.9) million. Deferred WRAM revenue balances are expected to be collected from ratepayers beyond 24 months following the end of the accounting period in which these revenues were recorded.

(2)

The 2012 increase was mostly due to an increase in customer usage. The decreases in 2011 and 2010 were mostly due to decreases in customer usage.

        The usage by existing customers can materially change based upon current weather patterns, influenced both by temperature and rainfall. However, with the adoption of the WRAM and MCBA for California customers on July 1, 2008, the impact of weather on gross margin has been minimized.

        In 2012, rate relief increased revenues by $28.9 million with a significant portion due to increased rates from Cal Water's 2009 GRC and purchased water offsets. See the "Rates and Regulation" section of this annual report for more information on regulatory activity occurring in 2011, 2012, and through February 28, 2013.

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Water Production Expenses

        Water production expenses, which consist of purchased water, purchased power, and pump taxes, comprise the largest segment of total operating expenses. Water production costs accounted for 41.6%, 41.8%, and 41.1% of total operating costs in 2012, 2011, and 2010, respectively. The rates charged for wholesale water supplies, electricity, and pump taxes are established by various public agencies. As such, these rates are beyond our control.

        The table below provides the amount of increases and percent changes in water production costs during the past two years:

	2012							2011							2010
	Amount		Change		% Change			Amount		Change		% Change			Amount		Change			% Change
	Dollars in millions
Purchased water	$	161.3	$	18.7		13.2	%	$	142.6	$	16.7		13.3	%	$	125.9	$	4.2			3.5	%
Purchased power		31.0		0.9		3.2	%		30.1		0.5		1.7	%		29.6		1.3			4.6	%
Pump taxes		10.3		1.2		13.2	%		9.1		0.5		5.8	%		8.6		(0.9	)		(9.5	)%
Total water production expenses	$	202.6	$	20.8		11.5	%	$	181.8	$	17.7		10.8	%	$	164.1	$	4.6			2.9	%

        The principal factors affecting water production expenses are the quantity, price and source of the water. Generally, water from wells costs less than water purchased from wholesale suppliers.

        The table below provides the amounts, percentage change, and source mix for the respective years:

	2012						2011						2010
	MG			% of Total			MG			% of Total			MG			% of Total
				Millions of gallons (MG)
Source:
Wells		59,932			47.6	%		57,433			47.7	%		58,609			48.1	%
% change from prior year		4.4	%					(2.0	)%					(9.4	)%
Purchased		59,708			47.4	%		56,253			46.7	%		56,654			46.5	%
% change from prior year		6.0	%					(0.7	)%					(6.0	)%
Surface		6,252			5.0	%		6,667			5.6	%		6,679			5.4	%
% change from prior year		(6.2	)%					(0.2	)%					1.5	%
Total		125,892			100.0	%		120,353			100.0	%		121,942			100.0	%
% change from prior year		4.6	%					(1.3	)%					(7.3	)%

        Purchased water expenses are affected by changes in quantities purchased, supplier prices, and cost differences between wholesale suppliers. The MCBA mechanism is designed to recover all incurred purchase water expenses. For 2012, the $18.8 million increase in purchased water is due to wholesaler water rate increases between 3% and 12% and a 6% increase in purchased quantities. On an overall blended basis, wholesale water rates increased 7% on a cost-per-million-gallon basis in 2012. Purchased water expense for 2012 was partially offset by lease water rights credits of $0.9 million.

        For 2011, the $16.7 million increase in purchased water is due to wholesaler water rate increases between 3% and 38% despite a 1% decrease in purchased quantities. On an overall blended basis, wholesale water rates increased 14% on a cost-per-million-gallon basis in 2011. Purchased water expense for 2011 was partially offset by lease water rights credits of $1.0 million.

        For 2010, the $4.2 million increase in purchased water is due to wholesaler water rate increases between 5% and 24% despite a 6% decrease in purchased quantities. On an overall blended basis, wholesale water rates increased 10% on a cost-per-million-gallon basis in 2010. Purchased water expense for 2010 was partially offset by lease water rights credits of $1.9 million. The impact of variation of actual

49

water production expense from the adopted expense, effective July 1, 2008, is recorded as a component of revenue under the MCBA. See Item 1, "Rates and Regulation" of this annual report.

        Purchased power expenses are affected by the quantity of water pumped from wells and moved through the distribution system, rates charged by electric utility companies, and rate structures applied to usage during peak and non-peak times of the day or season. In 2012, 2011, and 2010 purchased power expense increased $1.0 million, or 3%, $0.5 million, or 2%, and $1.3 million, or 5%, respectively, primarily due to power supplier rate increases.

        Changes in climate change regulations could increase the cost of purchased power which in turn would result in an increase in the rates our power suppliers charge us. Any change in pricing of our purchased power in California would be recovered from our rate payers by the MCBA. Any change in power costs in other states would be requested to be recovered by the rate payers in those states. The impact of such legislation, is dependent upon the enacted date, the factors that impact our suppliers cost structure, and their ability to pass the costs to us in their approved tariffs. These items are not known at this time.

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, legal fees, expenses associated with being a public company, and general corporate expenses.

        During 2012, administrative and general expenses increased $8.2 million, or 9.5%, as compared to last year. The increase was due primarily to increases in employee payroll costs, health care, pension and other employee benefit costs. These increases were partially offset by a reduction to outside service costs.

        During 2011, administrative and general expenses increased $10.5 million, or 13.9%, as compared to last year. The increase was due primarily to increases in employee payroll costs, health care, pension and other employee costs, benefit costs, and outside service costs.

Other Operations Expenses

        The components of other operations expenses include payroll, material and supplies, and contract service costs of operating the regulated water systems, including the costs associated with water transmission and distribution, pumping, water quality, meter reading, billing, operations of district offices, and water conservation programs.

        During 2012, other operating expenses increased $22.4 million, or 41%, compared to 2011 primarily attributable to $10.5 million of MCBA costs from the recording of the 2011 deferred WRAM revenues and associated costs recorded during 2012, increased labor and benefit costs related to the operating activities and increased conservation program expenses compared to 2011. Conservation program expenses are fully recovered in rates for 2011, 2012, and 2013 and are tracked in a balancing account, such that revenues are recovered on a dollar-for-dollar basis up to the amounts authorized in the 2009 GRC.

        During 2011, excluding the deferral of $10.5 million of operating expenses associated with the deferral of WRAM revenues, other operating expenses increased $8.7 million, or 15.3%, due to increased costs for water treatment, water quality testing, chemicals, labor, and conservation program expenses compared to 2010.

Maintenance

        Maintenance expenses decreased $1.6 million, or 7.5%, in 2012, compared to 2011 due to decreased costs for repairs of mains, services, meters, hydrants, and other structures. For 2011, maintenance expenses increased $1.0 million, or 5.2%, compared to 2010, due to increased costs for repairs of mains.

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Depreciation and Amortization

        Depreciation and amortization increased $4.3 million in 2012 due to capital additions from the previous year, and increased $7.6 million in 2011 due to capital additions from the previous year and 2009 GRC authorized depreciation rate changes, effective January 1, 2011, and increased $3.1 million in 2010 due to capital additions from the previous year.

        Our capital expenditures in California will be impacted by certain California environmental legislation passed in prior years. The CEQA permitting process involved in certain capital projects has increased the administrative cost of certain projects. California emission controls are expected to increase the cost of vehicle acquisitions. Certain existing vehicles will also have to be retrofitted to comply with the current legislation. The costs will be recovered via depreciation expense by our rate payers upon the filing of future general rate cases.

Income Taxes

        For 2012, income taxes decreased $1.7 million as compared to 2011. For 2011, income taxes decreased $1.4 million as compared to 2010. The effective tax rate was 31.7% (with the section 481 adjustment, which reduced 2012 state income taxes by $7.0 million), 38.4% (with the section 481 adjustment, which reduced 2011 state income taxes by $1.6 million), and 39.6%, in 2012, 2011, 2010, respectively. The effective tax rate is impacted by the allowable federal income tax benefit from an additional tax deduction for the qualified production activity deduction (QPAD) for income attributed to the production of water. The tax rate is also affected by the flow through method of accounting for income taxes which resulted from differences between tax depreciation and book depreciation on both pre-1982 assets, as well as all California assets. The flow through method of accounting is described in the Summary of Significant Accounting Policies in the Notes to Consolidated Financial Statements. We anticipate the reversal of federal tax depreciation on pre-1982 assets to continue in future years; however, its effect on our tax provision is uncertain due to the offsetting flow-through of state tax depreciation, which continues to increase with capital additions and the impact of cost to remove of pre-1982 assets. In September of 2010, the 50% bonus depreciation for federal income tax filings was extended through 2012 which reduced 2011 and 2010 income tax payments $12.6 million and $6.6 million, respectively. On January 2, 2013, U.S. federal legislation was enacted that provides an extension of the 50% bonus depreciation allowance for qualifying capital expenditures incurred in 2013. We expect the 50% bonus depreciation to reduce 2012 income taxes $1.6 million. The 2012 and prior years tax repairs and maintenance deductions and bonus depreciation deductions created a federal NOL which eliminated the Company's QPAD deductions of $0.8 million for tax years 2010 and 2011. The federal NOL was $26 million as of December 31, 2012. The loss of the QPAD deduction will continue until the federal income tax NOL is fully expired in calendar year 2014.

Property and Other Taxes

        For 2012, property and other tax expenses increased $0.9 million, or 4.9% from 2011. The increase was primary due to increased property taxes for utility plant placed in service during 2011. For 2011, property and other tax expenses increased $1.2 million, or 7.2% from 2010. The increase was primary due to increased property taxes due to utility plant additions during 2010 and an increase in payroll taxes.

Non-Regulated Revenue and Expense, Net

        The major components of non-regulated income are revenue and operating expenses related to the following activities:

•

operating and maintenance services (O&M) and meter reading and billing services;

•

antenna site leases;

•

design and construction services;

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•

billing of optional third-party insurance program to our residential customers;

•

interest income;

•

selling surplus property;

•

change in cash surrender value of life insurance; and

•

non-regulated and new business expenses.

        Revenues from antenna site leases to telecommunication companies were $2.0 million, $1.9 million, and $2.2 million in 2012, 2011, and 2010, respectively. Revenues from the billing and marketing contract with Home Serve USA were $2.0 million in 2012, 2011, and 2010. Changes to the cash surrender value (CSV) of life insurance contracts associated with our benefit plans have had a significant impact to non-regulated expenses. There was an unrealized gain of $2.5 million in 2012, an unrealized loss of $1.9 million in 2011, and an unrealized gain of $2.6 million in 2010. The CSV is determined in part by the market of certain underlining funds, the value of which reflects the changes in the stock market. For 2012, non-regulated income net of expenses increased $2.9 million, or 1,105%, compared to 2011. The increase was primarily due to an unrealized gain on the life insurance contracts associated with our benefit plans during 2012. See Note 3 of the Notes to Consolidated Financial Statements for additional information.

Gain on Sale of Non-Utility Property

        For 2012, 2011, and 2010, there were no significant non-utility property sales. Earnings and cash flow from these transactions are sporadic and may or may not continue in future periods, depending upon market conditions. The Company has other non-utility properties that may be marketed in the future based on real estate market conditions.

Interest Expenses

        In 2012, interest expense decreased $1.6 million compared to 2011. This decrease was attributable to lower financing costs on the Company's short-term lines of credit, the TIRBA balancing account interest charges ending on December 31, 2011, and an increase in capitalized interest charged to construction projects during 2012. In 2011, interest expense increased $3.3 million compared to 2010. This increase was mainly attributable to higher interest expense on the $100 million of first mortgage bonds issued in November 2010 and borrowings on our short-term line of credit which was partially offset by a $1.2 million increase in capitalized interest.

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Rates and Regulation

        The following is a summary of 2012 rate filings and the anticipated annual impact on revenues. California decisions and resolutions may be found on the CPUC website at www.cpuc.ca.gov.

Type of Filing	Decision/Resolution	Approval Date		Increase (Decrease) Annual Revenue		CA District/ Subsidiary
GRC, Step Rate and Offset Filings
Step Rate Increase	AL 2053-2054		Jan 2012	$	8.5 million	20 districts
Hawaii Ka'anapali GRC			Feb 2012	$	1.2 million
2012 Expense Offset	AL 2057-2062		Feb 2012	$	5.1 million	6 districts
2012 Expense Offset	AL 2078-2083		Jul 2012	$	4.1 million	6 districts
2012 Rate Base Offset	Various(1)		Jul 2012	$	1.6 million	8 districts
Surcharges and Surcredits
Cost of Capital	AL 2085		Sep 2012	$	(1.2) million	All districts
Other Compliance Filing	AL 2070		May 2012	$	0.4 million	6 districts

(1)

Increases result from advice letters 2056, 2063, 2064, 2065, 2068, 2069, 2075, and 2076.

        The estimated impact of current and prior year rate changes on operating revenues compared to prior years is listed in the following table:

	2012			2011		2010
	Dollars in millions
General Rate Case (GRC)(a)	$	3.8		$	28.1	$	0.4
Step rate increases		8.5			1.8		6.3
Offset (purchased water/pump taxes)		17.1			21.4		19.9
Balancing accounts, net		0.2			1.0		0.1
Other rate (decreases) increases		(0.7	)		0.9		1.8
Total rate increases	$	28.9		$	53.2	$	28.5

(a)

GRC activity was lower during 2010 because all 24 districts are filed together once every three years. The 2009 GRC was the first filing for all 24 districts with rate increases effective January 1, 2011. The 2010 rate increases were a carry-over from the 2007 GRC rate changes. GRC activity in 2012 includes Hawaii Water.

Water Supply

        Our source of supply varies among our operating districts. Certain districts obtain all of their supply from wells; some districts purchase all of their supply from wholesale suppliers; and other districts obtain supply from a combination of wells and wholesale suppliers. A small portion of supply comes from surface sources and is processed through Company-owned water treatment plants. To the best of management's knowledge, we are meeting water quality, environmental, and other regulatory standards for all company-owned systems.

        California's normal weather pattern yields little precipitation between mid-spring and mid-fall. The Washington Water service areas receive precipitation in all seasons, with the heaviest amounts during the winter. New Mexico Water's rainfall is heaviest in the summer monsoon season. Hawaii Water receives precipitation throughout the year, with the largest amounts in the winter months. Water usage in all service areas is highest during the warm and dry summers and declines in the cool winter months. Rain and snow during the winter months replenish underground water aquifers and fill reservoirs, providing the water

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supply for subsequent delivery to customers. To date, snowpack water content and rainfall accumulation during the 2012-2013 water year is 48% of normal (as of January 1, 2013 per the California Department of Water Resources). Precipitation in latter half of 2011 was below average. Management believes that supply pumped from underground aquifers and purchased from wholesale suppliers will be adequate to meet customer demand during 2013 and beyond. However, water rationing may be required in future periods, if declared by the state or local jurisdictions. Long-term water supply plans are developed for each of our districts to help assure an adequate water supply under various operating and supply conditions. Some districts have unique challenges in meeting water quality standards, but management believes that supplies will meet current standards using current treatment processes.

Liquidity and Capital Resources

Cash flow from Operations

        During 2012, we generated cash flow from operations of $131.9 million, compared to $111.3 million during 2011, and $75.5 million during 2010. In general, cash flow from operations is primarily generated by net income, non-cash expenses for depreciation and amortization, deferred income taxes, regulatory liabilities, other current liabilities, changes of prepaid income taxes, and the amortization periods allowed by the commission to recover MCBA and other incurred costs. Cash generated by operations varies during the year. The increase during 2012 compared to 2011 was primarily due to higher billing rates due to the 2009 GRC, a reduction of $10.5 million in federal and state income tax payments mostly due to the repairs and maintenance deductions, a $3.5 million reduction of the December 31, 2011 undercollected net WRAM and MCBA receivable balances due to a reduction in the amortization periods and customer usage, the timing of employee pensions and other benefit payments, and the timing of liability payments. The increase during 2011 compared to 2010 was primarily due to higher billing rates due to the 2009 GRC, decreased prepaid income taxes as a result of tax refunds, the timing of employee pension and other benefit payments, the timing of liability payments, an increase in deferred income tax liabilities from additional bonus depreciation which was partially offset by growth in the undercollected net WRAM and MCBA receivable balances.

        The water business is seasonal. Billed revenue is lower in the cool, wet winter months when less water is used compared to the warm, dry summer months when water use is highest. This seasonality results in the possible need for short-term borrowings under the bank lines of credit in the event cash is not sufficient to cover operating and capital costs during the winter period. The increase in cash flow during the summer allows short-term borrowings to be paid down. Customer water usage can be lower than normal in years when more than normal precipitation falls in our service areas or temperatures are lower than normal, especially in the summer months. The reduction in water usage reduces cash flow from operations and increases the need for short-term bank borrowings. In addition, short-term borrowings are used to finance capital expenditures until long-term financing is arranged.

Investing Activities

        During 2012 and 2011, we used $127.7 million and $118.5 million, respectively, of cash for capital expenditures, both company-funded and developer-funded. The 2013 budget estimated capital expenditures between $120 million and $130 million. Annual expenditures fluctuate each year due to the availability of construction resources and our ability to obtain construction permits in a timely manner.

Financing Activities

        During 2012 and 2011, there were no significant long-term debt or equity offerings; however, on June 29, 2011, the Company and Cal Water entered into new Syndicated Credit Agreements, which provide for unsecured revolving credit facilities of up to an initial aggregate amount of $400 million. The Syndicated Credit Facilities amend, expand, and replace the Company's and its subsidiaries' existing credit

54

facilities originally entered into on October 27, 2009. The new credit facilities extended the terms until June 29, 2016, increased the Company's and Cal Water's unsecured revolving lines of credit, and lowered interest rates and fees. The Company and subsidiaries which it designates may borrow up to $100 million under the Company's revolving credit facility. Cal Water may borrow up to $300 million under its revolving credit facility; however, all borrowings need to be repaid within twelve months unless otherwise authorized by the CPUC. The proceeds from the revolving credit facilities may be used for working capital purposes, including the short-term financing of capital projects. The base loan rate may vary from LIBOR plus 72.5 basis points to LIBOR plus 95 basis points, depending on the Company's total capitalization ratio. Likewise, the unused commitment fee may vary from 8 basis points to 12.5 basis points based on the same ratio.

        The undercollected net WRAM and MCBA receivable balances were $46.1 million and $49.6 million as of December 31, 2012 and 2011, respectively. On April 19, 2012, the CPUC issued a decision to shorten the amortization periods for Cal Water's undercollected net WRAM and MCBA receivable balances for calendar years 2012, 2011, and 2010. The decrease of $3.5 million to the undercollected net WRAM and MCBA receivable balances during 2012 was due to an increase in collections and customer usage in 2012. The undercollected net WRAM and MCBA receivable balances were primarily financed by Cal Water with short-term and long-term financing arrangements to meet operational cash requirements. Interest on the undercollected net WRAM and MCBA receivable balances, the interest recoverable from ratepayers, is limited to the current 90-day commercial paper rates which is significantly lower than Cal Water's short and long-term financing rates.

        The Company borrowed $94.3 million on our bank lines of credit, repaid $52.0 million of short-term borrowings, and added $7.0 million of advances and contributions in aid of construction, which was reduced by refunds to developers of $7.4 million.

        On October 4, 2011, Cal Water entered into a capital lease arrangement with the City of Hawthorne to operate the City's water system for a 15-year period. The capital lease increased debt $9.2 million during 2011.

        Bond principal and other long-term debt payments were $7.0 million during 2012, compared to $3.0 million during 2011. The increase in 2012 compared to 2011 was the $3.6 million repayment of series GGG and HHH during 2012.

        We raised the dividend rate in January 2012 to a post-split annual rate of $0.630 from the 2011 rate of $0.615. The annual dividend rate has increased from $0.570 per share of common stock in 2005 to $0.630 per share of common stock in 2012.

        During the month of November 2010, Cal Water issued $100 million aggregate principal amount of its 5.50% first mortgage bonds due in 2040, which are fully and unconditionally guaranteed by the Company.

Short-Term Financing

        Short-term liquidity is provided by the bank lines of credit described above and by internally generated funds. Long-term financing is accomplished through the use of both debt and equity. As of December 31, 2012, there were short-term borrowings of $89.5 million outstanding on our unsecured revolving line of credit, which was amended and replaced on June 29, 2011, compared to $47.1 million outstanding on our original unsecured revolving line of credit as of December 31, 2011. The increase during 2012 was mostly to finance Cal Water, Hawaii Water, and Washington Water capital projects and operating activities during 2012.

        Given our ability to access our lines of credit on a daily basis, cash balances are managed to levels required for daily cash needs and excess cash is invested in short-term or cash equivalent instruments. Minimal operating levels of cash are maintained for Washington Water, New Mexico Water, and Hawaii Water.

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        California Water Service Group and subsidiaries which it designates may borrow up to $100 million under its new short-term credit facility. California Water Service Company may borrow up to $300 million under its new credit facility; however, all borrowings need to be repaid within twelve months unless otherwise authorized by the CPUC.

        Both short-term credit agreements contain affirmative and negative covenants and events of default customary for credit facilities of this type including, among other things, limitations and prohibitions relating to additional indebtedness, liens, mergers, and asset sales. Also, these unsecured credit agreements contain financial covenants governing the Company and its subsidiaries' consolidated total capitalization ratio not to exceed 66.7% and interest coverage ratio of three or more. As of December 31, 2012, the Company's total capitalization ratio was 47.3% (trade payable is included as debt for this calculation) and interest ratio was four and three fourths. In summary, we have met all of the covenant requirements and are eligible to use the full amounts of these credit agreements.

        There was $0.1 million of new debt added to long-term debt during 2012, and we made principal payments on Cal Water's first mortgage bonds and other long-term debt of $7.0 million during 2012.

        Long-term financing, which includes first mortgage bonds, senior notes, other debt securities, and common stock, has typically been used to replace short-term borrowings and fund capital expenditures. Internally generated funds, after making dividend payments, provide positive cash flow, but have not been at a level to meet the needs of our capital expenditure requirements. Management expects this trend to continue given our capital expenditures plan for the next five years. Some capital expenditures are funded by payments received from developers for contributions in aid of construction or advances for construction. Funds received for contributions in aid of construction are non-refundable, whereas funds classified as advances in construction are refundable. Management believes long-term financing is available to meet our cash flow needs through issuances in both debt and equity instruments.

Long-Term Financing

        On January 7, 2010, Cal Water filed an application for additional financing authority with the CPUC. This request was approved on September 23, 2010, and the CPUC decision authorizes Cal Water to issue $350 million of debt and common stock to finance capital projects and operations. In November 2010, Cal Water issued $100 million of first mortgage bonds in accordance with the CPUC decision.

        In 2012, we utilized cash generated from operations, borrowings on the lines of credit, and the first mortgage bond offerings. We did not issue any significant common stock in 2012. In future periods, management anticipates funding our capital needs through a relatively balanced approach between long term debt and equity.

        Additional information regarding the bank borrowings and long-term debt is presented in Notes 7 and 8 in the Notes to Consolidated Financial Statements.

Off-Balance Sheet Transactions

        We do not utilize off-balance-sheet financing or utilize special purpose entity arrangements for financing. We do not have equity ownership through joint ventures or partnership arrangements.

Contractual Obligations

        The contractual obligations presented in the table below represent our estimates of future payments under fixed contractual obligations and commitments. Changes in our business needs, cancellation provisions and changes in interest rates, as well as action by third parties and other factors, may cause

56

these estimates to change. Therefore, our actual payments in future periods may vary from those presented in the table below. The following table summarizes our contractual obligations as of December 31, 2012.

	Total		Less than 1 Year		1 - 3 Years		3 - 5 Years		After 5 Years
	(In thousands)
Long-term debt(*)	$	471,382	$	46,653	$	13,056	$	33,022	$	378,651
Interest payments		368,503		28,390		51,509		50,151		238,453
Advances for construction		187,584		7,179		14,292		14,180		151,933
Pension and post retirement benefits(**)		246,187		7,587		19,728		25,861		193,011
Capital lease obligations(***)		14,154		1,109		2,218		2,218		8,609
Facility leases		4,404		632		919		359		2,494
System leases		4,718		845		1,690		1,690		493
Water supply contracts		549,494		19,378		38,969		39,256		451,891
TOTAL	$	1,846,426	$	111,773	$	142,381	$	166,737	$	1,425,535

*

Excludes capital lease obligations as reported below.

**

Pension and post retirement benefits includes $1.3 million of short-term pension obligations.

***

Capital lease obligations represent total cash payments to be made in the future and includes interest expense of $4.3 million.

        Our contractual obligations are summarized in the table above. For pension and post retirement benefits other than pension obligations see Note 11 of the Notes to the consolidated Financial Statements. Long-term debt payments include annual sinking fund payments on first mortgage bonds, maturities of long-term debt, and annual payments on other long-term obligations. Advances for construction represent annual contract refunds to developers for the cost of water systems paid for by the developers. The contracts are non-interest bearing, and refunds are generally on a straight-line basis over a 40-year period. System and office leases include obligations associated with leasing water systems and rents for office space.

        There are three capital leases, the most significant was the City of Hawthorne water system. In 2011, we entered into a 15-year capital lease agreement to operate the City of Hawthorne water system. The system, which is located near the Hermosa-Redondo district, serves about half of Hawthorne's population. The lease agreement required us to make an up-front $8.1 million lease payment to the city that is being amortized over the lease term. Additionally, annual lease payments of $0.9 million are made to the city and shall be increased or decreased each year on July 1, by the same percentage that the rates charged to customers served by the water system increased or decreased, exclusive of pass-through increases or decreases in the cost of water, power, and city-imposed fees, compared to the rates in effect on July 1 of the prior year, provided, that in no event will the annual lease payment be less than $0.9 million. Under the lease, we are responsible for all aspects of system operation and capital improvements, although title to the system and system improvements reside with the city. In exchange, we receive all revenue from the water system, which was $7.6 million, $7.5 million, and $7.5 million in 2012, 2011, and 2010, respectively. At the end of the lease, the city is required to reimburse us for the unamortized value of capital improvements made during the term of the lease.

        Cal Water has water supply contracts with wholesale suppliers in 14 of its operating districts and for the two leased systems in Hawthorne and Commerce. For each contract, the cost of water is established by the wholesale supplier and is generally beyond our control. The amount paid annually to the wholesale suppliers is charged to purchased water expense on our statement of income. Most contracts do not require minimum annual payments and vary with the volume of water purchased.

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        We have a contract with the Santa Clara Valley Water District, which contains minimum purchase obligations. The contract payment varies with the volume of water purchased above the minimum purchase levels. Management plans to continue to purchase and use at least the minimum quantity of water that is required to purchase under this contract in the future. Total paid to Santa Clara Valley Water District was $6.2 million in 2012, $5.5 million in 2011, and $5.3 million in 2010.

        The water supply contract with Stockton East Water District (SEWD) expires on April 1, 2035, requires a fixed, annual payment and does not vary during the year with the quantity of water delivered by the district. Due to the fixed price arrangement, we utilize as much water as possible from SEWD in order to minimize the cost of operating Company-owned wells used to supplement SEWD deliveries. The total paid under the contract was $6.6 million in 2012, $6.7 million in 2011, $6.2 million in 2010. Pricing under the contract varies annually. Estimated annual contractual obligations in the above table are based on the same payment level as 2012. Future cost increases by SEWD are expected to be offset by a decline in the allocation of costs to us as more of these costs are expected to be allocated to other SEWD customers due to growth within their service areas.

        On September 21, 2005, we entered into an agreement with Kern County Water Agency (Agency) to obtain treated water for our operations. The term of the agreement is to January 1, 2035, or until the Agency's bonds are repaid. The Agency's bonds are described below. Under the terms of the agreement, we were obligated to purchase approximately 18,000 acre feet of treated water in 2012 and an incrementally higher volume of water for each subsequent year until 2017, when we are obligated to purchase 20,500 acre feet of treated water per year. We are obligated to pay a capital facilities charge and a treated water charge regardless of whether we can use the water in our operation, and we are obligated for these charges even if the Agency cannot produce an adequate amount to supply the 20,500 acre feet in the year. This agreement supersedes a prior agreement with Kern County Water Agency for the supply of 11,500 acre feet of water per year. Total expense, under the prior agreement, was $6.3 million in 2012, $6.1 million in 2011, and $5.5 million in 2010.

        Three other parties, including the City of Bakersfield, are also obligated to purchase a total of 32,500 acre feet per year under separate agreements with the Agency. Further, the Agency has the right to proportionally reduce the water supply provided to all of the participants if it cannot produce adequate supplies. The participation of all parties in the transaction for expansion of the Agency's facilities, including its water purification plant, purchase of the water, and payment of interest and principal on the bonds being issued by the Agency to finance the transaction, is required as a condition to the obligation of the Agency to proceed with expansion of the Agency's facilities. If any of the other parties does not use its allocation in a given year, that party is still obligated to pay its contracted amount.

        The Agency has issued bonds to fund the project and will use the payments of the capital facilities charges by us and the other contracted parties to meet the Agency's obligations to pay interest and repay principal on the bonds. If any of the parties were to default on making payments of the capital facilities charge, then the other parties are obligated to pay for the defaulting party's share on a pro-rata basis. If there is a payment default by a party and the remaining parties have to make payments, they are also entitled to a pro-rata share of the defaulting party's water allocation.

        We expect to use all of its entitled water in our operations every year. If additional treated water is available, all parties have an option to purchase this additional treated water, subject to the Agency's right to allocate the water among the parties. If we were to pay for and receive additional amounts of water due to a default of another participating party, we believe we could use this additional water in our operations without incurring substantial increases in incremental costs.

        The total obligation of all parties, excluding us, is approximately $82.4 million to the Agency. Based on the credit worthiness of the other participants, which are government entities, our management believes it to be highly unlikely that we would be required to assume any other parties' obligations under the

58

contract due to their default. If a party defaults, we would receive entitlement to the additional water for assuming the additional obligation.

        Once the project is complete, we are obligated to pay a capital facilities charge and charges related to treated water that together total $7.2 million annually, which equates to $349 dollars per acre foot. Annual payments of $3.6 million for the capital facilities charge began when the Agency issued bonds to fund the project. Total treated water charge for 2012 was $2.6 million. Once the entire expansion project is completed, the full annual payments will be $7.2 million which will continue through the term of the agreement. As treated water is being delivered, we will also be obligated for our portion of the operating costs; that portion is currently estimated to be $7 dollars per acre foot. The actual amount will vary due to variations from estimates, inflation, and other changes in the cost structure. Our overall estimated cost of $349 dollars per acre foot is less than the estimated cost of procuring untreated water (assuming water rights could be obtained) and then providing treatment.

Capital Requirements

        Capital requirements consist primarily of new construction expenditures for expanding and replacing utility plant facilities and the acquisition of water systems. They also include refunds of advances for construction.

        Company-funded and developer-funded utility plant expenditures were $127.7 million, $118.5 million, and $123.9 million in 2012, 2011, and 2010, respectively. A majority of capital expenditures was associated with mains and water treatment equipment.

        For 2013, the Company is estimating its capital expenditures to be between $120 and $130 million. We do not expect significant increases or declines in annual capital expenditure for the next five years.

        Management expects developer-funded expenditures in 2013. These expenditures will be financed by developers through refundable advances for construction and non-refundable contributions in aid of construction. Developers are required to deposit the cost of a water construction project with us prior to our commencing construction work, or the developers may construct the facilities themselves and deed the completed facilities to us. Funds are generally received in advance of incurring costs for these projects. Advances are normally refunded over a 40-year period without interest. Future payments for advances received are listed under contractual obligations above. Because non-company-funded construction activity is solely at the discretion of developers, we cannot predict the level of future activity. The cash flow impact is expected to be minor due to the structure of the arrangements.

Capital Structure

        Common stockholders' equity was $473.7 million at December 31, 2012 compared to $449.8 million at December 31, 2011. As noted above, the Company incurred additional long-term debt in 2012 and 2011.

        Total capitalization, including the current portion of long-term debt, at December 31, 2012, was $955.0 million and $938.0 million at December 31, 2011. In future periods, the Company intends to issue common stock and long-term debt to finance our operations. The capitalization ratios will vary depending upon the method we choose to finance our operations.

        At December 31, capitalization ratios were:

	2012			2011
Common equity		49.6	%		48.0	%
Long-term debt		50.4	%		52.0	%

        The return (from both regulated and non-regulated operations) on average common equity was 10.6% in 2012 compared to 8.5% in 2011.

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Acquisitions

        In 2012, 2011, and 2010 there were no significant acquisitions.

Real Estate Program

        We own real estate. From time to time, certain parcels are deemed no longer used or useful for water utility operations. Most surplus properties have a low cost basis. We developed a program to realize the value of certain surplus properties through sale or lease of those properties. The program will be ongoing for a period of several years. Property sales produced pretax gains of less than $0.1 million in 2012, 2011 and 2010. As sales are dependent on real estate market conditions, future sales, if any, may or may not be at prior year levels.

Item 7A.    Quantitative and Qualitative Disclosures About Market Risk

        We do not participate in hedge arrangements, such as forward contracts, swap agreements, options, or other contractual agreements to mitigate the impact of market fluctuations on our assets, liabilities, production, or contractual commitments. We operate only in the United States and, therefore, are not subject to foreign currency exchange rate risks.

Interest Rate Risk

        We are subject to interest rate risk, although this risk is lessened because we operate in a regulated industry. If interest rates were to increase, management believes customer rates would increase accordingly, subject to Commission approval in future GRC filings. The majority of our debt is long-term at a fixed rate. Interest rate risk does exist on short-term borrowings within our credit facilities, as these interest rates are variable. We also have interest rate risk on new financing, as higher interest cost may occur on new debt if interest rates increase.

        Over the next 12 months, approximately $46.8 million of the $481.3 million of existing long-term debt instruments will mature or require sinking fund payments. Applying a hypothetical 10 percent increase in the rate of interest charged on those borrowings would not have a material effect on our earnings.

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Item 8.    Financial Statements and Supplementary Data.

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders of
California Water Service Group
San Jose, California

        We have audited the accompanying consolidated balance sheets of California Water Service Group and subsidiaries (the "Company") as of December 31, 2012 and 2011, and the related consolidated statements of income, common stockholders' equity and cash flows for each of the three years in the period ended December 31, 2012. We have also audited the Company's internal control over financial reporting as of December 31, 2012, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company's management is responsible for these financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on these financial statements and an opinion on the Company's internal control over financial reporting based on our audits.

        We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the financial statements included examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

        A company's internal control over financial reporting is a process designed by, or under the supervision of, the company's principal executive and principal financial officers, or persons performing similar functions, and effected by the company's board of directors, management, and other personnel 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. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.

        Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

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        In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of California Water Service Group and subsidiaries as of December 31, 2012 and 2011, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2012, in conformity with accounting principles generally accepted in the United States of America. Also, in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2012, based on the criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

San Francisco, California
February 28, 2013

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CALIFORNIA WATER SERVICE GROUP

Consolidated Balance Sheets

	December 31,
	2012			2011
	In thousands, except per share data
ASSETS
Utility plant:
Land	$	42,023		$	37,703
Depreciable plant and equipment		1,903,365			1,807,569
Construction work in progress		132,362			98,623
Intangible assets		18,613			16,486
Total utility plant		2,096,363			1,960,381
Less accumulated depreciation and amortization		(639,307	)		(579,262	)
Net utility plant		1,457,056			1,381,119
Current assets:
Cash and cash equivalents		38,790			27,203
Receivables: net of allowance for doubtful accounts of $714 and $669, respectively
Customers		29,958			28,418
Regulatory balancing accounts		34,020			21,680
Other		11,943			6,422
Unbilled revenue		15,394			15,068
Materials and supplies at weighted average cost		5,874			5,913
Taxes, prepaid expenses, and other assets		10,585			9,184
Total current assets		146,564			113,888
Other assets:
Regulatory assets		344,419			319,898
Unamortized debt premium and expense		5,591			6,071
Goodwill		2,615			2,615
Other		39,679			30,996
Total other assets		392,304			359,580
	$	1,995,924		$	1,854,587
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock, $0.01 par value; 68,000 shares authorized, 41,908 and 41,817, outstanding in 2012 and 2011, respectively		419			418
Additional paid-in capital		221,013			219,572
Retained earnings		252,280			229,839
Total common stockholders' equity		473,712			449,829
Long-term debt, less current maturities		434,467			481,632
Total capitalization		908,179			931,461
Current liabilities:
Current maturities of long-term debt		46,783			6,533
Short-term borrowings		89,475			47,140
Accounts payable		47,199			48,923
Regulatory balancing accounts		5,018			2,655
Accrued other taxes		3,379			3,942
Accrued interest		4,705			4,756
Other accrued liabilities		46,508			37,926
Total current liabilities		243,067			151,875
Unamortized investment tax credits		2,180			2,254
Deferred income taxes		158,846			116,368
Regulatory liabilities		35,720			28,037
Pension and postretirement benefits other than pension		244,901			232,110
Advances for construction		187,584			187,278
Contributions in aid of construction		158,574			154,191
Other long-term liabilities		56,873			51,013
Commitments and contingencies		—			—
	$	1,995,924		$	1,854,587

See accompanying Notes to Consolidated Financial Statements.

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CALIFORNIA WATER SERVICE GROUP

Consolidated Statements of Income

	For the Years Ended December 31,
	2012			2011			2010
	In thousands, except per share data
Operating revenue	$	559,966		$	501,814		$	460,399
Operating expenses:
Operations:
Purchased water		161,336			142,570			125,930
Purchased power		31,027			30,053			29,577
Pump taxes		10,336			9,130			8,600
Administrative and general		93,927			85,758			75,276
Other		77,104			54,696			56,518
Maintenance		19,142			20,698			19,685
Depreciation and amortization		54,668			50,385			42,828
Income taxes		19,356			23,025			23,069
Property and other taxes		19,227			18,332			17,103
Total operating expenses		486,123			434,647			398,586
Net operating income		73,843			67,167			61,813
Other income and expenses:
Non-regulated revenue		16,686			16,160			15,993
Non-regulated expense		(11,553	)		(15,822	)		(12,312	)
Gain on sale of non-utility property		84			62			22
Income tax (expense) on other income and expenses		(2,096	)		(141	)		(1,487	)
Net other income		3,121			259			2,216
Interest expense:
Interest expense		31,537			32,455			27,936
Less: capitalized interest		(3,401	)		(2,741	)		(1,563	)
Net interest expense		28,136			29,714			26,373
Net income	$	48,828		$	37,712		$	37,656
Earnings per share:
Basic	$	1.17		$	0.90		$	0.90
Diluted	$	1.17		$	0.90		$	0.90
Weighted average number of common shares outstanding:
Basic		41,892			41,762			41,612
Diluted		41,892			41,772			41,638

See accompanying Notes to Consolidated Financial Statements.

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CALIFORNIA WATER SERVICE GROUP

Consolidated Statements of Common Stockholders' Equity

For the Years Ended December 31, 2012, 2011 and 2010

	Common Stock
					Additional Paid-in Capital		Retained Earnings			Total Stockholders' Equity
	Shares		Amount
					In thousands
Balance at December 31, 2009		41,531	$	416	$	215,320	$	204,898		$	420,634
Net income		—		—		—		37,656			37,656
Issuance of common stock		136		—		1,989		—			1,989
Dividends paid on common stock ($0.595 per share)		—		—		—		(24,753	)		(24,753	)
Balance at December 31, 2010		41,667		416		217,309		217,801			435,526
Net income		—		—		—		37,712			37,712
Issuance of common stock		150		2		2,263		—			2,265
Dividends paid on common stock ($0.615 per share)		—		—		—		(25,674	)		(25,674	)
Balance at December 31, 2011		41,817		418		219,572		229,839			449,829
Net income		—		—		—		48,828			48,828
Issuance of common stock		91		1		1,441		—			1,442
Dividends paid on common stock ($0.630 per share)		—		—		—		(26,387	)		(26,387	)
Balance at December 31, 2012		41,908	$	419	$	221,013	$	252,280		$	473,712

See accompanying Notes to Consolidated Financial Statements.

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CALIFORNIA WATER SERVICE GROUP

Consolidated Statements of Cash Flows

	For the Years Ended December 31,
	2012			2011			2010
	In thousands
Operating activities:
Net income	$	48,828		$	37,712		$	37,656
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		56,866			51,981			45,265
Amortization of debt premium and expenses		1,107			1,082			979
Changes in deferred income taxes		34,133			2,723			—
Other changes in noncurrent assets and liabilities		(8,490	)		611			(1,139	)
Change in value of life insurance contracts		(2,504	)		1,876			(2,641	)
Gain on sale of non-utility property		(84	)		(62	)		(22	)
Changes in operating assets and liabilities:
Receivables		(1,392	)		(8,213	)		(860	)
Unbilled revenue		(326	)		(1,143	)		(508	)
Taxes, prepaid expenses, and other assets		(3,322	)		11,823			(2,842	)
Accounts payable		879			4,612			220
Other current liabilities		6,219			8,270			(598	)
Net adjustments		83,086			73,560			37,854
Net cash provided by operating activities		131,914			111,272			75,510
Investing activities:
Utility plant expenditures		(127,681	)		(118,546	)		(123,926	)
Proceeds from sale of non-utility assets		85			64			34
Purchase of life insurance		(3,294	)		(1,744	)		(1,891	)
Change in restricted cash		1,959			(3,042	)		3,169
Net cash used in investing activities		(128,931	)		(123,268	)		(122,614	)
Financing activities:
Short-term borrowings		94,335			23,390			85,750
Repayment of short-term borrowings		(52,000	)		—			(74,000	)
Issuance of common stock, net of expenses		—			965			912
Issuance of long-term debt, net of expenses		124			178			106,173
Advances and contributions in aid of construction		6,966			7,231			5,313
Refunds of advances for construction		(7,397	)		(6,205	)		(6,188	)
Retirement of long-term debt		(7,037	)		(2,963	)		(13,692	)
Dividends paid		(26,387	)		(25,674	)		(24,753	)
Net cash provided by (used in) financing activities		8,604			(3,078	)		79,515
Change in cash and cash equivalents		11,587			(15,074	)		32,411
Cash and cash equivalents at beginning of year		27,203			42,277			9,866
Cash and cash equivalents at end of year	$	38,790		$	27,203		$	42,277
Supplemental disclosures of cash flow information:
Cash paid (received) during the year for:
Interest (net of amounts capitalized)	$	27,120		$	26,998		$	24,425
Income taxes		—			10,535			9,815
Income tax refunds		(5,349	)		(11,028	)		—
Supplemental disclosure of non-cash activities:
Accrued payables for investments in utility plant		11,048			9,008			6,565
Utility plant contributed by developers		13,630			14,991			31,422
MTBE reclassification from other long-term liabilities to CIAC		4,462			16,735			—
Capital leases		—			9,388			—

See accompanying Notes to Consolidated Financial Statements.

66

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

1 ORGANIZATION AND OPERATIONS

        California Water Service Group (Company) is a holding company that provides water utility and other related services in California, Washington, New Mexico, and Hawaii through its wholly-owned subsidiaries. California Water Service Company (Cal Water), Washington Water Service Company (Washington Water), New Mexico Water Service Company (New Mexico Water), and Hawaii Water Service Company, Inc. (Hawaii Water) provide regulated utility services under the rules and regulations of their respective state's regulatory commissions (jointly referred to as the Commissions). CWS Utility Services and HWS Utility Services LLC provide non-regulated water utility and utility-related services.

        The Company operates in one reportable segment, providing water and related utility services.

Basis of Presentation

        The consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (GAAP) and include the Company's accounts and those of its wholly owned subsidiaries. All intercompany transactions have been eliminated from the consolidated financial statements. In the opinion of management, the consolidated financial statements reflect all adjustments that are necessary to provide a fair presentation of the results for the periods covered.

        The preparation of the Company's consolidated financial statements in accordance with GAAP 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 consolidated balance sheet dates and the reported amounts of revenues and expenses for the periods presented. These include, but are not limited to, estimates and assumptions used in determining the Company's regulatory asset and liability balances based upon probability assessments of regulatory recovery, revenues earned but not yet billed, asset retirement obligations, allowance for doubtful accounts, pension and other employee benefit plan liabilities, and income tax-related assets and liabilities. Actual results could differ from these estimates.

2 SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Revenue

        Revenue generally includes monthly cycle customer billings for regulated water and wastewater services at rates authorized by regulatory commissions (plus an estimate for water used between the customer's last meter reading and the end of the accounting period) and billings to certain non-regulated customers at rates authorized by contract with government agencies.

        The Company's regulated water and waste water revenue requirements are authorized by the Commissions in the states in which we operate. The revenue requirements are intended to provide the Company a reasonable opportunity to recover its operating costs and earn a return on investments.

        For metered customers, Cal Water recognizes revenue from rates which are designed and authorized by the California Public Utilities Commission (CPUC). Under the Water Revenue Adjustment Mechanism (WRAM), Cal Water records the adopted level of volumetric revenues, which would include recovery of cost of service and a return on investments, as established by the CPUC for metered accounts (adopted volumetric revenues). In addition to volumetric-based revenues, the revenue requirements approved by the CPUC include service charges, flat rate charges, and other items not subject to the WRAM. The adopted

67

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

2 SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

volumetric revenue considers the seasonality of consumption of water based upon historical averages. The variance between adopted volumetric revenues and actual billed volumetric revenues for metered accounts is recorded as a component of revenue with an offsetting entry to a regulatory asset or liability balancing account (tracked individually for each Cal Water district) subject to certain criteria under the accounting for regulated operations being met. The variance amount may be positive or negative and represents amounts that will be billed or refunded to customers in the future.

        Cost-recovery rates are designed to permit full recovery of certain costs allowed to be recovered by the Commissions. Cost-recovery rates such as the Modified Cost Balancing Account (MCBA) provides for recovery of adopted expense levels for purchased water, purchased power and pump taxes, as established by the CPUC. In addition, cost-recovery rates include recovery of cost related to water conservation programs and certain other operating expenses adopted by the CPUC. Variances (which include the effects of changes in both rate and volume for the MCBA) between adopted and actual costs are recorded as a component of revenue, as the amount of such variances will be recovered from or refunded to our customers at a later date. There is no markup for return or profit for cost-recovery expenses and they are generally recognized when expenses are incurred.

        The balances in the WRAM and MCBA assets and liabilities accounts will fluctuate on a monthly basis depending upon the variance between adopted and actual results. The recovery or refund of the WRAM is netted against the MCBA over- or under-recovery for the corresponding district and is interest bearing at the current 90 day commercial paper rate. At the end of any calendar year, Cal Water files with the CPUC to refund or collect the balance in the accounts. Most undercollected net WRAM and MCBA receivable balances are collected over 12 and 18 months. Cal Water defers net WRAM and MCBA operating revenues and associated costs whenever the net receivable balances are estimated to be collected more than 24 months after the respective reporting periods in which it was recognized. The deferred net WRAM and MCBA revenues and associated costs were determined using forecasts of rate payer consumption trends in future reporting periods and the timing of when the CPUC will authorize Cal Water's filings to recover the undercollected balances. Deferred net WRAM and MCBA revenues and associated costs will be recognized as revenues and costs in future periods when collection is within twenty-four months of the respective reporting period.

        The change to net WRAM and MCBA deferred balances:

	Operating Revenues			Operating Costs			Income Before Income Taxes
Net WRAM and MCBA deferred balances as of December 31, 2011	$	12,864		$	10,492		$	2,372
Reversal of deferred amounts during 2012		(12,864	)		(10,492	)		(2,372	)
Deferred amounts added during 2012		882			719			163
Net WRAM and MCBA deferred balances as of December 31, 2012	$	882		$	719		$	163

68

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

2 SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

        The net undercollected WRAM and MCBA receivable balances as of December 31, 2012 and 2011 were:

	2012		2011
Net short-term receivable	$	34,020	$	19,357
Net long-term receivable		12,051		30,268
Total receivable	$	46,071	$	49,625
Net short-term payable	$	371	$	543
Net long-term payable		119		145
Total payable	$	490	$	688

        Flat rate customers are billed in advance at the beginning of the service period. The revenue is prorated so that the portion of revenue applicable to the current period is included in that period's revenue, with the balance recorded as unearned revenue on the balance sheet and recognized as revenue when earned in the subsequent accounting period. Our unearned revenue liability was $1,708 and $1,871 as of December 31, 2012 and 2011, respectively. This liability is included in "other accrued liabilities" on our consolidated balance sheets.

Allowance for Doubtful Accounts

        The Company provides an allowance for doubtful accounts receivable. The allowance is based upon specific identified accounts plus an estimate of uncollectible accounts based upon historical percentages. The balance of customer receivables is net of the allowance for doubtful accounts at December 31, 2012 and 2011 of $714 and $669, respectively.

        The activities in the allowance for doubtful accounts are as follows:

	2012			2011			2010
Beginning Balance	$	669		$	804		$	847
Provision for uncollectible accounts		1,548			1,250			1,500
Net write off of uncollectible accounts		(1,503	)		(1,385	)		(1,543	)
Ending Balance	$	714		$	669		$	804

Non-Regulated Revenue

        Revenues from non-regulated operations and maintenance agreements are recognized when services have been rendered to companies or municipalities under such agreements. For construction and design services, revenue is generally recognized on the completed contract method, as most projects are completed in less than three months. Other non-regulated revenue is recognized when title has transferred to the buyer, or ratably over the term of the lease.

69

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

2 SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Utility Plant

        Utility plant is carried at original cost when first constructed or purchased, or at fair value when acquired through acquisition. When depreciable plant is retired, the cost is eliminated from utility plant accounts and such costs are charged against accumulated depreciation. Maintenance of utility plant is charged to operating expenses as incurred. Maintenance projects are not accrued for in advance. Interest is capitalized on plant expenditures during the construction period and amounted to $3,401 in 2012, $2,741 in 2011, and $1,563 in 2010.

        Intangible assets acquired as part of water systems purchased are recorded at fair value. All other intangibles have been recorded at cost and are amortized over their useful life.

        The following table represents depreciable plant and equipment as of December 31:

	2012		2011
Equipment	$	400,610	$	382,195
Transmission and distribution plant		1,351,158		1,287,010
Office buildings and other structures		151,597		138,364
Total	$	1,903,365	$	1,807,569

        Depreciation of utility plant for financial statement purposes is computed on a straight-line basis over the assets' estimated useful lives including cost of removal of certain assets as follows:

	Useful Lives
Equipment	5 to 50 years
Transmission and distribution plant	40 to 65 years
Office Buildings and other structures	50 years

        The provision for depreciation expressed as a percentage of the aggregate depreciable asset balances was 3.1% in 2012, 3.0% in 2011, and 2.8% 2010. For income tax purposes, as applicable, the Company computes depreciation using the accelerated methods allowed by the respective taxing authorities.

Asset Retirement Obligation

        The Company has a legal obligation to retire wells in accordance with Department of Public Health regulations. In addition, upon decommission of a wastewater plant or lift station certain wastewater infrastructure would need to be retired in accordance with Department of Public Health regulations. The Company has collected retirement obligation costs from ratepayers through depreciation expense. As of December 31, 2012 and 2011 the retirement obligation is estimated to be $16,105 and $14,049, respectively. The change only impacted the consolidated balance sheet.

Cash Equivalents

        Cash equivalents include highly liquid investments with remaining maturities of three months or less at the time of acquisition.

70

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

2 SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Restricted Cash

        In 2012 restricted cash includes $1.0 million of Cal Water and a third party cash deposits for a capital project. It also includes $1.1 million of proceeds collected through a surcharge on certain customers' bills plus interest earned on the proceeds and is used to service California Safe Drinking Water Bond obligations. All restricted cash is included in prepaid expenses. At December 31, 2012 and 2011, restricted cash was $2,266 and $4,225, respectively.

Regulatory Assets and Liabilities

        Regulatory assets and liabilities were comprised of the following as of December 31:

	2012		2011
Regulatory Assets
Pension and retiree group health	$	223,153	$	213,819
Income tax temporary differences		56,991		34,664
Other accrued benefits		40,362		31,453
Net WRAM and MCBA long-term accounts receivable		12,051		30,268
Asset retirement obligations, net		11,862		9,694
Total Regulatory Assets	$	344,419	$	319,898
Regulatory Liabilities
Future tax benefits due ratepayers	$	24,932	$	16,978
Conservation program		6,538		4,328
Pension balancing account		—		1,936
Other liabilities		4,250		4,795
Total Regulatory Liabilities	$	35,720	$	28,037

        Short-term regulatory assets and liabilities are excluded from the above table. The short-term regulatory assets for 2012 and 2011 were $34,020 and $21,680, respectively. The short-term regulatory assets were primarily net WRAM/MCBA receivable balances. The short-term portion of regulatory liabilities for 2012 and 2011 were $5,018 and $2,655, respectively.

        The Company operates extensively in a regulated business, and as such is subject to the accounting standards for regulated utilities. Utility companies defer costs and credits on the balance sheet as regulatory assets and liabilities when it is probable that those costs and credits will be recognized in the ratemaking process in a period different from the period in which they would have been reflected in income by an unregulated company. Regulatory assets other than WRAM represent deferral of costs that will be recovered in the future and do not include a return. In determining the probability of costs being recognized in other periods, the Company considers regulatory rules and decisions, past practices, and other facts or circumstances that would indicate if recovery is probable. In the event that a portion of the Company's operations were no longer subject to the accounting standards for regulated utilities, the Company would be required to write off related regulatory assets and liabilities. If a commission determined that a portion of the Company's assets were not recoverable in customer rates, the Company

71

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

2 SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

would be required to determine if the Company had suffered an asset impairment that would require a write-down in the assets' valuation.

        The Company's qualified, defined-benefit, non-contributory pension plan and other postretirement plan benefit (Retire Group Health) regulatory asset is the amount the Company expects to recover from ratepayers in the future for these plans at the end of the calendar year, which also includes amounts that otherwise would be recorded to accumulated other comprehensive loss in the Consolidated Balance Sheet.

        The income tax temporary differences relate primarily to the difference between book and federal income tax depreciation on utility plant that was placed in service before the regulatory Commissions adopted normalization for rate making purposes. Previously, the tax benefit of tax depreciation was passed on to customers (flow-through). For state income tax purposes, the Commission continues to use the flow-through method. As such timing differences reverse, the Company will be able to include the impact of such differences in customer rates. These federal tax differences will continue to reverse over the remaining book lives of the related assets.

        Other accrued benefits are accrued benefits for vacation, self-insured workers' compensation, and directors' retirement benefits. The net WRAM and MCBA long-term accounts receivable is the undercollected portion of recorded revenues that are not expected to be collected from ratepayers within 12 months. The asset retirement obligations is recorded net of depreciation which has been recorded and recognized through the regulatory process over the remaining useful life of the related asset.

        The future tax benefits regulatory liability are future benefits to ratepayers for tax deductions that will be allowed in the future. Regulatory liabilities also reflect timing differences provided at higher than the current tax rate, which will flow-through to future ratepayers. The conservation program regulatory liability is for cost recovery in rates that exceeded incurred costs and is refundable to ratepayers as of December 31, 2012.

Impairment of Long-Lived Assets, Intangibles and Goodwill

        The Company regularly reviews its long-lived assets, intangible assets and goodwill for impairment annually or when events or changes in business circumstances have occurred that indicate the carrying amount of such assets may not be fully realizable. Potential impairment of assets held for use is determined by comparing the carrying amount of an asset to the future undiscounted cash flows expected to be generated by the asset. If assets are considered to be impaired, the impairment to be recognized is measured as the amount by which the carrying value of the asset exceeds its fair value. In the 2010 Hawaii Water GRC for the Ka'anapali Water District, construction costs of $320 were removed from rate base and expensed as a non-regulated expense during 2011 and in the Cal Water 2009 GRC settlement, construction costs of $634 were removed from rate base and expensed to non-regulated expense during 2010.

        Goodwill is measured as the excess of the cost of an acquisition over the sum of the amounts assigned to identifiable assets acquired less liabilities assumed. Goodwill and other identifiable intangible assets are accounted for in accordance with generally accepted accounting principles. Goodwill is not amortized but instead is reviewed annually at November 30^th for impairment or more frequently if impairment indicators arise.

72

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

2 SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

        The impairment test is performed at the reporting unit level using a two-step, fair-value based approach. The first step determines the fair value of the reporting unit and compares it to the reporting unit's carrying value. If the fair value of the reporting unit is less than its carrying amount, a second step is performed to measure the amount of impairment loss, if any. The second step allocates the fair value of the reporting unit to the Company's tangible and intangible assets and liabilities. This derives an implied fair value for the reporting unit's goodwill. If the carrying amount of the reporting unit's goodwill exceeds the implied fair value of that goodwill, an impairment loss is recognized equal to the excess.

        The recorded goodwill balance as of December 31, 2012 and 2011, relate to the Hawaii Water Service Company reporting unit. Based on our annual goodwill impairment test, no impairment was recorded in 2012 or 2011.

Long-Term Debt Premium, Discount and Expense

        The discount and issuance expense on long-term debt is amortized over the original lives of the related debt on a straight-line basis which approximates the effective interest method. Premiums paid on the early redemption of certain debt and the unamortized original issuance discount and expense are amortized over the life of new debt issued in conjunction with the early redemption. Amortization expense included in interest expense was $1,107, $1,082, and $979 for 2012, 2011, and 2010, respectively.

Advances for Construction

        Advances for Construction consist of payments received from developers for installation of water production and distribution facilities to serve new developments. Advances are excluded from rate base for rate setting purposes. Annual refunds are made to developers without interest. Advances of $186,753, and $185,902 at December 31, 2012 and 2011, respectively, will be refunded primarily over a 40-year period in equal annual amounts. In addition, other Advances for Construction totaling $831 and $1,376 at December 31, 2012, and 2011, respectively, are refundable based upon customer connections. Estimated refunds of advances for each succeeding year (2013 through 2017) are approximately $7,179, $7,178, $7,115, $7,098, $7,081 and $151,102 thereafter.

Contributions in Aid of Construction

        Contributions in Aid of Construction represent payments received from developers, primarily for fire protection purposes, which are not subject to refunds. Facilities funded by contributions are included in utility plant, but excluded from rate base. Depreciation related to assets acquired from contributions is charged to the Contributions in Aid of Construction account.

Income Taxes

        The Company accounts for income taxes using the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Measurement of the deferred tax assets and liabilities is at enacted tax rates expected to apply to taxable income in the years

73

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

2 SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the period that includes the enactment date.

        Historically the Commissions have allowed revenue requirements for the tax effects of temporary differences recognized, which have previously been flowed through to customers. The Commissions have granted the Company rate increases to reflect the normalization of the tax benefits of the federal accelerated methods and available Investment Tax Credits (ITC) for all assets placed in service after 1980. ITCs are deferred and amortized over the lives of the related properties for book purposes.

        Advances for Construction and Contributions in Aid of Construction received from developers subsequent to 1986 were taxable for federal income tax purposes and subsequent to 1991 were subject to California income tax. In 1996, the federal tax law, and in 1997, the California tax law, changed and only deposits for new services were taxable. In late 2000, federal regulations were further modified to exclude contributions of fire services from taxable income.

        The accounting standards for accounting for uncertainty in income taxes also requires the inclusion of interest and penalties related to uncertain tax positions as a component of income taxes. See note 10 "Income Taxes".

Workers' Compensation, General Liability and Other Claims

        For workers' compensation, the Company estimates the liability associated with claims submitted and claims not yet submitted based on historical data. Expenses for workers compensation insurance are included in rates on a pay-as-you-go basis. Therefore, a corresponding regulatory asset has been recorded. For general liability claims and other claims, the Company estimates the cost incurred but not yet paid using historical information.

Collective Bargaining Agreements

        As of December 31, 2012, the Company had 1,131 employees, including 734 non-supervisory employees who are represented by the Utility Workers Union of America, AFL-CIO, except certain engineering and laboratory employees who are represented by the International Federation of Professional and Technical Engineers, AFL-CIO. The union agreements expire at the end of 2014.

Earnings Per Share

        The computations of basic and diluted earnings per share are noted below. Basic earnings per share are computed by dividing net income available to common stockholders by the weighted average number of common shares outstanding during the period. Diluted earnings per share reflect the potential dilution that could occur if securities or other contracts were exercised or converted into common stock. Restricted Stock Awards (RSAs) are included in the common shares outstanding because the shares have all the same voting and dividend rights as issued and unrestricted common stock.

        At December 31, 2012, there were no common stock options outstanding. The Company did not grant any Stock Appreciation Rights (SAR) in 2012, 2011, and 2010. SARs outstanding were 333,856 shares as of December 31, 2012 and 361,356 shares as of December 31, 2011 and 2010.

74

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

2 SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

        All options are dilutive and the SARs are antidilutive. The dilutive effect is shown in the table below.

	2012		2011		2010
	(In thousands, except per share data)
Net income as reported and available to common stockholders	$	48,828	$	37,712	$	37,656
Weighted average common shares, basic		41,892		41,762		41,612
Dilutive common stock equivalents (treasury method)		—		10		26
Shares used for dilutive calculation		41,892		41,772		41,638
Earnings per share—basic	$	1.17	$	0.90	$	0.90
Earnings per share—diluted	$	1.17	$	0.90	$	0.90

Stock-based Compensation

        The Company follows accounting standards for stock-based compensation. Compensation cost is measured at the grant date based on the fair value of the award. The Company recognizes compensation as expense on a straight-line basis over the requisite service period, which is the vesting period.

Comprehensive Income or Loss

        Comprehensive income for all periods presented was the same as net income.

Accumulated Other Comprehensive Income or Loss

        The Company did not have any accumulated other comprehensive income or loss transactions for 2012, 2011, and 2010.

3 OTHER INCOME AND EXPENSES

        The Company conducts various non-regulated activities as reflected in the table below.

	2012					2011				2010
	Revenue		Expense			Revenue		Expense		Revenue		Expense
Operating and maintenance	$	9,938	$	10,976		$	9,176	$	9,689	$	9,237	$	9,713
Meter reading and billing		1,255		882			1,212		944		1,207		990
Leases		1,956		153			1,892		330		2,162		877
Design and construction		1,407		1,135			1,689		1,420		1,306		1,041
Interest income		41		—			75		—		28		—
Change in value of life insurance contracts (gain) loss		—		(2,504	)		—		1,876		—		(2,641	)
Other non-regulated income and expenses		2,089		911			2,116		1,563		2,053		2,332
Total	$	16,686	$	11,553		$	16,160	$	15,822	$	15,993	$	12,312

75

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

3 OTHER INCOME AND EXPENSES (Continued)

        Operating and maintenance services and meter reading and billing services are provided for water and wastewater systems owned by private companies and municipalities. The agreements call for a fee-per-service or a flat-rate amount per month. Leases have been entered into with telecommunications companies for cellular phone antennas placed on the Company's property. Design and construction services are for the design and installation of water mains and other water infrastructure for others outside the Company's regulated service areas. Third-party insurance program revenues are included in other non-regulated income and expenses.

4 INTANGIBLE ASSETS

        As of December 31, 2012 and 2011, intangible assets that will continue to be amortized and those not amortized were:

	Weighted Average Amortization Period (years)	2012						2011
		Gross Carrying Value		Accumulated Amortization		Net Carrying Value		Gross Carrying Value		Accumulated Amortization		Net Carrying Value
Amortized intangible assets:
Water pumping rights	usage	$	1,084	$	79	$	1,005	$	1,084	$	14	$	1,070
Water planning studies	12		11,894		4,322		7,572		11,087		3,413		7,674
Leasehold improvements and other	21		1,140		249		891		1,086		345		741
Total	13	$	14,118	$	4,650	$	9,468	$	13,257	$	3,772	$	9,485
Unamortized intangible assets:
Perpetual water rights and other		$	4,495	$	—	$	4,495	$	3,229	$	—	$	3,229

        For the years ended December 31, 2012, 2011, and 2010, amortization of intangible assets was $1,298, $1,421, and $1,894, respectively. Estimated future amortization expense related to intangible assets for the succeeding five years is approximately $1,319, $1,296, $1,237, $1,192, and $4,638 thereafter.

5 PREFERRED STOCK

        The Company is authorized to issue 241,000 shares of Preferred Stock as of December 31, 2012. No shares of Preferred Stock were issued and outstanding at December 31, 2012 or 2011.

6 COMMON STOCKHOLDERS' EQUITY

        As of December 31, 2012 and 2011, 41,908,218 shares and 41,817,218 shares, respectively, of common stock were issued and outstanding.

Dividend Reinvestment and Stock Repurchase Plan

        The Company has a Dividend Reinvestment and Stock Purchase Plan (DRIP Plan). Under the DRIP Plan, stockholders may reinvest dividends to purchase additional Company common stock without

76

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

6 COMMON STOCKHOLDERS' EQUITY (Continued)

commission fees. The Plan also allows existing stockholders and other interested investors to purchase Company common stock through the transfer agent up to certain limits. The Company's transfer agent operates the DRIP Plan and purchases shares on the open market to provide shares for the Plan.

7 SHORT-TERM BORROWINGS

        On June 29, 2011, the Company and Cal Water entered into Syndicated Credit Agreements, which provide for unsecured revolving credit facilities of up to an initial aggregate amount of $400 million. The Syndicated Credit Facilities amend, expand, and replace the Company's and its subsidiaries' existing credit facilities originally entered into on October 27, 2009. The new credit facilities extended the terms until June 29, 2016, increased the Company's and Cal Water's unsecured revolving lines of credit, and lowered interest rates and fees. The Company and subsidiaries which it designates may borrow up to $100 million under the Company's revolving credit facility. Cal Water may borrow up to $300 million under its revolving credit facility; however, all borrowings need to be repaid within twelve months unless otherwise authorized by the CPUC. The proceeds from the revolving credit facilities may be used for working capital purposes, including the short-term financing of capital projects. The base loan rate may vary from LIBOR plus 72.5 basis points to LIBOR plus 95 basis points, depending on the Company's total capitalization ratio. Likewise, the unused commitment fee may vary from 8 basis points to 12.5 basis points based on the same ratio.

        Both short-term unsecured credit agreements contain affirmative and negative covenants and events of default customary for credit facilities of this type including, among other things, limitations and prohibitions relating to additional indebtedness, liens, mergers, and asset sales. Also, these unsecured credit agreements contain financial covenants governing the Company and its subsidiaries' consolidated total capitalization ratio and interest coverage ratio. As of December 31, 2012, the Company and Cal Water have met all borrowing covenants for both credit agreements.

        As of December 31, 2012 and December 31, 2011, the outstanding borrowings on the Company lines of credit were $64.5 million and $47.1 million, respectively. The borrowings on the Cal Water lines of credit were $25.0 million as of December 31, 2012, and there were no borrowings as of December 31, 2011.

        The following table represents borrowings under the bank lines of credit:

	2012			2011
Maximum short-term borrowings	$	89,475		$	47,140
Average amount outstanding	$	71,715		$	32,324
Weighted average interest rate		1.74	%		2.41	%
Interest rate at December 31		2.14	%		2.10	%

77

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

8 LONG-TERM DEBT

        As of December 31, 2012 and 2011, long-term debt outstanding was:

	Series	Interest Rate	Maturity Date		2012		2011
First Mortgage Bonds	PPP	5.500%		2040	$	100,000	$	100,000
	LL	5.875%		2019		100,000		100,000
	AAA	7.280%		2025		20,000		20,000
	BBB	6.770%		2028		20,000		20,000
	CCC	8.150%		2030		20,000		20,000
	DDD	7.130%		2031		20,000		20,000
	EEE	7.110%		2032		20,000		20,000
	FFF	5.900%		2017		20,000		20,000
	GGG	5.290%		2022		18,182		20,000
	HHH	5.290%		2022		18,182		20,000
	III	5.540%		2023		10,000		10,000
	JJJ	5.440%		2018		5,455		6,364
	LLL	5.480%		2018		10,000		10,000
	MMM	5.520%		2013		20,000		20,000
	NNN	5.550%		2013		20,000		20,000
	OOO	6.020%		2031		20,000		20,000
	CC	9.860%		2020		17,400		17,500
	K	6.940%		2012		—		800
Total First Mortgage Bonds						459,219		464,664
California Department of Water Resources Loans		2.6% to 8%		2012 - 32		8,451		8,780
Other Long-term debt						13,580		14,721
Total long-term debt						481,250		488,165
Less current maturities						46,783		6,533
Long-term debt excluding current maturities					$	434,467	$	481,632

        On October 4, 2011, Cal Water entered into a new capital lease arrangement with the City of Hawthorne to operate the City's water system for a 15-year period. The $9.2 million capital lease liability is included in other long-term debt and current maturities set forth above.

        On November 17, 2010, Cal Water completed the sale and issuance of $100 million aggregate principal amount of its 5.50% First Mortgage Bonds PPP due 2040, which are fully and unconditionally guaranteed by the Company.

78

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

9 OTHER ACCRUED LIABILITIES

        As of December 31, 2012 and 2011, other accrued liabilities were:

	2012		2011
Accrued and deferred compensation	$	16,320	$	14,143
Deferred tax liability		15,000		10,535
Accrued benefit and workers' compensation claims		6,906		5,222
Other		8,282		8,026
	$	46,508	$	37,926

10 INCOME TAXES

        Income tax expense consisted of the following:

	Federal			State			Total
2012
Current	$	(9,018	)	$	(5,246	)	$	(14,264	)
Deferred		37,196			(1,480	)		35,716
Total	$	28,178		$	(6,726	)	$	21,452
2011
Current	$	7,413		$	2,629		$	10,042
Deferred		12,982			142			13,124
Total	$	20,395		$	2,771		$	23,166
2010
Current	$	4,027		$	3,020		$	7,047
Deferred		15,730			1,779			17,509
Total	$	19,757		$	4,799		$	24,556

        The Company filed an application for a change in accounting method (section 481 adjustment) with the Internal Revenue Service (IRS) in 2012 to implement the new repairs and maintenance deduction. The new deduction is for qualified tangible property placed into service during 2012 and prior years. The new tax regulations allow the Company to deduct a significant amount of costs previously capitalized for book and tax purposes. During 2012, the Company completed its analysis of the federal repairs maintenance deduction related to 2012 and prior years. The Company's federal repairs and maintenance deductions for qualified tangible property placed into service during 2012 and prior years was $100.7 million and created a $35.3 million deferred tax liability for the temporary timing difference between book and tax treatments in 2012. The 2012 and prior years federal repairs and maintenance deduction eliminated the Company's 2010 and 2011 previously filed federal qualified U.S. production activities deductions (QPAD) and was recorded as a $0.8 million federal income tax expense in 2012. The Company's state repairs deduction for qualified tangible property deductions placed into service during 2012 and prior years was $136.2 million and was recorded as a $7.8 million reduction to state income tax expense in 2012.

79

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

10 INCOME TAXES (Continued)

        The Company filed an application for a change in accounting method (Section 481 adjustment) with the State of California to change its plant-in-service state tax depreciation method from the double- declining method to the straight line method at the respective assets mid-life. The Company's application was approved by the State of California during the first quarter of 2011. California uses the flow-through method of accounting for income tax depreciation. As a result, the Company reduced its income tax obligation $1.6 million, net of federal income taxes in 2011. Income tax expense was computed by applying the current federal 35% tax rate to pretax book income differs from the amount shown in the Consolidated Statements of Income. The difference is reconciled in the table below:

	2012			2011			2010
Computed "expected" tax expense	$	24,600		$	21,308		$	21,774
Increase (reduction) in taxes due to:
State income taxes net of federal tax benefit		4,041			3,500			3,577
Effect of regulatory treatment of fixed asset differences		(7,030	)		(1,614	)		—
Investment tax credits		(74	)		(74	)		(74	)
Other		(85	)		46			(721	)
Total income tax	$	21,452		$	23,166		$	24,556

        The 2012 section 481 adjustment was a benefit of ($7,030) due to the tax repairs and maintenance deductions for 2011 and prior years. The 2011 section 481 adjustment was a benefit of ($1,614) due to an accounting method change with the State of California to change its plant-in-service state tax depreciation method from the double- declining method to the straight line method at the respective assets mid-life.

        Included in "Other" in the above table is the recognition of the flow-through accounting for federal depreciation expense on assets acquired prior to 1982 and retirement costs of such assets. For assets acquired prior to 1982, the benefit of excess tax depreciation was previously passed through to the ratepayers. The tax benefit is now reversing and a higher tax expense is being recognized and is included in customer rates. Offsetting the flow-through depreciation in 2012, 2011, and 2010 was the impact of cost to remove pre-1982 assets. Also included in "Other" in the above table, were 2012, 2011 and 2010 QPAD deductions. QPAD activities include production of potable water, but exclude the transmission and distribution of the potable water. The impact of the deduction is being reported in the year in which the deduction is claimed on the Company's tax return. The QPAD is limited to the lesser of 9% of taxable income or 50% of taxable gross wages in 2012. The 2012 section 481adjustment eliminated the QPAD deduction for 2012 and eliminated the 2011 and 2010 QPAD deductions which were recognized as an $831 increase to the income tax provision in 2012. The QPAD lowered the income tax provision by $397 and $433 in 2011 and 2010, respectively.

        The Tax Relief, Unemployment Insurance Reauthorization and Job Creation Act of 2010 will provide the Company with additional federal income tax deductions for assets placed in service after September 8, 2010 and before December 31, 2012. As of December 31, 2012 and 2011 the deferred income tax liability for bonus depreciation was $1,610 and $12,600, respectively.

80

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

10 INCOME TAXES (Continued)

        The tax effects of differences that give rise to significant portions of the deferred tax assets and deferred tax liabilities at December 31, 2012 and 2011 are presented in the following table:

	2012		2011
Deferred tax assets:
Developer deposits for extension agreements and contributions in aid of construction	$	44,530	$	45,587
Net operating loss		8,437		1,015
Other		3,607		3,449
Total deferred tax assets		56,574		50,051
Deferred tax liabilities:
Utility plant, principally due to depreciation differences		207,642		155,916
WRAM/MCBA balancing accounts		19,533		17,393
Other		3,245		3,645
Total deferred tax liabilities		230,420		176,954
Net deferred tax liabilities	$	173,846	$	126,903

        The current portion of our deferred income tax liability is $15,000 and $10,535 as of December 31, 2012 and 2011, respectively, which includes prepaid expenses and billed WRAM/MCBA surcharge, expected to reverse in the following 12 months.

        A valuation allowance was not required at December 31, 2012 and 2011. Based on historical taxable income and future taxable income projections over the period in which the deferred assets are deductible, management believes it is more likely than not that the Company will realize the benefits of the deductible differences.

        The following table reconciles the changes in unrecognized tax benefits:

	December 31, 2012			December 31, 2011
Balance at beginning of year	$	831		$	831
Additions for tax positions taken during prior year		—			—
Additions for tax positions taken during current year		—			—
Reductions for tax positions taken during a prior year		—			—
Lapse of statute of limitations		(831	)		—
Balance at end of year	$	—		$	831

        As of December 31, 2012 and 2011, the total amount of net unrecognized tax benefits was none and $831, respectively. The Company accrues interest and penalties related to unrecognized tax benefits in its provision for income taxes. The total amount of penalties and interest was $114 as of December 31, 2011 and 2010. The total accrued penalties and interest of $114 was reversed as of December 31, 2012.

81

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

10 INCOME TAXES (Continued)

Additionally, the Company does not expect a material change in its unrecognized tax benefits within the next 12 months.

        Tax years of 2010 and 2011 are subject to examination by the federal and state taxing authorities, respectively. The IRS is presently auditing the Company's 2010 and 2011 federal income tax returns. It is uncertain when the IRS will complete its audit. The Company believes that the final resolution of the IRS audit will not have a material adverse impact on its financial condition or results of operations. The California Franchise Tax Board (FTB) finished the examination for the Company's 2008 and 2009 California income tax returns in December 2012 with no audit adjustment.

11 EMPLOYEE BENEFIT PLANS

Savings Plan

        The Company sponsors a 401(k) qualified, defined contribution savings plan that allows participants to contribute up to 20% of pre-tax compensation. Effective January 1, 2010, the Company matches seventy-five cents for each dollar contributed by the employee up to a maximum Company match of 6.0% of base salary. In the prior year, the Company matched fifty cents for each dollar contributed up to a maximum Company match of 4.0% of base salary. Company contributions were $4,029, $3,499, and $3,232, for the years 2012, 2011, and 2010, respectively.

Pension Plans

        The Company provides a qualified, defined-benefit, non-contributory pension plan for substantially all employees. The accumulated benefit obligations of the pension plan are $307,197 and $266,496 as of December 31, 2012 and 2011, respectively. The fair value of pension plan assets was $202,947 and $155,749 as of December 31, 2012 and 2011, respectively.

        Prior to 2010, pension payment obligations were generally funded by the purchase of an annuity from a life insurance company. In 2010, the pension plan trust paid monthly benefits to retirees, rather than the purchase of an annuity. Payments are expected to be made in each year from 2013 to 2017 are $6,189, $7,547, $8,770, $10,090, and $11,577, respectively. The aggregate benefits expected to be paid in the five years 2018 through 2022 are $81,916. The expected benefit payments are based upon the same assumptions used to measure the Company's benefit obligation at December 31, 2012, and include estimated future employee service.

        The Company also maintains an unfunded, non-qualified, supplemental executive retirement plan. The unfunded supplemental executive retirement plan accumulated benefit obligations were $31,696 and $26,060 as of December 31, 2012 and 2011, respectively. Benefit payments under the supplemental executive retirement plan are paid currently and are included in the preceding paragraph.

        The costs of the pension and retirement plans are charged to expense and utility plant. The Company makes annual contributions to fund the amounts accrued for pension cost.

82

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

11 EMPLOYEE BENEFIT PLANS (Continued)

Other Postretirement Plan

        The Company provides substantially all active, permanent employees with medical, dental, and vision benefits through a self-insured plan. Employees retiring at or after age 58, along with their spouses and dependents, continue participation in the plan by payment of a premium. Plan assets are invested in mutual funds, short-term money market instruments and commercial paper based upon the same asset mix as the pension plan. Retired employees are also provided with a five thousand dollar life insurance benefit.

        The Company records the costs of postretirement benefits other than pension (PBOP) during the employees' years of active service. Postretirement benefit expense recorded in 2012, 2011, and 2010, was $8,131, $6,291, and $4,782, respectively. Prior to 2006, the Company recorded a regulatory asset for the difference between the Company-funded amount and the net periodic benefit cost. The remaining net periodic benefit cost was $9,790 at December 31, 2006, and is being recovered through future customer rates and is recorded as a regulatory asset. The expected benefit payments, net of retiree premiums and Medicare part D subsidies, for the years from 2013 to 2017 are $1,398, $1,592, $1,819, $1,998, and $2,196, respectively. The Medicare Part D subsidies for the years from 2013 to 2017 are $253, $295, $337, $379, and $424.

Benefit Plan Assets

        The Company actively manages pensions and PBOP trust (Plan) assets. The Company's investment objectives are:

•

Maximize the return on the assets of the Plan, commensurate with the risk that the Company deem appropriate to, meet the obligations of the Plan, minimize the volatility of the pension expense, and account for contingencies;

•

Generate a rate of return for the total portfolio that equals or exceeds the actuarial investment rate assumption;

•

Additionally, the rate of return of the total fund shall be measured periodically against a special index comprised of 35% of the Standard & Poor's Index, 15% of the Russell 2000 Index, 10% of the MSCI EAFE Index, and 40% of the Lehman Aggregate Bond Index. The special index is consistent with the rate of return objective and indicates the Company's long-term asset allocation objective.

        The Company applies a risk management framework for managing the risks associated with employee benefit plan trust assets. The guiding principles of this risk management framework are the clear articulation of roles and responsibilities, appropriate delegation of authority, and proper accountability and documentation. Trust investment policies and investment manager guidelines include provisions to ensure prudent diversification, manage risk through appropriate use of physical direct asset holdings and derivative securities, and identify permitted and prohibited investments.

83

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

11 EMPLOYEE BENEFIT PLANS (Continued)

        The Company's target asset allocation percentages for major categories of the pension plan are reflected in the table below:

	Minimum Exposure			Target			Maximum Exposure
Fixed Income		35	%		40	%		45	%
Total Domestic Equity		40	%		50	%		60	%
Small Cap Stocks		10	%		15	%		20	%
Large Cap Stocks		30	%		35	%		45	%
Non-U.S. Equities		5	%		10	%		15	%

        The fixed income category includes money market funds, short-term bond funds, and cash. The majority of fixed income investments range in maturities from less than one to five years.

        The Company's target allocation percentages for the PBOP trust is similar to the pension plan except for a larger allocation in fixed income investments and a lower allocation in equity investments.

        We use the following criteria to select investment funds:

•

Fund past performance;

•

Fund meets criteria of Employee Retirements Income Security Act (ERISA);

•

Timeliness and completeness of fund communications and reporting to investors;

•

Stability of fund management company;

•

Fund management fees; and

•

Administrative costs incurred by the Plan.

        The fair value measurements standard establishes a framework for measuring fair value. That framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (level 1 measurements) and the lowest priority to unobservable inputs (level 3 measurements). The three levels of the fair value hierarchy under the standard are described below:

Level 1—Inputs to the valuation methodology are unadjusted quoted prices for identical assets or liabilities in active markets that the Plan has the ability to access.

Level 2—Inputs to the valuation methodology include:

•

Quoted market prices for similar assets or liabilities in active markets;

•

Quoted prices for identical or similar assets or liabilities in inactive markets;

•

Inputs other than quoted prices that are observable for the asset or liability; and

•

Inputs that are derived principally from or corroborated by observable market data by correlation or other means.

84

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

11 EMPLOYEE BENEFIT PLANS (Continued)

If the asset or liability has a specified (contractual) term, the level 2 input must be observable for substantially the full term of the asset or liability.

Level 3—Inputs to the valuation methodology are unobservable and significant to the fair value measurement.

        All Plan investments are level 1 investments in mutual funds and are valued at the net asset value (NAV) of the shares held by the Plan at December 31, 2012 and 2011:

	Pension Benefits										Other Benefits
	2012		%			2011		%			2012		%			2011		%
Fixed Income	$	79,391		39	%	$	79,859		51	%	$	22,845		61	%	$	16,006		59	%
Domestic Equity
Small Cap Stocks		33,949					27,262					—					—
Large Cap Stocks		69,406					40,689					14,563					10,972
Total Domestic Equity		103,355		51	%		67,951		44	%		14,563		39	%		10,972		41	%
Non U.S. Equities		20,201		10	%		7,939		5	%		—		0	%		—		0	%
Total Plan Assets	$	202,947		100	%	$	155,749		100	%	$	37,408		100	%	$	26,978		100	%

        The pension benefits fixed income category includes $26,069 and $43,364 of money market fund investments as of December 31, 2012 and 2011, respectively. The other benefits fixed income category includes $14,159 and $16,006 of money market fund investments as of December 31, 2012 and 2011.

85

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

11 EMPLOYEE BENEFIT PLANS (Continued)

        The following table reconciles the funded status of the plans with the accrued pension liability and the net postretirement benefit liability as of December 31, 2012 and 2011:

	Pension Benefits						Other Benefits
	2012			2011			2012			2011
Change in projected benefit obligation:
Beginning of year	$	346,305		$	269,940		$	69,107		$	45,944
Service cost		15,450			11,713			4,399			3,199
Interest cost		15,287			14,683			3,139			2,872
Assumption change		24,269			59,028			7,673			12,600
Experience (gain) loss		4,833			(6,030	)		1,250			5,705
Benefits paid, net of retiree premiums		(4,023	)		(3,029	)		(1,147	)		(1,213	)
End of year	$	402,121		$	346,305		$	84,421		$	69,107
Change in plan assets:
Fair value of plan assets at beginning of year	$	155,749		$	139,034		$	26,978		$	21,178
Actual return on plan assets		21,979			555			2,788			64
Employer contributions		29,242			19,189			8,789			6,949
Retiree contributions and Medicare part D subsidies		—			—			1,255			1,130
Benefits paid		(4,023	)		(3,029	)		(2,402	)		(2,343	)
Fair value of plan assets at end of year	$	202,947		$	155,749		$	37,408		$	26,978
Funded status(1)	$	(199,174	)	$	(190,556	)	$	(47,013	)	$	(42,129	)
Unrecognized actuarial loss		133,579			123,177			40,449			34,515
Unrecognized prior service cost		41,972			47,976			421			537
Unrecognized transition obligation		—			—			9			285
Net amount recognized	$	(23,623	)	$	(19,403	)	$	(6,134	)	$	(6,792	)

(1)

The short-term portion of the pension benefits was $1,286 and $692 as of December 31, 2012 and 2011, respectively.

        Amounts recognized on the balance sheet consist of:

	Pension Benefits						Other Benefits
	2012			2011			2012			2011
Prepaid (Accrued) benefit costs	$	—		$	—		$	(6,723	)	$	(6,792	)
Accrued benefit liability		(199,174	)		(190,556	)		(47,013	)		(35,337	)
Regulatory asset		175,551			171,153			47,602			35,337
Net amount recognized	$	(23,623	)	$	(19,403	)	$	(6,134	)	$	(6,792	)

86

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

11 EMPLOYEE BENEFIT PLANS (Continued)

        Below are the actuarial assumptions used in determining the benefit obligation for the benefit plans:

	Pension Benefits						Other Benefits
	2012			2011			2012			2011
Weighted average assumptions as of December 31:
Discount rate		4.10	%		4.40	%		4.20	%		4.50	%
Long-term rate of return on plan assets		7.00	%		7.00	%		6.00	%		6.25	%
Rate of compensation increases		3.50	%		3.50	%		—			—
Cost of living adjustment		3.00	%		3.00	%		—			—

        The discount rate was derived from the Citigroup Pension Discount Curve using the expected payouts for the plan. The long-term rate of return assumption is the expected rate of return on a balanced portfolio invested roughly 60% in equities and 40% in fixed income securities. Returns on equity investments were estimated based on estimates of dividend yield and real earnings added to a 3% long-term inflation rate. For the pension and other benefit plans, the assumed returns were 9.20% for domestic equities and 9.34% for foreign equities. Returns on fixed-income investments were projected based on investment maturities and credit spreads added to a 3% long-term inflation rate. For the pension and other benefit plans, the assumed returns were 5.05% for fixed income investments and 3.46% for short-term cash investments. The average return for the pension and other benefit plans for the last five and ten years was 3.00% and 7.10%, respectively. The company is using a long-term rate of return of 7.00% for the pension plan and 6.00% for the other benefit plan, which is between the 25th and 75th percentile of expected results.

        Changes to the pension benefits actuarial assumptions can significantly affect pension costs, regulatory assets, and liabilities. The following table reflects the sensitivity of pension amounts reported for the year ended December 31, 2012, to changes in actuarial assumptions:

	Increase/(Decrease) in Pension Actuarial Assumption			Increase/(Decrease) in 2012 Net Periodic Pension Benefit Cost			Increase/(Decrease) in Projected Pension Benefit Obligation as of December 31, 2012
Discount rate		(0.5	)%	$	4,280		$	40,189
Long-term rate of return on plan assets		(0.5	)%		826			—
Rate of compensation increases		(0.5	)%		(1,929	)		(11,227	)
Cost of living adjustment		(0.5	)%		(3,291	)		(24,427	)
Discount rate		0.5	%		(3,793	)		(35,196	)
Long-term rate of return on plan assets		0.5	%		(825	)		—
Rate of compensation increases		0.5	%		2,095			12,099

87

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

11 EMPLOYEE BENEFIT PLANS (Continued)

        Net periodic benefit costs for the pension and other postretirement plans for the years ended December 31, 2012, 2011, and 2010 included the following components:

	Pension Plan									Other Benefits
	2012			2011			2010			2012			2011			2010
Service cost	$	15,450		$	11,713		$	10,076		$	4,399		$	3,199		$	2,491
Interest cost		15,287			14,683			13,701			3,139			2,872			2,329
Expected return on plan assets		(11,558	)		(8,949	)		(8,228	)		(1,832	)		(1,372	)		(1,119	)
Net amortization and deferral		14,283			10,387			9,224			2,425			1,592			1,081
Net periodic benefit cost	$	33,462		$	27,834		$	24,773		$	8,131		$	6,291		$	4,782

        Below are the actuarial assumptions used in determining the net periodic benefit costs for the benefit plans, which uses the end of the prior year as the measurement date:

	Pension Benefits						Other Benefits
	2012			2011			2012			2011
Weighted average assumptions as of December 31:
Discount rate		4.40	%		5.60	%		4.50	%		5.60	%
Long-term rate of return on plan assets		7.00	%		6.75	%		6.25	%		6.00	%
Rate of compensation increases		3.50	%		4.00	%		—			—

        The health care cost trend rate assumption has a significant effect on the amounts reported. For 2012 measurement purposes, the Company assumed an 8.2% annual rate of increase in the per capita cost of covered benefits with the rate decreasing to 6.2% by 2017, then gradually grading down to 5.4% over the next 50 years. A one-percentage point change in assumed health care cost trends is estimated to have the following effect:

	1-Percentage Point Increase		1-Percentage Point Decrease
Effect on total service and interest costs	$	2,036	$	(1,506	)
Effect on accumulated postretirement benefit obligation	$	18,576	$	(14,147	)

        The Company intends to make annual contributions to the plans up to the amount deductible for tax purposes. The Company estimates in 2013 that the annual contribution to the pension plans will be $35,684 and the annual contribution to the other postretirement plan will be $8,892.

12 STOCK-BASED COMPENSATION PLANS

        The Company has two stockholder-approved stock-based compensation plans.

88

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

12 STOCK-BASED COMPENSATION PLANS (Continued)

Long-term Incentive Plan

        The long-term incentive plan was replaced on April 27, 2005, by a stockholder-approved equity incentive plan. The Long-Term Incentive Plan allowed granting of nonqualified stock options. There will be no future grants made under the Long-term Incentive Plan. The Company had accounted for options using the intrinsic value method. Options were granted at an exercise price that was not less than the per share common stock market price on the date of grant. The options vested at a 25% rate on their anniversary date over their first four years and are exercisable over a ten-year period. At December 31, 2012, all the options under the Long-term Incentive Plan were exercised. No options were granted under the Long-term Incentive Plan in 2012, 2011, or 2010.

Equity Incentive Plan

        Under the Equity Incentive Plan, which was approved by stockholders on April 27, 2005, the Company is authorized to issue awards of up to 2,000,000 shares of common stock. In 2012 and 2011, the Company granted RSAs of 101,236 and 85,426 shares, respectively, of common stock both to employees and to directors of the Company. In 2012, 10,050 RSAs were cancelled and no RSAs were cancelled in 2011. Employee awards vest ratably over 48 months, while independent director awards vest at the end of 12 months. The shares were valued at the weighted average price of $17.97 and $17.44 per share, respectively based upon the fair market value of the Company's common stock on the date of grant. In 2012, no new Stock Appreciation Rights (SARs) were granted to employees and 27,500 shares of SARs were cancelled.

        The Company did not apply a forfeiture rate in the expense computation relating to SARs and RSAs issued to employees as they vest monthly and, as a result, the expense is recorded for actual number vested during the period. For outside directors, the Company did not apply a forfeiture rate in the expense computation relating to RSAs, as the Company expects 100% to vest at the end of 12 months.

        The SARs vest ratably over 48 months and expire at the end of 10 years. Upon exercise of a SAR, the appreciation is payable in common shares of the Company. The assumptions utilized to determine the grant-date fair value of the SARs in 2009 was an expected dividend yield of 3.07%, expected volatility of 22.10%, a risk-free interest rate of 2.84%, and an expected holding period of 6.75 years. As of December 31, 2012, there were 333,856 shares outstanding of which 325,602 shares were exercisable at a weighted average fair value of $3.66.

        The Company has recorded compensation expense for the RSAs and SARs of $1,442, $1,300, and $1,077 in 2012, 2011, and 2010, respectively. The unrecognized future compensation expense for the RSAs and SARs at December 31, 2012 is $1,913.

13 FAIR VALUE OF FINANCIAL INSTRUMENTS

        The accounting guidance for fair value measurements and disclosures provides a single definition of fair value and requires certain disclosures about assets and liabilities measured at fair value. A hierarchal

89

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

13 FAIR VALUE OF FINANCIAL INSTRUMENTS (Continued)

framework for disclosing the observability of the inputs utilized in measuring assets and liabilities at fair value is established by this guidance. The three levels in the hierarchy are as follows:

Level 1—Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. The types of assets and liabilities included in Level 1 are highly liquid and actively traded instruments with quoted prices.

Level 2—Pricing inputs are other than quoted prices inactive markets, but are either directly or indirectly observable as of the reporting date. The types of assets and liabilities included in Level 2 are typically either comparable to actively traded securities or contracts, or priced with discounted cash flow or option pricing models using highly observable inputs.

Level 3—Significant inputs to pricing have little or no observability as of the reporting date. The types of assets and liabilities included in Level 3 are those valued with models requiring significant management judgment or estimation.

        Specific valuation methods include the following:

        Cash equivalents, accounts receivable and accounts payable carrying amounts approximated the fair value because of the short-term maturity of the instruments.

        Long-term debt fair values were estimated using the published quoted market price, if available, or the discounted cash flow analysis, based on the current rates available using a risk-free rate (a U.S. Treasury securities yield curve) plus a risk premium of 1.19%.

        Advances for construction fair values were estimated using broker quotes from companies that frequently purchase these investments.

	December 31, 2012
			Fair Value
	Cost		Level 1		Level 2		Level 3		Total
Long -term debt, including current maturities	$	481,250	$	—	$	613,211	$	—	$	613,211
Advances for construction		187,584		—		70,914		—		70,914
Total	$	668,834	$	—	$	684,125	$	—	$	684,125

	December 31, 2011
			Fair Value
	Cost		Level 1		Level 2		Level 3		Total
Long -term debt, including current maturities	$	488,165	$	—	$	625,202	$	—	$	625,202
Advances for construction		187,278		—		69,952		—		69,952
Total	$	675,443	$	—	$	695,154	$	—	$	695,154

90

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

14 COMMITMENTS AND CONTINGENCIES

Commitments

        The Company leases offices, equipment and other facilities, two water systems from cities, and has long-term commitments to purchase water from water wholesalers. The commitments are noted in the table below.

	Facility Leases		System Lease		Water Contracts		Capital Lease Obligations
2013	$	632	$	845	$	19,378	$	1,109
2014		515		845		19,448		1,109
2015		404		845		19,521		1,109
2016		193		845		19,592		1,109
2017		166		845		19,664		1,109
Thereafter		2,494		493		451,891		8,609

        Company Facility leases include office and other facilities in many of its operating districts. The total paid and charged to operations for such leases was $1,156 in 2012, $1,271 in 2011, and $1,080 in 2010. The system lease is a 15-year lease with the City of Commerce. The lease includes an annual lease payment of $845 per year plus a cost savings sharing arrangement.

        The Company has a long-term contract with the Santa Clara Valley Water District that requires the Company to purchase minimum annual water quantities. Purchases are priced at the districts then-current wholesale water rate. The Company operates to purchase sufficient water to equal or exceed the minimum quantities under the contract. The total paid to Santa Clara Valley Water District was $6,164 in 2012, $5,524 in 2011, and $5,306 in 2010.

        The Company also has a water supply contract with Stockton East Water District (SEWD) that requires a fixed, annual payment. Each year, the fixed annual payment is adjusted for changes to SEWD's costs. Because of the fixed annual price arrangement, the Company operates to receive as much water as possible from SEWD in order to minimize the cost of operating Company-owned wells used to supplement SEWD deliveries. The total paid under the contract was $6,591 in 2012, $6,658 in 2011, and $6,159 in 2010.

        Estimated annual contractual obligations in the table above are based on the same payment levels as 2012. Future increased costs by SEWD are expected to be offset by a decline in the allocation of costs to the Company, as other customers of SEWD are expected to receive a larger allocation based upon growth of their service areas.

        On September 21, 2005, the Company entered into an agreement with Kern County Water Agency (Agency) to obtain treated water for the Company's operations. The term of the agreement is to January 1, 2035, or until the repayment of the Agency's bonds (described hereafter) occurs. Under the terms of the agreement, the Company is obligated to purchase approximately 18,000 acre feet of treated water in 2012 and an incrementally higher volume of water for each subsequent year until 2017, when the Company is obligated to purchase 20,500 acre feet of treated water per year. The Company is obligated to pay the Capital Facilities Charge and the Treated Water Charge regardless of whether it can use the water in its operation, and is obligated for these charges even if the Agency cannot produce an adequate amount to

91

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

14 COMMITMENTS AND CONTINGENCIES (Continued)

supply the 20,500 acre feet in the year. (This agreement supersedes a prior agreement with Kern County Water Agency for the supply of 11,500 acre feet of water per year). Total annual expense in 2012 was $6,272, $6,129 in 2011, and $5,454 in 2010.

        Three other parties, including the City of Bakersfield, are also obligated to purchase a total of 32,500 acre feet per year under separate agreements with the Agency. Further, the Agency has the right to proportionally reduce the water supply provided to all of the participants if it cannot produce adequate supplies. The participation of all parties in the transaction for expansion of the Agency's facilities, including the Water Purification Plant, purchase of the water, and payment of interest and principal on the bonds being issued by the Agency to finance the transaction is required as a condition to the obligation of the Agency to proceed with expansion of the Agency's facilities. If any of the other parties does not use its allocation, that party is obligated to pay its contracted amount.

        The Agency has issued bonds to fund the project and uses the payments of the Capital Facilities Charges by the Company and the other contracted parties to meet the Agency's obligations to pay interest and repay principal on the bonds. If any of the parties were to default on making payments of the Capital Facilities Charge, then the other parties are obligated to pay for the defaulting party's share on a pro-rata basis. If there is a payment default by a party and the remaining parties have to make payments, they are also entitled to a pro-rata share of the defaulting party's water allocation.

        The Company expects to use all its entitled water in its operations every year. In addition, if the Company were to pay for and receive additional amounts of water due to a default of another participating party; the Company believes it could use this additional water in its operations without incurring substantial incremental cost increases. If additional treated water is available, all parties have an option to purchase this additional treated water, subject to the Agency's right to allocate the water among the parties.

        The total obligation of all parties, excluding the Company, is approximately $82.4 million to the Agency. Based on the credit worthiness of the other participants, which are government entities, it is believed to be highly unlikely that the Company would be required to assume any other parties' obligations under the contract due to their default. In the event of default by a party, the Company would receive entitlement to the additional water for assuming any obligation.

        Once the project is complete, the Company is obligated to pay a Capital Facilities Charge and charges related to treated water that together total $7,160 annually, which equates to $349 dollars per acre foot. Annual payments of $3,600 for the Capital Facilities Charge began when the Agency issued bonds to fund the project. Total treated water charge for 2012 was $2,583. Once the entire expansion project is completed the full annual payments will be $7,160 which will continue through the term of the agreement. As treated water is being delivered, the Company is also obligated for its portion of the operating costs; that portion is currently estimated to be $7 dollars per acre foot. The actual amount will vary due to variations from reimbursable operating cost estimates, inflation, and other changes in the cost structure. The Company's overall estimated cost of $349 dollars per acre foot is less than the estimated cost of procuring untreated water (assuming water rights could be obtained) and then providing treatment.

92

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

14 COMMITMENTS AND CONTINGENCIES (Continued)

        There are three capital leases, the most significant was the City of Hawthorne water system. In 2011, we entered into a 15-year capital lease agreement to operate the City of Hawthorne water system. The system, which is located near the Hermosa-Redondo district, serves about half of Hawthorne's population. The agreement required us to make an up-front $8,100 lease deposit to the city that is being amortized over the lease term. Additionally, annual lease payments of $940 are made to the city and shall be increased or decreased each year on July 1, by the same percentage that the rates charged to customers served by the water system increased or decreased, exclusive of pass-through increases or decreases in the cost of water, power, and city-imposed fees, compared to the rates in effect on July 1 of the prior year, provided, that in no event will the annual lease payment be less than $940. Under the lease we are responsible for all aspects of system operation and capital improvements, although title to the system and system improvements reside with the city. In exchange, we receive all revenue from the water system, which was $7,621, $7,506, and $7,547 in 2012, 2011, and 2010, respectively. At the end of the lease, the city is required to reimburse us for the unamortized value of capital improvements made during the term of the lease. The annual payments were $940 in 2012, $537 in 2011, and $116 in 2010.

Contingencies

Groundwater Contamination

        The Company has undertaken litigation against third parties to recover past and future costs related to ground water contamination in our service areas. The cost of litigation is expensed as incurred and any settlement is first offset against such costs. The Commission general policy require all proceeds from contamination litigation to be used first to pay transactional expenses, then to make ratepayers whole for water treatment costs to comply with the Commission's water quality standards. The Commission allows for a risk-based consideration of contamination proceeds which exceed the costs of the remediation described above and may result in some sharing of proceeds with the shareholder, determined on a case by case basis. The Commission has authorized various memorandum accounts that allow the Company to track significant litigation costs to request recovery of these costs in future filings and uses of proceeds to comply with Commission's general policy.

Other Legal Matters

        From time to time, the Company is involved in various disputes and litigation matters that arise in the ordinary course of business. The status of each significant matter is reviewed and assessed for potential financial exposure. If the potential loss from any claim or legal proceeding is considered probable and the amount of the range of loss can be estimated, a liability is accrued for the estimated loss in accordance with the accounting standards for contingencies. Legal proceedings are subject to uncertainties, and the outcomes are difficult to predict. Because of such uncertainties, accruals are based on the best information available at the time. While the outcome of these disputes and litigation matters cannot be predicted with any certainty, management does not believe when taking into account existing reserves the ultimate resolution of these matters will materially affect the Company's financial position, results of operations, or cash flows.

93

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

15 QUARTERLY FINANCIAL DATA (UNAUDITED)

        The Company's common stock is traded on the New York Stock Exchange under the symbol "CWT."

2012	First		Second		Third		Fourth
Operating revenue	$	116,749	$	143,552	$	178,135	$	121,530
Net operating income		6,607		19,622		36,361		11,253
Net income		1,085		12,965		29,772		5,006
Diluted earnings per share		0.03		0.31		0.71		0.12
Common stock market price range:
High		19.25		18.60		19.05		18.90
Low		17.67		17.14		17.93		16.84
Dividends paid per common share		0.1575		0.1575		0.1575		0.1575

2011	First		Second		Third		Fourth
Operating revenue	$	98,149	$	131,397	$	169,254	$	103,014
Net operating income		9,948		19,555		30,078		7,586
Net income		2,719		12,190		20,935		1,868
Diluted earnings per share		0.07		0.29		0.50		0.04
Common stock market price range:
High		19.18		19.16		19.37		19.20
Low		17.28		18.06		16.65		16.81
Dividends paid per common share		0.15375		0.15375		0.15375		0.15375

16 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS

        On April 17, 2009, Cal Water issued $100 million aggregate principal amount of 5.875% First Mortgage Bonds due 2019, and on November 17, 2010, Cal Water issued $100 million aggregate principal amount of 5.500% First Mortgage Bonds due 2040, all of which are fully and unconditionally guaranteed by California Water Service Group (Parent Company). The following tables present the condensed consolidating statements of income of California Water Service Group (Guarantor and Parent), Cal Water (issuer and 100% owned consolidated subsidiary of California Water Service Group) and other 100% owned subsidiaries of the Company for the years ended December 31, 2012, 2011 and 2010, the condensed consolidating statements of cash flows for the 12-months ended December 31, 2012, 2011, and 2010, and the condensed consolidating balance sheets as of December 31, 2012 and 2011.

94

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

16 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Continued)

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING BALANCE SHEET
As of December 31, 2012

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
ASSETS
Utility plant:
Utility plant	$	606		$	1,927,190		$	175,764		$	(7,197	)	$	2,096,363
Less accumulated depreciation and amortization		(108	)		(607,992	)		(32,710	)		1,503			(639,307	)
Net utility plant		498			1,319,198			143,054			(5,694	)		1,457,056
Current assets:
Cash and cash equivalents		1,470			34,609			2,711			—			38,790
Receivables		—			87,482			3,833			—			91,315
Receivables from affiliates		19,367			3,195			1,152			(23,714	)		—
Other current assets		—			15,535			924			—			16,459
Total current assets		20,837			140,821			8,620			(23,714	)		146,564
Other assets:
Regulatory assets		—			341,877			2,542			—			344,419
Investments in affiliates		492,188			—			—			(492,188	)		—
Long-term affiliate notes receivable		31,218			7,781			—			(38,999	)		—
Other assets		1,023			40,005			7,062			(205	)		47,885
Total other assets		524,429			389,663			9,604			(531,392	)		392,304
	$	545,764		$	1,849,682		$	161,278		$	(560,800	)	$	1,995,924
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stockholders' equity	$	473,712		$	442,923		$	54,774		$	(497,697	)	$	473,712
Affiliate long-term debt		7,781			—			31,218			(38,999	)		—
Long-term debt, less current maturities		—			431,433			3,034			—			434,467
Total capitalization		481,493			874,356			89,026			(536,696	)		908,179
Current liabilities:
Current maturities of long-term debt		—			46,104			679			—			46,783
Short-term borrowings		64,475			25,000			—			—			89,475
Payables to affiliates		77			1,152			22,485			(23,714	)		—
Accounts payable		—			41,352			5,847			—			47,199
Accrued expenses and other liabilities		298			58,293			1,019			—			59,610
Total current liabilities		64,850			171,901			30,030			(23,714	)		243,067
Unamortized investment tax credits		—			2,180			—			—			2,180
Deferred income taxes, net		(579	)		155,481			4,334			(390	)		158,846
Pension and postretirement benefits other than pensions		—			244,901			—			—			244,901
Regulatory and other liabilities		—			83,942			8,651			—			92,593
Advances for construction		—			186,753			831			—			187,584
Contributions in aid of construction		—			130,168			28,406			—			158,574
	$	545,764		$	1,849,682		$	161,278		$	(560,800	)	$	1,995,924

95

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

16 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Continued)

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING BALANCE SHEET
As of December 31, 2011

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
ASSETS
Utility plant:
Utility plant	$	324		$	1,808,568		$	158,688		$	(7,199	)	$	1,960,381
Less accumulated depreciation and amortization		(51	)		(551,345	)		(29,251	)		1,385			(579,262	)
Net utility plant		273			1,257,223			129,437			(5,814	)		1,381,119
Current assets:
Cash and cash equivalents		89			18,475			8,639			—			27,203
Receivables		158			76,227			(4,797	)		—			71,588
Receivables from affiliates		7,817			3,446			5			(11,268	)		—
Other current assets		—			14,225			872			—			15,097
Total current assets		8,064			112,373			4,719			(11,268	)		113,888
Other assets:
Regulatory assets		—			317,564			2,334			—			319,898
Investments in affiliates		466,515			—			—			(466,515	)		—
Long-term affiliate notes receivable		28,921			7,832			—			(36,753	)		—
Other assets		1,144			31,662			7,081			(205	)		39,682
Total other assets		496,580			357,058			9,415			(503,473	)		359,580
	$	504,917		$	1,726,654		$	143,571		$	(520,555	)	$	1,854,587
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stockholders' equity	$	449,829		$	417,810		$	54,377		$	(472,187	)	$	449,829
Affiliate long-term debt		7,832			—			28,921			(36,753	)		—
Long-term debt, less current maturities		—			477,998			3,634			—			481,632
Total capitalization		457,661			895,808			86,932			(508,940	)		931,461
Current liabilities:
Current maturities of long-term debt		—			5,851			682			—			6,533
Short-term borrowings		47,140			—			—			—			47,140
Payables to affiliates		52			190			11,026			(11,268	)		—
Accounts payable		—			47,568			4,010			—			51,578
Accrued expenses and other liabilities		625			46,462			(547	)		84			46,624
Total current liabilities		47,817			100,071			15,171			(11,184	)		151,875
Unamortized investment tax credits		—			2,254			—			—			2,254
Deferred income taxes, net		(561	)		113,925			3,435			(431	)		116,368
Pension and postretirement benefits other than pensions		—			232,110			—			—			232,110
Regulatory and other liabilities		—			71,034			8,016			—			79,050
Advances for construction		—			185,902			1,376			—			187,278
Contributions in aid of construction		—			125,550			28,641			—			154,191
	$	504,917		$	1,726,654		$	143,571		$	(520,555	)	$	1,854,587

96

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

16 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Continued)

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING STATEMENT OF INCOME
For the Year Ended December 31, 2012

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating revenue	$	—		$	527,449		$	32,517		$	—		$	559,966
Operating expenses:
Operations:
Purchased water		—			160,913			423			—			161,336
Purchased power		—			21,435			9,592			—			31,027
Pump taxes		—			10,336			—			—			10,336
Administrative and general		—			84,399			9,528			—			93,927
Other		—			70,864			6,744			(504	)		77,104
Maintenance		—			18,478			664			—			19,142
Depreciation and amortization		—			52,012			2,774			(118	)		54,668
Income taxes (benefits)		(583	)		18,992			(375	)		1,322			19,356
Taxes other than income taxes		—			16,630			2,597			—			19,227
Total operating expenses (income)		(583	)		454,059			31,947			700			486,123
Net operating income		583			73,390			570			(700	)		73,843
Other Income and Expenses:
Non-regulated revenue		1,919			15,204			2,420			(2,857	)		16,686
Non-regulated expense		—			(9,588	)		(1,965	)		—			(11,553	)
Gain on sale on non-utility property		—			81			—			3			84
Income tax benefit (expense) on other income and expense		(782	)		(2,321	)		(266	)		1,273			(2,096	)
Net other income (expense)		1,137			3,376			189			(1,581	)		3,121
Interest:
Interest expense		1,430			30,328			2,132			(2,353	)		31,537
Less: capitalized interest		—			(2,334	)		(1,067	)		—			(3,401	)
Net interest expense		1,430			27,994			1,065			(2,353	)		28,136
Equity earnings of subsidiaries		48,538			—			—			(48,538	)		—
Net income	$	48,828		$	48,772		$	(306	)	$	(48,466	)	$	48,828

97

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

16 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Continued)

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING STATEMENT OF INCOME
For the Year Ended December 31, 2011

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating revenue	$	—		$	472,150		$	29,664		$	—		$	501,814
Operating expenses:
Operations:
Purchased water		—			142,355			215			—			142,570
Purchased power		—			20,719			9,334			—			30,053
Pump taxes		—			8,764			366			—			9,130
Administrative and general		—			77,622			8,136			—			85,758
Other		—			47,800			7,401			(505	)		54,696
Maintenance		—			19,916			782			—			20,698
Depreciation and amortization		—			47,872			2,637			(124	)		50,385
Income taxes (benefits)		(580	)		23,727			(1,727	)		1,605			23,025
Taxes other than income taxes		—			15,908			2,424			—			18,332
Total operating expenses (income)		(580	)		404,683			29,568			976			434,647
Net operating income		580			67,467			96			(976	)		67,167
Other Income and Expenses:
Non-regulated revenue		2,248			12,972			4,322			(3,382	)		16,160
Non-regulated expense		—			(12,287	)		(3,535	)		—			(15,822	)
Gain on sale on non-utility property		—			62			—			—			62
Income tax benefit (expense) on other income and expense		(916	)		(304	)		(422	)		1,501			(141	)
Net other income (expense)		1,332			443			365			(1,881	)		259
Interest:
Interest expense		1,422			31,421			2,489			(2,877	)		32,455
Less: capitalized interest		—			(1,844	)		(897	)		—			(2,741	)
Net interest expense		1,422			29,577			1,592			(2,877	)		29,714
Equity earnings of subsidiaries		37,222			—			—			(37,222	)		—
Net income	$	37,712		$	38,333		$	(1,131	)	$	(37,202	)	$	37,712

98

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

16 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Continued)

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING STATEMENT OF INCOME
For the Year Ended December 31, 2010

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating revenue	$	—		$	430,988		$	29,411		$	—		$	460,399
Operating expenses:
Operations:
Purchased water		—			125,749			181			—			125,930
Purchased power		—			21,616			7,961			—			29,577
Pump taxes		—			8,017			583			—			8,600
Administrative and general		—			67,536			7,740			—			75,276
Other		—			49,356			7,667			(505	)		56,518
Maintenance		—			18,998			687			—			19,685
Depreciation and amortization		—			40,349			2,610			(131	)		42,828
Income taxes (benefits)		(843	)		23,812			(229	)		329			23,069
Taxes other than income taxes		—			14,904			2,199			—			17,103
Total operating expenses (income)		(843	)		370,337			29,399			(307	)		398,586
Net operating income		843			60,651			12			307			61,813
Other Income and Expenses:
Non-regulated revenue		1,220			10,064			6,670			(1,961	)		15,993
Non-regulated expense		—			(7,954	)		(4,358	)		—			(12,312	)
Gain on sale on non-utility property		—			22			—			—			22
Income tax benefit (expense) on other income and expense		(497	)		(869	)		(1,027	)		906			(1,487	)
Net other income (expense)		723			1,263			1,285			(1,055	)		2,216
Interest:
Interest expense		698			27,059			1,635			(1,456	)		27,936
Less: capitalized interest		—			(1,085	)		(478	)		—			(1,563	)
Net interest expense		698			25,974			1,157			(1,456	)		26,373
Equity earnings of subsidiaries		36,788			—			—			(36,788	)		—
Net income	$	37,656		$	35,940		$	140		$	(36,080	)	$	37,656

99

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

16 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Continued)

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
For the Year Ended December 31, 2012

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating activities:
Net income (loss)	$	48,828		$	48,772		$	(306	)	$	(48,466	)	$	48,828
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Equity earnings of subsidiaries		(48,538	)		—			—			48,538			—
Dividends received from affiliates		26,387			—			—			(26,387	)		—
Depreciation and amortization		56			54,040			2,888			(118	)		56,866
Change in value of life insurance contracts		—			(2,504	)		—			—			(2,504	)
Gain on sale of non-utility property		—			(81	)		—			(3	)		(84	)
Changes in deferred income taxes		—			34,133			—			—			34,133
Other changes in noncurrent assets and liabilities		1,544			(10,367	)		1,307			133			(7,383	)
Changes in operating assets and liabilities:
Other changes, net		(170	)		9,035			(6,723	)		(84	)		2,058
Net adjustments		(20,721	)		84,256			(2,528	)		22,079			83,086
Net cash provided by (used in) operating activities		28,107			133,028			(2,834	)		(26,387	)		131,914
Investing activities:
Utility plant expenditures		(281	)		(111,636	)		(15,761	)		(3	)		(127,681	)
Proceeds from sale of non-utility assets		—			82			—			3			85
Affiliate advances		(12,245	)		254			(853	)		12,844			—
Proceeds from affiliate loans		552			48			—			(600	)		—
Reduction of loans to affiliates		(5,675	)		—			—			5,675			—
Purchase of life insurance		—			(3,294	)		—			—			(3,294	)
Restricted cash decrease		—			1,959			—			—			1,959
Net cash (used in) investing activities		(17,649	)		(112,587	)		(16,614	)		17,919			(128,931	)
Financing Activities:
Short-term borrowings		18,335			76,000			—			—			94,335
Repayment of short-term borrowings		(1,000	)		(51,000	)		—			—			(52,000	)
Affiliate advances		23			962			11,859			(12,844	)		—
Proceeds from affiliates long-term borrowings		—			—			5,675			(5,675	)		—
Reduction of affiliate long-term borrowings		(48	)		—			(552	)		600			—
Proceeds from long-term debt		—			—			124			—			124
Retirement of long-term debt		—			(6,310	)		(727	)		—			(7,037	)
Advances and contributions in aid for construction		—			6,883			83			—			6,966
Refunds of advances for construction		—			(7,275	)		(122	)		—			(7,397	)
Dividends paid to non-affiliates		(26,387	)		—			—			—			(26,387	)
Dividends paid to affiliates		—			(23,567	)		(2,820	)		26,387			—
Net cash (used in) provided by financing activities		(9,077	)		(4,307	)		13,520			8,468			8,604
Change in cash and cash equivalents		1,381			16,134			(5,928	)		—			11,587
Cash and cash equivalents at beginning of year		89			18,475			8,639			—			27,203
Cash and cash equivalents at end of year	$	1,470		$	34,609		$	2,711		$	—		$	38,790

100

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

16 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Continued)

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
For the Year Ended December 31, 2011

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating activities:
Net income (loss)	$	37,712		$	38,333		$	(1,131	)	$	(37,202	)	$	37,712
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Equity earnings of subsidiaries		(37,222	)		—			—			37,222			—
Dividends received from affiliates		25,674			—			—			(25,674	)		—
Depreciation and amortization		51			49,283			2,771			(124	)		51,981
Change in value of life insurance contracts		—			1,876			—			—			1,876
Gain on sale of non-utility property		—			(62	)		—			—			(62	)
Section 481 adjustment		—			2,723			—			—			2,723
Other changes in noncurrent assets and liabilities		1,001			(45	)		684			53			1,693
Changes in operating assets and liabilities:
Other changes, net		582			11,662			3,054			51			15,349
Net adjustments		(9,914	)		65,437			6,509			11,528			73,560
Net cash provided by operating activities		27,798			103,770			5,378			(25,674	)		111,272
Investing activities:
Utility plant expenditures		—			(98,410	)		(20,136	)		—			(118,546	)
Proceeds from sale of non-utility assets		—			64			—			—			64
Affiliate advances		(25,495	)		1,597			—			23,898			—
Reduction of loans to affiliates		962			45			2,000			(3,007	)		—
Purchase of life insurance		—			(1,744	)		—			—			(1,744	)
Restricted cash increase		—			(3,042	)		—			—			(3,042	)
Net cash (used in) investing activities		(24,533	)		(101,490	)		(18,136	)		20,891			(123,268	)
Financing Activities:
Short-term borrowings		23,390			—			—			—			23,390
Affiliate advances		—			—			23,898			(23,898	)		—
Reduction of affiliate long-term borrowings		(2,045	)		—			(962	)		3,007			—
Proceeds from long-term debt, net of issuance cost of $1,857		—			—			178			—			178
Retirement of long-term debt		—			(2,279	)		(684	)		—			(2,963	)
Advances and contributions in aid for construction		—			7,082			149			—			7,231
Refunds of advances for construction		—			(6,129	)		(76	)		—			(6,205	)
Dividends paid to non-affiliates		(25,674	)		—			—			—			(25,674	)
Dividends paid to affiliates		—			(22,925	)		(2,749	)		25,674			—
Issuance of common stock		965			—			—			—			965
Net cash (used in) provided by financing activities		(3,364	)		(24,251	)		19,754			4,783			(3,078	)
Change in cash and cash equivalents		(99	)		(21,971	)		6,996			—			(15,074	)
Cash and cash equivalents at beginning of year		188			40,446			1,643			—			42,277
Cash and cash equivalents at end of year	$	89		$	18,475		$	8,639		$	—		$	27,203

101

CALIFORNIA WATER SERVICE GROUP

Notes to Consolidated Financial Statements (Continued)

December 31, 2012, 2011, and 2010

Amounts in thousands, except share data

16 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Continued)

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
For the Year Ended December 31, 2010

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating activities:
Net income	$	37,656		$	35,940		$	140		$	(36,080	)	$	37,656
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Equity earnings of subsidiaries		(36,788	)		—			—			36,788			—
Dividends received from affiliates		24,753			—			—			(24,753	)		—
Depreciation and amortization		—			42,680			2,716			(131	)		45,265
Other changes in noncurrent assets and liabilities		229			(880	)		1,089			(598	)		(160	)
Change in value of life insurance contracts		—			(2,641	)		—			—			(2,641	)
Gain on sale of non-utility property		—			(22	)		—			—			(22	)
Changes in operating assets and liabilities:
Other changes, net		(1,054	)		(997	)		(2,558	)		21			(4,588	)
Net adjustments		(12,860	)		38,140			1,247			11,327			37,854
Net cash provided by operating activities		24,796			74,080			1,387			(24,753	)		75,510
Investing activities:
Utility plant expenditures		(324	)		(108,990	)		(14,612	)		—			(123,926	)
Proceeds from sale of non-utility assets		—			34			—			—			34
Affiliate advances		(14,579	)		85			—			14,494			—
Reduction of loans to affiliates		1,854			—			—			(1,854	)		—
Purchase of life insurance		—			(1,891	)		—			—			(1,891	)
Restricted cash decrease		—			3,169			—			—			3,169
Net cash (used in) investing activities		(13,049	)		(107,593	)		(14,612	)		12,640			(122,614	)
Financing Activities:
Short-term borrowings		16,750			69,000			—			—			85,750
Repayment of short-term borrowings		(5,000	)		(69,000	)		—			—			(74,000	)
Affiliate advances		—			—			14,494			(14,494	)		—
Reduction of affiliate note payable		—			—			(1,854	)		1,854			—
Proceeds from long-term debt, net of issuance cost of $1,857		—			103,947			2,226			—			106,173
Retirement of long-term debt		—			(12,212	)		(1,480	)		—			(13,692	)
Advances and contributions in aid for construction		—			4,962			351			—			5,313
Refunds of advances for construction		—			(6,104	)		(84	)		—			(6,188	)
Dividends paid to non-affiliates		(24,753	)		—			—			—			(24,753	)
Dividends paid to affiliates		—			(22,634	)		(2,119	)		24,753			—
Issuance of common stock		912			—			—			—			912
Net cash (used in) provided by financing activities		(12,091	)		67,959			11,534			12,113			79,515
Change in cash and cash equivalents		(344	)		34,446			(1,691	)		—			32,411
Cash and cash equivalents at beginning of year		532			6,000			3,334			—			9,866
Cash and cash equivalents at end of year	$	188		$	40,446		$	1,643		$	—		$	42,277

102

Item 9.    Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.

        None

Item 9A.    Controls and Procedures

Management's Evaluation of Disclosure Controls and Procedures

        We maintain disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended) that are designed to ensure that information required to be disclosed in our reports filed or submitted under the Securities Exchange Act of 1934, as amended, is recorded, processed, summarized and reported, within the time periods specified in the Securities and Exchange Commission's rules and forms, and that such information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow for timely decisions regarding required disclosure.

        In designing and evaluating the disclosure controls and procedures, management, including the Chief Executive Officer and Chief Financial Officer, recognized that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives, and management is required to apply its judgment in evaluating the cost-benefit relationship of possible controls and procedures. Accordingly, our disclosure controls and procedures have been designed to provide reasonable assurance of achieving their objectives.

        Our management, with the participation of our Chief Executive Officer and our Chief Financial Officer, evaluated the effectiveness of our disclosure controls and procedures as of December 31, 2012. Based on that evaluation, we concluded that our disclosure controls and procedures were effective at the reasonable assurance level.

        There was no change in our internal control over financial reporting during the quarter ended December 31, 2012, that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

Management's Report on Internal Control over Financial Reporting

        Management is responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rule 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended). Management assessed the effectiveness of our internal control over financial reporting as of December 31, 2012. In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission ("COSO") in "Internal Control—Integrated Framework." Management has concluded that, as of December 31, 2012, our internal control over financial reporting is effective based on these criteria. Our independent registered public accounting firm, Deloitte & Touche LLP, has audited the effectiveness of our internal control over financial reporting as of December 31, 2012, as stated in their report, which is included herein.

Item 9B.    Other Information

        None.

103

PART III

Item 10.    Directors and Executive Officers and Corporate Governance

        The information required by this Item as to directors of the Company and the Company's Audit Committee is contained in the sections captioned "Board Structure" and "Proposal No. 1—Election of Directors" of the 2013 Proxy Statement, and is incorporated herein by reference.

        Information required by this Item regarding executive officers is included in a separate section captioned "Executive Officers of the Registrant" contained in Part I of this annual report.

        Information required by this Item as to our Code of Ethics is contained in the section captioned "Other Matters—Code of Ethics" of the 2013 Proxy Statement, and is incorporated herein by reference.

        We have adopted code of ethics that applies to all of our directors, officers, and employees. Our Code of Ethics is posted on our corporate governance website located at http://www.calwatergroup.com. In addition, amendments to the Code of Ethics and any grant of a waiver from a provision of the Code of Ethics requiring disclosure under applicable SEC and NYSE rules will be disclosed at the same location as the Code of Ethics on our corporate governance website located at http://www.calwatergroup.com.

        Information required to be disclosed by this Item as to compliance with Section 16(a) filing requirements is contained in the section captioned "Stock Ownership of Management and Certain Beneficial Owners" of the 2013 Proxy Statement, and is incorporated herein by reference.

Item 11.    Executive Compensation

        The information required by this Item is contained under the captions "Compensation Discussion and Analysis," "Report of the Organization and Compensation Committee of the Board of Directors on Executive Compensation," and "Organization and Compensation Committee Interlocks and Insider Participation" of the 2013 Proxy Statement and is incorporated herein by reference.

Item 12.    Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

        The information required by this Item regarding security ownership of certain beneficial owners and management is contained in the section captioned "Stock Ownership of Management and Certain Beneficial Owners" of the 2013 Proxy Statement and is incorporated herein by reference.

        Certain information required by this Item regarding our equity compensation plans is included in a separate section captioned "Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities" contained in Part I of this annual report.

104

        The following table represents securities authorized to be issued under our equity compensation plans:

Plan Category	Number of Securities to be Issued Upon Exercise of Outstanding Options, Warrants and Rights (a)		Weighted-Average Exercise Price of Outstanding Options, Warrants and Rights		Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans (Excluding Securities Reflected in Column (a))
Equity compensation plans approved by security holders		333,856	$	19.13		1,301,656
Equity compensation plans not approved by security holders		-0-		-0-		-0-
Total		333,856	$	19.13		1,301,656

Item 13.    Certain Relationships and Related Transactions and Director Independence

        The information required by this Item is contained in the sections captioned "Certain Related Persons Transactions" and "Board Structure" of the 2013 Proxy Statement and is incorporated herein by reference.

Item 14.    Principal Accountant Fees and Services

        The information required by this Item is contained in the section captioned "Report of the Audit Committee" and "Relationship with the Independent Registered Public Accounting Firm" of the 2013 Proxy Statement and is incorporated herein by reference.

PART IV

Item 15.    Exhibits, Financial Statement Schedules

(a)

As part of this Form 10-K, the following documents are being filed:

        1.     Financial Statement:    See "Index to Consolidated Financial Statements" in Part II, Item 8 of this Form 10-K.

        2.     Financial Statement Schedules:    No financial statement schedules are being included since the information otherwise required is included in the financial statements and the notes thereto.

        3.     Exhibits:    The exhibits listed in the accompanying index to exhibits are filed or incorporated by reference.

105

SIGNATURES

        Pursuant to the requirements of Section 13 or 15(d) 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

	CALIFORNIA WATER SERVICE GROUP
	By	/s/ PETER C. NELSON PETER C. NELSON, Chairman, Board of Directors and Chief Executive Officer
Date: February 28, 2013

        Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

/s/ PETER C. NELSON PETER C. NELSON	Chairman, Board of Directors and Chief Executive Officer, Principal Executive Officer	Date: February 28, 2013
/s/ DOUGLAS M. BROWN DOUGLAS M. BROWN	Member, Board of Directors	Date: February 28, 2013
/s/ EDWIN A. GUILES EDWIN A. GUILES	Member, Board of Directors	Date: February 28, 2013
/s/ BONNIE G. HILL BONNIE G. HILL	Member, Board of Directors	Date: February 28, 2013
/s/ THOMAS M. KRUMMEL THOMAS M. KRUMMEL, M.D.	Member, Board of Directors	Date: February 28, 2013
/s/ RICHARD P. MAGNUSON RICHARD P. MAGNUSON	Member, Board of Directors	Date: February 28, 2013
/s/ LINDA R. MEIER LINDA R. MEIER	Member, Board of Directors	Date: February 28, 2013

106

/s/ LESTER A. SNOW LESTER A. SNOW	Member, Board of Directors	Date: February 28, 2013
/s/ GEORGE A. VERA GEORGE A. VERA	Member, Board of Directors	Date: February 28, 2013
/s/ MARTIN A. KROPELNICKI MARTIN A. KROPELNICKI	President and Chief Operating Officer,	Date: February 28, 2013
/s/ THOMAS F. SMEGAL III THOMAS F. SMEGAL III	Chief Financial Officer and Treasurer; Principal Financial Officer	Date: February 28, 2013
/s/ DAVID B. HEALEY DAVID B. HEALEY	Corporate Controller, Assistant Secretary and Assistant Treasurer; Principal Accounting Officer	Date: February 28, 2013

107

EXHIBIT INDEX

        Unless filed with this Form 10-K, the documents listed are incorporated by reference to the filings referred to:

Exhibit Number
	3.1	Certificate of Incorporation of California Water Service Group (Exhibit 3.1 to the Quarterly Report on Form 10-Q filed August 9, 2006)
	3.2	Certificate of Amendment to Certificate of Incorporation of California Water Service Group (Exhibit 3.1 to the Current Report on Form 8-K filed June 10, 2011)
	3.3	Restated Bylaws of California Water Service Group as amended on October 26, 2011 (Exhibit 3.2 to Current Report on Form 8-K filed October 26, 2011)
	4.1	[reserved]
	4.2	Certificate of Designations regarding Series D Participating Preferred Stock, as filed with Delaware Secretary of State on September 16, 1999 (Exhibit 4.2 to Annual Report on Form 10-K for the year ended December 31, 2003)
	4.3	Thirty-Ninth Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee (Exhibit 4.1 to Current Report on Form 8-K filed April 21, 2009)
	4.4	Fortieth Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 9.86% First Mortgage Bonds due 2020, Series CC. (Exhibit 4.2 to Current Report on Form 8-K filed April 21, 2009)
	4.5	Forty-First Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 5.875% First Mortgage Bonds due 2019, Series LL. (Exhibit 4.3 to Current Report on Form 8-K filed April 21, 2009)
	4.6	Forty-Second Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 6.94% First Mortgage Bonds due 2012, Series KK. (Exhibit 4.4 to Current Report on Form 8-K filed April 21, 2009)
	4.7	Forty-Third Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 7.28% First Mortgage Bonds due 2025, Series AAA. (Exhibit 4.5 to Current Report on Form 8-K filed April 21, 2009)
	4.8	Forty-Fourth Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 6.77% First Mortgage Bonds due 2028, Series BBB. (Exhibit 4.6 to Current Report on Form 8-K filed April 21, 2009)
	4.9	Forty-Fifth Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 8.15% First Mortgage Bonds due 2030, Series CCC. (Exhibit 4.7 to Current Report on Form 8-K filed April 21, 2009)

108

Exhibit Number
	4.10	Forty-Sixth Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 7.13% First Mortgage Bonds due 2031, Series DDD. (Exhibit 4.8 to Current Report on Form 8-K filed April 21, 2009)
	4.11	Forty-Seventh Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 7.11% First Mortgage Bonds due 2032, Series EEE. (Exhibit 4.9 to Current Report on Form 8-K filed April 21, 2009)
	4.12	Forty-Eighth Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 5.90% First Mortgage Bonds due 2017, Series FFF. (Exhibit 4.10 to Current Report on Form 8-K filed April 21, 2009)
	4.13	Forty-Ninth Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 5.29% First Mortgage Bonds due 2022, Series GGG. (Exhibit 4.11 to Current Report on Form 8-K filed April 21, 2009)
	4.14	Fiftieth Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 5.29% First Mortgage Bonds due 2022, Series HHH. (Exhibit 4.12 to Current Report on Form 8-K filed April 21, 2009)
	4.15	Fifty-First Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 5.54% First Mortgage Bonds due 2023, Series III. (Exhibit 4.13 to Current Report on Form 8-K filed April 21, 2009)
	4.16	Fifty-Second Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 5.44% First Mortgage Bonds due 2018, Series JJJ. (Exhibit 4.14 to Current Report on Form 8-K filed April 21, 2009)
	4.17	Fifty-Third Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 4.58% First Mortgage Bonds due 2010, Series KKK. (Exhibit 4.15 to Current Report on Form 8-K filed April 21, 2009)
	4.18	Fifty-Fourth Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 5.48% First Mortgage Bonds due 2018, Series LLL. (Exhibit 4.16 to Current Report on Form 8-K filed April 21, 2009)
	4.19	Fifty-Fifth Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 5.52% First Mortgage Bonds due 2013, Series MMM. (Exhibit 4.17 to Current Report on Form 8-K filed April 21, 2009)
	4.20	Fifty-Sixth Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 5.55% First Mortgage Bonds due 2013, Series NNN. (Exhibit 4.18 to Current Report on Form 8-K filed April 21, 2009)

109

Exhibit Number
	4.21	Fifty-Seventh Supplemental Indenture dated as of April 17, 2009, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 6.02% First Mortgage Bonds due 2031, Series OOO. (Exhibit 4.19 to Current Report on Form 8-K filed April 21, 2009)
	4.22	Fifty-Eighth Supplemental Indenture dated as of November 22, 2010, between California Water Service Company and U.S. Bank National Association, as Trustee, covering 5.50% First Mortgage Bonds due 2040, Series PPP. (Exhibit 4.1 to Current Report on form 8-K filed November 22, 2010).
	10.1	Water Supply Contract between Cal Water and County of Butte relating to Cal Water's Oroville District; Water Supply Contract between Cal Water and the Kern County Water Agency relating to Cal Water's Bakersfield District; Water Supply Contract between Cal Water and Stockton East Water District relating to Cal Water's Stockton District. (Exhibits 5(g), 5(h), 5(i), 5(j), Registration Statement No. 2-53678, which exhibits are incorporated by reference to Annual Report on Form 10-K for the year ended December 31, 1974)
	10.2	Water Supply Contract between the City and County of San Francisco and wholesale customers in Alameda County, San Mateo County and Santa Clara County for a term of twenty-five years beginning on July 1, 2009 and ending on June 30, 2034. The agreement was dated June 24, 2009. Water Supply Contract dated July 1, 2009 between the City and County of San Francisco and California Water Service Company to provide water to Bear Gulch and Bayshore service areas for a term of twenty-five years beginning July 1, 2009 and ending June 30, 2034. (Exhibit 10.3 and 10.4 to Quarterly Report on Form 10-Q for the quarter ending September 30, 2009).
	10.3	Water Supply Contract dated January 27, 1981, between Cal Water and the Santa Clara Valley Water District relating to Cal Water's Los Altos District (Exhibit 10.3 to Annual Report on Form 10-K for the year ended December 31, 1992)
	10.4	Amendments No. 3, 6 and 7 and Amendment dated June 17, 1980, to Water Supply Contract between Cal Water and the County of Butte relating to Cal Water's Oroville District. (Exhibit 10.5 to Annual Report on Form 10-K for the year ended December 31, 1992)
	10.5	Amendment dated May 31, 1977, to Water Supply Contract between Cal Water and Stockton East Water District relating to Cal Water's Stockton District. (Exhibit 10.6 to Annual Report on Form 10-K for the year ended December 31, 1992)
	10.6	Second Amended Contract dated September 25, 1987, among Stockton East Water District, California Water Service Company, the City of Stockton, the Lincoln Village Maintenance District, and the Colonial Heights Maintenance District Providing for the Sale of Treated Water. (Exhibit 10.7 to Annual Report on Form 10-K for the year ended December 31, 1987)
	10.7	Water Supply Contract dated April 19, 1927, and Supplemental Agreement dated June 5, 1953, between Cal Water and Pacific Gas and Electric Company relating to Cal Water's Oroville District. (Exhibit 10.9 to Annual Report on Form 10-K for the year ended December 31, 1992)
	10.8	[reserved]
	10.9	[reserved]
	10.10	Agreement between the City of Hawthorne and California Water Service Company for the 15-year lease of the City's water system. (Exhibit 10.17 to Quarterly Report on Form 10-Q for the quarter ended March 31, 1996)

110

Exhibit Number
	10.11	Water Supply Agreement dated September 25, 1996, between the City of Bakersfield and California Water Service Company. (Exhibit 10.18 to Quarterly Report on Form 10-Q for the quarter ended September 30, 1996)
	10.12	Water Supply Contract dated November 16, 1994, between California Water Service Company and Alameda County Flood Control and Water Conservation District relating to Cal Water's Livermore District (Exhibit 10.15 to Annual Report on Form 10-K for the year ended December 31, 1994)
	10.13	[reserved]
	10.14	California Water Service Group Directors' Retirement Plan (As amended and restated on February 22, 2006) (Exhibit 10.14 to the Annual Report on Form 10-K for the year ended December 31, 2005)
	10.15	[reserved]
	10.16	Amended and Restated Credit Agreement dated as of June 29, 2011 among California Water Service Group and certain of its subsidiaries from time to time party thereto, as borrowers, Bank of America, N.A., as administrative agent, swing line lender and letter of credit issuer, Merrill Lynch, Pierce, Fenner & Smith Incorporated, as sole lead arranger and sole book manager, CoBank, ACB, as syndication agent, and Wells Fargo Bank, National Association, Bank of China, Los Angeles Branch, and U.S. Bank National Association, as co-documentation agents, and the other lender parties thereto.(Exhibit 10.1 to the Current Report on Form 8-K of the registrant dated July 1, 2011).
	10.17	Amended and Restated Credit Agreement dated as of June 29, 2011 among California Water Service Company, as borrower, Bank of America, N.A., as administrative agent, swing line lender and letter of credit issuer, Merrill Lynch, Pierce, Fenner & Smith Incorporated, as sole lead arranger and sole book manager, CoBank, ACB, as syndication agent, Wells Fargo Bank, National Association, Bank of China, Los Angeles Branch, and U.S. Bank National Association, as co-documentation agents, and the other lender parties thereto (Exhibit 10.2 to the Current Report on Form 8-K of the registrant dated July 1, 2011).
	10.18	Executive Severance Plan (Exhibit 10.24 to Annual Report on Form 10-K for the year ended December 31, 1998)*
	10.19	California Water Service Group Long-Term Incentive Plan (filed as Appendix A of the California Water Service Group proxy statement dated March 17, 2000)*
	10.20	California Water Service Group Deferred Compensation Plan effective January 1, 2001 (Exhibit 10.22 to Annual Report on Form 10-K for the year ended December 31, 2000)*
	10.21	California Water Service Company Supplemental Executive Retirement Plan effective January 1, 2001 (Exhibit 10.23 to Annual Report on Form 10-K for the year ended December 31, 2000)*
	10.22	Amendment No. 1 to California Water Service Company Supplemental Executive Retirement Plan effective January 1, 2001 (Exhibit 10.22 to Quarterly Report on Form 10-Q for the quarter ended September 30, 2004)*
	10.23	[reserved]
	10.24	Water Supply Contract 99-73 between the City of Bakersfield and California Water Service Company, dated March 31, 1999 (Exhibit 10.25 to Quarterly Report on Form 10-Q for the quarter ended September 30, 2003)

111

Exhibit Number
	10.25	Amendment No. 1 to Water Supply Contract between the City of Bakersfield and California Water Service Company, dated October 3, 2001 (Exhibit 10.26 to Quarterly Report on Form 10-Q for the quarter ended September 30, 2003)
	10.26	[reserved]
	10.27	Amendment No. 2 to California Water Service Company Supplemental Executive Retirement Plan effective January 1, 2001 (Exhibit 10.27 to Quarterly Report on Form 10-Q for the quarter ended September 30, 2004)*
	10.28	[reserved]
	10.29	[reserved]
	10.30	California Water Service Group Equity Incentive Plan (filed as Appendix B of the California Water Service Group proxy statement dated March 25, 2005, for its Annual Meeting of Stockholders to be held on April 27, 2005, as filed with the SEC on March 22, 2005 (File No. 1-13883))*
	10.31	The registrant's policy on option repricing under its Equity Incentive Plan (incorporated by reference to Item 8.01 Other Events in the registrant's Current Report on Form 8-K dated April 7, 2005)*
	10.32	Water Supply Contract dated September 21, 2005, between Cal Water and the Kern County Water Agency. (Exhibit 10.1 to Current Report on Form 8-K filed on September 21, 2005)
	10.33	Separation Agreement between California Water Service Group and Richard D. Nye. (Exhibit 10 to Current Report on Form 8-K filed on December 22, 2005)*
	10.34	Form of Stock Appreciation Right Grant Notice under the California Water Service Group Equity Incentive Plan. (Exhibit 10.34 to the Annual Report on Form 10-K for the year ended December 31, 2005)
	10.35	Form of Stock Appreciation Right Agreement under the California Water Service Group Equity Incentive Plan with Notice of Exercise. (Exhibit 10.35 to the Annual Report on Form 10-K for the year ended December 31, 2005)
	10.36	Form of Restricted Stock Award Grant Notice under the California Water Service Group Equity Incentive Plan. (Exhibit 10.36 to the Annual Report on Form 10-K for the year ended December 31, 2005)
	10.37	[reserved]
	10.38	Form of Restricted Stock Award Agreement under the California Water Service Group Equity Incentive Plan with Assignment Separate From Certificate and Joint Escrow Instructions. (Exhibit 10.38 to the Annual Report on Form 10-K for the year ended December 31, 2005)
	10.39	Form of Stock Option Grant Notice for outside director under the California Water Service Group Equity Incentive Plan. (Exhibit 10.39 to the Annual Report on Form 10-K for the year ended December 31, 2005)
	10.40	Form of Stock Option Grant Notice under the California Water Service Group Equity Incentive Plan. (Exhibit 10.40 to the Annual Report on Form 10-K for the year ended December 31, 2005)

112

Exhibit Number
	10.41	Form of Stock Option Agreement (Incentive Stock Option or Nonstatutory Stock Option) under the California Water Service Group Equity Incentive Plan with Notice of Exercise. (Exhibit 10.41 to the Annual Report on Form 10-K for the year ended December 31, 2005)
	10.42	Offer Letter between the registrant and Martin A. Kropelnicki, dated February 15, 2006 (incorporated by reference to Exhibit 10.1 to Amendment No. 1 to Current Report on Form 8-K of the registrant, dated February 22, 2006)
	10.43	Underwriting Agreement between California Water Service Group and Robert W. Baird & Co. Incorporated, as representative of the underwriters, October 5, 2006 (incorporated by reference to Exhibit 1.1 to Current Report on Form 8-K filed on October 6, 2006)
	10.44	Form of Indemnification Agreement to be entered between California Water Service Group and its directors and officers. (Exhibit 10.44 to the Annual Report on Form 10-K for the year ended December 31, 2006)
	12.1	Computation of Ratios of Earnings to Fixed Charges
	21.	Subsidiaries of the Registrant
	23.1	Consent of Independent Registered Public Accounting Firm
	31.1	Chief Executive Officer certification of financial statements pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
	31.2	Chief Financial Officer certification of financial statements pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
	32.	Chief Executive Officer and Chief Financial Officer Certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
	101.INS	XBRL Instance Document
	101.SCH	XBRL Taxonomy Extension Schema
	101.CAL	XBRL Taxonomy Extension Calcuation Linkbase
	101.DEF	XBRL Taxonomy Extension Definition Linkbase Document
	101.LAB	XBRL Taxonomy Extension Label Linkbase
	101.PRE	XBRL Taxonomy Extension Presentation Linkbase

*

Management contract or compensatory plan or arrangement

113

EX-12.1

Exhibit 12.1

California Water Service Group
Computation of Ratios of Earnings to Fixed Charges
(In thousands except ratios)

	Year ended December 31,
	2012			2011			2010			2009			2008
Earnings:
Income before Income Tax Expense	$	70,279		$	60,878		$	62,211		$	67,916		$	63,936
Fixed Charges Interest Expense		32,354			32,455			27,936			24,394			20,591
Capitalized Interest		(3,401	)		(2,741	)		(1,563	)		(3,081	)		(3,411	)
Total	$	99,232		$	90,592		$	88,584		$	89,229		$	81,116
Fixed Charges:
Interest Expensed & Capitalized, & amortization of capitalized expense related to indebtedness	$	32,072		$	32,455		$	27,936		$	24,394		$	20,591
Estimated Interest Component of Rent Expense		282			474			338			329			237
Total	$	32,354		$	32,929		$	28,274		$	24,723		$	20,828
Ratio of Earnings to Fixed Charges		3.07			2.75			3.13			3.61			3.89

EX-21

Exhibit 21

Subsidiaries of the Registrant

Subsidiary Name	State of Incorporation	Business Name
California Water Service Company	California	California Water Service Company
CWS Utility Services	California	CWS Utility Services
New Mexico Water Service Company	New Mexico	New Mexico Water Service Company
Washington Water Service Company	Washington	Washington Water Service Company
Hawaii Water Service Company, Inc.	Hawaii	Hawaii Water Service Company
HWS Utility Services LLC	Hawaii	HWS Utility Services

EX-23.1

Exhibit 23.1

Consent of Independent Registered Public Accounting Firm

        We consent to the incorporation by reference in Registration Statements No. 333-158484 on Form S-3 and No. 333-60810 and 333-127495 on Form S-8 of our report dated February 28, 2013, relating to the consolidated financial statements of California Water Service Group and the effectiveness of California Water Service Group's internal control over financial reporting, appearing in this Annual Report on Form 10-K of California Water Service Group for the year ended December 31, 2012.

/s/ Deloitte & Touche LLP

San Francisco, California
February 28, 2013

EX-31.1

Exhibit 31.1

UNITED STATES SECURITIES AND EXCHANGE COMMISSION
CERTIFICATION

I, Peter C. Nelson, certify that:

1.

I have reviewed this annual report on Form 10-K of California Water Service Group;

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(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(c)) 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; and

5.

The registrant's other certifying officer(s) 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 the registrant's board of directors (or persons performing the equivalent functions):

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 control over financial reporting.

Date: February 28, 2013 By: /s/ PETER C. NELSON
Peter C. Nelson
Chief Executive Officer

EX-31.2

Exhibit 31.2

UNITED STATES SECURITIES AND EXCHANGE COMMISSION
CERTIFICATION

I, Thomas F. Smegal, certify that:

1.

I have reviewed this annual report on Form 10-K of California Water Service Group;

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(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(c)) 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; and

5.

The registrant's other certifying officer(s) 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 the registrant's board of directors (or persons performing the equivalent functions):

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 control over financial reporting.

Date: February 28, 2013 By: /s/ THOMAS F. SMEGAL III
Thomas F. Smegal III
Chief Financial Officer and Treasurer

EX-32

Exhibit 32

CERTIFICATION OF CEO AND CFO
PURSUANT TO 18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO SECTION 906
OF THE SARBANES-OXLEY ACT OF 2002

        Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, each of the undersigned hereby certifies, in his capacity as an officer of California Water Service Group, that the Annual Report of California Water Service Group on Form 10-K for the period ended December 31, 2012, as filed with the Securities and Exchange Commission on the date hereof (the "Annual Report"), fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended, and that the information contained in the Annual Report fairly presents, in all material respects, the financial condition and results of operations of California Water Service Group.

Date: February 28, 2013	By:	/s/ PETER C. NELSON PETER C. NELSON Chief Executive Officer California Water Service Group
Date: February 28, 2013	By:	/s/ THOMAS F. SMEGAL III THOMAS F. SMEGAL III Chief Financial Officer California Water Service Group

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details 2) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Non-Regulated Revenue
Maximum project completion period (in months)	3
Allowance for doubtful accounts
Activities in the allowance for doubtful accounts
Beginning Balance	$ 669	$ 804	$ 847
Provision for uncollectible accounts	1,548	1,250	1,500
Net write off of uncollectible accounts	(1,503)	(1,385)	(1,543)
Ending Balance	$ 714	$ 669	$ 804

XML

INCOME TAXES (Details 3) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Deferred tax assets:
Developer deposits for extension agreements and contributions in aid of construction	$ 44,530	$ 45,587
Net operating loss	8,437	1,015
Other	3,607	3,449
Total deferred tax assets	56,574	50,051
Deferred tax liabilities:
Utility plant, principally due to depreciation differences	207,642	155,916
WRAM/MCBA balancing accounts	19,533	17,393
Other	3,245	3,645
Total deferred tax liabilities	230,420	176,954
Net deferred tax liabilities	173,846	126,903
Current portion of deferred income tax	15,000	10,535
Reconciliation of the changes in unrecognized tax benefits
Balance at beginning of year	831		831
Lapse of statute of limitations	(831)
Balance at end of year			831
Total amount of penalties and interest accrued	$ (114)	$ 114	$ 114

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COMMON STOCKHOLDERS' EQUITY (Details)	Dec. 31, 2012	Dec. 31, 2011
COMMON STOCKHOLDERS' EQUITY
Common stock, issued (in shares)	41,908,218	41,817,218

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EMPLOYEE BENEFIT PLANS (Details) (USD $)	12 Months Ended									12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2012 Pension plans	Dec. 31, 2011 Pension plans	Dec. 31, 2010 Pension plans	Dec. 31, 2012 Unfunded supplemental executive retirement plan	Dec. 31, 2011 Unfunded supplemental executive retirement plan	Dec. 31, 2012 Other Benefits Y	Dec. 31, 2011 Other Benefits	Dec. 31, 2010 Other Benefits	Dec. 31, 2006 Other Benefits
Savings Plan
Maximum participants' contribution as a percentage of pre-tax compensation	20.00%
Employer's matching contribution for each dollar contributed by the employee	$ 0.75	$ 0.75	$ 0.75	$ 0.50
Maximum employer contribution as a percentage of base salary	6.00%	6.00%	6.00%	4.00%
Company contributions	4,029,000	3,499,000	3,232,000
Pension plan and other postretirement benefits
Accumulated benefit obligations					307,197,000	266,496,000		31,696,000	26,060,000
Fair value of pension plan assets					202,947,000	155,749,000	139,034,000			37,408,000	26,978,000	21,178,000
Expected future benefit payments
2013					6,189,000					1,398,000
2014					7,547,000					1,592,000
2015					8,770,000					1,819,000
2016					10,090,000					1,998,000
2017					11,577,000					2,196,000
2018-2022					81,916,000
Threshold retirement age for participation in plan on payment of a premium (in years)										58
Net periodic benefit cost					33,462,000	27,834,000	24,773,000			8,131,000	6,291,000	4,782,000
Regulatory asset related to underfunded postretirement benefit expense													9,790,000
Medicare Part D subsidies
2013										253,000
2014										295,000
2015										337,000
2016										379,000
2017										424,000
Life insurance benefit										$ 5,000

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INTANGIBLE ASSETS (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012 Y	Dec. 31, 2011	Dec. 31, 2010
Amortized intangible assets:
Weighted Average Amortization Period (in years)	13
Gross Carrying Value	$ 14,118	$ 13,257
Accumulated Amortization	4,650	3,772
Net Carrying Value	9,468	9,485
Unamortized intangible assets:
Perpetual water rights and other	4,495	3,229
Amortization of intangible assets	1,298	1,421	1,894
Estimated future amortization expense related to intangible assets for the succeeding five years
2013	1,319
2014	1,296
2015	1,237
2016	1,192
Thereafter	4,638
Water pumping rights
Amortized intangible assets:
Gross Carrying Value	1,084	1,084
Accumulated Amortization	79	14
Net Carrying Value	1,005	1,070
Water planning studies
Amortized intangible assets:
Weighted Average Amortization Period (in years)	12
Gross Carrying Value	11,894	11,087
Accumulated Amortization	4,322	3,413
Net Carrying Value	7,572	7,674
Leasehold improvements and other
Amortized intangible assets:
Weighted Average Amortization Period (in years)	21
Gross Carrying Value	1,140	1,086
Accumulated Amortization	249	345
Net Carrying Value	$ 891	$ 741

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FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)

12 Months Ended

Dec. 31, 2012

FAIR VALUE OF FINANCIAL INSTRUMENTS

Schedule of fair value of long-term debt, including current maturities, and advances for construction

	December 31, 2012
			Fair Value
	Cost		Level 1		Level 2		Level 3		Total
Long -term debt, including current maturities	$	481,250	$	—	$	613,211	$	—	$	613,211
Advances for construction		187,584		—		70,914		—		70,914
Total	$	668,834	$	—	$	684,125	$	—	$	684,125

	December 31, 2011
			Fair Value
	Cost		Level 1		Level 2		Level 3		Total
Long -term debt, including current maturities	$	488,165	$	—	$	625,202	$	—	$	625,202
Advances for construction		187,278		—		69,952		—		69,952
Total	$	675,443	$	—	$	695,154	$	—	$	695,154

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EMPLOYEE BENEFIT PLANS (Details 3) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Reconciliation of funded status
Average return for last five years (as a percent)	3.00%
Average return for last ten years (as a percent)	7.10%
Assumed health care cost trend rate
Annual rate of increase in the per capita cost (as a percent)	8.20%
Decreased annual rate by 2017 (as a percent)	6.20%
Ultimate health care cost trend rate (as a percent)	5.40%
Period in which ultimate health care cost trend rate is expected to be reached (in years)	50
Assumed health care cost trend rates affect the amounts reported for the postretirement benefit plans
Effect on total service and interest cost, increase	$ 2,036
Effect on total service and interest cost, decrease	(1,506)
Effect on accumulated postretirement benefit obligations, increase	18,576
Effect on accumulated postretirement benefit obligations, decrease	(14,147)
Minimum
Reconciliation of funded status
Percentage of expected results within which long-term rate of return falls	25.00%
Maximum
Reconciliation of funded status
Percentage of expected results within which long-term rate of return falls	75.00%
Fixed Income
Reconciliation of funded status
Assumed percentage of portfolio investment	40.00%
Assumed long-term inflation rate (as a percent)	3.00%
Weighted average assumptions used to determine net periodic benefit costs
Long-term rate of return on assets (as a percent)	5.05%
Fixed Income | Minimum
Target asset allocation percentages for major categories of the pension plan
Maturity period (in years)	1
Fixed Income | Maximum
Target asset allocation percentages for major categories of the pension plan
Maturity period (in years)	5
Equity securities
Reconciliation of funded status
Assumed percentage of portfolio investment	60.00%
Assumed long-term inflation rate (as a percent)	3.00%
Total Domestic Equity
Actuarial assumptions used in determining the benefit obligation for the benefit plans
Long-term rate of return on assets (as a percent)	9.20%
Non-U.S. Equities
Actuarial assumptions used in determining the benefit obligation for the benefit plans
Long-term rate of return on assets (as a percent)	9.34%
Short-term cash investments
Weighted average assumptions used to determine net periodic benefit costs
Long-term rate of return on assets (as a percent)	3.46%
Pension plans
Target asset allocation percentages for major categories of the pension plan
Fair value of pension plan assets	202,947	155,749	139,034
Actuarial assumptions used in determining the benefit obligation for the benefit plans
Discount rate (as a percent)	4.10%	4.40%
Long-term rate of return on assets (as a percent)	7.00%	7.00%
Rate of compensation increase (as a percent)	3.50%	3.50%
Cost of living adjustment (as a percent)	3.00%	3.00%
Change in projected benefit obligation:
Balance at the beginning of the period	346,305	269,940
Service cost	15,450	11,713	10,076
Interest cost	15,287	14,683	13,701
Assumption change	24,269	59,028
Experience (gain) loss	4,833	(6,030)
Benefits paid, net of retiree premiums	(4,023)	(3,029)
Balance at the end of the period	402,121	346,305	269,940
Change in plan assets:
Fair value of plan assets at beginning of year	155,749	139,034
Actual return on plan assets	21,979	555
Employer contributions	29,242	19,189
Benefits paid	(4,023)	(3,029)
Fair value of plan assets at end of year	202,947	155,749	139,034
Amounts recognized in the consolidated balance sheets:
Accrued benefit liability	(199,174)	(190,556)
Regulatory asset	175,551	171,153
Net amount recognized in the balance sheet	(23,623)	(19,403)
Reconciliation of funded status
Funded status	(199,174)	(190,556)
Unrecognized actuarial loss	133,579	123,177
Unrecognized prior service cost	41,972	47,976
Net amount recognized in the balance sheet	(23,623)	(19,403)
Short-term portion of the pension benefits	1,286	692
Components of the pension plans and other postretirement benefits
Service cost	15,450	11,713	10,076
Interest cost	15,287	14,683	13,701
Expected return on plan assets	(11,558)	(8,949)	(8,228)
Net amortization and deferral	14,283	10,387	9,224
Net periodic benefit cost	33,462	27,834	24,773
Sensitivity of pension amounts to changes in actuarial assumptions
Effect of 0.5 percentage-point decrease in the discount rate on the net periodic pension benefit cost	4,280
Effect of 0.5 percentage-point decrease in the discount rate on the projected pension benefit obligation	40,189
Effect of 0.5 percentage-point decrease in the long-term rate of return on plan assets on the net periodic pension benefit cost	826
Effect of 0.5 percentage-point decrease in the rate of compensation increases on the net periodic pension benefit cost	(1,929)
Effect of 0.5 percentage-point decrease in the rate of compensation increases on the projected pension benefit obligation	(11,227)
Effect of 0.5 percentage-point decrease in the cost of living adjustment on the net periodic pension benefit cost	(3,291)
Effect of 0.5 percentage-point decrease in the cost of living adjustment on the projected pension benefit obligation	(24,427)
Effect of 0.5 percentage-point increase in the discount rate on the net periodic pension benefit cost	(3,793)
Effect of 0.5 percentage-point increase in the discount rate on the projected pension benefit obligation	(35,196)
Effect of 0.5 percentage-point increase in the long-term rate of return on plan assets on the net periodic pension benefit cost	(825)
Effect of 0.5 percentage-point increase in the rate of compensation increases on the net periodic pension benefit cost	2,095
Effect of 0.5 percentage-point increase in the rate of compensation increases on the projected pension benefit obligation	12,099
Weighted average assumptions used to determine net periodic benefit costs
Discount rate (as a percent)	4.40%	5.60%
Long-term rate of return on assets (as a percent)	7.00%	6.75%
Rate of compensation increase (as a percent)	3.50%	4.00%
Assumed health care cost trend rates affect the amounts reported for the postretirement benefit plans
Estimated annual contributions in 2013	35,684
Pension plans | Level 1
Target asset allocation percentages for major categories of the pension plan
Fair value of pension plan assets	202,947	155,749
Total (as a percent)	100.00%	100.00%
Change in plan assets:
Fair value of plan assets at end of year	202,947	155,749
Pension plans | Fixed Income
Target asset allocation percentages for major categories of the pension plan
Target asset allocation percentages	40.00%
Pension plans | Fixed Income | Level 1
Target asset allocation percentages for major categories of the pension plan
Fair value of pension plan assets	79,391	79,859
Total (as a percent)	39.00%	51.00%
Change in plan assets:
Fair value of plan assets at end of year	79,391	79,859
Pension plans | Fixed Income | Level 1 | Money market fund investments
Target asset allocation percentages for major categories of the pension plan
Fair value of pension plan assets	26,069	43,364
Change in plan assets:
Fair value of plan assets at end of year	26,069	43,364
Pension plans | Fixed Income | Minimum
Target asset allocation percentages for major categories of the pension plan
Target asset allocation percentages	35.00%
Pension plans | Fixed Income | Maximum
Target asset allocation percentages for major categories of the pension plan
Target asset allocation percentages	45.00%
Pension plans | Total Domestic Equity
Target asset allocation percentages for major categories of the pension plan
Target asset allocation percentages	50.00%
Pension plans | Total Domestic Equity | Level 1
Target asset allocation percentages for major categories of the pension plan
Fair value of pension plan assets	103,355	67,951
Total (as a percent)	51.00%	44.00%
Change in plan assets:
Fair value of plan assets at end of year	103,355	67,951
Pension plans | Total Domestic Equity | Minimum
Target asset allocation percentages for major categories of the pension plan
Target asset allocation percentages	40.00%
Pension plans | Total Domestic Equity | Maximum
Target asset allocation percentages for major categories of the pension plan
Target asset allocation percentages	60.00%
Pension plans | Small Cap Stocks
Target asset allocation percentages for major categories of the pension plan
Target asset allocation percentages	15.00%
Pension plans | Small Cap Stocks | Level 1
Target asset allocation percentages for major categories of the pension plan
Fair value of pension plan assets	33,949	27,262
Change in plan assets:
Fair value of plan assets at end of year	33,949	27,262
Pension plans | Small Cap Stocks | Minimum
Target asset allocation percentages for major categories of the pension plan
Target asset allocation percentages	10.00%
Pension plans | Small Cap Stocks | Maximum
Target asset allocation percentages for major categories of the pension plan
Target asset allocation percentages	20.00%
Pension plans | Large Cap Stocks
Target asset allocation percentages for major categories of the pension plan
Target asset allocation percentages	35.00%
Pension plans | Large Cap Stocks | Level 1
Target asset allocation percentages for major categories of the pension plan
Fair value of pension plan assets	69,406	40,689
Change in plan assets:
Fair value of plan assets at end of year	69,406	40,689
Pension plans | Large Cap Stocks | Minimum
Target asset allocation percentages for major categories of the pension plan
Target asset allocation percentages	30.00%
Pension plans | Large Cap Stocks | Maximum
Target asset allocation percentages for major categories of the pension plan
Target asset allocation percentages	45.00%
Pension plans | Non-U.S. Equities
Target asset allocation percentages for major categories of the pension plan
Target asset allocation percentages	10.00%
Pension plans | Non-U.S. Equities | Level 1
Target asset allocation percentages for major categories of the pension plan
Fair value of pension plan assets	20,201	7,939
Total (as a percent)	10.00%	5.00%
Change in plan assets:
Fair value of plan assets at end of year	20,201	7,939
Pension plans | Non-U.S. Equities | Minimum
Target asset allocation percentages for major categories of the pension plan
Target asset allocation percentages	5.00%
Pension plans | Non-U.S. Equities | Maximum
Target asset allocation percentages for major categories of the pension plan
Target asset allocation percentages	15.00%
Other Benefits
Target asset allocation percentages for major categories of the pension plan
Fair value of pension plan assets	37,408	26,978	21,178
Actuarial assumptions used in determining the benefit obligation for the benefit plans
Discount rate (as a percent)	4.20%	4.50%
Long-term rate of return on assets (as a percent)	6.00%	6.25%
Change in projected benefit obligation:
Balance at the beginning of the period	69,107	45,944
Service cost	4,399	3,199	2,491
Interest cost	3,139	2,872	2,329
Assumption change	7,673	12,600
Experience (gain) loss	1,250	5,705
Benefits paid, net of retiree premiums	(1,147)	(1,213)
Balance at the end of the period	84,421	69,107	45,944
Change in plan assets:
Fair value of plan assets at beginning of year	26,978	21,178
Actual return on plan assets	2,788	64
Employer contributions	8,789	6,949
Retiree contributions and Medicare part D subsidies	1,255	1,130
Benefits paid	(2,402)	(2,343)
Fair value of plan assets at end of year	37,408	26,978	21,178
Amounts recognized in the consolidated balance sheets:
Prepaid (Accrued) benefit costs	(6,723)	(6,792)
Accrued benefit liability	(47,013)	(35,337)
Regulatory asset	47,602	35,337
Net amount recognized in the balance sheet	(6,134)	(6,792)
Reconciliation of funded status
Funded status	(47,013)	(42,129)
Unrecognized actuarial loss	40,449	34,515
Unrecognized prior service cost	421	537
Unrecognized transition obligation	9	285
Net amount recognized in the balance sheet	(6,134)	(6,792)
Components of the pension plans and other postretirement benefits
Service cost	4,399	3,199	2,491
Interest cost	3,139	2,872	2,329
Expected return on plan assets	(1,832)	(1,372)	(1,119)
Net amortization and deferral	2,425	1,592	1,081
Net periodic benefit cost	8,131	6,291	4,782
Weighted average assumptions used to determine net periodic benefit costs
Discount rate (as a percent)	4.50%	5.60%
Long-term rate of return on assets (as a percent)	6.25%	6.00%
Assumed health care cost trend rates affect the amounts reported for the postretirement benefit plans
Estimated annual contributions in 2013	8,892
Other Benefits | Level 1
Target asset allocation percentages for major categories of the pension plan
Fair value of pension plan assets	37,408	26,978
Total (as a percent)	100.00%	100.00%
Change in plan assets:
Fair value of plan assets at end of year	37,408	26,978
Other Benefits | Fixed Income | Level 1
Target asset allocation percentages for major categories of the pension plan
Fair value of pension plan assets	22,845	16,006
Total (as a percent)	61.00%	59.00%
Change in plan assets:
Fair value of plan assets at end of year	22,845	16,006
Other Benefits | Fixed Income | Level 1 | Money market fund investments
Target asset allocation percentages for major categories of the pension plan
Fair value of pension plan assets	14,159	16,006
Change in plan assets:
Fair value of plan assets at end of year	14,159	16,006
Other Benefits | Total Domestic Equity | Level 1
Target asset allocation percentages for major categories of the pension plan
Fair value of pension plan assets	14,563	10,972
Total (as a percent)	39.00%	41.00%
Change in plan assets:
Fair value of plan assets at end of year	14,563	10,972
Other Benefits | Large Cap Stocks | Level 1
Target asset allocation percentages for major categories of the pension plan
Fair value of pension plan assets	14,563	10,972
Change in plan assets:
Fair value of plan assets at end of year	$ 14,563	$ 10,972
Other Benefits | Non-U.S. Equities | Level 1
Target asset allocation percentages for major categories of the pension plan
Total (as a percent)	0.00%	0.00%

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

12 Months Ended

Dec. 31, 2012

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Schedule of change to net WRAM and MCBA deferred balances

	Operating Revenues			Operating Costs			Income Before Income Taxes
Net WRAM and MCBA deferred balances as of December 31, 2011	$	12,864		$	10,492		$	2,372
Reversal of deferred amounts during 2012		(12,864	)		(10,492	)		(2,372	)
Deferred amounts added during 2012		882			719			163
Net WRAM and MCBA deferred balances as of December 31, 2012	$	882		$	719		$	163

Schedule of net undercollected WRAM and MCBA receivable balances

	2012		2011
Net short-term receivable	$	34,020	$	19,357
Net long-term receivable		12,051		30,268
Total receivable	$	46,071	$	49,625
Net short-term payable	$	371	$	543
Net long-term payable		119		145
Total payable	$	490	$	688

Schedule of activities in the allowance for doubtful accounts

	2012			2011			2010
Beginning Balance	$	669		$	804		$	847
Provision for uncollectible accounts		1,548			1,250			1,500
Net write off of uncollectible accounts		(1,503	)		(1,385	)		(1,543	)
Ending Balance	$	714		$	669		$	804

Schedule of depreciable plant and equipment

	2012		2011
Equipment	$	400,610	$	382,195
Transmission and distribution plant		1,351,158		1,287,010
Office buildings and other structures		151,597		138,364
Total	$	1,903,365	$	1,807,569

Schedule of estimated useful lives of depreciable plant and equipment

	Useful Lives
Equipment	5 to 50 years
Transmission and distribution plant	40 to 65 years
Office Buildings and other structures	50 years

Schedule of regulatory assets and liabilities

	2012		2011
Regulatory Assets
Pension and retiree group health	$	223,153	$	213,819
Income tax temporary differences		56,991		34,664
Other accrued benefits		40,362		31,453
Net WRAM and MCBA long-term accounts receivable		12,051		30,268
Asset retirement obligations, net		11,862		9,694
Total Regulatory Assets	$	344,419	$	319,898
Regulatory Liabilities
Future tax benefits due ratepayers	$	24,932	$	16,978
Conservation program		6,538		4,328
Pension balancing account		—		1,936
Other liabilities		4,250		4,795
Total Regulatory Liabilities	$	35,720	$	28,037

Schedule of dilutive effect of options

	2012		2011		2010
	(In thousands, except per share data)
Net income as reported and available to common stockholders	$	48,828	$	37,712	$	37,656
Weighted average common shares, basic		41,892		41,762		41,612
Dilutive common stock equivalents (treasury method)		—		10		26
Shares used for dilutive calculation		41,892		41,772		41,638
Earnings per share—basic	$	1.17	$	0.90	$	0.90
Earnings per share—diluted	$	1.17	$	0.90	$	0.90

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LONG-TERM DEBT (Details) (USD $)			1 Months Ended								1 Months Ended																																					12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Oct. 31, 2011 Cal Water Y	Dec. 31, 2012 Cal Water	Dec. 31, 2011 Cal Water	Oct. 04, 2011 Cal Water	Dec. 31, 2012 First Mortgage Bonds	Dec. 31, 2011 First Mortgage Bonds	Dec. 31, 2012 First Mortgage Bonds, 5.500% due 2040	Dec. 31, 2011 First Mortgage Bonds, 5.500% due 2040	Nov. 30, 2010 First Mortgage Bonds, 5.500% due 2040 Cal Water	Nov. 17, 2010 First Mortgage Bonds, 5.500% due 2040 Cal Water	Dec. 31, 2012 First Mortgage Bonds, 5.875% due 2019	Dec. 31, 2011 First Mortgage Bonds, 5.875% due 2019	Apr. 17, 2009 First Mortgage Bonds, 5.875% due 2019 Cal Water	Dec. 31, 2012 First Mortgage Bonds, AAA Series, due in 2025	Dec. 31, 2011 First Mortgage Bonds, AAA Series, due in 2025	Dec. 31, 2012 First Mortgage Bonds, BBB Series, due in 2028	Dec. 31, 2011 First Mortgage Bonds, BBB Series, due in 2028	Dec. 31, 2012 First Mortgage Bonds, CCC Series, due in 2030	Dec. 31, 2011 First Mortgage Bonds, CCC Series, due in 2030	Dec. 31, 2012 First Mortgage Bonds, DDD Series, due in 2031	Dec. 31, 2011 First Mortgage Bonds, DDD Series, due in 2031	Dec. 31, 2012 First Mortgage Bonds, EEE Series, due in 2032	Dec. 31, 2011 First Mortgage Bonds, EEE Series, due in 2032	Dec. 31, 2012 First Mortgage Bonds, FFF Series, due in 2017	Dec. 31, 2011 First Mortgage Bonds, FFF Series, due in 2017	Dec. 31, 2012 First Mortgage Bonds, GGG Series, due in 2022	Dec. 31, 2011 First Mortgage Bonds, GGG Series, due in 2022	Dec. 31, 2012 First Mortgage Bonds, HHH Series, due in 2022	Dec. 31, 2011 First Mortgage Bonds, HHH Series, due in 2022	Dec. 31, 2012 First Mortgage Bonds, III Series, due in 2023	Dec. 31, 2011 First Mortgage Bonds, III Series, due in 2023	Dec. 31, 2012 First Mortgage Bonds, JJJ Series, due in 2018	Dec. 31, 2011 First Mortgage Bonds, JJJ Series, due in 2018	Dec. 31, 2012 First Mortgage Bonds, LLL Series, due in 2018	Dec. 31, 2011 First Mortgage Bonds, LLL Series, due in 2018	Dec. 31, 2012 First Mortgage Bonds, MMM Series, due in 2013	Dec. 31, 2011 First Mortgage Bonds, MMM Series, due in 2013	Dec. 31, 2012 First Mortgage Bonds, NNN Series, due in 2013	Dec. 31, 2011 First Mortgage Bonds, NNN Series, due in 2013	Dec. 31, 2012 First Mortgage Bonds, OOO Series, due in 2031	Dec. 31, 2011 First Mortgage Bonds, OOO Series, due in 2031	Dec. 31, 2012 First Mortgage Bonds, CC Series, due in 2020	Dec. 31, 2011 First Mortgage Bonds, CC Series, due in 2020	Dec. 31, 2012 First Mortgage Bonds, K Series, due in 2012	Dec. 31, 2011 First Mortgage Bonds, K Series, due in 2012	Dec. 31, 2012 California Department of Water Resources Loans	Dec. 31, 2011 California Department of Water Resources Loans	Dec. 31, 2012 Other Long-term debt	Dec. 31, 2011 Other Long-term debt
Long-term debt
Interest Rate (as a percent)									5.50%	5.50%		5.50%	5.875%	5.875%	5.875%	7.28%	7.28%	6.77%	6.77%	8.15%	8.15%	7.13%	7.13%	7.11%	7.11%	5.90%	5.90%	5.29%	5.29%	5.29%	5.29%	5.54%	5.54%	5.44%	5.44%	5.48%	5.48%	5.52%	5.52%	5.55%	5.55%	6.02%	6.02%	9.86%	9.86%	6.94%	6.94%
Interest rate, low end of range (as a percent)																																																2.60%	2.60%
Interest rate, high end of range (as a percent)																																																8.00%	8.00%
Total long-term debt	$ 481,250,000	$ 488,165,000					$ 459,219,000	$ 464,664,000	$ 100,000,000	$ 100,000,000			$ 100,000,000	$ 100,000,000		$ 20,000,000	$ 20,000,000	$ 20,000,000	$ 20,000,000	$ 20,000,000	$ 20,000,000	$ 20,000,000	$ 20,000,000	$ 20,000,000	$ 20,000,000	$ 20,000,000	$ 20,000,000	$ 18,182,000	$ 20,000,000	$ 18,182,000	$ 20,000,000	$ 10,000,000	$ 10,000,000	$ 5,455,000	$ 6,364,000	$ 10,000,000	$ 10,000,000	$ 20,000,000	$ 20,000,000	$ 20,000,000	$ 20,000,000	$ 20,000,000	$ 20,000,000	$ 17,400,000	$ 17,500,000		$ 800,000	$ 8,451,000	$ 8,780,000	$ 13,580,000	$ 14,721,000
Less current maturities	46,783,000	6,533,000		46,104,000	5,851,000
Long-term debt excluding current maturities	434,467,000	481,632,000		431,433,000	477,998,000
Debt maturity period (in years)			15
Capital lease liability						9,200,000
Sale and issuance of First Mortgage Bonds											$ 100,000,000

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details 5) (USD $)	Dec. 31, 2012	Dec. 31, 2011
Restricted Cash
Carrying value of restricted cash	$ 2,266,000	$ 4,225,000
Cal Water
Restricted Cash
Cal Water and a third party cash deposits	1,000,000
Proceeds collected through a surcharge on certain customers' bills	$ 1,100,000

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ORGANIZATION AND OPERATIONS (Details)	12 Months Ended
	Dec. 31, 2012 segment
ORGANIZATION AND OPERATIONS
Number of reportable segments	1

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INCOME TAXES (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Federal
Current	$ (9,018)	$ 7,413	$ 4,027
Deferred	37,196	12,982	15,730
Total	28,178	20,395	19,757
State
Current	(5,246)	2,629	3,020
Deferred	(1,480)	142	1,779
Total	(6,726)	2,771	4,799
Total income tax expense
Current	(14,264)	10,042	7,047
Deferred	35,716	13,124	17,509
Total	$ 21,452	$ 23,166	$ 24,556

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COMMITMENTS AND CONTINGENCIES (Details 2) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Capital Lease Obligations
2013	$ 1,109,000
2014	1,109,000
2015	1,109,000
2016	1,109,000
2017	1,109,000
Thereafter	8,609,000
Water Contracts
Future minimum commitments
2013	19,378,000
2014	19,448,000
2015	19,521,000
2016	19,592,000
2017	19,664,000
Thereafter	451,891,000
Santa Clara Valley Water District
Long-term purchase commitments - other disclosures
Annual cost	6,164,000	5,524,000	5,306,000
Stockton East Water District (SEWD)
Long-term purchase commitments - other disclosures
Annual cost	6,591,000	6,658,000	6,159,000
Kern County Water Agency (Agency)
Long-term purchase commitments - other disclosures
Annual cost	6,272,000	6,129,000	5,454,000
Minimum acre feet of treated water to be purchased under prior agreement	11,500
Number of other parties obligated to purchase treated water	3
Minimum acre feet of treated water to be purchased per year by other parties	32,500
Total obligation of all parties, excluding the Company	82,400,000
Total capital facilities charge and treated water charge obligation	7,160,000
Total capital facilities charge and treated water charge obligation per acre foot	349,000
Annual capital facilities charge	3,600,000
Total treated water charge	2,583,000
Portion of estimated operating cost per acre foot for treated water delivered	$ 7,000
Kern County Water Agency (Agency) | Minimum
Long-term purchase commitments - other disclosures
Minimum acre feet of treated water to be purchased per year over life of contract	18,000
Kern County Water Agency (Agency) | Maximum
Long-term purchase commitments - other disclosures
Minimum acre feet of treated water to be purchased per year over life of contract	20,500

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PREFERRED STOCK (Details)	Dec. 31, 2012
PREFERRED STOCK
Preferred stock, shares authorized	241,000

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

12 Months Ended

Dec. 31, 2012

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

2 SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

• Revenue

        Revenue generally includes monthly cycle customer billings for regulated water and wastewater services at rates authorized by regulatory commissions (plus an estimate for water used between the customer's last meter reading and the end of the accounting period) and billings to certain non-regulated customers at rates authorized by contract with government agencies.

        The Company's regulated water and waste water revenue requirements are authorized by the Commissions in the states in which we operate. The revenue requirements are intended to provide the Company a reasonable opportunity to recover its operating costs and earn a return on investments.

        For metered customers, Cal Water recognizes revenue from rates which are designed and authorized by the California Public Utilities Commission (CPUC). Under the Water Revenue Adjustment Mechanism (WRAM), Cal Water records the adopted level of volumetric revenues, which would include recovery of cost of service and a return on investments, as established by the CPUC for metered accounts (adopted volumetric revenues). In addition to volumetric-based revenues, the revenue requirements approved by the CPUC include service charges, flat rate charges, and other items not subject to the WRAM. The adopted volumetric revenue considers the seasonality of consumption of water based upon historical averages. The variance between adopted volumetric revenues and actual billed volumetric revenues for metered accounts is recorded as a component of revenue with an offsetting entry to a regulatory asset or liability balancing account (tracked individually for each Cal Water district) subject to certain criteria under the accounting for regulated operations being met. The variance amount may be positive or negative and represents amounts that will be billed or refunded to customers in the future.

        Cost-recovery rates are designed to permit full recovery of certain costs allowed to be recovered by the Commissions. Cost-recovery rates such as the Modified Cost Balancing Account (MCBA) provides for recovery of adopted expense levels for purchased water, purchased power and pump taxes, as established by the CPUC. In addition, cost-recovery rates include recovery of cost related to water conservation programs and certain other operating expenses adopted by the CPUC. Variances (which include the effects of changes in both rate and volume for the MCBA) between adopted and actual costs are recorded as a component of revenue, as the amount of such variances will be recovered from or refunded to our customers at a later date. There is no markup for return or profit for cost-recovery expenses and they are generally recognized when expenses are incurred.

        The balances in the WRAM and MCBA assets and liabilities accounts will fluctuate on a monthly basis depending upon the variance between adopted and actual results. The recovery or refund of the WRAM is netted against the MCBA over- or under-recovery for the corresponding district and is interest bearing at the current 90 day commercial paper rate. At the end of any calendar year, Cal Water files with the CPUC to refund or collect the balance in the accounts. Most undercollected net WRAM and MCBA receivable balances are collected over 12 and 18 months. Cal Water defers net WRAM and MCBA operating revenues and associated costs whenever the net receivable balances are estimated to be collected more than 24 months after the respective reporting periods in which it was recognized. The deferred net WRAM and MCBA revenues and associated costs were determined using forecasts of rate payer consumption trends in future reporting periods and the timing of when the CPUC will authorize Cal Water's filings to recover the undercollected balances. Deferred net WRAM and MCBA revenues and associated costs will be recognized as revenues and costs in future periods when collection is within twenty-four months of the respective reporting period.

        The change to net WRAM and MCBA deferred balances:

	Operating Revenues			Operating Costs			Income Before Income Taxes
Net WRAM and MCBA deferred balances as of December 31, 2011	$	12,864		$	10,492		$	2,372
Reversal of deferred amounts during 2012		(12,864	)		(10,492	)		(2,372	)
Deferred amounts added during 2012		882			719			163
Net WRAM and MCBA deferred balances as of December 31, 2012	$	882		$	719		$	163

        The net undercollected WRAM and MCBA receivable balances as of December 31, 2012 and 2011 were:

	2012		2011
Net short-term receivable	$	34,020	$	19,357
Net long-term receivable		12,051		30,268
Total receivable	$	46,071	$	49,625
Net short-term payable	$	371	$	543
Net long-term payable		119		145
Total payable	$	490	$	688

        Flat rate customers are billed in advance at the beginning of the service period. The revenue is prorated so that the portion of revenue applicable to the current period is included in that period's revenue, with the balance recorded as unearned revenue on the balance sheet and recognized as revenue when earned in the subsequent accounting period. Our unearned revenue liability was $1,708 and $1,871 as of December 31, 2012 and 2011, respectively. This liability is included in "other accrued liabilities" on our consolidated balance sheets.

• Allowance for Doubtful Accounts

        The Company provides an allowance for doubtful accounts receivable. The allowance is based upon specific identified accounts plus an estimate of uncollectible accounts based upon historical percentages. The balance of customer receivables is net of the allowance for doubtful accounts at December 31, 2012 and 2011 of $714 and $669, respectively.

        The activities in the allowance for doubtful accounts are as follows:

	2012			2011			2010
Beginning Balance	$	669		$	804		$	847
Provision for uncollectible accounts		1,548			1,250			1,500
Net write off of uncollectible accounts		(1,503	)		(1,385	)		(1,543	)
Ending Balance	$	714		$	669		$	804

• Non-Regulated Revenue

        Revenues from non-regulated operations and maintenance agreements are recognized when services have been rendered to companies or municipalities under such agreements. For construction and design services, revenue is generally recognized on the completed contract method, as most projects are completed in less than three months. Other non-regulated revenue is recognized when title has transferred to the buyer, or ratably over the term of the lease.

• Utility Plant

        Utility plant is carried at original cost when first constructed or purchased, or at fair value when acquired through acquisition. When depreciable plant is retired, the cost is eliminated from utility plant accounts and such costs are charged against accumulated depreciation. Maintenance of utility plant is charged to operating expenses as incurred. Maintenance projects are not accrued for in advance. Interest is capitalized on plant expenditures during the construction period and amounted to $3,401 in 2012, $2,741 in 2011, and $1,563 in 2010.

        Intangible assets acquired as part of water systems purchased are recorded at fair value. All other intangibles have been recorded at cost and are amortized over their useful life.

        The following table represents depreciable plant and equipment as of December 31:

	2012		2011
Equipment	$	400,610	$	382,195
Transmission and distribution plant		1,351,158		1,287,010
Office buildings and other structures		151,597		138,364
Total	$	1,903,365	$	1,807,569

        Depreciation of utility plant for financial statement purposes is computed on a straight-line basis over the assets' estimated useful lives including cost of removal of certain assets as follows:

	Useful Lives
Equipment	5 to 50 years
Transmission and distribution plant	40 to 65 years
Office Buildings and other structures	50 years

        The provision for depreciation expressed as a percentage of the aggregate depreciable asset balances was 3.1% in 2012, 3.0% in 2011, and 2.8% 2010. For income tax purposes, as applicable, the Company computes depreciation using the accelerated methods allowed by the respective taxing authorities.

• Asset Retirement Obligation

        The Company has a legal obligation to retire wells in accordance with Department of Public Health regulations. In addition, upon decommission of a wastewater plant or lift station certain wastewater infrastructure would need to be retired in accordance with Department of Public Health regulations. The Company has collected retirement obligation costs from ratepayers through depreciation expense. As of December 31, 2012 and 2011 the retirement obligation is estimated to be $16,105 and $14,049, respectively. The change only impacted the consolidated balance sheet.

• Cash Equivalents

        Cash equivalents include highly liquid investments with remaining maturities of three months or less at the time of acquisition.

• Restricted Cash

        In 2012 restricted cash includes $1.0 million of Cal Water and a third party cash deposits for a capital project. It also includes $1.1 million of proceeds collected through a surcharge on certain customers' bills plus interest earned on the proceeds and is used to service California Safe Drinking Water Bond obligations. All restricted cash is included in prepaid expenses. At December 31, 2012 and 2011, restricted cash was $2,266 and $4,225, respectively.

• Regulatory Assets and Liabilities

        Regulatory assets and liabilities were comprised of the following as of December 31:

	2012		2011
Regulatory Assets
Pension and retiree group health	$	223,153	$	213,819
Income tax temporary differences		56,991		34,664
Other accrued benefits		40,362		31,453
Net WRAM and MCBA long-term accounts receivable		12,051		30,268
Asset retirement obligations, net		11,862		9,694
Total Regulatory Assets	$	344,419	$	319,898
Regulatory Liabilities
Future tax benefits due ratepayers	$	24,932	$	16,978
Conservation program		6,538		4,328
Pension balancing account		—		1,936
Other liabilities		4,250		4,795
Total Regulatory Liabilities	$	35,720	$	28,037

        Short-term regulatory assets and liabilities are excluded from the above table. The short-term regulatory assets for 2012 and 2011 were $34,020 and $21,680, respectively. The short-term regulatory assets were primarily net WRAM/MCBA receivable balances. The short-term portion of regulatory liabilities for 2012 and 2011 were $5,018 and $2,655, respectively.

        The Company operates extensively in a regulated business, and as such is subject to the accounting standards for regulated utilities. Utility companies defer costs and credits on the balance sheet as regulatory assets and liabilities when it is probable that those costs and credits will be recognized in the ratemaking process in a period different from the period in which they would have been reflected in income by an unregulated company. Regulatory assets other than WRAM represent deferral of costs that will be recovered in the future and do not include a return. In determining the probability of costs being recognized in other periods, the Company considers regulatory rules and decisions, past practices, and other facts or circumstances that would indicate if recovery is probable. In the event that a portion of the Company's operations were no longer subject to the accounting standards for regulated utilities, the Company would be required to write off related regulatory assets and liabilities. If a commission determined that a portion of the Company's assets were not recoverable in customer rates, the Company would be required to determine if the Company had suffered an asset impairment that would require a write-down in the assets' valuation.

        The Company's qualified, defined-benefit, non-contributory pension plan and other postretirement plan benefit (Retire Group Health) regulatory asset is the amount the Company expects to recover from ratepayers in the future for these plans at the end of the calendar year, which also includes amounts that otherwise would be recorded to accumulated other comprehensive loss in the Consolidated Balance Sheet.

        The income tax temporary differences relate primarily to the difference between book and federal income tax depreciation on utility plant that was placed in service before the regulatory Commissions adopted normalization for rate making purposes. Previously, the tax benefit of tax depreciation was passed on to customers (flow-through). For state income tax purposes, the Commission continues to use the flow-through method. As such timing differences reverse, the Company will be able to include the impact of such differences in customer rates. These federal tax differences will continue to reverse over the remaining book lives of the related assets.

        Other accrued benefits are accrued benefits for vacation, self-insured workers' compensation, and directors' retirement benefits. The net WRAM and MCBA long-term accounts receivable is the undercollected portion of recorded revenues that are not expected to be collected from ratepayers within 12 months. The asset retirement obligations is recorded net of depreciation which has been recorded and recognized through the regulatory process over the remaining useful life of the related asset.

        The future tax benefits regulatory liability are future benefits to ratepayers for tax deductions that will be allowed in the future. Regulatory liabilities also reflect timing differences provided at higher than the current tax rate, which will flow-through to future ratepayers. The conservation program regulatory liability is for cost recovery in rates that exceeded incurred costs and is refundable to ratepayers as of December 31, 2012.

• Impairment of Long-Lived Assets, Intangibles and Goodwill

        The Company regularly reviews its long-lived assets, intangible assets and goodwill for impairment annually or when events or changes in business circumstances have occurred that indicate the carrying amount of such assets may not be fully realizable. Potential impairment of assets held for use is determined by comparing the carrying amount of an asset to the future undiscounted cash flows expected to be generated by the asset. If assets are considered to be impaired, the impairment to be recognized is measured as the amount by which the carrying value of the asset exceeds its fair value. In the 2010 Hawaii Water GRC for the Ka'anapali Water District, construction costs of $320 were removed from rate base and expensed as a non-regulated expense during 2011 and in the Cal Water 2009 GRC settlement, construction costs of $634 were removed from rate base and expensed to non-regulated expense during 2010.

        Goodwill is measured as the excess of the cost of an acquisition over the sum of the amounts assigned to identifiable assets acquired less liabilities assumed. Goodwill and other identifiable intangible assets are accounted for in accordance with generally accepted accounting principles. Goodwill is not amortized but instead is reviewed annually at November 30^th for impairment or more frequently if impairment indicators arise.

        The impairment test is performed at the reporting unit level using a two-step, fair-value based approach. The first step determines the fair value of the reporting unit and compares it to the reporting unit's carrying value. If the fair value of the reporting unit is less than its carrying amount, a second step is performed to measure the amount of impairment loss, if any. The second step allocates the fair value of the reporting unit to the Company's tangible and intangible assets and liabilities. This derives an implied fair value for the reporting unit's goodwill. If the carrying amount of the reporting unit's goodwill exceeds the implied fair value of that goodwill, an impairment loss is recognized equal to the excess.

        The recorded goodwill balance as of December 31, 2012 and 2011, relate to the Hawaii Water Service Company reporting unit. Based on our annual goodwill impairment test, no impairment was recorded in 2012 or 2011.

• Long-Term Debt Premium, Discount and Expense

        The discount and issuance expense on long-term debt is amortized over the original lives of the related debt on a straight-line basis which approximates the effective interest method. Premiums paid on the early redemption of certain debt and the unamortized original issuance discount and expense are amortized over the life of new debt issued in conjunction with the early redemption. Amortization expense included in interest expense was $1,107, $1,082, and $979 for 2012, 2011, and 2010, respectively.

• Advances for Construction

        Advances for Construction consist of payments received from developers for installation of water production and distribution facilities to serve new developments. Advances are excluded from rate base for rate setting purposes. Annual refunds are made to developers without interest. Advances of $186,753, and $185,902 at December 31, 2012 and 2011, respectively, will be refunded primarily over a 40-year period in equal annual amounts. In addition, other Advances for Construction totaling $831 and $1,376 at December 31, 2012, and 2011, respectively, are refundable based upon customer connections. Estimated refunds of advances for each succeeding year (2013 through 2017) are approximately $7,179, $7,178, $7,115, $7,098, $7,081 and $151,102 thereafter.

• Contributions in Aid of Construction

        Contributions in Aid of Construction represent payments received from developers, primarily for fire protection purposes, which are not subject to refunds. Facilities funded by contributions are included in utility plant, but excluded from rate base. Depreciation related to assets acquired from contributions is charged to the Contributions in Aid of Construction account.

• Income Taxes

        The Company accounts for income taxes using the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Measurement of the deferred tax assets and liabilities is at enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the period that includes the enactment date.

        Historically the Commissions have allowed revenue requirements for the tax effects of temporary differences recognized, which have previously been flowed through to customers. The Commissions have granted the Company rate increases to reflect the normalization of the tax benefits of the federal accelerated methods and available Investment Tax Credits (ITC) for all assets placed in service after 1980. ITCs are deferred and amortized over the lives of the related properties for book purposes.

        Advances for Construction and Contributions in Aid of Construction received from developers subsequent to 1986 were taxable for federal income tax purposes and subsequent to 1991 were subject to California income tax. In 1996, the federal tax law, and in 1997, the California tax law, changed and only deposits for new services were taxable. In late 2000, federal regulations were further modified to exclude contributions of fire services from taxable income.

        The accounting standards for accounting for uncertainty in income taxes also requires the inclusion of interest and penalties related to uncertain tax positions as a component of income taxes. See note 10 "Income Taxes".

• Workers' Compensation, General Liability and Other Claims

        For workers' compensation, the Company estimates the liability associated with claims submitted and claims not yet submitted based on historical data. Expenses for workers compensation insurance are included in rates on a pay-as-you-go basis. Therefore, a corresponding regulatory asset has been recorded. For general liability claims and other claims, the Company estimates the cost incurred but not yet paid using historical information.

• Collective Bargaining Agreements

        As of December 31, 2012, the Company had 1,131 employees, including 734 non-supervisory employees who are represented by the Utility Workers Union of America, AFL-CIO, except certain engineering and laboratory employees who are represented by the International Federation of Professional and Technical Engineers, AFL-CIO. The union agreements expire at the end of 2014.

• Earnings Per Share

        The computations of basic and diluted earnings per share are noted below. Basic earnings per share are computed by dividing net income available to common stockholders by the weighted average number of common shares outstanding during the period. Diluted earnings per share reflect the potential dilution that could occur if securities or other contracts were exercised or converted into common stock. Restricted Stock Awards (RSAs) are included in the common shares outstanding because the shares have all the same voting and dividend rights as issued and unrestricted common stock.

        At December 31, 2012, there were no common stock options outstanding. The Company did not grant any Stock Appreciation Rights (SAR) in 2012, 2011, and 2010. SARs outstanding were 333,856 shares as of December 31, 2012 and 361,356 shares as of December 31, 2011 and 2010.

        All options are dilutive and the SARs are antidilutive. The dilutive effect is shown in the table below.

	2012		2011		2010
	(In thousands, except per share data)
Net income as reported and available to common stockholders	$	48,828	$	37,712	$	37,656
Weighted average common shares, basic		41,892		41,762		41,612
Dilutive common stock equivalents (treasury method)		—		10		26
Shares used for dilutive calculation		41,892		41,772		41,638
Earnings per share—basic	$	1.17	$	0.90	$	0.90
Earnings per share—diluted	$	1.17	$	0.90	$	0.90

• Stock-based Compensation

        The Company follows accounting standards for stock-based compensation. Compensation cost is measured at the grant date based on the fair value of the award. The Company recognizes compensation as expense on a straight-line basis over the requisite service period, which is the vesting period.

• Comprehensive Income or Loss

        Comprehensive income for all periods presented was the same as net income.

• Accumulated Other Comprehensive Income or Loss

        The Company did not have any accumulated other comprehensive income or loss transactions for 2012, 2011, and 2010.

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QUARTERLY FINANCIAL DATA (UNAUDITED) (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Operating revenue	$ 121,530	$ 178,135	$ 143,552	$ 116,749	$ 103,014	$ 169,254	$ 131,397	$ 98,149	$ 559,966	$ 501,814	$ 460,399
Net operating income	11,253	36,361	19,622	6,607	7,586	30,078	19,555	9,948	73,843	67,167	61,813
Net income	$ 5,006	$ 29,772	$ 12,965	$ 1,085	$ 1,868	$ 20,935	$ 12,190	$ 2,719
Diluted earnings per share (in dollars per share)	$ 0.12	$ 0.71	$ 0.31	$ 0.03	$ 0.04	$ 0.50	$ 0.29	$ 0.07	$ 1.17	$ 0.90	$ 0.90
Common stock market price range:
Dividends paid per common share (in dollars per share)	$ 0.1575	$ 0.1575	$ 0.1575	$ 0.1575	$ 0.15375	$ 0.15375	$ 0.15375	$ 0.15375	$ 0.630	$ 0.615	$ 0.595
High
Common stock market price range:
Common stock market price (in dollars per share)	$ 18.90	$ 19.05	$ 18.60	$ 19.25	$ 19.20	$ 19.37	$ 19.16	$ 19.18	$ 18.90	$ 19.20
Low
Common stock market price range:
Common stock market price (in dollars per share)	$ 16.84	$ 17.93	$ 17.14	$ 17.67	$ 16.81	$ 16.65	$ 18.06	$ 17.28	$ 16.84	$ 16.81

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details 6) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012 Y employee	Dec. 31, 2011	Dec. 31, 2010
Regulatory Assets and Liabilities
Regulatory assets	$ 344,419	$ 319,898
Regulatory assets, net long-term receivable	344,419	319,898
Regulatory liability	35,720	28,037
Short-term portion of the regulatory assets	34,020	21,680
Short-term portion of the regulatory liabilities	5,018	2,655
Long-Term Debt Premium, Discount and Expense
Amortization expense included in interest expense	1,107	1,082	979
Advances for Construction
Advances for construction refunded primarily over a 40-year period	186,753	185,902
Refund period (in years)	40
Other advances for construction refundable based upon customer connections	831	1,376
Estimated refunds of advances
2013	7,179
2014	7,178
2015	7,115
2016	7,098
2017	7,081
Thereafter	151,102
Collective Bargaining Agreements
Number of employees	1,131
Number of non-supervisory employees represented by the Utility Workers Union of America	734
Future tax benefits due ratepayers
Regulatory Assets and Liabilities
Regulatory liability	24,932	16,978
Conservation program
Regulatory Assets and Liabilities
Regulatory liability	6,538	4,328
Pension balancing account
Regulatory Assets and Liabilities
Regulatory liability		1,936
Other liabilities
Regulatory Assets and Liabilities
Regulatory liability	4,250	4,795
Pension and retiree group health
Regulatory Assets and Liabilities
Regulatory assets	223,153	213,819
Income tax temporary differences
Regulatory Assets and Liabilities
Regulatory assets	56,991	34,664
Other accrued benefits
Regulatory Assets and Liabilities
Regulatory assets	40,362	31,453
Net WRAM and MCBA accounts receivable
Regulatory Assets and Liabilities
Regulatory assets	42,071	49,625
Regulatory assets, net long-term receivable	12,051	30,268
Short-term portion of the regulatory assets	34,020	19,357
Asset retirement obligations, net
Regulatory Assets and Liabilities
Regulatory assets	11,862	9,694
Impairment of Long-Lived Assets, Intangibles and Goodwill
Construction costs removed from rate base		$ 320	$ 634

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LONG-TERM DEBT (Tables)

12 Months Ended

Dec. 31, 2012

LONG-TERM DEBT.

Schedule of long-term debt outstanding

	Series	Interest Rate	Maturity Date		2012		2011
First Mortgage Bonds	PPP	5.500%		2040	$	100,000	$	100,000
	LL	5.875%		2019		100,000		100,000
	AAA	7.280%		2025		20,000		20,000
	BBB	6.770%		2028		20,000		20,000
	CCC	8.150%		2030		20,000		20,000
	DDD	7.130%		2031		20,000		20,000
	EEE	7.110%		2032		20,000		20,000
	FFF	5.900%		2017		20,000		20,000
	GGG	5.290%		2022		18,182		20,000
	HHH	5.290%		2022		18,182		20,000
	III	5.540%		2023		10,000		10,000
	JJJ	5.440%		2018		5,455		6,364
	LLL	5.480%		2018		10,000		10,000
	MMM	5.520%		2013		20,000		20,000
	NNN	5.550%		2013		20,000		20,000
	OOO	6.020%		2031		20,000		20,000
	CC	9.860%		2020		17,400		17,500
	K	6.940%		2012		—		800
Total First Mortgage Bonds						459,219		464,664
California Department of Water Resources Loans		2.6% to 8%		2012 - 32		8,451		8,780
Other Long-term debt						13,580		14,721
Total long-term debt						481,250		488,165
Less current maturities						46,783		6,533
Long-term debt excluding current maturities					$	434,467	$	481,632

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SHORT-TERM BORROWINGS (Tables)

12 Months Ended

Dec. 31, 2012

SHORT-TERM BORROWINGS

Schedule of borrowings under the bank lines of credit

	2012			2011
Maximum short-term borrowings	$	89,475		$	47,140
Average amount outstanding	$	71,715		$	32,324
Weighted average interest rate		1.74	%		2.41	%
Interest rate at December 31		2.14	%		2.10	%

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EMPLOYEE BENEFIT PLANS (Details 2)	Dec. 31, 2012
S&P Index
Pension plan and other postretirement benefits
Performance benchmark of special index (as a percent)	35.00%
Russell 2000 Index
Pension plan and other postretirement benefits
Performance benchmark of special index (as a percent)	15.00%
MSCI EAFE Index
Pension plan and other postretirement benefits
Performance benchmark of special index (as a percent)	10.00%
Lehman Aggregate Bond Index
Pension plan and other postretirement benefits
Performance benchmark of special index (as a percent)	40.00%

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details 7) (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Earnings per share
Net income (loss)									$ 48,828	$ 37,712	$ 37,656
Weighted average common shares, basic									41,892,000	41,762,000	41,612,000
Dilutive common stock options (treasury method) (in shares)										10,000	26,000
Shares used for dilutive computation									41,892,000	41,772,000	41,638,000
Net income per share - basic (in dollars per share)									$ 1.17	$ 0.90	$ 0.90
Diluted earnings per share (in dollars per share)	$ 0.12	$ 0.71	$ 0.31	$ 0.03	$ 0.04	$ 0.50	$ 0.29	$ 0.07	$ 1.17	$ 0.90	$ 0.90
Stock Appreciation Rights (SARs)
Stock-based awards included in earnings per share
Stock Appreciation Rights (SAR) outstanding	333,856				361,356				333,856	361,356	361,356

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OTHER ACCRUED LIABILITIES (Table)

12 Months Ended

Dec. 31, 2012

OTHER ACCRUED LIABILITIES

Schedule of other accrued liabilities

	2012		2011
Accrued and deferred compensation	$	16,320	$	14,143
Deferred tax liability		15,000		10,535
Accrued benefit and workers' compensation claims		6,906		5,222
Other		8,282		8,026
	$	46,508	$	37,926

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INCOME TAXES (Tables)

12 Months Ended

Dec. 31, 2012

INCOME TAXES

Schedule of income tax expense

	Federal			State			Total
2012
Current	$	(9,018	)	$	(5,246	)	$	(14,264	)
Deferred		37,196			(1,480	)		35,716
Total	$	28,178		$	(6,726	)	$	21,452
2011
Current	$	7,413		$	2,629		$	10,042
Deferred		12,982			142			13,124
Total	$	20,395		$	2,771		$	23,166
2010
Current	$	4,027		$	3,020		$	7,047
Deferred		15,730			1,779			17,509
Total	$	19,757		$	4,799		$	24,556

Schedule of differences in income tax expense computed by applying the current federal tax rate to pretax book income and the amount shown in the Consolidated Statements of Income

	2012			2011			2010
Computed "expected" tax expense	$	24,600		$	21,308		$	21,774
Increase (reduction) in taxes due to:
State income taxes net of federal tax benefit		4,041			3,500			3,577
Effect of regulatory treatment of fixed asset differences		(7,030	)		(1,614	)		—
Investment tax credits		(74	)		(74	)		(74	)
Other		(85	)		46			(721	)
Total income tax	$	21,452		$	23,166		$	24,556

Schedule of tax effects of differences that give rise to significant portions of the deferred tax assets and deferred tax liabilities

	2012		2011
Deferred tax assets:
Developer deposits for extension agreements and contributions in aid of construction	$	44,530	$	45,587
Net operating loss		8,437		1,015
Other		3,607		3,449
Total deferred tax assets		56,574		50,051
Deferred tax liabilities:
Utility plant, principally due to depreciation differences		207,642		155,916
WRAM/MCBA balancing accounts		19,533		17,393
Other		3,245		3,645
Total deferred tax liabilities		230,420		176,954
Net deferred tax liabilities	$	173,846	$	126,903

Schedule of reconciliation of changes in unrecognized tax benefits

	December 31, 2012			December 31, 2011
Balance at beginning of year	$	831		$	831
Additions for tax positions taken during prior year		—			—
Additions for tax positions taken during current year		—			—
Reductions for tax positions taken during a prior year		—			—
Lapse of statute of limitations		(831	)		—
Balance at end of year	$	—		$	831

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ORGANIZATION AND OPERATIONS

12 Months Ended

Dec. 31, 2012

ORGANIZATION AND OPERATIONS

ORGANIZATION AND OPERATIONS

1 ORGANIZATION AND OPERATIONS

        California Water Service Group (Company) is a holding company that provides water utility and other related services in California, Washington, New Mexico, and Hawaii through its wholly-owned subsidiaries. California Water Service Company (Cal Water), Washington Water Service Company (Washington Water), New Mexico Water Service Company (New Mexico Water), and Hawaii Water Service Company, Inc. (Hawaii Water) provide regulated utility services under the rules and regulations of their respective state's regulatory commissions (jointly referred to as the Commissions). CWS Utility Services and HWS Utility Services LLC provide non-regulated water utility and utility-related services.

        The Company operates in one reportable segment, providing water and related utility services.

• Basis of Presentation

        The consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (GAAP) and include the Company's accounts and those of its wholly owned subsidiaries. All intercompany transactions have been eliminated from the consolidated financial statements. In the opinion of management, the consolidated financial statements reflect all adjustments that are necessary to provide a fair presentation of the results for the periods covered.

        The preparation of the Company's consolidated financial statements in accordance with GAAP 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 consolidated balance sheet dates and the reported amounts of revenues and expenses for the periods presented. These include, but are not limited to, estimates and assumptions used in determining the Company's regulatory asset and liability balances based upon probability assessments of regulatory recovery, revenues earned but not yet billed, asset retirement obligations, allowance for doubtful accounts, pension and other employee benefit plan liabilities, and income tax-related assets and liabilities. Actual results could differ from these estimates.

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EMPLOYEE BENEFIT PLANS (Tables)

12 Months Ended

Dec. 31, 2012

EMPLOYEE BENEFIT PLANS

Summary of target asset allocation percentages for major categories of the pension plan

	Minimum Exposure			Target			Maximum Exposure
Fixed Income		35	%		40	%		45	%
Total Domestic Equity		40	%		50	%		60	%
Small Cap Stocks		10	%		15	%		20	%
Large Cap Stocks		30	%		35	%		45	%
Non-U.S. Equities		5	%		10	%		15	%

Schedule of fair value plan assets

	Pension Benefits										Other Benefits
	2012		%			2011		%			2012		%			2011		%
Fixed Income	$	79,391		39	%	$	79,859		51	%	$	22,845		61	%	$	16,006		59	%
Domestic Equity
Small Cap Stocks		33,949					27,262					—					—
Large Cap Stocks		69,406					40,689					14,563					10,972
Total Domestic Equity		103,355		51	%		67,951		44	%		14,563		39	%		10,972		41	%
Non U.S. Equities		20,201		10	%		7,939		5	%		—		0	%		—		0	%
Total Plan Assets	$	202,947		100	%	$	155,749		100	%	$	37,408		100	%	$	26,978		100	%

Schedule of reconciliation of the funded status of the plans with the accrued pension liability and the net postretirement benefit liability

	Pension Benefits						Other Benefits
	2012			2011			2012			2011
Change in projected benefit obligation:
Beginning of year	$	346,305		$	269,940		$	69,107		$	45,944
Service cost		15,450			11,713			4,399			3,199
Interest cost		15,287			14,683			3,139			2,872
Assumption change		24,269			59,028			7,673			12,600
Experience (gain) loss		4,833			(6,030	)		1,250			5,705
Benefits paid, net of retiree premiums		(4,023	)		(3,029	)		(1,147	)		(1,213	)
End of year	$	402,121		$	346,305		$	84,421		$	69,107
Change in plan assets:
Fair value of plan assets at beginning of year	$	155,749		$	139,034		$	26,978		$	21,178
Actual return on plan assets		21,979			555			2,788			64
Employer contributions		29,242			19,189			8,789			6,949
Retiree contributions and Medicare part D subsidies		—			—			1,255			1,130
Benefits paid		(4,023	)		(3,029	)		(2,402	)		(2,343	)
Fair value of plan assets at end of year	$	202,947		$	155,749		$	37,408		$	26,978
Funded status(1)	$	(199,174	)	$	(190,556	)	$	(47,013	)	$	(42,129	)
Unrecognized actuarial loss		133,579			123,177			40,449			34,515
Unrecognized prior service cost		41,972			47,976			421			537
Unrecognized transition obligation		—			—			9			285
Net amount recognized	$	(23,623	)	$	(19,403	)	$	(6,134	)	$	(6,792	)

(1)

The short-term portion of the pension benefits was $1,286 and $692 as of December 31, 2012 and 2011, respectively.

Schedule of amounts recognized in consolidated balance sheets

	Pension Benefits						Other Benefits
	2012			2011			2012			2011
Prepaid (Accrued) benefit costs	$	—		$	—		$	(6,723	)	$	(6,792	)
Accrued benefit liability		(199,174	)		(190,556	)		(47,013	)		(35,337	)
Regulatory asset		175,551			171,153			47,602			35,337
Net amount recognized	$	(23,623	)	$	(19,403	)	$	(6,134	)	$	(6,792	)

Schedule of actuarial assumptions used in determining the benefit obligation

	Pension Benefits						Other Benefits
	2012			2011			2012			2011
Weighted average assumptions as of December 31:
Discount rate		4.10	%		4.40	%		4.20	%		4.50	%
Long-term rate of return on plan assets		7.00	%		7.00	%		6.00	%		6.25	%
Rate of compensation increases		3.50	%		3.50	%		—			—
Cost of living adjustment		3.00	%		3.00	%		—			—

Schedule of sensitivity of pension amounts to changes in actuarial assumptions

	Increase/(Decrease) in Pension Actuarial Assumption			Increase/(Decrease) in 2012 Net Periodic Pension Benefit Cost			Increase/(Decrease) in Projected Pension Benefit Obligation as of December 31, 2012
Discount rate		(0.5	)%	$	4,280		$	40,189
Long-term rate of return on plan assets		(0.5	)%		826			—
Rate of compensation increases		(0.5	)%		(1,929	)		(11,227	)
Cost of living adjustment		(0.5	)%		(3,291	)		(24,427	)
Discount rate		0.5	%		(3,793	)		(35,196	)
Long-term rate of return on plan assets		0.5	%		(825	)		—
Rate of compensation increases		0.5	%		2,095			12,099

Components of net periodic benefit costs for the pension and other postretirement plans

	Pension Plan									Other Benefits
	2012			2011			2010			2012			2011			2010
Service cost	$	15,450		$	11,713		$	10,076		$	4,399		$	3,199		$	2,491
Interest cost		15,287			14,683			13,701			3,139			2,872			2,329
Expected return on plan assets		(11,558	)		(8,949	)		(8,228	)		(1,832	)		(1,372	)		(1,119	)
Net amortization and deferral		14,283			10,387			9,224			2,425			1,592			1,081
Net periodic benefit cost	$	33,462		$	27,834		$	24,773		$	8,131		$	6,291		$	4,782

Schedule of actuarial assumptions used in determining the net periodic benefit costs

	Pension Benefits						Other Benefits
	2012			2011			2012			2011
Weighted average assumptions as of December 31:
Discount rate		4.40	%		5.60	%		4.50	%		5.60	%
Long-term rate of return on plan assets		7.00	%		6.75	%		6.25	%		6.00	%
Rate of compensation increases		3.50	%		4.00	%		—			—

Schedule of the effect of a one-percentage point change in assumed health care cost trends

	1-Percentage Point Increase		1-Percentage Point Decrease
Effect on total service and interest costs	$	2,036	$	(1,506	)
Effect on accumulated postretirement benefit obligation	$	18,576	$	(14,147	)

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details 3) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Utility Plant
Interest capitalized on plant	$ 3,401	$ 2,741	$ 1,563

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INCOME TAXES (Details 2) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Income taxes
Federal income tax expense	$ 28,178,000	$ 20,395,000	$ 19,757,000
Deferred tax liability bonus depreciation	207,642,000	155,916,000
Reconciliation of the income tax expense computed by applying the current federal tax rate to pretax book income and the amount shown in the Consolidated Statements of Income
Computed expected tax expense	24,600,000	21,308,000	21,774,000
Increase (reduction) in taxes due to:
State income taxes net of federal tax benefit	4,041,000	3,500,000	3,577,000
Effect of regulatory treatment of fixed asset differences	(7,030,000)	(1,614,000)
Investment tax credits	(74,000)	(74,000)	(74,000)
Other	(85,000)	46,000	(721,000)
Total	21,452,000	23,166,000	24,556,000
Federal
Income taxes
Federal income tax repairs deduction for qualified tangible property	100,700,000
Deferred Tax Liabilities	35,300,000
Increase (decrease) to income tax expense	831,000	(397,000)	(433,000)
Deferred tax liability bonus depreciation	1,610,000	12,600,000
Current federal tax rate (as a percent)	35.00%
Federal | Lesser of
Income taxes
Qualified US production activities deduction rate of taxable income (as a percent)	9.00%
Qualified US production activities deduction rate of taxable gross wages (as a percent)	50.00%
State
Income taxes
Federal income tax repairs deduction for qualified tangible property	136,200,000
Increase (decrease) to income tax expense	(7,800,000)
State | State of California
Income taxes
Increase (decrease) to income tax expense		$ (1,600,000)

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Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Utility plant:
Land	$ 42,023	$ 37,703
Depreciable plant and equipment	1,903,365	1,807,569
Construction work in progress	132,362	98,623
Intangible assets	18,613	16,486
Total utility plant	2,096,363	1,960,381
Less accumulated depreciation and amortization	(639,307)	(579,262)
Net utility plant	1,457,056	1,381,119
Current assets:
Cash and cash equivalents	38,790	27,203
Receivables: net of allowance for doubtful accounts of $714 and $669, respectively
Customers	29,958	28,418
Regulatory balancing accounts	34,020	21,680
Other	11,943	6,422
Unbilled revenue	15,394	15,068
Materials and supplies at weighted average cost	5,874	5,913
Taxes, prepaid expenses, and other assets	10,585	9,184
Total current assets	146,564	113,888
Other assets:
Regulatory assets	344,419	319,898
Unamortized debt premium and expense	5,591	6,071
Goodwill	2,615	2,615
Other	39,679	30,996
Total other assets	392,304	359,580
Total assets	1,995,924	1,854,587
Capitalization:
Common stock, $0.01 par value; 68,000 shares authorized, 41,908 and 41,817, outstanding in 2012 and 2011, respectively	419	418
Additional paid-in capital	221,013	219,572
Retained earnings	252,280	229,839
Total common stockholders' equity	473,712	449,829
Long-term debt, less current maturities	434,467	481,632
Total capitalization	908,179	931,461
Current liabilities:
Current maturities of long-term debt	46,783	6,533
Short-term borrowings	89,475	47,140
Accounts payable	47,199	48,923
Regulatory balancing accounts	5,018	2,655
Accrued other taxes	3,379	3,942
Accrued interest	4,705	4,756
Other accrued liabilities	46,508	37,926
Total current liabilities	243,067	151,875
Unamortized investment tax credits	2,180	2,254
Deferred income taxes	158,846	116,368
Regulatory liabilities	35,720	28,037
Pension and postretirement benefits other than pension	244,901	232,110
Advances for construction	187,584	187,278
Contributions in aid of construction	158,574	154,191
Other long-term liabilities	56,873	51,013
Commitments and contingencies
Total capitalization and liabilities	$ 1,995,924	$ 1,854,587

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OTHER INCOME AND EXPENSES (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Other income and expenses
Revenue	$ 16,686	$ 16,160	$ 15,993
Expense	11,553	15,822	12,312
Operating and maintenance
Other income and expenses
Revenue	9,938	9,176	9,237
Expense	10,976	9,689	9,713
Meter reading and billing
Other income and expenses
Revenue	1,255	1,212	1,207
Expense	882	944	990
Leases
Other income and expenses
Revenue	1,956	1,892	2,162
Expense	153	330	877
Design and construction
Other income and expenses
Revenue	1,407	1,689	1,306
Expense	1,135	1,420	1,041
Interest income
Other income and expenses
Revenue	41	75	28
Change in value of life insurance contracts (gain) loss
Other income and expenses
Expense	(2,504)	1,876	(2,641)
Other non-regulated income and expenses
Other income and expenses
Revenue	2,089	2,116	2,053
Expense	$ 911	$ 1,563	$ 2,332

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Consolidated Statements of Common Stockholders' Equity (Parenthetical) (USD $)	3 Months Ended								12 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Consolidated Statements of Common Stockholders' Equity
Dividends paid on common stock (in dollars per share)	$ 0.1575	$ 0.1575	$ 0.1575	$ 0.1575	$ 0.15375	$ 0.15375	$ 0.15375	$ 0.15375	$ 0.630	$ 0.615	$ 0.595

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FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Fair Value of Financial Assets and Liabilities
Risk premium (as a percent)	1.19%
Carrying value of the long-term debt, including current maturities	$ 481,250	$ 488,165
Carrying value of the advances for construction contracts	187,584	187,278
Total carrying value	668,834	675,443
Level 2
Fair Value of Financial Assets and Liabilities
Long-term debt, including current maturities	613,211	625,202
Advances for construction	70,914	69,952
Total	684,125	695,154
Total
Fair Value of Financial Assets and Liabilities
Long-term debt, including current maturities	613,211	625,202
Advances for construction	70,914	69,952
Total	$ 684,125	$ 695,154

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QUARTERLY FINANCIAL DATA (UNAUDITED) (Tables)

12 Months Ended

Dec. 31, 2012

QUARTERLY FINANCIAL DATA (UNAUDITED)

Schedule of Quarterly Financial Data (Unaudited)

2012	First		Second		Third		Fourth
Operating revenue	$	116,749	$	143,552	$	178,135	$	121,530
Net operating income		6,607		19,622		36,361		11,253
Net income		1,085		12,965		29,772		5,006
Diluted earnings per share		0.03		0.31		0.71		0.12
Common stock market price range:
High		19.25		18.60		19.05		18.90
Low		17.67		17.14		17.93		16.84
Dividends paid per common share		0.1575		0.1575		0.1575		0.1575

2011	First		Second		Third		Fourth
Operating revenue	$	98,149	$	131,397	$	169,254	$	103,014
Net operating income		9,948		19,555		30,078		7,586
Net income		2,719		12,190		20,935		1,868
Diluted earnings per share		0.07		0.29		0.50		0.04
Common stock market price range:
High		19.18		19.16		19.37		19.20
Low		17.28		18.06		16.65		16.81
Dividends paid per common share		0.15375		0.15375		0.15375		0.15375

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CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Details 3) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Condensed Consolidating Financial Statements
Operating revenue	$ 121,530	$ 178,135	$ 143,552	$ 116,749	$ 103,014	$ 169,254	$ 131,397	$ 98,149	$ 559,966	$ 501,814	$ 460,399
Operations:
Purchased water									161,336	142,570	125,930
Purchased power									31,027	30,053	29,577
Pump taxes									10,336	9,130	8,600
Administrative and general									93,927	85,758	75,276
Other									77,104	54,696	56,518
Maintenance									19,142	20,698	19,685
Depreciation and amortization									54,668	50,385	42,828
Income taxes (benefits)									19,356	23,025	23,069
Taxes other than income taxes									19,227	18,332	17,103
Total operating expenses									486,123	434,647	398,586
Net operating income	11,253	36,361	19,622	6,607	7,586	30,078	19,555	9,948	73,843	67,167	61,813
Other Income and Expenses:
Non-regulated revenue									16,686	16,160	15,993
Non-regulated expense									(11,553)	(15,822)	(12,312)
Gain on sale on non-utility property									84	62	22
Income tax benefit (expense) on other income and expense									(2,096)	(141)	(1,487)
Net other income									3,121	259	2,216
Interest:
Interest expense									31,537	32,455	27,936
Less: capitalized interest									(3,401)	(2,741)	(1,563)
Net interest expense									28,136	29,714	26,373
Net income									48,828	37,712	37,656
Parent Company
Operations:
Income taxes (benefits)									(583)	(580)	(843)
Total operating expenses									(583)	(580)	(843)
Net operating income									583	580	843
Other Income and Expenses:
Non-regulated revenue									1,919	2,248	1,220
Income tax benefit (expense) on other income and expense									(782)	(916)	(497)
Net other income									1,137	1,332	723
Interest:
Interest expense									1,430	1,422	698
Net interest expense									1,430	1,422	698
Equity earnings of subsidiaries									48,538	37,222	36,788
Net income									48,828	37,712	37,656
Cal Water
Condensed Consolidating Financial Statements
Operating revenue									527,449	472,150	430,988
Operations:
Purchased water									160,913	142,355	125,749
Purchased power									21,435	20,719	21,616
Pump taxes									10,336	8,764	8,017
Administrative and general									84,399	77,622	67,536
Other									70,864	47,800	49,356
Maintenance									18,478	19,916	18,998
Depreciation and amortization									52,012	47,872	40,349
Income taxes (benefits)									18,992	23,727	23,812
Taxes other than income taxes									16,630	15,908	14,904
Total operating expenses									454,059	404,683	370,337
Net operating income									73,390	67,467	60,651
Other Income and Expenses:
Non-regulated revenue									15,204	12,972	10,064
Non-regulated expense									(9,588)	(12,287)	(7,954)
Gain on sale on non-utility property									81	62	22
Income tax benefit (expense) on other income and expense									(2,321)	(304)	(869)
Net other income									3,376	443	1,263
Interest:
Interest expense									30,328	31,421	27,059
Less: capitalized interest									(2,334)	(1,844)	(1,085)
Net interest expense									27,994	29,577	25,974
Net income									48,772	38,333	35,940
All Other Subsidiaries
Condensed Consolidating Financial Statements
Operating revenue									32,517	29,664	29,411
Operations:
Purchased water									423	215	181
Purchased power									9,592	9,334	7,961
Pump taxes										366	583
Administrative and general									9,528	8,136	7,740
Other									6,744	7,401	7,667
Maintenance									664	782	687
Depreciation and amortization									2,774	2,637	2,610
Income taxes (benefits)									(375)	(1,727)	(229)
Taxes other than income taxes									2,597	2,424	2,199
Total operating expenses									31,947	29,568	29,399
Net operating income									570	96	12
Other Income and Expenses:
Non-regulated revenue									2,420	4,322	6,670
Non-regulated expense									(1,965)	(3,535)	(4,358)
Income tax benefit (expense) on other income and expense									(266)	(422)	(1,027)
Net other income									189	365	1,285
Interest:
Interest expense									2,132	2,489	1,635
Less: capitalized interest									(1,067)	(897)	(478)
Net interest expense									1,065	1,592	1,157
Net income									(306)	(1,131)	140
Consolidating Adjustments
Operations:
Other									(504)	(505)	(505)
Depreciation and amortization									(118)	(124)	(131)
Income taxes (benefits)									1,322	1,605	329
Total operating expenses									700	976	(307)
Net operating income									(700)	(976)	307
Other Income and Expenses:
Non-regulated revenue									(2,857)	(3,382)	(1,961)
Gain on sale on non-utility property									3
Income tax benefit (expense) on other income and expense									1,273	1,501	906
Net other income									(1,581)	(1,881)	(1,055)
Interest:
Interest expense									(2,353)	(2,877)	(1,456)
Net interest expense									(2,353)	(2,877)	(1,456)
Equity earnings of subsidiaries									(48,538)	(37,222)	(36,788)
Net income									$ (48,466)	$ (37,202)	$ (36,080)

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QUARTERLY FINANCIAL DATA (UNAUDITED)

12 Months Ended

Dec. 31, 2012

QUARTERLY FINANCIAL DATA (UNAUDITED)

QUARTERLY FINANCIAL DATA (UNAUDITED)

15 QUARTERLY FINANCIAL DATA (UNAUDITED)

        The Company's common stock is traded on the New York Stock Exchange under the symbol "CWT."

2012	First		Second		Third		Fourth
Operating revenue	$	116,749	$	143,552	$	178,135	$	121,530
Net operating income		6,607		19,622		36,361		11,253
Net income		1,085		12,965		29,772		5,006
Diluted earnings per share		0.03		0.31		0.71		0.12
Common stock market price range:
High		19.25		18.60		19.05		18.90
Low		17.67		17.14		17.93		16.84
Dividends paid per common share		0.1575		0.1575		0.1575		0.1575

2011	First		Second		Third		Fourth
Operating revenue	$	98,149	$	131,397	$	169,254	$	103,014
Net operating income		9,948		19,555		30,078		7,586
Net income		2,719		12,190		20,935		1,868
Diluted earnings per share		0.07		0.29		0.50		0.04
Common stock market price range:
High		19.18		19.16		19.37		19.20
Low		17.28		18.06		16.65		16.81
Dividends paid per common share		0.15375		0.15375		0.15375		0.15375

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CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Tables)

12 Months Ended

Dec. 31, 2012

CONDENSED CONSOLIDATING FINANCIAL STATEMENTS

Schedule of Condensed Consolidating Balance Sheet

As of December 31, 2012

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
ASSETS
Utility plant:
Utility plant	$	606		$	1,927,190		$	175,764		$	(7,197	)	$	2,096,363
Less accumulated depreciation and amortization		(108	)		(607,992	)		(32,710	)		1,503			(639,307	)
Net utility plant		498			1,319,198			143,054			(5,694	)		1,457,056
Current assets:
Cash and cash equivalents		1,470			34,609			2,711			—			38,790
Receivables		—			87,482			3,833			—			91,315
Receivables from affiliates		19,367			3,195			1,152			(23,714	)		—
Other current assets		—			15,535			924			—			16,459
Total current assets		20,837			140,821			8,620			(23,714	)		146,564
Other assets:
Regulatory assets		—			341,877			2,542			—			344,419
Investments in affiliates		492,188			—			—			(492,188	)		—
Long-term affiliate notes receivable		31,218			7,781			—			(38,999	)		—
Other assets		1,023			40,005			7,062			(205	)		47,885
Total other assets		524,429			389,663			9,604			(531,392	)		392,304
	$	545,764		$	1,849,682		$	161,278		$	(560,800	)	$	1,995,924
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stockholders' equity	$	473,712		$	442,923		$	54,774		$	(497,697	)	$	473,712
Affiliate long-term debt		7,781			—			31,218			(38,999	)		—
Long-term debt, less current maturities		—			431,433			3,034			—			434,467
Total capitalization		481,493			874,356			89,026			(536,696	)		908,179
Current liabilities:
Current maturities of long-term debt		—			46,104			679			—			46,783
Short-term borrowings		64,475			25,000			—			—			89,475
Payables to affiliates		77			1,152			22,485			(23,714	)		—
Accounts payable		—			41,352			5,847			—			47,199
Accrued expenses and other liabilities		298			58,293			1,019			—			59,610
Total current liabilities		64,850			171,901			30,030			(23,714	)		243,067
Unamortized investment tax credits		—			2,180			—			—			2,180
Deferred income taxes, net		(579	)		155,481			4,334			(390	)		158,846
Pension and postretirement benefits other than pensions		—			244,901			—			—			244,901
Regulatory and other liabilities		—			83,942			8,651			—			92,593
Advances for construction		—			186,753			831			—			187,584
Contributions in aid of construction		—			130,168			28,406			—			158,574
	$	545,764		$	1,849,682		$	161,278		$	(560,800	)	$	1,995,924

As of December 31, 2011

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
ASSETS
Utility plant:
Utility plant	$	324		$	1,808,568		$	158,688		$	(7,199	)	$	1,960,381
Less accumulated depreciation and amortization		(51	)		(551,345	)		(29,251	)		1,385			(579,262	)
Net utility plant		273			1,257,223			129,437			(5,814	)		1,381,119
Current assets:
Cash and cash equivalents		89			18,475			8,639			—			27,203
Receivables		158			76,227			(4,797	)		—			71,588
Receivables from affiliates		7,817			3,446			5			(11,268	)		—
Other current assets		—			14,225			872			—			15,097
Total current assets		8,064			112,373			4,719			(11,268	)		113,888
Other assets:
Regulatory assets		—			317,564			2,334			—			319,898
Investments in affiliates		466,515			—			—			(466,515	)		—
Long-term affiliate notes receivable		28,921			7,832			—			(36,753	)		—
Other assets		1,144			31,662			7,081			(205	)		39,682
Total other assets		496,580			357,058			9,415			(503,473	)		359,580
	$	504,917		$	1,726,654		$	143,571		$	(520,555	)	$	1,854,587
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stockholders' equity	$	449,829		$	417,810		$	54,377		$	(472,187	)	$	449,829
Affiliate long-term debt		7,832			—			28,921			(36,753	)		—
Long-term debt, less current maturities		—			477,998			3,634			—			481,632
Total capitalization		457,661			895,808			86,932			(508,940	)		931,461
Current liabilities:
Current maturities of long-term debt		—			5,851			682			—			6,533
Short-term borrowings		47,140			—			—			—			47,140
Payables to affiliates		52			190			11,026			(11,268	)		—
Accounts payable		—			47,568			4,010			—			51,578
Accrued expenses and other liabilities		625			46,462			(547	)		84			46,624
Total current liabilities		47,817			100,071			15,171			(11,184	)		151,875
Unamortized investment tax credits		—			2,254			—			—			2,254
Deferred income taxes, net		(561	)		113,925			3,435			(431	)		116,368
Pension and postretirement benefits other than pensions		—			232,110			—			—			232,110
Regulatory and other liabilities		—			71,034			8,016			—			79,050
Advances for construction		—			185,902			1,376			—			187,278
Contributions in aid of construction		—			125,550			28,641			—			154,191
	$	504,917		$	1,726,654		$	143,571		$	(520,555	)	$	1,854,587

Schedule of Condensed Consolidating Statement of Income

For the Year Ended December 31, 2012

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating revenue	$	—		$	527,449		$	32,517		$	—		$	559,966
Operating expenses:
Operations:
Purchased water		—			160,913			423			—			161,336
Purchased power		—			21,435			9,592			—			31,027
Pump taxes		—			10,336			—			—			10,336
Administrative and general		—			84,399			9,528			—			93,927
Other		—			70,864			6,744			(504	)		77,104
Maintenance		—			18,478			664			—			19,142
Depreciation and amortization		—			52,012			2,774			(118	)		54,668
Income taxes (benefits)		(583	)		18,992			(375	)		1,322			19,356
Taxes other than income taxes		—			16,630			2,597			—			19,227
Total operating expenses (income)		(583	)		454,059			31,947			700			486,123
Net operating income		583			73,390			570			(700	)		73,843
Other Income and Expenses:
Non-regulated revenue		1,919			15,204			2,420			(2,857	)		16,686
Non-regulated expense		—			(9,588	)		(1,965	)		—			(11,553	)
Gain on sale on non-utility property		—			81			—			3			84
Income tax benefit (expense) on other income and expense		(782	)		(2,321	)		(266	)		1,273			(2,096	)
Net other income (expense)		1,137			3,376			189			(1,581	)		3,121
Interest:
Interest expense		1,430			30,328			2,132			(2,353	)		31,537
Less: capitalized interest		—			(2,334	)		(1,067	)		—			(3,401	)
Net interest expense		1,430			27,994			1,065			(2,353	)		28,136
Equity earnings of subsidiaries		48,538			—			—			(48,538	)		—
Net income	$	48,828		$	48,772		$	(306	)	$	(48,466	)	$	48,828

For the Year Ended December 31, 2011

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating revenue	$	—		$	472,150		$	29,664		$	—		$	501,814
Operating expenses:
Operations:
Purchased water		—			142,355			215			—			142,570
Purchased power		—			20,719			9,334			—			30,053
Pump taxes		—			8,764			366			—			9,130
Administrative and general		—			77,622			8,136			—			85,758
Other		—			47,800			7,401			(505	)		54,696
Maintenance		—			19,916			782			—			20,698
Depreciation and amortization		—			47,872			2,637			(124	)		50,385
Income taxes (benefits)		(580	)		23,727			(1,727	)		1,605			23,025
Taxes other than income taxes		—			15,908			2,424			—			18,332
Total operating expenses (income)		(580	)		404,683			29,568			976			434,647
Net operating income		580			67,467			96			(976	)		67,167
Other Income and Expenses:
Non-regulated revenue		2,248			12,972			4,322			(3,382	)		16,160
Non-regulated expense		—			(12,287	)		(3,535	)		—			(15,822	)
Gain on sale on non-utility property		—			62			—			—			62
Income tax benefit (expense) on other income and expense		(916	)		(304	)		(422	)		1,501			(141	)
Net other income (expense)		1,332			443			365			(1,881	)		259
Interest:
Interest expense		1,422			31,421			2,489			(2,877	)		32,455
Less: capitalized interest		—			(1,844	)		(897	)		—			(2,741	)
Net interest expense		1,422			29,577			1,592			(2,877	)		29,714
Equity earnings of subsidiaries		37,222			—			—			(37,222	)		—
Net income	$	37,712		$	38,333		$	(1,131	)	$	(37,202	)	$	37,712

For the Year Ended December 31, 2010

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating revenue	$	—		$	430,988		$	29,411		$	—		$	460,399
Operating expenses:
Operations:
Purchased water		—			125,749			181			—			125,930
Purchased power		—			21,616			7,961			—			29,577
Pump taxes		—			8,017			583			—			8,600
Administrative and general		—			67,536			7,740			—			75,276
Other		—			49,356			7,667			(505	)		56,518
Maintenance		—			18,998			687			—			19,685
Depreciation and amortization		—			40,349			2,610			(131	)		42,828
Income taxes (benefits)		(843	)		23,812			(229	)		329			23,069
Taxes other than income taxes		—			14,904			2,199			—			17,103
Total operating expenses (income)		(843	)		370,337			29,399			(307	)		398,586
Net operating income		843			60,651			12			307			61,813
Other Income and Expenses:
Non-regulated revenue		1,220			10,064			6,670			(1,961	)		15,993
Non-regulated expense		—			(7,954	)		(4,358	)		—			(12,312	)
Gain on sale on non-utility property		—			22			—			—			22
Income tax benefit (expense) on other income and expense		(497	)		(869	)		(1,027	)		906			(1,487	)
Net other income (expense)		723			1,263			1,285			(1,055	)		2,216
Interest:
Interest expense		698			27,059			1,635			(1,456	)		27,936
Less: capitalized interest		—			(1,085	)		(478	)		—			(1,563	)
Net interest expense		698			25,974			1,157			(1,456	)		26,373
Equity earnings of subsidiaries		36,788			—			—			(36,788	)		—
Net income	$	37,656		$	35,940		$	140		$	(36,080	)	$	37,656

Schedule of Condensed Consolidating Statement of Cash Flows

For the Year Ended December 31, 2012

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating activities:
Net income (loss)	$	48,828		$	48,772		$	(306	)	$	(48,466	)	$	48,828
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Equity earnings of subsidiaries		(48,538	)		—			—			48,538			—
Dividends received from affiliates		26,387			—			—			(26,387	)		—
Depreciation and amortization		56			54,040			2,888			(118	)		56,866
Change in value of life insurance contracts		—			(2,504	)		—			—			(2,504	)
Gain on sale of non-utility property		—			(81	)		—			(3	)		(84	)
Changes in deferred income taxes		—			34,133			—			—			34,133
Other changes in noncurrent assets and liabilities		1,544			(10,367	)		1,307			133			(7,383	)
Changes in operating assets and liabilities:
Other changes, net		(170	)		9,035			(6,723	)		(84	)		2,058
Net adjustments		(20,721	)		84,256			(2,528	)		22,079			83,086
Net cash provided by (used in) operating activities		28,107			133,028			(2,834	)		(26,387	)		131,914
Investing activities:
Utility plant expenditures		(281	)		(111,636	)		(15,761	)		(3	)		(127,681	)
Proceeds from sale of non-utility assets		—			82			—			3			85
Affiliate advances		(12,245	)		254			(853	)		12,844			—
Proceeds from affiliate loans		552			48			—			(600	)		—
Reduction of loans to affiliates		(5,675	)		—			—			5,675			—
Purchase of life insurance		—			(3,294	)		—			—			(3,294	)
Restricted cash decrease		—			1,959			—			—			1,959
Net cash (used in) investing activities		(17,649	)		(112,587	)		(16,614	)		17,919			(128,931	)
Financing Activities:
Short-term borrowings		18,335			76,000			—			—			94,335
Repayment of short-term borrowings		(1,000	)		(51,000	)		—			—			(52,000	)
Affiliate advances		23			962			11,859			(12,844	)		—
Proceeds from affiliates long-term borrowings		—			—			5,675			(5,675	)		—
Reduction of affiliate long-term borrowings		(48	)		—			(552	)		600			—
Proceeds from long-term debt		—			—			124			—			124
Retirement of long-term debt		—			(6,310	)		(727	)		—			(7,037	)
Advances and contributions in aid for construction		—			6,883			83			—			6,966
Refunds of advances for construction		—			(7,275	)		(122	)		—			(7,397	)
Dividends paid to non-affiliates		(26,387	)		—			—			—			(26,387	)
Dividends paid to affiliates		—			(23,567	)		(2,820	)		26,387			—
Net cash (used in) provided by financing activities		(9,077	)		(4,307	)		13,520			8,468			8,604
Change in cash and cash equivalents		1,381			16,134			(5,928	)		—			11,587
Cash and cash equivalents at beginning of year		89			18,475			8,639			—			27,203
Cash and cash equivalents at end of year	$	1,470		$	34,609		$	2,711		$	—		$	38,790

For the Year Ended December 31, 2011

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating activities:
Net income (loss)	$	37,712		$	38,333		$	(1,131	)	$	(37,202	)	$	37,712
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Equity earnings of subsidiaries		(37,222	)		—			—			37,222			—
Dividends received from affiliates		25,674			—			—			(25,674	)		—
Depreciation and amortization		51			49,283			2,771			(124	)		51,981
Change in value of life insurance contracts		—			1,876			—			—			1,876
Gain on sale of non-utility property		—			(62	)		—			—			(62	)
Section 481 adjustment		—			2,723			—			—			2,723
Other changes in noncurrent assets and liabilities		1,001			(45	)		684			53			1,693
Changes in operating assets and liabilities:
Other changes, net		582			11,662			3,054			51			15,349
Net adjustments		(9,914	)		65,437			6,509			11,528			73,560
Net cash provided by operating activities		27,798			103,770			5,378			(25,674	)		111,272
Investing activities:
Utility plant expenditures		—			(98,410	)		(20,136	)		—			(118,546	)
Proceeds from sale of non-utility assets		—			64			—			—			64
Affiliate advances		(25,495	)		1,597			—			23,898			—
Reduction of loans to affiliates		962			45			2,000			(3,007	)		—
Purchase of life insurance		—			(1,744	)		—			—			(1,744	)
Restricted cash increase		—			(3,042	)		—			—			(3,042	)
Net cash (used in) investing activities		(24,533	)		(101,490	)		(18,136	)		20,891			(123,268	)
Financing Activities:
Short-term borrowings		23,390			—			—			—			23,390
Affiliate advances		—			—			23,898			(23,898	)		—
Reduction of affiliate long-term borrowings		(2,045	)		—			(962	)		3,007			—
Proceeds from long-term debt, net of issuance cost of $1,857		—			—			178			—			178
Retirement of long-term debt		—			(2,279	)		(684	)		—			(2,963	)
Advances and contributions in aid for construction		—			7,082			149			—			7,231
Refunds of advances for construction		—			(6,129	)		(76	)		—			(6,205	)
Dividends paid to non-affiliates		(25,674	)		—			—			—			(25,674	)
Dividends paid to affiliates		—			(22,925	)		(2,749	)		25,674			—
Issuance of common stock		965			—			—			—			965
Net cash (used in) provided by financing activities		(3,364	)		(24,251	)		19,754			4,783			(3,078	)
Change in cash and cash equivalents		(99	)		(21,971	)		6,996			—			(15,074	)
Cash and cash equivalents at beginning of year		188			40,446			1,643			—			42,277
Cash and cash equivalents at end of year	$	89		$	18,475		$	8,639		$	—		$	27,203

For the Year Ended December 31, 2010

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating activities:
Net income	$	37,656		$	35,940		$	140		$	(36,080	)	$	37,656
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Equity earnings of subsidiaries		(36,788	)		—			—			36,788			—
Dividends received from affiliates		24,753			—			—			(24,753	)		—
Depreciation and amortization		—			42,680			2,716			(131	)		45,265
Other changes in noncurrent assets and liabilities		229			(880	)		1,089			(598	)		(160	)
Change in value of life insurance contracts		—			(2,641	)		—			—			(2,641	)
Gain on sale of non-utility property		—			(22	)		—			—			(22	)
Changes in operating assets and liabilities:
Other changes, net		(1,054	)		(997	)		(2,558	)		21			(4,588	)
Net adjustments		(12,860	)		38,140			1,247			11,327			37,854
Net cash provided by operating activities		24,796			74,080			1,387			(24,753	)		75,510
Investing activities:
Utility plant expenditures		(324	)		(108,990	)		(14,612	)		—			(123,926	)
Proceeds from sale of non-utility assets		—			34			—			—			34
Affiliate advances		(14,579	)		85			—			14,494			—
Reduction of loans to affiliates		1,854			—			—			(1,854	)		—
Purchase of life insurance		—			(1,891	)		—			—			(1,891	)
Restricted cash decrease		—			3,169			—			—			3,169
Net cash (used in) investing activities		(13,049	)		(107,593	)		(14,612	)		12,640			(122,614	)
Financing Activities:
Short-term borrowings		16,750			69,000			—			—			85,750
Repayment of short-term borrowings		(5,000	)		(69,000	)		—			—			(74,000	)
Affiliate advances		—			—			14,494			(14,494	)		—
Reduction of affiliate note payable		—			—			(1,854	)		1,854			—
Proceeds from long-term debt, net of issuance cost of $1,857		—			103,947			2,226			—			106,173
Retirement of long-term debt		—			(12,212	)		(1,480	)		—			(13,692	)
Advances and contributions in aid for construction		—			4,962			351			—			5,313
Refunds of advances for construction		—			(6,104	)		(84	)		—			(6,188	)
Dividends paid to non-affiliates		(24,753	)		—			—			—			(24,753	)
Dividends paid to affiliates		—			(22,634	)		(2,119	)		24,753			—
Issuance of common stock		912			—			—			—			912
Net cash (used in) provided by financing activities		(12,091	)		67,959			11,534			12,113			79,515
Change in cash and cash equivalents		(344	)		34,446			(1,691	)		—			32,411
Cash and cash equivalents at beginning of year		532			6,000			3,334			—			9,866
Cash and cash equivalents at end of year	$	188		$	40,446		$	1,643		$	—		$	42,277

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

12 Months Ended

Dec. 31, 2012

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Revenue

• Revenue

        Revenue generally includes monthly cycle customer billings for regulated water and wastewater services at rates authorized by regulatory commissions (plus an estimate for water used between the customer's last meter reading and the end of the accounting period) and billings to certain non-regulated customers at rates authorized by contract with government agencies.

        The Company's regulated water and waste water revenue requirements are authorized by the Commissions in the states in which we operate. The revenue requirements are intended to provide the Company a reasonable opportunity to recover its operating costs and earn a return on investments.

        For metered customers, Cal Water recognizes revenue from rates which are designed and authorized by the California Public Utilities Commission (CPUC). Under the Water Revenue Adjustment Mechanism (WRAM), Cal Water records the adopted level of volumetric revenues, which would include recovery of cost of service and a return on investments, as established by the CPUC for metered accounts (adopted volumetric revenues). In addition to volumetric-based revenues, the revenue requirements approved by the CPUC include service charges, flat rate charges, and other items not subject to the WRAM. The adopted volumetric revenue considers the seasonality of consumption of water based upon historical averages. The variance between adopted volumetric revenues and actual billed volumetric revenues for metered accounts is recorded as a component of revenue with an offsetting entry to a regulatory asset or liability balancing account (tracked individually for each Cal Water district) subject to certain criteria under the accounting for regulated operations being met. The variance amount may be positive or negative and represents amounts that will be billed or refunded to customers in the future.

        Cost-recovery rates are designed to permit full recovery of certain costs allowed to be recovered by the Commissions. Cost-recovery rates such as the Modified Cost Balancing Account (MCBA) provides for recovery of adopted expense levels for purchased water, purchased power and pump taxes, as established by the CPUC. In addition, cost-recovery rates include recovery of cost related to water conservation programs and certain other operating expenses adopted by the CPUC. Variances (which include the effects of changes in both rate and volume for the MCBA) between adopted and actual costs are recorded as a component of revenue, as the amount of such variances will be recovered from or refunded to our customers at a later date. There is no markup for return or profit for cost-recovery expenses and they are generally recognized when expenses are incurred.

        The balances in the WRAM and MCBA assets and liabilities accounts will fluctuate on a monthly basis depending upon the variance between adopted and actual results. The recovery or refund of the WRAM is netted against the MCBA over- or under-recovery for the corresponding district and is interest bearing at the current 90 day commercial paper rate. At the end of any calendar year, Cal Water files with the CPUC to refund or collect the balance in the accounts. Most undercollected net WRAM and MCBA receivable balances are collected over 12 and 18 months. Cal Water defers net WRAM and MCBA operating revenues and associated costs whenever the net receivable balances are estimated to be collected more than 24 months after the respective reporting periods in which it was recognized. The deferred net WRAM and MCBA revenues and associated costs were determined using forecasts of rate payer consumption trends in future reporting periods and the timing of when the CPUC will authorize Cal Water's filings to recover the undercollected balances. Deferred net WRAM and MCBA revenues and associated costs will be recognized as revenues and costs in future periods when collection is within twenty-four months of the respective reporting period.

        The change to net WRAM and MCBA deferred balances:

	Operating Revenues			Operating Costs			Income Before Income Taxes
Net WRAM and MCBA deferred balances as of December 31, 2011	$	12,864		$	10,492		$	2,372
Reversal of deferred amounts during 2012		(12,864	)		(10,492	)		(2,372	)
Deferred amounts added during 2012		882			719			163
Net WRAM and MCBA deferred balances as of December 31, 2012	$	882		$	719		$	163

        The net undercollected WRAM and MCBA receivable balances as of December 31, 2012 and 2011 were:

	2012		2011
Net short-term receivable	$	34,020	$	19,357
Net long-term receivable		12,051		30,268
Total receivable	$	46,071	$	49,625
Net short-term payable	$	371	$	543
Net long-term payable		119		145
Total payable	$	490	$	688

        Flat rate customers are billed in advance at the beginning of the service period. The revenue is prorated so that the portion of revenue applicable to the current period is included in that period's revenue, with the balance recorded as unearned revenue on the balance sheet and recognized as revenue when earned in the subsequent accounting period. Our unearned revenue liability was $1,708 and $1,871 as of December 31, 2012 and 2011, respectively. This liability is included in "other accrued liabilities" on our consolidated balance sheets.

Allowance for Doubtful Accounts

• Allowance for Doubtful Accounts

        The Company provides an allowance for doubtful accounts receivable. The allowance is based upon specific identified accounts plus an estimate of uncollectible accounts based upon historical percentages. The balance of customer receivables is net of the allowance for doubtful accounts at December 31, 2012 and 2011 of $714 and $669, respectively.

        The activities in the allowance for doubtful accounts are as follows:

	2012			2011			2010
Beginning Balance	$	669		$	804		$	847
Provision for uncollectible accounts		1,548			1,250			1,500
Net write off of uncollectible accounts		(1,503	)		(1,385	)		(1,543	)
Ending Balance	$	714		$	669		$	804

Non-Regulated Revenue

• Non-Regulated Revenue

        Revenues from non-regulated operations and maintenance agreements are recognized when services have been rendered to companies or municipalities under such agreements. For construction and design services, revenue is generally recognized on the completed contract method, as most projects are completed in less than three months. Other non-regulated revenue is recognized when title has transferred to the buyer, or ratably over the term of the lease.

Utility Plant

• Utility Plant

        Utility plant is carried at original cost when first constructed or purchased, or at fair value when acquired through acquisition. When depreciable plant is retired, the cost is eliminated from utility plant accounts and such costs are charged against accumulated depreciation. Maintenance of utility plant is charged to operating expenses as incurred. Maintenance projects are not accrued for in advance. Interest is capitalized on plant expenditures during the construction period and amounted to $3,401 in 2012, $2,741 in 2011, and $1,563 in 2010.

        Intangible assets acquired as part of water systems purchased are recorded at fair value. All other intangibles have been recorded at cost and are amortized over their useful life.

        The following table represents depreciable plant and equipment as of December 31:

	2012		2011
Equipment	$	400,610	$	382,195
Transmission and distribution plant		1,351,158		1,287,010
Office buildings and other structures		151,597		138,364
Total	$	1,903,365	$	1,807,569

        Depreciation of utility plant for financial statement purposes is computed on a straight-line basis over the assets' estimated useful lives including cost of removal of certain assets as follows:

	Useful Lives
Equipment	5 to 50 years
Transmission and distribution plant	40 to 65 years
Office Buildings and other structures	50 years

        The provision for depreciation expressed as a percentage of the aggregate depreciable asset balances was 3.1% in 2012, 3.0% in 2011, and 2.8% 2010. For income tax purposes, as applicable, the Company computes depreciation using the accelerated methods allowed by the respective taxing authorities.

Asset Retirement Obligation

• Asset Retirement Obligation

        The Company has a legal obligation to retire wells in accordance with Department of Public Health regulations. In addition, upon decommission of a wastewater plant or lift station certain wastewater infrastructure would need to be retired in accordance with Department of Public Health regulations. The Company has collected retirement obligation costs from ratepayers through depreciation expense. As of December 31, 2012 and 2011 the retirement obligation is estimated to be $16,105 and $14,049, respectively. The change only impacted the consolidated balance sheet.

Cash Equivalents

• Cash Equivalents

        Cash equivalents include highly liquid investments with remaining maturities of three months or less at the time of acquisition.

Restricted Cash

• Restricted Cash

        In 2012 restricted cash includes $1.0 million of Cal Water and a third party cash deposits for a capital project. It also includes $1.1 million of proceeds collected through a surcharge on certain customers' bills plus interest earned on the proceeds and is used to service California Safe Drinking Water Bond obligations. All restricted cash is included in prepaid expenses. At December 31, 2012 and 2011, restricted cash was $2,266 and $4,225, respectively.

Regulatory Assets and Liabilities

• Regulatory Assets and Liabilities

        Regulatory assets and liabilities were comprised of the following as of December 31:

	2012		2011
Regulatory Assets
Pension and retiree group health	$	223,153	$	213,819
Income tax temporary differences		56,991		34,664
Other accrued benefits		40,362		31,453
Net WRAM and MCBA long-term accounts receivable		12,051		30,268
Asset retirement obligations, net		11,862		9,694
Total Regulatory Assets	$	344,419	$	319,898
Regulatory Liabilities
Future tax benefits due ratepayers	$	24,932	$	16,978
Conservation program		6,538		4,328
Pension balancing account		—		1,936
Other liabilities		4,250		4,795
Total Regulatory Liabilities	$	35,720	$	28,037

        Short-term regulatory assets and liabilities are excluded from the above table. The short-term regulatory assets for 2012 and 2011 were $34,020 and $21,680, respectively. The short-term regulatory assets were primarily net WRAM/MCBA receivable balances. The short-term portion of regulatory liabilities for 2012 and 2011 were $5,018 and $2,655, respectively.

        The Company operates extensively in a regulated business, and as such is subject to the accounting standards for regulated utilities. Utility companies defer costs and credits on the balance sheet as regulatory assets and liabilities when it is probable that those costs and credits will be recognized in the ratemaking process in a period different from the period in which they would have been reflected in income by an unregulated company. Regulatory assets other than WRAM represent deferral of costs that will be recovered in the future and do not include a return. In determining the probability of costs being recognized in other periods, the Company considers regulatory rules and decisions, past practices, and other facts or circumstances that would indicate if recovery is probable. In the event that a portion of the Company's operations were no longer subject to the accounting standards for regulated utilities, the Company would be required to write off related regulatory assets and liabilities. If a commission determined that a portion of the Company's assets were not recoverable in customer rates, the Company would be required to determine if the Company had suffered an asset impairment that would require a write-down in the assets' valuation.

        The Company's qualified, defined-benefit, non-contributory pension plan and other postretirement plan benefit (Retire Group Health) regulatory asset is the amount the Company expects to recover from ratepayers in the future for these plans at the end of the calendar year, which also includes amounts that otherwise would be recorded to accumulated other comprehensive loss in the Consolidated Balance Sheet.

        The income tax temporary differences relate primarily to the difference between book and federal income tax depreciation on utility plant that was placed in service before the regulatory Commissions adopted normalization for rate making purposes. Previously, the tax benefit of tax depreciation was passed on to customers (flow-through). For state income tax purposes, the Commission continues to use the flow-through method. As such timing differences reverse, the Company will be able to include the impact of such differences in customer rates. These federal tax differences will continue to reverse over the remaining book lives of the related assets.

        Other accrued benefits are accrued benefits for vacation, self-insured workers' compensation, and directors' retirement benefits. The net WRAM and MCBA long-term accounts receivable is the undercollected portion of recorded revenues that are not expected to be collected from ratepayers within 12 months. The asset retirement obligations is recorded net of depreciation which has been recorded and recognized through the regulatory process over the remaining useful life of the related asset.

        The future tax benefits regulatory liability are future benefits to ratepayers for tax deductions that will be allowed in the future. Regulatory liabilities also reflect timing differences provided at higher than the current tax rate, which will flow-through to future ratepayers. The conservation program regulatory liability is for cost recovery in rates that exceeded incurred costs and is refundable to ratepayers as of December 31, 2012.

Impairment of Long-Lived Assets, Intangibles and Goodwill

• Impairment of Long-Lived Assets, Intangibles and Goodwill

        The Company regularly reviews its long-lived assets, intangible assets and goodwill for impairment annually or when events or changes in business circumstances have occurred that indicate the carrying amount of such assets may not be fully realizable. Potential impairment of assets held for use is determined by comparing the carrying amount of an asset to the future undiscounted cash flows expected to be generated by the asset. If assets are considered to be impaired, the impairment to be recognized is measured as the amount by which the carrying value of the asset exceeds its fair value. In the 2010 Hawaii Water GRC for the Ka'anapali Water District, construction costs of $320 were removed from rate base and expensed as a non-regulated expense during 2011 and in the Cal Water 2009 GRC settlement, construction costs of $634 were removed from rate base and expensed to non-regulated expense during 2010.

        Goodwill is measured as the excess of the cost of an acquisition over the sum of the amounts assigned to identifiable assets acquired less liabilities assumed. Goodwill and other identifiable intangible assets are accounted for in accordance with generally accepted accounting principles. Goodwill is not amortized but instead is reviewed annually at November 30^th for impairment or more frequently if impairment indicators arise.

        The impairment test is performed at the reporting unit level using a two-step, fair-value based approach. The first step determines the fair value of the reporting unit and compares it to the reporting unit's carrying value. If the fair value of the reporting unit is less than its carrying amount, a second step is performed to measure the amount of impairment loss, if any. The second step allocates the fair value of the reporting unit to the Company's tangible and intangible assets and liabilities. This derives an implied fair value for the reporting unit's goodwill. If the carrying amount of the reporting unit's goodwill exceeds the implied fair value of that goodwill, an impairment loss is recognized equal to the excess.

        The recorded goodwill balance as of December 31, 2012 and 2011, relate to the Hawaii Water Service Company reporting unit. Based on our annual goodwill impairment test, no impairment was recorded in 2012 or 2011.

Long-Term Debt Premium, Discount and Expense

• Long-Term Debt Premium, Discount and Expense

        The discount and issuance expense on long-term debt is amortized over the original lives of the related debt on a straight-line basis which approximates the effective interest method. Premiums paid on the early redemption of certain debt and the unamortized original issuance discount and expense are amortized over the life of new debt issued in conjunction with the early redemption. Amortization expense included in interest expense was $1,107, $1,082, and $979 for 2012, 2011, and 2010, respectively.

Advances for Construction

• Advances for Construction

        Advances for Construction consist of payments received from developers for installation of water production and distribution facilities to serve new developments. Advances are excluded from rate base for rate setting purposes. Annual refunds are made to developers without interest. Advances of $186,753, and $185,902 at December 31, 2012 and 2011, respectively, will be refunded primarily over a 40-year period in equal annual amounts. In addition, other Advances for Construction totaling $831 and $1,376 at December 31, 2012, and 2011, respectively, are refundable based upon customer connections. Estimated refunds of advances for each succeeding year (2013 through 2017) are approximately $7,179, $7,178, $7,115, $7,098, $7,081 and $151,102 thereafter.

Contributions in Aid of Construction

• Contributions in Aid of Construction

        Contributions in Aid of Construction represent payments received from developers, primarily for fire protection purposes, which are not subject to refunds. Facilities funded by contributions are included in utility plant, but excluded from rate base. Depreciation related to assets acquired from contributions is charged to the Contributions in Aid of Construction account.

Income Taxes

• Income Taxes

        The Company accounts for income taxes using the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Measurement of the deferred tax assets and liabilities is at enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the period that includes the enactment date.

        Historically the Commissions have allowed revenue requirements for the tax effects of temporary differences recognized, which have previously been flowed through to customers. The Commissions have granted the Company rate increases to reflect the normalization of the tax benefits of the federal accelerated methods and available Investment Tax Credits (ITC) for all assets placed in service after 1980. ITCs are deferred and amortized over the lives of the related properties for book purposes.

        Advances for Construction and Contributions in Aid of Construction received from developers subsequent to 1986 were taxable for federal income tax purposes and subsequent to 1991 were subject to California income tax. In 1996, the federal tax law, and in 1997, the California tax law, changed and only deposits for new services were taxable. In late 2000, federal regulations were further modified to exclude contributions of fire services from taxable income.

        The accounting standards for accounting for uncertainty in income taxes also requires the inclusion of interest and penalties related to uncertain tax positions as a component of income taxes. See note 10 "Income Taxes".

Workers' Compensation, General Liability and Other Claims

• Workers' Compensation, General Liability and Other Claims

        For workers' compensation, the Company estimates the liability associated with claims submitted and claims not yet submitted based on historical data. Expenses for workers compensation insurance are included in rates on a pay-as-you-go basis. Therefore, a corresponding regulatory asset has been recorded. For general liability claims and other claims, the Company estimates the cost incurred but not yet paid using historical information.

Collective Bargaining Agreements

• Collective Bargaining Agreements

        As of December 31, 2012, the Company had 1,131 employees, including 734 non-supervisory employees who are represented by the Utility Workers Union of America, AFL-CIO, except certain engineering and laboratory employees who are represented by the International Federation of Professional and Technical Engineers, AFL-CIO. The union agreements expire at the end of 2014.

Earnings Per Share

• Earnings Per Share

        The computations of basic and diluted earnings per share are noted below. Basic earnings per share are computed by dividing net income available to common stockholders by the weighted average number of common shares outstanding during the period. Diluted earnings per share reflect the potential dilution that could occur if securities or other contracts were exercised or converted into common stock. Restricted Stock Awards (RSAs) are included in the common shares outstanding because the shares have all the same voting and dividend rights as issued and unrestricted common stock.

        At December 31, 2012, there were no common stock options outstanding. The Company did not grant any Stock Appreciation Rights (SAR) in 2012, 2011, and 2010. SARs outstanding were 333,856 shares as of December 31, 2012 and 361,356 shares as of December 31, 2011 and 2010.

        All options are dilutive and the SARs are antidilutive. The dilutive effect is shown in the table below.

	2012		2011		2010
	(In thousands, except per share data)
Net income as reported and available to common stockholders	$	48,828	$	37,712	$	37,656
Weighted average common shares, basic		41,892		41,762		41,612
Dilutive common stock equivalents (treasury method)		—		10		26
Shares used for dilutive calculation		41,892		41,772		41,638
Earnings per share—basic	$	1.17	$	0.90	$	0.90
Earnings per share—diluted	$	1.17	$	0.90	$	0.90

Stock-based Compensation

• Stock-based Compensation

        The Company follows accounting standards for stock-based compensation. Compensation cost is measured at the grant date based on the fair value of the award. The Company recognizes compensation as expense on a straight-line basis over the requisite service period, which is the vesting period.

Comprehensive Income or Loss

• Comprehensive Income or Loss

        Comprehensive income for all periods presented was the same as net income.

Accumulated Other Comprehensive Income or Loss

• Accumulated Other Comprehensive Income or Loss

        The Company did not have any accumulated other comprehensive income or loss transactions for 2012, 2011, and 2010.

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Consolidated Statements of Cash Flows (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Operating activities:
Net income	$ 48,828	$ 37,712	$ 37,656
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	56,866	51,981	45,265
Amortization of debt premium and expenses	1,107	1,082	979
Changes in deferred income taxes	34,133	2,723
Other changes in noncurrent assets and liabilities	(8,490)	611	(1,139)
Change in value of life insurance contracts	(2,504)	1,876	(2,641)
Gain on sale of non-utility property	(84)	(62)	(22)
Changes in operating assets and liabilities:
Receivables	(1,392)	(8,213)	(860)
Unbilled revenue	(326)	(1,143)	(508)
Taxes, prepaid expenses, and other assets	(3,322)	11,823	(2,842)
Accounts payable	879	4,612	220
Other current liabilities	6,219	8,270	(598)
Net adjustments	83,086	73,560	37,854
Net cash provided by operating activities	131,914	111,272	75,510
Investing activities:
Utility plant expenditures	(127,681)	(118,546)	(123,926)
Proceeds from sale of non-utility assets	85	64	34
Purchase of life insurance	(3,294)	(1,744)	(1,891)
Change in restricted cash	1,959	(3,042)	3,169
Net cash used in investing activities	(128,931)	(123,268)	(122,614)
Financing activities:
Short-term borrowings	94,335	23,390	85,750
Repayment of short-term borrowings	(52,000)		(74,000)
Issuance of common stock, net of expenses		965	912
Issuance of long-term debt, net of expenses	124	178	106,173
Advances and contributions in aid of construction	6,966	7,231	5,313
Refunds of advances for construction	(7,397)	(6,205)	(6,188)
Retirement of long-term debt	(7,037)	(2,963)	(13,692)
Dividends paid	(26,387)	(25,674)	(24,753)
Net cash provided by (used in) financing activities	8,604	(3,078)	79,515
Change in cash and cash equivalents	11,587	(15,074)	32,411
Cash and cash equivalents at beginning of year	27,203	42,277	9,866
Cash and cash equivalents at end of year	38,790	27,203	42,277
Cash paid (received) during the year for:
Interest (net of amounts capitalized)	27,120	26,998	24,425
Income taxes		10,535	9,815
Income tax refunds	(5,349)	(11,028)
Supplemental disclosure of non-cash activities:
Accrued payables for investments in utility plant	11,048	9,008	6,565
Utility plant contributed by developers	13,630	14,991	31,422
MTBE reclassification from other long-term liabilities to CIAC	4,462	16,735
Capital leases		$ 9,388

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Consolidated Balance Sheets (Parenthetical) (USD $) In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Consolidated Balance Sheets
Allowance for doubtful accounts (in dollars)	$ 714	$ 669
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized	68,000	68,000
Common stock, shares outstanding	41,908	41,817

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INCOME TAXES

12 Months Ended

Dec. 31, 2012

INCOME TAXES

INCOME TAXES

10 INCOME TAXES

        Income tax expense consisted of the following:

	Federal			State			Total
2012
Current	$	(9,018	)	$	(5,246	)	$	(14,264	)
Deferred		37,196			(1,480	)		35,716
Total	$	28,178		$	(6,726	)	$	21,452
2011
Current	$	7,413		$	2,629		$	10,042
Deferred		12,982			142			13,124
Total	$	20,395		$	2,771		$	23,166
2010
Current	$	4,027		$	3,020		$	7,047
Deferred		15,730			1,779			17,509
Total	$	19,757		$	4,799		$	24,556

        The Company filed an application for a change in accounting method (section 481 adjustment) with the Internal Revenue Service (IRS) in 2012 to implement the new repairs and maintenance deduction. The new deduction is for qualified tangible property placed into service during 2012 and prior years. The new tax regulations allow the Company to deduct a significant amount of costs previously capitalized for book and tax purposes. During 2012, the Company completed its analysis of the federal repairs maintenance deduction related to 2012 and prior years. The Company's federal repairs and maintenance deductions for qualified tangible property placed into service during 2012 and prior years was $100.7 million and created a $35.3 million deferred tax liability for the temporary timing difference between book and tax treatments in 2012. The 2012 and prior years federal repairs and maintenance deduction eliminated the Company's 2010 and 2011 previously filed federal qualified U.S. production activities deductions (QPAD) and was recorded as a $0.8 million federal income tax expense in 2012. The Company's state repairs deduction for qualified tangible property deductions placed into service during 2012 and prior years was $136.2 million and was recorded as a $7.8 million reduction to state income tax expense in 2012.

        The Company filed an application for a change in accounting method (Section 481 adjustment) with the State of California to change its plant-in-service state tax depreciation method from the double- declining method to the straight line method at the respective assets mid-life. The Company's application was approved by the State of California during the first quarter of 2011. California uses the flow-through method of accounting for income tax depreciation. As a result, the Company reduced its income tax obligation $1.6 million, net of federal income taxes in 2011. Income tax expense was computed by applying the current federal 35% tax rate to pretax book income differs from the amount shown in the Consolidated Statements of Income. The difference is reconciled in the table below:

	2012			2011			2010
Computed "expected" tax expense	$	24,600		$	21,308		$	21,774
Increase (reduction) in taxes due to:
State income taxes net of federal tax benefit		4,041			3,500			3,577
Effect of regulatory treatment of fixed asset differences		(7,030	)		(1,614	)		—
Investment tax credits		(74	)		(74	)		(74	)
Other		(85	)		46			(721	)
Total income tax	$	21,452		$	23,166		$	24,556

        The 2012 section 481 adjustment was a benefit of ($7,030) due to the tax repairs and maintenance deductions for 2011 and prior years. The 2011 section 481 adjustment was a benefit of ($1,614) due to an accounting method change with the State of California to change its plant-in-service state tax depreciation method from the double- declining method to the straight line method at the respective assets mid-life.

        Included in "Other" in the above table is the recognition of the flow-through accounting for federal depreciation expense on assets acquired prior to 1982 and retirement costs of such assets. For assets acquired prior to 1982, the benefit of excess tax depreciation was previously passed through to the ratepayers. The tax benefit is now reversing and a higher tax expense is being recognized and is included in customer rates. Offsetting the flow-through depreciation in 2012, 2011, and 2010 was the impact of cost to remove pre-1982 assets. Also included in "Other" in the above table, were 2012, 2011 and 2010 QPAD deductions. QPAD activities include production of potable water, but exclude the transmission and distribution of the potable water. The impact of the deduction is being reported in the year in which the deduction is claimed on the Company's tax return. The QPAD is limited to the lesser of 9% of taxable income or 50% of taxable gross wages in 2012. The 2012 section 481adjustment eliminated the QPAD deduction for 2012 and eliminated the 2011 and 2010 QPAD deductions which were recognized as an $831 increase to the income tax provision in 2012. The QPAD lowered the income tax provision by $397 and $433 in 2011 and 2010, respectively.

        The Tax Relief, Unemployment Insurance Reauthorization and Job Creation Act of 2010 will provide the Company with additional federal income tax deductions for assets placed in service after September 8, 2010 and before December 31, 2012. As of December 31, 2012 and 2011 the deferred income tax liability for bonus depreciation was $1,610 and $12,600, respectively.

        The tax effects of differences that give rise to significant portions of the deferred tax assets and deferred tax liabilities at December 31, 2012 and 2011 are presented in the following table:

	2012		2011
Deferred tax assets:
Developer deposits for extension agreements and contributions in aid of construction	$	44,530	$	45,587
Net operating loss		8,437		1,015
Other		3,607		3,449
Total deferred tax assets		56,574		50,051
Deferred tax liabilities:
Utility plant, principally due to depreciation differences		207,642		155,916
WRAM/MCBA balancing accounts		19,533		17,393
Other		3,245		3,645
Total deferred tax liabilities		230,420		176,954
Net deferred tax liabilities	$	173,846	$	126,903

        The current portion of our deferred income tax liability is $15,000 and $10,535 as of December 31, 2012 and 2011, respectively, which includes prepaid expenses and billed WRAM/MCBA surcharge, expected to reverse in the following 12 months.

        A valuation allowance was not required at December 31, 2012 and 2011. Based on historical taxable income and future taxable income projections over the period in which the deferred assets are deductible, management believes it is more likely than not that the Company will realize the benefits of the deductible differences.

        The following table reconciles the changes in unrecognized tax benefits:

	December 31, 2012			December 31, 2011
Balance at beginning of year	$	831		$	831
Additions for tax positions taken during prior year		—			—
Additions for tax positions taken during current year		—			—
Reductions for tax positions taken during a prior year		—			—
Lapse of statute of limitations		(831	)		—
Balance at end of year	$	—		$	831

        As of December 31, 2012 and 2011, the total amount of net unrecognized tax benefits was none and $831, respectively. The Company accrues interest and penalties related to unrecognized tax benefits in its provision for income taxes. The total amount of penalties and interest was $114 as of December 31, 2011 and 2010. The total accrued penalties and interest of $114 was reversed as of December 31, 2012. Additionally, the Company does not expect a material change in its unrecognized tax benefits within the next 12 months.

        Tax years of 2010 and 2011 are subject to examination by the federal and state taxing authorities, respectively. The IRS is presently auditing the Company's 2010 and 2011 federal income tax returns. It is uncertain when the IRS will complete its audit. The Company believes that the final resolution of the IRS audit will not have a material adverse impact on its financial condition or results of operations. The California Franchise Tax Board (FTB) finished the examination for the Company's 2008 and 2009 California income tax returns in December 2012 with no audit adjustment.

XML

Document and Entity Information (USD $) In Millions, except Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Feb. 11, 2013	Jun. 30, 2012
Document and Entity Information
Entity Registrant Name	CALIFORNIA WATER SERVICE GROUP
Entity Central Index Key	0001035201
Document Type	10-K
Document Period End Date	Dec. 31, 2012
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Public Float			$ 774
Entity Common Stock, Shares Outstanding		41,908,218
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	FY

XML

EMPLOYEE BENEFIT PLANS

12 Months Ended

Dec. 31, 2012

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS

11 EMPLOYEE BENEFIT PLANS

• Savings Plan

        The Company sponsors a 401(k) qualified, defined contribution savings plan that allows participants to contribute up to 20% of pre-tax compensation. Effective January 1, 2010, the Company matches seventy-five cents for each dollar contributed by the employee up to a maximum Company match of 6.0% of base salary. In the prior year, the Company matched fifty cents for each dollar contributed up to a maximum Company match of 4.0% of base salary. Company contributions were $4,029, $3,499, and $3,232, for the years 2012, 2011, and 2010, respectively.

• Pension Plans

        The Company provides a qualified, defined-benefit, non-contributory pension plan for substantially all employees. The accumulated benefit obligations of the pension plan are $307,197 and $266,496 as of December 31, 2012 and 2011, respectively. The fair value of pension plan assets was $202,947 and $155,749 as of December 31, 2012 and 2011, respectively.

        Prior to 2010, pension payment obligations were generally funded by the purchase of an annuity from a life insurance company. In 2010, the pension plan trust paid monthly benefits to retirees, rather than the purchase of an annuity. Payments are expected to be made in each year from 2013 to 2017 are $6,189, $7,547, $8,770, $10,090, and $11,577, respectively. The aggregate benefits expected to be paid in the five years 2018 through 2022 are $81,916. The expected benefit payments are based upon the same assumptions used to measure the Company's benefit obligation at December 31, 2012, and include estimated future employee service.

        The Company also maintains an unfunded, non-qualified, supplemental executive retirement plan. The unfunded supplemental executive retirement plan accumulated benefit obligations were $31,696 and $26,060 as of December 31, 2012 and 2011, respectively. Benefit payments under the supplemental executive retirement plan are paid currently and are included in the preceding paragraph.

        The costs of the pension and retirement plans are charged to expense and utility plant. The Company makes annual contributions to fund the amounts accrued for pension cost.

• Other Postretirement Plan

        The Company provides substantially all active, permanent employees with medical, dental, and vision benefits through a self-insured plan. Employees retiring at or after age 58, along with their spouses and dependents, continue participation in the plan by payment of a premium. Plan assets are invested in mutual funds, short-term money market instruments and commercial paper based upon the same asset mix as the pension plan. Retired employees are also provided with a five thousand dollar life insurance benefit.

        The Company records the costs of postretirement benefits other than pension (PBOP) during the employees' years of active service. Postretirement benefit expense recorded in 2012, 2011, and 2010, was $8,131, $6,291, and $4,782, respectively. Prior to 2006, the Company recorded a regulatory asset for the difference between the Company-funded amount and the net periodic benefit cost. The remaining net periodic benefit cost was $9,790 at December 31, 2006, and is being recovered through future customer rates and is recorded as a regulatory asset. The expected benefit payments, net of retiree premiums and Medicare part D subsidies, for the years from 2013 to 2017 are $1,398, $1,592, $1,819, $1,998, and $2,196, respectively. The Medicare Part D subsidies for the years from 2013 to 2017 are $253, $295, $337, $379, and $424.

• Benefit Plan Assets

        The Company actively manages pensions and PBOP trust (Plan) assets. The Company's investment objectives are:

• •

  Maximize the return on the assets of the Plan, commensurate with the risk that the Company deem appropriate to, meet the obligations of the Plan, minimize the volatility of the pension expense, and account for contingencies;

  •

  Generate a rate of return for the total portfolio that equals or exceeds the actuarial investment rate assumption;

  •

  Additionally, the rate of return of the total fund shall be measured periodically against a special index comprised of 35% of the Standard & Poor's Index, 15% of the Russell 2000 Index, 10% of the MSCI EAFE Index, and 40% of the Lehman Aggregate Bond Index. The special index is consistent with the rate of return objective and indicates the Company's long-term asset allocation objective.

        The Company applies a risk management framework for managing the risks associated with employee benefit plan trust assets. The guiding principles of this risk management framework are the clear articulation of roles and responsibilities, appropriate delegation of authority, and proper accountability and documentation. Trust investment policies and investment manager guidelines include provisions to ensure prudent diversification, manage risk through appropriate use of physical direct asset holdings and derivative securities, and identify permitted and prohibited investments.

        The Company's target asset allocation percentages for major categories of the pension plan are reflected in the table below:

	Minimum Exposure			Target			Maximum Exposure
Fixed Income		35	%		40	%		45	%
Total Domestic Equity		40	%		50	%		60	%
Small Cap Stocks		10	%		15	%		20	%
Large Cap Stocks		30	%		35	%		45	%
Non-U.S. Equities		5	%		10	%		15	%

        The fixed income category includes money market funds, short-term bond funds, and cash. The majority of fixed income investments range in maturities from less than one to five years.

        The Company's target allocation percentages for the PBOP trust is similar to the pension plan except for a larger allocation in fixed income investments and a lower allocation in equity investments.

        We use the following criteria to select investment funds:

• •

  Fund past performance;

  •

  Fund meets criteria of Employee Retirements Income Security Act (ERISA);

  •

  Timeliness and completeness of fund communications and reporting to investors;

  •

  Stability of fund management company;

  •

  Fund management fees; and

  •

  Administrative costs incurred by the Plan.

        The fair value measurements standard establishes a framework for measuring fair value. That framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (level 1 measurements) and the lowest priority to unobservable inputs (level 3 measurements). The three levels of the fair value hierarchy under the standard are described below:

• Level 1—Inputs to the valuation methodology are unadjusted quoted prices for identical assets or liabilities in active markets that the Plan has the ability to access.

  Level 2—Inputs to the valuation methodology include:

  • •

    Quoted market prices for similar assets or liabilities in active markets;

    •

    Quoted prices for identical or similar assets or liabilities in inactive markets;

    •

    Inputs other than quoted prices that are observable for the asset or liability; and

    •

    Inputs that are derived principally from or corroborated by observable market data by correlation or other means.

  • If the asset or liability has a specified (contractual) term, the level 2 input must be observable for substantially the full term of the asset or liability.

  Level 3—Inputs to the valuation methodology are unobservable and significant to the fair value measurement.

        All Plan investments are level 1 investments in mutual funds and are valued at the net asset value (NAV) of the shares held by the Plan at December 31, 2012 and 2011:

	Pension Benefits										Other Benefits
	2012		%			2011		%			2012		%			2011		%
Fixed Income	$	79,391		39	%	$	79,859		51	%	$	22,845		61	%	$	16,006		59	%
Domestic Equity
Small Cap Stocks		33,949					27,262					—					—
Large Cap Stocks		69,406					40,689					14,563					10,972
Total Domestic Equity		103,355		51	%		67,951		44	%		14,563		39	%		10,972		41	%
Non U.S. Equities		20,201		10	%		7,939		5	%		—		0	%		—		0	%
Total Plan Assets	$	202,947		100	%	$	155,749		100	%	$	37,408		100	%	$	26,978		100	%

        The pension benefits fixed income category includes $26,069 and $43,364 of money market fund investments as of December 31, 2012 and 2011, respectively. The other benefits fixed income category includes $14,159 and $16,006 of money market fund investments as of December 31, 2012 and 2011.

        The following table reconciles the funded status of the plans with the accrued pension liability and the net postretirement benefit liability as of December 31, 2012 and 2011:

	Pension Benefits						Other Benefits
	2012			2011			2012			2011
Change in projected benefit obligation:
Beginning of year	$	346,305		$	269,940		$	69,107		$	45,944
Service cost		15,450			11,713			4,399			3,199
Interest cost		15,287			14,683			3,139			2,872
Assumption change		24,269			59,028			7,673			12,600
Experience (gain) loss		4,833			(6,030	)		1,250			5,705
Benefits paid, net of retiree premiums		(4,023	)		(3,029	)		(1,147	)		(1,213	)
End of year	$	402,121		$	346,305		$	84,421		$	69,107
Change in plan assets:
Fair value of plan assets at beginning of year	$	155,749		$	139,034		$	26,978		$	21,178
Actual return on plan assets		21,979			555			2,788			64
Employer contributions		29,242			19,189			8,789			6,949
Retiree contributions and Medicare part D subsidies		—			—			1,255			1,130
Benefits paid		(4,023	)		(3,029	)		(2,402	)		(2,343	)
Fair value of plan assets at end of year	$	202,947		$	155,749		$	37,408		$	26,978
Funded status(1)	$	(199,174	)	$	(190,556	)	$	(47,013	)	$	(42,129	)
Unrecognized actuarial loss		133,579			123,177			40,449			34,515
Unrecognized prior service cost		41,972			47,976			421			537
Unrecognized transition obligation		—			—			9			285
Net amount recognized	$	(23,623	)	$	(19,403	)	$	(6,134	)	$	(6,792	)

(1)

The short-term portion of the pension benefits was $1,286 and $692 as of December 31, 2012 and 2011, respectively.

        Amounts recognized on the balance sheet consist of:

	Pension Benefits						Other Benefits
	2012			2011			2012			2011
Prepaid (Accrued) benefit costs	$	—		$	—		$	(6,723	)	$	(6,792	)
Accrued benefit liability		(199,174	)		(190,556	)		(47,013	)		(35,337	)
Regulatory asset		175,551			171,153			47,602			35,337
Net amount recognized	$	(23,623	)	$	(19,403	)	$	(6,134	)	$	(6,792	)

        Below are the actuarial assumptions used in determining the benefit obligation for the benefit plans:

	Pension Benefits						Other Benefits
	2012			2011			2012			2011
Weighted average assumptions as of December 31:
Discount rate		4.10	%		4.40	%		4.20	%		4.50	%
Long-term rate of return on plan assets		7.00	%		7.00	%		6.00	%		6.25	%
Rate of compensation increases		3.50	%		3.50	%		—			—
Cost of living adjustment		3.00	%		3.00	%		—			—

        The discount rate was derived from the Citigroup Pension Discount Curve using the expected payouts for the plan. The long-term rate of return assumption is the expected rate of return on a balanced portfolio invested roughly 60% in equities and 40% in fixed income securities. Returns on equity investments were estimated based on estimates of dividend yield and real earnings added to a 3% long-term inflation rate. For the pension and other benefit plans, the assumed returns were 9.20% for domestic equities and 9.34% for foreign equities. Returns on fixed-income investments were projected based on investment maturities and credit spreads added to a 3% long-term inflation rate. For the pension and other benefit plans, the assumed returns were 5.05% for fixed income investments and 3.46% for short-term cash investments. The average return for the pension and other benefit plans for the last five and ten years was 3.00% and 7.10%, respectively. The company is using a long-term rate of return of 7.00% for the pension plan and 6.00% for the other benefit plan, which is between the 25th and 75th percentile of expected results.

        Changes to the pension benefits actuarial assumptions can significantly affect pension costs, regulatory assets, and liabilities. The following table reflects the sensitivity of pension amounts reported for the year ended December 31, 2012, to changes in actuarial assumptions:

	Increase/(Decrease) in Pension Actuarial Assumption			Increase/(Decrease) in 2012 Net Periodic Pension Benefit Cost			Increase/(Decrease) in Projected Pension Benefit Obligation as of December 31, 2012
Discount rate		(0.5	)%	$	4,280		$	40,189
Long-term rate of return on plan assets		(0.5	)%		826			—
Rate of compensation increases		(0.5	)%		(1,929	)		(11,227	)
Cost of living adjustment		(0.5	)%		(3,291	)		(24,427	)
Discount rate		0.5	%		(3,793	)		(35,196	)
Long-term rate of return on plan assets		0.5	%		(825	)		—
Rate of compensation increases		0.5	%		2,095			12,099

        Net periodic benefit costs for the pension and other postretirement plans for the years ended December 31, 2012, 2011, and 2010 included the following components:

	Pension Plan									Other Benefits
	2012			2011			2010			2012			2011			2010
Service cost	$	15,450		$	11,713		$	10,076		$	4,399		$	3,199		$	2,491
Interest cost		15,287			14,683			13,701			3,139			2,872			2,329
Expected return on plan assets		(11,558	)		(8,949	)		(8,228	)		(1,832	)		(1,372	)		(1,119	)
Net amortization and deferral		14,283			10,387			9,224			2,425			1,592			1,081
Net periodic benefit cost	$	33,462		$	27,834		$	24,773		$	8,131		$	6,291		$	4,782

        Below are the actuarial assumptions used in determining the net periodic benefit costs for the benefit plans, which uses the end of the prior year as the measurement date:

	Pension Benefits						Other Benefits
	2012			2011			2012			2011
Weighted average assumptions as of December 31:
Discount rate		4.40	%		5.60	%		4.50	%		5.60	%
Long-term rate of return on plan assets		7.00	%		6.75	%		6.25	%		6.00	%
Rate of compensation increases		3.50	%		4.00	%		—			—

        The health care cost trend rate assumption has a significant effect on the amounts reported. For 2012 measurement purposes, the Company assumed an 8.2% annual rate of increase in the per capita cost of covered benefits with the rate decreasing to 6.2% by 2017, then gradually grading down to 5.4% over the next 50 years. A one-percentage point change in assumed health care cost trends is estimated to have the following effect:

	1-Percentage Point Increase		1-Percentage Point Decrease
Effect on total service and interest costs	$	2,036	$	(1,506	)
Effect on accumulated postretirement benefit obligation	$	18,576	$	(14,147	)

        The Company intends to make annual contributions to the plans up to the amount deductible for tax purposes. The Company estimates in 2013 that the annual contribution to the pension plans will be $35,684 and the annual contribution to the other postretirement plan will be $8,892.

XML

Consolidated Statements of Income (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Consolidated Statements of Income
Operating revenue	$ 121,530	$ 178,135	$ 143,552	$ 116,749	$ 103,014	$ 169,254	$ 131,397	$ 98,149	$ 559,966	$ 501,814	$ 460,399
Operations:
Purchased water									161,336	142,570	125,930
Purchased power									31,027	30,053	29,577
Pump taxes									10,336	9,130	8,600
Administrative and general									93,927	85,758	75,276
Other									77,104	54,696	56,518
Maintenance									19,142	20,698	19,685
Depreciation and amortization									54,668	50,385	42,828
Income taxes									19,356	23,025	23,069
Property and other taxes									19,227	18,332	17,103
Total operating expenses									486,123	434,647	398,586
Net operating income	11,253	36,361	19,622	6,607	7,586	30,078	19,555	9,948	73,843	67,167	61,813
Other income and expenses:
Non-regulated revenue									16,686	16,160	15,993
Non-regulated expense									(11,553)	(15,822)	(12,312)
Gain on sale of non-utility property									84	62	22
Income tax (expense) on other income and expenses									(2,096)	(141)	(1,487)
Net other income									3,121	259	2,216
Interest expense:
Interest expense									31,537	32,455	27,936
Less: capitalized interest									(3,401)	(2,741)	(1,563)
Net interest expense									28,136	29,714	26,373
Net income									$ 48,828	$ 37,712	$ 37,656
Earnings per share:
Basic (in dollars per share)									$ 1.17	$ 0.90	$ 0.90
Diluted (in dollars per share)	$ 0.12	$ 0.71	$ 0.31	$ 0.03	$ 0.04	$ 0.50	$ 0.29	$ 0.07	$ 1.17	$ 0.90	$ 0.90
Weighted average number of common shares outstanding:
Basic (in shares)									41,892	41,762	41,612
Diluted (in shares)									41,892	41,772	41,638

XML

PREFERRED STOCK

12 Months Ended

Dec. 31, 2012

PREFERRED STOCK

PREFERRED STOCK

5 PREFERRED STOCK

        The Company is authorized to issue 241,000 shares of Preferred Stock as of December 31, 2012. No shares of Preferred Stock were issued and outstanding at December 31, 2012 or 2011.

XML

INTANGIBLE ASSETS

12 Months Ended

Dec. 31, 2012

INTANGIBLE ASSETS

INTANGIBLE ASSETS

4 INTANGIBLE ASSETS

        As of December 31, 2012 and 2011, intangible assets that will continue to be amortized and those not amortized were:

	Weighted Average Amortization Period (years)	2012						2011
		Gross Carrying Value		Accumulated Amortization		Net Carrying Value		Gross Carrying Value		Accumulated Amortization		Net Carrying Value
Amortized intangible assets:
Water pumping rights	usage	$	1,084	$	79	$	1,005	$	1,084	$	14	$	1,070
Water planning studies	12		11,894		4,322		7,572		11,087		3,413		7,674
Leasehold improvements and other	21		1,140		249		891		1,086		345		741
Total	13	$	14,118	$	4,650	$	9,468	$	13,257	$	3,772	$	9,485
Unamortized intangible assets:
Perpetual water rights and other		$	4,495	$	—	$	4,495	$	3,229	$	—	$	3,229

        For the years ended December 31, 2012, 2011, and 2010, amortization of intangible assets was $1,298, $1,421, and $1,894, respectively. Estimated future amortization expense related to intangible assets for the succeeding five years is approximately $1,319, $1,296, $1,237, $1,192, and $4,638 thereafter.

XML

CONDENSED CONSOLIDATING FINANCIAL STATEMENTS

12 Months Ended

Dec. 31, 2012

CONDENSED CONSOLIDATING FINANCIAL STATEMENTS

CONDENSED CONSOLIDATING FINANCIAL STATEMENTS

16 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS

        On April 17, 2009, Cal Water issued $100 million aggregate principal amount of 5.875% First Mortgage Bonds due 2019, and on November 17, 2010, Cal Water issued $100 million aggregate principal amount of 5.500% First Mortgage Bonds due 2040, all of which are fully and unconditionally guaranteed by California Water Service Group (Parent Company). The following tables present the condensed consolidating statements of income of California Water Service Group (Guarantor and Parent), Cal Water (issuer and 100% owned consolidated subsidiary of California Water Service Group) and other 100% owned subsidiaries of the Company for the years ended December 31, 2012, 2011 and 2010, the condensed consolidating statements of cash flows for the 12-months ended December 31, 2012, 2011, and 2010, and the condensed consolidating balance sheets as of December 31, 2012 and 2011.

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING BALANCE SHEET
As of December 31, 2012

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
ASSETS
Utility plant:
Utility plant	$	606		$	1,927,190		$	175,764		$	(7,197	)	$	2,096,363
Less accumulated depreciation and amortization		(108	)		(607,992	)		(32,710	)		1,503			(639,307	)
Net utility plant		498			1,319,198			143,054			(5,694	)		1,457,056
Current assets:
Cash and cash equivalents		1,470			34,609			2,711			—			38,790
Receivables		—			87,482			3,833			—			91,315
Receivables from affiliates		19,367			3,195			1,152			(23,714	)		—
Other current assets		—			15,535			924			—			16,459
Total current assets		20,837			140,821			8,620			(23,714	)		146,564
Other assets:
Regulatory assets		—			341,877			2,542			—			344,419
Investments in affiliates		492,188			—			—			(492,188	)		—
Long-term affiliate notes receivable		31,218			7,781			—			(38,999	)		—
Other assets		1,023			40,005			7,062			(205	)		47,885
Total other assets		524,429			389,663			9,604			(531,392	)		392,304
	$	545,764		$	1,849,682		$	161,278		$	(560,800	)	$	1,995,924
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stockholders' equity	$	473,712		$	442,923		$	54,774		$	(497,697	)	$	473,712
Affiliate long-term debt		7,781			—			31,218			(38,999	)		—
Long-term debt, less current maturities		—			431,433			3,034			—			434,467
Total capitalization		481,493			874,356			89,026			(536,696	)		908,179
Current liabilities:
Current maturities of long-term debt		—			46,104			679			—			46,783
Short-term borrowings		64,475			25,000			—			—			89,475
Payables to affiliates		77			1,152			22,485			(23,714	)		—
Accounts payable		—			41,352			5,847			—			47,199
Accrued expenses and other liabilities		298			58,293			1,019			—			59,610
Total current liabilities		64,850			171,901			30,030			(23,714	)		243,067
Unamortized investment tax credits		—			2,180			—			—			2,180
Deferred income taxes, net		(579	)		155,481			4,334			(390	)		158,846
Pension and postretirement benefits other than pensions		—			244,901			—			—			244,901
Regulatory and other liabilities		—			83,942			8,651			—			92,593
Advances for construction		—			186,753			831			—			187,584
Contributions in aid of construction		—			130,168			28,406			—			158,574
	$	545,764		$	1,849,682		$	161,278		$	(560,800	)	$	1,995,924

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING BALANCE SHEET
As of December 31, 2011

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
ASSETS
Utility plant:
Utility plant	$	324		$	1,808,568		$	158,688		$	(7,199	)	$	1,960,381
Less accumulated depreciation and amortization		(51	)		(551,345	)		(29,251	)		1,385			(579,262	)
Net utility plant		273			1,257,223			129,437			(5,814	)		1,381,119
Current assets:
Cash and cash equivalents		89			18,475			8,639			—			27,203
Receivables		158			76,227			(4,797	)		—			71,588
Receivables from affiliates		7,817			3,446			5			(11,268	)		—
Other current assets		—			14,225			872			—			15,097
Total current assets		8,064			112,373			4,719			(11,268	)		113,888
Other assets:
Regulatory assets		—			317,564			2,334			—			319,898
Investments in affiliates		466,515			—			—			(466,515	)		—
Long-term affiliate notes receivable		28,921			7,832			—			(36,753	)		—
Other assets		1,144			31,662			7,081			(205	)		39,682
Total other assets		496,580			357,058			9,415			(503,473	)		359,580
	$	504,917		$	1,726,654		$	143,571		$	(520,555	)	$	1,854,587
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stockholders' equity	$	449,829		$	417,810		$	54,377		$	(472,187	)	$	449,829
Affiliate long-term debt		7,832			—			28,921			(36,753	)		—
Long-term debt, less current maturities		—			477,998			3,634			—			481,632
Total capitalization		457,661			895,808			86,932			(508,940	)		931,461
Current liabilities:
Current maturities of long-term debt		—			5,851			682			—			6,533
Short-term borrowings		47,140			—			—			—			47,140
Payables to affiliates		52			190			11,026			(11,268	)		—
Accounts payable		—			47,568			4,010			—			51,578
Accrued expenses and other liabilities		625			46,462			(547	)		84			46,624
Total current liabilities		47,817			100,071			15,171			(11,184	)		151,875
Unamortized investment tax credits		—			2,254			—			—			2,254
Deferred income taxes, net		(561	)		113,925			3,435			(431	)		116,368
Pension and postretirement benefits other than pensions		—			232,110			—			—			232,110
Regulatory and other liabilities		—			71,034			8,016			—			79,050
Advances for construction		—			185,902			1,376			—			187,278
Contributions in aid of construction		—			125,550			28,641			—			154,191
	$	504,917		$	1,726,654		$	143,571		$	(520,555	)	$	1,854,587

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING STATEMENT OF INCOME
For the Year Ended December 31, 2012

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating revenue	$	—		$	527,449		$	32,517		$	—		$	559,966
Operating expenses:
Operations:
Purchased water		—			160,913			423			—			161,336
Purchased power		—			21,435			9,592			—			31,027
Pump taxes		—			10,336			—			—			10,336
Administrative and general		—			84,399			9,528			—			93,927
Other		—			70,864			6,744			(504	)		77,104
Maintenance		—			18,478			664			—			19,142
Depreciation and amortization		—			52,012			2,774			(118	)		54,668
Income taxes (benefits)		(583	)		18,992			(375	)		1,322			19,356
Taxes other than income taxes		—			16,630			2,597			—			19,227
Total operating expenses (income)		(583	)		454,059			31,947			700			486,123
Net operating income		583			73,390			570			(700	)		73,843
Other Income and Expenses:
Non-regulated revenue		1,919			15,204			2,420			(2,857	)		16,686
Non-regulated expense		—			(9,588	)		(1,965	)		—			(11,553	)
Gain on sale on non-utility property		—			81			—			3			84
Income tax benefit (expense) on other income and expense		(782	)		(2,321	)		(266	)		1,273			(2,096	)
Net other income (expense)		1,137			3,376			189			(1,581	)		3,121
Interest:
Interest expense		1,430			30,328			2,132			(2,353	)		31,537
Less: capitalized interest		—			(2,334	)		(1,067	)		—			(3,401	)
Net interest expense		1,430			27,994			1,065			(2,353	)		28,136
Equity earnings of subsidiaries		48,538			—			—			(48,538	)		—
Net income	$	48,828		$	48,772		$	(306	)	$	(48,466	)	$	48,828

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING STATEMENT OF INCOME
For the Year Ended December 31, 2011

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating revenue	$	—		$	472,150		$	29,664		$	—		$	501,814
Operating expenses:
Operations:
Purchased water		—			142,355			215			—			142,570
Purchased power		—			20,719			9,334			—			30,053
Pump taxes		—			8,764			366			—			9,130
Administrative and general		—			77,622			8,136			—			85,758
Other		—			47,800			7,401			(505	)		54,696
Maintenance		—			19,916			782			—			20,698
Depreciation and amortization		—			47,872			2,637			(124	)		50,385
Income taxes (benefits)		(580	)		23,727			(1,727	)		1,605			23,025
Taxes other than income taxes		—			15,908			2,424			—			18,332
Total operating expenses (income)		(580	)		404,683			29,568			976			434,647
Net operating income		580			67,467			96			(976	)		67,167
Other Income and Expenses:
Non-regulated revenue		2,248			12,972			4,322			(3,382	)		16,160
Non-regulated expense		—			(12,287	)		(3,535	)		—			(15,822	)
Gain on sale on non-utility property		—			62			—			—			62
Income tax benefit (expense) on other income and expense		(916	)		(304	)		(422	)		1,501			(141	)
Net other income (expense)		1,332			443			365			(1,881	)		259
Interest:
Interest expense		1,422			31,421			2,489			(2,877	)		32,455
Less: capitalized interest		—			(1,844	)		(897	)		—			(2,741	)
Net interest expense		1,422			29,577			1,592			(2,877	)		29,714
Equity earnings of subsidiaries		37,222			—			—			(37,222	)		—
Net income	$	37,712		$	38,333		$	(1,131	)	$	(37,202	)	$	37,712

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING STATEMENT OF INCOME
For the Year Ended December 31, 2010

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating revenue	$	—		$	430,988		$	29,411		$	—		$	460,399
Operating expenses:
Operations:
Purchased water		—			125,749			181			—			125,930
Purchased power		—			21,616			7,961			—			29,577
Pump taxes		—			8,017			583			—			8,600
Administrative and general		—			67,536			7,740			—			75,276
Other		—			49,356			7,667			(505	)		56,518
Maintenance		—			18,998			687			—			19,685
Depreciation and amortization		—			40,349			2,610			(131	)		42,828
Income taxes (benefits)		(843	)		23,812			(229	)		329			23,069
Taxes other than income taxes		—			14,904			2,199			—			17,103
Total operating expenses (income)		(843	)		370,337			29,399			(307	)		398,586
Net operating income		843			60,651			12			307			61,813
Other Income and Expenses:
Non-regulated revenue		1,220			10,064			6,670			(1,961	)		15,993
Non-regulated expense		—			(7,954	)		(4,358	)		—			(12,312	)
Gain on sale on non-utility property		—			22			—			—			22
Income tax benefit (expense) on other income and expense		(497	)		(869	)		(1,027	)		906			(1,487	)
Net other income (expense)		723			1,263			1,285			(1,055	)		2,216
Interest:
Interest expense		698			27,059			1,635			(1,456	)		27,936
Less: capitalized interest		—			(1,085	)		(478	)		—			(1,563	)
Net interest expense		698			25,974			1,157			(1,456	)		26,373
Equity earnings of subsidiaries		36,788			—			—			(36,788	)		—
Net income	$	37,656		$	35,940		$	140		$	(36,080	)	$	37,656

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
For the Year Ended December 31, 2012

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating activities:
Net income (loss)	$	48,828		$	48,772		$	(306	)	$	(48,466	)	$	48,828
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Equity earnings of subsidiaries		(48,538	)		—			—			48,538			—
Dividends received from affiliates		26,387			—			—			(26,387	)		—
Depreciation and amortization		56			54,040			2,888			(118	)		56,866
Change in value of life insurance contracts		—			(2,504	)		—			—			(2,504	)
Gain on sale of non-utility property		—			(81	)		—			(3	)		(84	)
Changes in deferred income taxes		—			34,133			—			—			34,133
Other changes in noncurrent assets and liabilities		1,544			(10,367	)		1,307			133			(7,383	)
Changes in operating assets and liabilities:
Other changes, net		(170	)		9,035			(6,723	)		(84	)		2,058
Net adjustments		(20,721	)		84,256			(2,528	)		22,079			83,086
Net cash provided by (used in) operating activities		28,107			133,028			(2,834	)		(26,387	)		131,914
Investing activities:
Utility plant expenditures		(281	)		(111,636	)		(15,761	)		(3	)		(127,681	)
Proceeds from sale of non-utility assets		—			82			—			3			85
Affiliate advances		(12,245	)		254			(853	)		12,844			—
Proceeds from affiliate loans		552			48			—			(600	)		—
Reduction of loans to affiliates		(5,675	)		—			—			5,675			—
Purchase of life insurance		—			(3,294	)		—			—			(3,294	)
Restricted cash decrease		—			1,959			—			—			1,959
Net cash (used in) investing activities		(17,649	)		(112,587	)		(16,614	)		17,919			(128,931	)
Financing Activities:
Short-term borrowings		18,335			76,000			—			—			94,335
Repayment of short-term borrowings		(1,000	)		(51,000	)		—			—			(52,000	)
Affiliate advances		23			962			11,859			(12,844	)		—
Proceeds from affiliates long-term borrowings		—			—			5,675			(5,675	)		—
Reduction of affiliate long-term borrowings		(48	)		—			(552	)		600			—
Proceeds from long-term debt		—			—			124			—			124
Retirement of long-term debt		—			(6,310	)		(727	)		—			(7,037	)
Advances and contributions in aid for construction		—			6,883			83			—			6,966
Refunds of advances for construction		—			(7,275	)		(122	)		—			(7,397	)
Dividends paid to non-affiliates		(26,387	)		—			—			—			(26,387	)
Dividends paid to affiliates		—			(23,567	)		(2,820	)		26,387			—
Net cash (used in) provided by financing activities		(9,077	)		(4,307	)		13,520			8,468			8,604
Change in cash and cash equivalents		1,381			16,134			(5,928	)		—			11,587
Cash and cash equivalents at beginning of year		89			18,475			8,639			—			27,203
Cash and cash equivalents at end of year	$	1,470		$	34,609		$	2,711		$	—		$	38,790

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
For the Year Ended December 31, 2011

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating activities:
Net income (loss)	$	37,712		$	38,333		$	(1,131	)	$	(37,202	)	$	37,712
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Equity earnings of subsidiaries		(37,222	)		—			—			37,222			—
Dividends received from affiliates		25,674			—			—			(25,674	)		—
Depreciation and amortization		51			49,283			2,771			(124	)		51,981
Change in value of life insurance contracts		—			1,876			—			—			1,876
Gain on sale of non-utility property		—			(62	)		—			—			(62	)
Section 481 adjustment		—			2,723			—			—			2,723
Other changes in noncurrent assets and liabilities		1,001			(45	)		684			53			1,693
Changes in operating assets and liabilities:
Other changes, net		582			11,662			3,054			51			15,349
Net adjustments		(9,914	)		65,437			6,509			11,528			73,560
Net cash provided by operating activities		27,798			103,770			5,378			(25,674	)		111,272
Investing activities:
Utility plant expenditures		—			(98,410	)		(20,136	)		—			(118,546	)
Proceeds from sale of non-utility assets		—			64			—			—			64
Affiliate advances		(25,495	)		1,597			—			23,898			—
Reduction of loans to affiliates		962			45			2,000			(3,007	)		—
Purchase of life insurance		—			(1,744	)		—			—			(1,744	)
Restricted cash increase		—			(3,042	)		—			—			(3,042	)
Net cash (used in) investing activities		(24,533	)		(101,490	)		(18,136	)		20,891			(123,268	)
Financing Activities:
Short-term borrowings		23,390			—			—			—			23,390
Affiliate advances		—			—			23,898			(23,898	)		—
Reduction of affiliate long-term borrowings		(2,045	)		—			(962	)		3,007			—
Proceeds from long-term debt, net of issuance cost of $1,857		—			—			178			—			178
Retirement of long-term debt		—			(2,279	)		(684	)		—			(2,963	)
Advances and contributions in aid for construction		—			7,082			149			—			7,231
Refunds of advances for construction		—			(6,129	)		(76	)		—			(6,205	)
Dividends paid to non-affiliates		(25,674	)		—			—			—			(25,674	)
Dividends paid to affiliates		—			(22,925	)		(2,749	)		25,674			—
Issuance of common stock		965			—			—			—			965
Net cash (used in) provided by financing activities		(3,364	)		(24,251	)		19,754			4,783			(3,078	)
Change in cash and cash equivalents		(99	)		(21,971	)		6,996			—			(15,074	)
Cash and cash equivalents at beginning of year		188			40,446			1,643			—			42,277
Cash and cash equivalents at end of year	$	89		$	18,475		$	8,639		$	—		$	27,203

CALIFORNIA WATER SERVICE GROUP
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
For the Year Ended December 31, 2010

	Parent Company			Cal Water			All Other Subsidiaries			Consolidating Adjustments			Consolidated
	(In thousands)
Operating activities:
Net income	$	37,656		$	35,940		$	140		$	(36,080	)	$	37,656
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Equity earnings of subsidiaries		(36,788	)		—			—			36,788			—
Dividends received from affiliates		24,753			—			—			(24,753	)		—
Depreciation and amortization		—			42,680			2,716			(131	)		45,265
Other changes in noncurrent assets and liabilities		229			(880	)		1,089			(598	)		(160	)
Change in value of life insurance contracts		—			(2,641	)		—			—			(2,641	)
Gain on sale of non-utility property		—			(22	)		—			—			(22	)
Changes in operating assets and liabilities:
Other changes, net		(1,054	)		(997	)		(2,558	)		21			(4,588	)
Net adjustments		(12,860	)		38,140			1,247			11,327			37,854
Net cash provided by operating activities		24,796			74,080			1,387			(24,753	)		75,510
Investing activities:
Utility plant expenditures		(324	)		(108,990	)		(14,612	)		—			(123,926	)
Proceeds from sale of non-utility assets		—			34			—			—			34
Affiliate advances		(14,579	)		85			—			14,494			—
Reduction of loans to affiliates		1,854			—			—			(1,854	)		—
Purchase of life insurance		—			(1,891	)		—			—			(1,891	)
Restricted cash decrease		—			3,169			—			—			3,169
Net cash (used in) investing activities		(13,049	)		(107,593	)		(14,612	)		12,640			(122,614	)
Financing Activities:
Short-term borrowings		16,750			69,000			—			—			85,750
Repayment of short-term borrowings		(5,000	)		(69,000	)		—			—			(74,000	)
Affiliate advances		—			—			14,494			(14,494	)		—
Reduction of affiliate note payable		—			—			(1,854	)		1,854			—
Proceeds from long-term debt, net of issuance cost of $1,857		—			103,947			2,226			—			106,173
Retirement of long-term debt		—			(12,212	)		(1,480	)		—			(13,692	)
Advances and contributions in aid for construction		—			4,962			351			—			5,313
Refunds of advances for construction		—			(6,104	)		(84	)		—			(6,188	)
Dividends paid to non-affiliates		(24,753	)		—			—			—			(24,753	)
Dividends paid to affiliates		—			(22,634	)		(2,119	)		24,753			—
Issuance of common stock		912			—			—			—			912
Net cash (used in) provided by financing activities		(12,091	)		67,959			11,534			12,113			79,515
Change in cash and cash equivalents		(344	)		34,446			(1,691	)		—			32,411
Cash and cash equivalents at beginning of year		532			6,000			3,334			—			9,866
Cash and cash equivalents at end of year	$	188		$	40,446		$	1,643		$	—		$	42,277

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STOCK-BASED COMPENSATION PLANS

12 Months Ended

Dec. 31, 2012

STOCK-BASED COMPENSATION PLANS

STOCK-BASED COMPENSATION PLANS

12 STOCK-BASED COMPENSATION PLANS

        The Company has two stockholder-approved stock-based compensation plans.

• Long-term Incentive Plan

        The long-term incentive plan was replaced on April 27, 2005, by a stockholder-approved equity incentive plan. The Long-Term Incentive Plan allowed granting of nonqualified stock options. There will be no future grants made under the Long-term Incentive Plan. The Company had accounted for options using the intrinsic value method. Options were granted at an exercise price that was not less than the per share common stock market price on the date of grant. The options vested at a 25% rate on their anniversary date over their first four years and are exercisable over a ten-year period. At December 31, 2012, all the options under the Long-term Incentive Plan were exercised. No options were granted under the Long-term Incentive Plan in 2012, 2011, or 2010.

• Equity Incentive Plan

        Under the Equity Incentive Plan, which was approved by stockholders on April 27, 2005, the Company is authorized to issue awards of up to 2,000,000 shares of common stock. In 2012 and 2011, the Company granted RSAs of 101,236 and 85,426 shares, respectively, of common stock both to employees and to directors of the Company. In 2012, 10,050 RSAs were cancelled and no RSAs were cancelled in 2011. Employee awards vest ratably over 48 months, while independent director awards vest at the end of 12 months. The shares were valued at the weighted average price of $17.97 and $17.44 per share, respectively based upon the fair market value of the Company's common stock on the date of grant. In 2012, no new Stock Appreciation Rights (SARs) were granted to employees and 27,500 shares of SARs were cancelled.

        The Company did not apply a forfeiture rate in the expense computation relating to SARs and RSAs issued to employees as they vest monthly and, as a result, the expense is recorded for actual number vested during the period. For outside directors, the Company did not apply a forfeiture rate in the expense computation relating to RSAs, as the Company expects 100% to vest at the end of 12 months.

        The SARs vest ratably over 48 months and expire at the end of 10 years. Upon exercise of a SAR, the appreciation is payable in common shares of the Company. The assumptions utilized to determine the grant-date fair value of the SARs in 2009 was an expected dividend yield of 3.07%, expected volatility of 22.10%, a risk-free interest rate of 2.84%, and an expected holding period of 6.75 years. As of December 31, 2012, there were 333,856 shares outstanding of which 325,602 shares were exercisable at a weighted average fair value of $3.66.

        The Company has recorded compensation expense for the RSAs and SARs of $1,442, $1,300, and $1,077 in 2012, 2011, and 2010, respectively. The unrecognized future compensation expense for the RSAs and SARs at December 31, 2012 is $1,913.

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LONG-TERM DEBT

12 Months Ended

Dec. 31, 2012

LONG-TERM DEBT.

LONG-TERM DEBT

8 LONG-TERM DEBT

        As of December 31, 2012 and 2011, long-term debt outstanding was:

	Series	Interest Rate	Maturity Date		2012		2011
First Mortgage Bonds	PPP	5.500%		2040	$	100,000	$	100,000
	LL	5.875%		2019		100,000		100,000
	AAA	7.280%		2025		20,000		20,000
	BBB	6.770%		2028		20,000		20,000
	CCC	8.150%		2030		20,000		20,000
	DDD	7.130%		2031		20,000		20,000
	EEE	7.110%		2032		20,000		20,000
	FFF	5.900%		2017		20,000		20,000
	GGG	5.290%		2022		18,182		20,000
	HHH	5.290%		2022		18,182		20,000
	III	5.540%		2023		10,000		10,000
	JJJ	5.440%		2018		5,455		6,364
	LLL	5.480%		2018		10,000		10,000
	MMM	5.520%		2013		20,000		20,000
	NNN	5.550%		2013		20,000		20,000
	OOO	6.020%		2031		20,000		20,000
	CC	9.860%		2020		17,400		17,500
	K	6.940%		2012		—		800
Total First Mortgage Bonds						459,219		464,664
California Department of Water Resources Loans		2.6% to 8%		2012 - 32		8,451		8,780
Other Long-term debt						13,580		14,721
Total long-term debt						481,250		488,165
Less current maturities						46,783		6,533
Long-term debt excluding current maturities					$	434,467	$	481,632

        On October 4, 2011, Cal Water entered into a new capital lease arrangement with the City of Hawthorne to operate the City's water system for a 15-year period. The $9.2 million capital lease liability is included in other long-term debt and current maturities set forth above.

        On November 17, 2010, Cal Water completed the sale and issuance of $100 million aggregate principal amount of its 5.50% First Mortgage Bonds PPP due 2040, which are fully and unconditionally guaranteed by the Company.

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COMMITMENTS AND CONTINGENCIES (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Office Leases
Lease Commitments
2013	$ 632
2014	515
2015	404
2016	193
2017	166
Thereafter	2,494
Other lease commitment disclosures
Annual lease payments made and charged	1,156	1,271	1,080
System Leases
Lease Commitments
Number of water systems leased	2
2013	845
2014	845
2015	845
2016	845
2017	845
Thereafter	493
Hawthorne lease
Lease Commitments
Number of water systems leased	3
Other lease commitment disclosures
Annual lease payments made and charged	940
Lease term		15 years
Lease deposit	8,100
Revenue from the water system received in exchange for handling of system and system improvements	7,621	7,506	7,547
Annual payments made under capital improvements	940	537	116
Hawthorne lease | Minimum
Other lease commitment disclosures
Annual lease payments made and charged	940
Commerce
Other lease commitment disclosures
Lease term	15 years
Annual lease payment	$ 845

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COMMON STOCKHOLDERS' EQUITY

12 Months Ended

Dec. 31, 2012

COMMON STOCKHOLDERS' EQUITY

COMMON STOCKHOLDERS' EQUITY

6 COMMON STOCKHOLDERS' EQUITY

        As of December 31, 2012 and 2011, 41,908,218 shares and 41,817,218 shares, respectively, of common stock were issued and outstanding.

• Dividend Reinvestment and Stock Repurchase Plan

        The Company has a Dividend Reinvestment and Stock Purchase Plan (DRIP Plan). Under the DRIP Plan, stockholders may reinvest dividends to purchase additional Company common stock without commission fees. The Plan also allows existing stockholders and other interested investors to purchase Company common stock through the transfer agent up to certain limits. The Company's transfer agent operates the DRIP Plan and purchases shares on the open market to provide shares for the Plan.

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SHORT-TERM BORROWINGS

12 Months Ended

Dec. 31, 2012

SHORT-TERM BORROWINGS

SHORT-TERM BORROWINGS

7 SHORT-TERM BORROWINGS

        On June 29, 2011, the Company and Cal Water entered into Syndicated Credit Agreements, which provide for unsecured revolving credit facilities of up to an initial aggregate amount of $400 million. The Syndicated Credit Facilities amend, expand, and replace the Company's and its subsidiaries' existing credit facilities originally entered into on October 27, 2009. The new credit facilities extended the terms until June 29, 2016, increased the Company's and Cal Water's unsecured revolving lines of credit, and lowered interest rates and fees. The Company and subsidiaries which it designates may borrow up to $100 million under the Company's revolving credit facility. Cal Water may borrow up to $300 million under its revolving credit facility; however, all borrowings need to be repaid within twelve months unless otherwise authorized by the CPUC. The proceeds from the revolving credit facilities may be used for working capital purposes, including the short-term financing of capital projects. The base loan rate may vary from LIBOR plus 72.5 basis points to LIBOR plus 95 basis points, depending on the Company's total capitalization ratio. Likewise, the unused commitment fee may vary from 8 basis points to 12.5 basis points based on the same ratio.

        Both short-term unsecured credit agreements contain affirmative and negative covenants and events of default customary for credit facilities of this type including, among other things, limitations and prohibitions relating to additional indebtedness, liens, mergers, and asset sales. Also, these unsecured credit agreements contain financial covenants governing the Company and its subsidiaries' consolidated total capitalization ratio and interest coverage ratio. As of December 31, 2012, the Company and Cal Water have met all borrowing covenants for both credit agreements.

        As of December 31, 2012 and December 31, 2011, the outstanding borrowings on the Company lines of credit were $64.5 million and $47.1 million, respectively. The borrowings on the Cal Water lines of credit were $25.0 million as of December 31, 2012, and there were no borrowings as of December 31, 2011.

        The following table represents borrowings under the bank lines of credit:

	2012			2011
Maximum short-term borrowings	$	89,475		$	47,140
Average amount outstanding	$	71,715		$	32,324
Weighted average interest rate		1.74	%		2.41	%
Interest rate at December 31		2.14	%		2.10	%

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OTHER ACCRUED LIABILITIES

12 Months Ended

Dec. 31, 2012

OTHER ACCRUED LIABILITIES

OTHER ACCRUED LIABILITIES

9 OTHER ACCRUED LIABILITIES

        As of December 31, 2012 and 2011, other accrued liabilities were:

	2012		2011
Accrued and deferred compensation	$	16,320	$	14,143
Deferred tax liability		15,000		10,535
Accrued benefit and workers' compensation claims		6,906		5,222
Other		8,282		8,026
	$	46,508	$	37,926

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CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Details 2) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Utility plant:
Utility plant	$ 2,096,363	$ 1,960,381
Less accumulated depreciation and amortization	(639,307)	(579,262)
Net utility plant	1,457,056	1,381,119
Current assets:
Cash and cash equivalents	38,790	27,203	42,277	9,866
Receivables	91,315	71,588
Other current assets	16,459	15,097
Total current assets	146,564	113,888
Other assets:
Regulatory assets	344,419	319,898
Other assets	47,885	39,682
Total other assets	392,304	359,580
Total assets	1,995,924	1,854,587
Capitalization:
Common stockholders' equity	473,712	449,829	435,526	420,634
Long-term debt, less current maturities	434,467	481,632
Total capitalization	908,179	931,461
Current liabilities:
Current maturities of long-term debt	46,783	6,533
Short-term borrowings	89,475	47,140
Accounts payable	47,199	51,578
Accrued expenses and other liabilities	59,610	46,624
Total current liabilities	243,067	151,875
Unamortized investment tax credits	2,180	2,254
Deferred income taxes, net	158,846	116,368
Pension and postretirement benefits other than pensions	244,901	232,110
Regulatory and other liabilities	92,593	79,050
Advances for construction	187,584	187,278
Contributions in aid of construction	158,574	154,191
Total capitalization and liabilities	1,995,924	1,854,587
Parent Company
Utility plant:
Utility plant	606	324
Less accumulated depreciation and amortization	(108)	(51)
Net utility plant	498	273
Current assets:
Cash and cash equivalents	1,470	89	188	532
Receivables		158
Receivables from affiliates	19,367	7,817
Total current assets	20,837	8,064
Other assets:
Investments in affiliates	492,188	466,515
Long-term affiliate notes receivable	31,218	28,921
Other assets	1,023	1,144
Total other assets	524,429	496,580
Total assets	545,764	504,917
Capitalization:
Common stockholders' equity	473,712	449,829
Affiliate long-term debt	7,781	7,832
Total capitalization	481,493	457,661
Current liabilities:
Short-term borrowings	64,475	47,140
Payables to affiliates	77	52
Accrued expenses and other liabilities	298	625
Total current liabilities	64,850	47,817
Deferred income taxes, net	(579)	(561)
Total capitalization and liabilities	545,764	504,917
Cal Water
Utility plant:
Utility plant	1,927,190	1,808,568
Less accumulated depreciation and amortization	(607,992)	(551,345)
Net utility plant	1,319,198	1,257,223
Current assets:
Cash and cash equivalents	34,609	18,475	40,446	6,000
Receivables	87,482	76,227
Receivables from affiliates	3,195	3,446
Other current assets	15,535	14,225
Total current assets	140,821	112,373
Other assets:
Regulatory assets	341,877	317,564
Long-term affiliate notes receivable	7,781	7,832
Other assets	40,005	31,662
Total other assets	389,663	357,058
Total assets	1,849,682	1,726,654
Capitalization:
Common stockholders' equity	442,923	417,810
Long-term debt, less current maturities	431,433	477,998
Total capitalization	874,356	895,808
Current liabilities:
Current maturities of long-term debt	46,104	5,851
Short-term borrowings	25,000
Payables to affiliates	1,152	190
Accounts payable	41,352	47,568
Accrued expenses and other liabilities	58,293	46,462
Total current liabilities	171,901	100,071
Unamortized investment tax credits	2,180	2,254
Deferred income taxes, net	155,481	113,925
Pension and postretirement benefits other than pensions	244,901	232,110
Regulatory and other liabilities	83,942	71,034
Advances for construction	186,753	185,902
Contributions in aid of construction	130,168	125,550
Total capitalization and liabilities	1,849,682	1,726,654
All Other Subsidiaries
Utility plant:
Utility plant	175,764	158,688
Less accumulated depreciation and amortization	(32,710)	(29,251)
Net utility plant	143,054	129,437
Current assets:
Cash and cash equivalents	2,711	8,639	1,643	3,334
Receivables	3,833	(4,797)
Receivables from affiliates	1,152	5
Other current assets	924	872
Total current assets	8,620	4,719
Other assets:
Regulatory assets	2,542	2,334
Other assets	7,062	7,081
Total other assets	9,604	9,415
Total assets	161,278	143,571
Capitalization:
Common stockholders' equity	54,774	54,377
Affiliate long-term debt	31,218	28,921
Long-term debt, less current maturities	3,034	3,634
Total capitalization	89,026	86,932
Current liabilities:
Current maturities of long-term debt	679	682
Payables to affiliates	22,485	11,026
Accounts payable	5,847	4,010
Accrued expenses and other liabilities	1,019	(547)
Total current liabilities	30,030	15,171
Deferred income taxes, net	4,334	3,435
Regulatory and other liabilities	8,651	8,016
Advances for construction	831	1,376
Contributions in aid of construction	28,406	28,641
Total capitalization and liabilities	161,278	143,571
Consolidating Adjustments
Utility plant:
Utility plant	(7,197)	(7,199)
Less accumulated depreciation and amortization	1,503	1,385
Net utility plant	(5,694)	(5,814)
Current assets:
Receivables from affiliates	(23,714)	(11,268)
Total current assets	(23,714)	(11,268)
Other assets:
Investments in affiliates	(492,188)	(466,515)
Long-term affiliate notes receivable	(38,999)	(36,753)
Other assets	(205)	(205)
Total other assets	(531,392)	(503,473)
Total assets	(560,800)	(520,555)
Capitalization:
Common stockholders' equity	(497,697)	(472,187)
Affiliate long-term debt	(38,999)	(36,753)
Total capitalization	(536,696)	(508,940)
Current liabilities:
Payables to affiliates	(23,714)	(11,268)
Accrued expenses and other liabilities		84
Total current liabilities	(23,714)	(11,184)
Deferred income taxes, net	(390)	(431)
Total capitalization and liabilities	$ (560,800)	$ (520,555)

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CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Details 4) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Operating activities:
Net income (loss)	$ 48,828	$ 37,712	$ 37,656
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation and amortization	56,866	51,981	45,265
Change in value of life insurance contracts	(2,504)	1,876	(2,641)
Gain on sale of non-utility property	(84)	(62)	(22)
Changes in deferred income taxes	34,133	2,723
Other changes in noncurrent assets and liabilities	(7,383)	1,693	(160)
Changes in operating assets and liabilities:
Other changes, net	2,058	15,349	(4,588)
Net adjustments	83,086	73,560	37,854
Net cash provided by operating activities	131,914	111,272	75,510
Investing activities:
Utility plant expenditures	(127,681)	(118,546)	(123,926)
Proceeds from sale of non-utility assets	85	64	34
Purchase of life insurance	(3,294)	(1,744)	(1,891)
Restricted cash increase (decrease)	1,959	(3,042)	3,169
Net cash used in investing activities	(128,931)	(123,268)	(122,614)
Financing activities:
Short-term borrowings	94,335	23,390	85,750
Repayment of short-term borrowings	(52,000)		(74,000)
Proceeds from long-term debt, net of issuance cost	124	178	106,173
Retirement of long-term debt	(7,037)	(2,963)	(13,692)
Advances and contributions in aid for construction	6,966	7,231	5,313
Refunds of advances for construction	(7,397)	(6,205)	(6,188)
Dividends paid to non-affiliates	(26,387)	(25,674)	(24,753)
Issuance of common stock		965	912
Net cash provided by (used in) financing activities	8,604	(3,078)	79,515
Change in cash and cash equivalents	11,587	(15,074)	32,411
Cash and cash equivalents at beginning of year	27,203	42,277	9,866
Cash and cash equivalents at end of year	38,790	27,203	42,277
Parent Company
Operating activities:
Net income (loss)	48,828	37,712	37,656
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Equity earnings of subsidiaries	(48,538)	(37,222)	(36,788)
Dividends received from affiliates	26,387	25,674	24,753
Depreciation and amortization	56	51
Other changes in noncurrent assets and liabilities	1,544	1,001	229
Changes in operating assets and liabilities:
Other changes, net	(170)	582	(1,054)
Net adjustments	(20,721)	(9,914)	(12,860)
Net cash provided by operating activities	28,107	27,798	24,796
Investing activities:
Utility plant expenditures	(281)		(324)
Affiliate advances	(12,245)	(25,495)	(14,579)
Proceeds from affiliate loans	552
Reduction of loans to affiliates	(5,675)	962	1,854
Net cash used in investing activities	(17,649)	(24,533)	(13,049)
Financing activities:
Short-term borrowings	18,335	23,390	16,750
Repayment of short-term borrowings	(1,000)		(5,000)
Affiliate advances	23
Reduction of affiliate long-term borrowings	(48)	(2,045)
Dividends paid to non-affiliates	(26,387)	(25,674)	(24,753)
Issuance of common stock		965	912
Net cash provided by (used in) financing activities	(9,077)	(3,364)	(12,091)
Change in cash and cash equivalents	1,381	(99)	(344)
Cash and cash equivalents at beginning of year	89	188	532
Cash and cash equivalents at end of year	1,470	89	188
Cal Water
Operating activities:
Net income (loss)	48,772	38,333	35,940
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation and amortization	54,040	49,283	42,680
Change in value of life insurance contracts	(2,504)	1,876	(2,641)
Gain on sale of non-utility property	(81)	(62)	(22)
Changes in deferred income taxes	34,133	2,723
Other changes in noncurrent assets and liabilities	(10,367)	(45)	(880)
Changes in operating assets and liabilities:
Other changes, net	9,035	11,662	(997)
Net adjustments	84,256	65,437	38,140
Net cash provided by operating activities	133,028	103,770	74,080
Investing activities:
Utility plant expenditures	(111,636)	(98,410)	(108,990)
Proceeds from sale of non-utility assets	82	64	34
Affiliate advances	254	1,597	85
Proceeds from affiliate loans	48
Reduction of loans to affiliates		45
Purchase of life insurance	(3,294)	(1,744)	(1,891)
Restricted cash increase (decrease)	1,959	(3,042)	3,169
Net cash used in investing activities	(112,587)	(101,490)	(107,593)
Financing activities:
Short-term borrowings	76,000		69,000
Repayment of short-term borrowings	(51,000)		(69,000)
Affiliate advances	962
Proceeds from long-term debt, net of issuance cost			103,947
Retirement of long-term debt	(6,310)	(2,279)	(12,212)
Advances and contributions in aid for construction	6,883	7,082	4,962
Refunds of advances for construction	(7,275)	(6,129)	(6,104)
Dividends paid to affiliates	(23,567)	(22,925)	(22,634)
Net cash provided by (used in) financing activities	(4,307)	(24,251)	67,959
Change in cash and cash equivalents	16,134	(21,971)	34,446
Cash and cash equivalents at beginning of year	18,475	40,446	6,000
Cash and cash equivalents at end of year	34,609	18,475	40,446
All Other Subsidiaries
Operating activities:
Net income (loss)	(306)	(1,131)	140
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation and amortization	2,888	2,771	2,716
Other changes in noncurrent assets and liabilities	1,307	684	1,089
Changes in operating assets and liabilities:
Other changes, net	(6,723)	3,054	(2,558)
Net adjustments	(2,528)	6,509	1,247
Net cash provided by operating activities	(2,834)	5,378	1,387
Investing activities:
Utility plant expenditures	(15,761)	(20,136)	(14,612)
Affiliate advances	(853)
Reduction of loans to affiliates		2,000
Net cash used in investing activities	(16,614)	(18,136)	(14,612)
Financing activities:
Affiliate advances	11,859	23,898	14,494
Proceeds from affiliates long-term borrowings	5,675
Reduction of affiliate long-term borrowings	(552)	(962)	(1,854)
Proceeds from long-term debt, net of issuance cost	124	178	2,226
Retirement of long-term debt	(727)	(684)	(1,480)
Advances and contributions in aid for construction	83	149	351
Refunds of advances for construction	(122)	(76)	(84)
Dividends paid to affiliates	(2,820)	(2,749)	(2,119)
Net cash provided by (used in) financing activities	13,520	19,754	11,534
Change in cash and cash equivalents	(5,928)	6,996	(1,691)
Cash and cash equivalents at beginning of year	8,639	1,643	3,334
Cash and cash equivalents at end of year	2,711	8,639	1,643
Consolidating Adjustments
Operating activities:
Net income (loss)	(48,466)	(37,202)	(36,080)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Equity earnings of subsidiaries	48,538	37,222	36,788
Dividends received from affiliates	(26,387)	(25,674)	(24,753)
Depreciation and amortization	(118)	(124)	(131)
Gain on sale of non-utility property	(3)
Other changes in noncurrent assets and liabilities	133	53	(598)
Changes in operating assets and liabilities:
Other changes, net	(84)	51	21
Net adjustments	22,079	11,528	11,327
Net cash provided by operating activities	(26,387)	(25,674)	(24,753)
Investing activities:
Utility plant expenditures	(3)
Proceeds from sale of non-utility assets	3
Affiliate advances	12,844	23,898	14,494
Proceeds from affiliate loans	(600)
Reduction of loans to affiliates	5,675	(3,007)	(1,854)
Net cash used in investing activities	17,919	20,891	12,640
Financing activities:
Affiliate advances	(12,844)	(23,898)	(14,494)
Proceeds from affiliates long-term borrowings	(5,675)
Reduction of affiliate long-term borrowings	600	3,007	1,854
Dividends paid to affiliates	26,387	25,674	24,753
Net cash provided by (used in) financing activities	$ 8,468	$ 4,783	$ 12,113

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CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012 Cal Water	Dec. 31, 2011 Cal Water	Dec. 31, 2010 Cal Water	Dec. 31, 2012 All Other Subsidiaries	Dec. 31, 2011 All Other Subsidiaries	Dec. 31, 2010 All Other Subsidiaries	Dec. 31, 2012 First Mortgage Bonds, 5.875% due 2019	Dec. 31, 2011 First Mortgage Bonds, 5.875% due 2019	Apr. 17, 2009 First Mortgage Bonds, 5.875% due 2019 Cal Water	Dec. 31, 2012 First Mortgage Bonds, 5.500% due 2040	Dec. 31, 2011 First Mortgage Bonds, 5.500% due 2040	Nov. 17, 2010 First Mortgage Bonds, 5.500% due 2040 Cal Water
Long-term debt
Debt issued									$ 100			$ 100
Interest rate (as a percent)							5.875%	5.875%	5.875%	5.50%	5.50%	5.50%
Ownership interest (as a percent)	100.00%	100.00%	100.00%	100.00%	100.00%	100.00%

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COMMITMENTS AND CONTINGENCIES (Tables)

12 Months Ended

Dec. 31, 2012

COMMITMENTS AND CONTINGENCIES

Schedule of commitments

	Facility Leases		System Lease		Water Contracts		Capital Lease Obligations
2013	$	632	$	845	$	19,378	$	1,109
2014		515		845		19,448		1,109
2015		404		845		19,521		1,109
2016		193		845		19,592		1,109
2017		166		845		19,664		1,109
Thereafter		2,494		493		451,891		8,609

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OTHER ACCRUED LIABILITIES (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
OTHER ACCRUED LIABILITIES
Accrued and deferred compensation	$ 16,320	$ 14,143
Deferred tax liability	15,000	10,535
Accrued benefit and workers' compensation claims	6,906	5,222
Other	8,282	8,026
Total	$ 46,508	$ 37,926

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COMMITMENTS AND CONTINGENCIES

12 Months Ended

Dec. 31, 2012

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES

14 COMMITMENTS AND CONTINGENCIES

• Commitments

        The Company leases offices, equipment and other facilities, two water systems from cities, and has long-term commitments to purchase water from water wholesalers. The commitments are noted in the table below.

	Facility Leases		System Lease		Water Contracts		Capital Lease Obligations
2013	$	632	$	845	$	19,378	$	1,109
2014		515		845		19,448		1,109
2015		404		845		19,521		1,109
2016		193		845		19,592		1,109
2017		166		845		19,664		1,109
Thereafter		2,494		493		451,891		8,609

        Company Facility leases include office and other facilities in many of its operating districts. The total paid and charged to operations for such leases was $1,156 in 2012, $1,271 in 2011, and $1,080 in 2010. The system lease is a 15-year lease with the City of Commerce. The lease includes an annual lease payment of $845 per year plus a cost savings sharing arrangement.

        The Company has a long-term contract with the Santa Clara Valley Water District that requires the Company to purchase minimum annual water quantities. Purchases are priced at the districts then-current wholesale water rate. The Company operates to purchase sufficient water to equal or exceed the minimum quantities under the contract. The total paid to Santa Clara Valley Water District was $6,164 in 2012, $5,524 in 2011, and $5,306 in 2010.

        The Company also has a water supply contract with Stockton East Water District (SEWD) that requires a fixed, annual payment. Each year, the fixed annual payment is adjusted for changes to SEWD's costs. Because of the fixed annual price arrangement, the Company operates to receive as much water as possible from SEWD in order to minimize the cost of operating Company-owned wells used to supplement SEWD deliveries. The total paid under the contract was $6,591 in 2012, $6,658 in 2011, and $6,159 in 2010.

        Estimated annual contractual obligations in the table above are based on the same payment levels as 2012. Future increased costs by SEWD are expected to be offset by a decline in the allocation of costs to the Company, as other customers of SEWD are expected to receive a larger allocation based upon growth of their service areas.

        On September 21, 2005, the Company entered into an agreement with Kern County Water Agency (Agency) to obtain treated water for the Company's operations. The term of the agreement is to January 1, 2035, or until the repayment of the Agency's bonds (described hereafter) occurs. Under the terms of the agreement, the Company is obligated to purchase approximately 18,000 acre feet of treated water in 2012 and an incrementally higher volume of water for each subsequent year until 2017, when the Company is obligated to purchase 20,500 acre feet of treated water per year. The Company is obligated to pay the Capital Facilities Charge and the Treated Water Charge regardless of whether it can use the water in its operation, and is obligated for these charges even if the Agency cannot produce an adequate amount to supply the 20,500 acre feet in the year. (This agreement supersedes a prior agreement with Kern County Water Agency for the supply of 11,500 acre feet of water per year). Total annual expense in 2012 was $6,272, $6,129 in 2011, and $5,454 in 2010.

        Three other parties, including the City of Bakersfield, are also obligated to purchase a total of 32,500 acre feet per year under separate agreements with the Agency. Further, the Agency has the right to proportionally reduce the water supply provided to all of the participants if it cannot produce adequate supplies. The participation of all parties in the transaction for expansion of the Agency's facilities, including the Water Purification Plant, purchase of the water, and payment of interest and principal on the bonds being issued by the Agency to finance the transaction is required as a condition to the obligation of the Agency to proceed with expansion of the Agency's facilities. If any of the other parties does not use its allocation, that party is obligated to pay its contracted amount.

        The Agency has issued bonds to fund the project and uses the payments of the Capital Facilities Charges by the Company and the other contracted parties to meet the Agency's obligations to pay interest and repay principal on the bonds. If any of the parties were to default on making payments of the Capital Facilities Charge, then the other parties are obligated to pay for the defaulting party's share on a pro-rata basis. If there is a payment default by a party and the remaining parties have to make payments, they are also entitled to a pro-rata share of the defaulting party's water allocation.

        The Company expects to use all its entitled water in its operations every year. In addition, if the Company were to pay for and receive additional amounts of water due to a default of another participating party; the Company believes it could use this additional water in its operations without incurring substantial incremental cost increases. If additional treated water is available, all parties have an option to purchase this additional treated water, subject to the Agency's right to allocate the water among the parties.

        The total obligation of all parties, excluding the Company, is approximately $82.4 million to the Agency. Based on the credit worthiness of the other participants, which are government entities, it is believed to be highly unlikely that the Company would be required to assume any other parties' obligations under the contract due to their default. In the event of default by a party, the Company would receive entitlement to the additional water for assuming any obligation.

        Once the project is complete, the Company is obligated to pay a Capital Facilities Charge and charges related to treated water that together total $7,160 annually, which equates to $349 dollars per acre foot. Annual payments of $3,600 for the Capital Facilities Charge began when the Agency issued bonds to fund the project. Total treated water charge for 2012 was $2,583. Once the entire expansion project is completed the full annual payments will be $7,160 which will continue through the term of the agreement. As treated water is being delivered, the Company is also obligated for its portion of the operating costs; that portion is currently estimated to be $7 dollars per acre foot. The actual amount will vary due to variations from reimbursable operating cost estimates, inflation, and other changes in the cost structure. The Company's overall estimated cost of $349 dollars per acre foot is less than the estimated cost of procuring untreated water (assuming water rights could be obtained) and then providing treatment.

        There are three capital leases, the most significant was the City of Hawthorne water system. In 2011, we entered into a 15-year capital lease agreement to operate the City of Hawthorne water system. The system, which is located near the Hermosa-Redondo district, serves about half of Hawthorne's population. The agreement required us to make an up-front $8,100 lease deposit to the city that is being amortized over the lease term. Additionally, annual lease payments of $940 are made to the city and shall be increased or decreased each year on July 1, by the same percentage that the rates charged to customers served by the water system increased or decreased, exclusive of pass-through increases or decreases in the cost of water, power, and city-imposed fees, compared to the rates in effect on July 1 of the prior year, provided, that in no event will the annual lease payment be less than $940. Under the lease we are responsible for all aspects of system operation and capital improvements, although title to the system and system improvements reside with the city. In exchange, we receive all revenue from the water system, which was $7,621, $7,506, and $7,547 in 2012, 2011, and 2010, respectively. At the end of the lease, the city is required to reimburse us for the unamortized value of capital improvements made during the term of the lease. The annual payments were $940 in 2012, $537 in 2011, and $116 in 2010.

• Contingencies

  Groundwater Contamination

        The Company has undertaken litigation against third parties to recover past and future costs related to ground water contamination in our service areas. The cost of litigation is expensed as incurred and any settlement is first offset against such costs. The Commission general policy require all proceeds from contamination litigation to be used first to pay transactional expenses, then to make ratepayers whole for water treatment costs to comply with the Commission's water quality standards. The Commission allows for a risk-based consideration of contamination proceeds which exceed the costs of the remediation described above and may result in some sharing of proceeds with the shareholder, determined on a case by case basis. The Commission has authorized various memorandum accounts that allow the Company to track significant litigation costs to request recovery of these costs in future filings and uses of proceeds to comply with Commission's general policy.

• Other Legal Matters

        From time to time, the Company is involved in various disputes and litigation matters that arise in the ordinary course of business. The status of each significant matter is reviewed and assessed for potential financial exposure. If the potential loss from any claim or legal proceeding is considered probable and the amount of the range of loss can be estimated, a liability is accrued for the estimated loss in accordance with the accounting standards for contingencies. Legal proceedings are subject to uncertainties, and the outcomes are difficult to predict. Because of such uncertainties, accruals are based on the best information available at the time. While the outcome of these disputes and litigation matters cannot be predicted with any certainty, management does not believe when taking into account existing reserves the ultimate resolution of these matters will materially affect the Company's financial position, results of operations, or cash flows.

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OTHER INCOME AND EXPENSES (Tables)

12 Months Ended

Dec. 31, 2012

OTHER INCOME AND EXPENSES

Schedule of various non-regulated activities

	2012					2011				2010
	Revenue		Expense			Revenue		Expense		Revenue		Expense
Operating and maintenance	$	9,938	$	10,976		$	9,176	$	9,689	$	9,237	$	9,713
Meter reading and billing		1,255		882			1,212		944		1,207		990
Leases		1,956		153			1,892		330		2,162		877
Design and construction		1,407		1,135			1,689		1,420		1,306		1,041
Interest income		41		—			75		—		28		—
Change in value of life insurance contracts (gain) loss		—		(2,504	)		—		1,876		—		(2,641	)
Other non-regulated income and expenses		2,089		911			2,116		1,563		2,053		2,332
Total	$	16,686	$	11,553		$	16,160	$	15,822	$	15,993	$	12,312

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SHORT-TERM BORROWINGS (Details) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Jun. 29, 2011
Short-term borrowings
Maximum borrowing capacity			$ 400,000,000
Basis of interest rate	LIBOR
Borrowings under the bank lines of credit
Maximum short-term borrowings	89,475,000	47,140,000
Average amount outstanding	71,715,000	32,324,000
Weighted average interest rate (as a percent)	1.74%	2.41%
Interest rate at end of period (as a percent)	2.14%	2.10%
Minimum
Short-term borrowings
Interest rate margin (as a percent)	0.725%
Commitment fee (as a percent)	0.08%
Maximum
Short-term borrowings
Interest rate margin (as a percent)	0.95%
Commitment fee (as a percent)	0.125%
California Water Service Group
Short-term borrowings
Maximum borrowing capacity			100,000,000
Amount outstanding under line of credit	64,500,000	47,100,000
Cal Water
Short-term borrowings
Maximum borrowing capacity			300,000,000
Period within which borrowings are to be repaid (in months)	12
Amount outstanding under line of credit	$ 25,000,000

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details 4) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Depreciable plant and equipment
Total	$ 1,903,365	$ 1,807,569
Provision for depreciation expressed as a percentage of the aggregate depreciable asset balances	3.10%	3.00%	2.80%
Asset Retirement Obligation
Estimated retirement obligation	16,105	14,049
Minimum
Depreciable plant and equipment
Equipment, Useful Lives (in years)	P5Y
Transmission and distribution plant, Useful Lives (in years)	P40Y
Maximum
Depreciable plant and equipment
Equipment, Useful Lives (in years)	P50Y
Transmission and distribution plant, Useful Lives (in years)	P65Y
Office Buildings and other structures, Useful Lives (in years)	P50Y
Utility Plant
Depreciable plant and equipment
Equipment	400,610	382,195
Transmission and distribution plant	1,351,158	1,287,010
Office buildings and other structures	151,597	138,364
Total	$ 1,903,365	$ 1,807,569

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Consolidated Statements of Common Stockholders' Equity (USD $) In Thousands, unless otherwise specified	Total	Common Stock	Additional Paid-in Capital	Retained Earnings
Balance at Dec. 31, 2009	$ 420,634	$ 416	$ 215,320	$ 204,898
Balance (in shares) at Dec. 31, 2009		41,531
Increase (Decrease) in Stockholders' Equity
Net income	37,656			37,656
Issuance of common stock	1,989		1,989
Issuance of common stock (in shares)		136
Dividends paid on common stock ($0.630, $0.615 and $0.595 per share for the years ended December 31, 2012, 2011 and 2010 respectively)	(24,753)			(24,753)
Balance at Dec. 31, 2010	435,526	416	217,309	217,801
Balance (in shares) at Dec. 31, 2010		41,667
Increase (Decrease) in Stockholders' Equity
Net income	37,712			37,712
Issuance of common stock	2,265	2	2,263
Issuance of common stock (in shares)		150
Dividends paid on common stock ($0.630, $0.615 and $0.595 per share for the years ended December 31, 2012, 2011 and 2010 respectively)	(25,674)			(25,674)
Balance at Dec. 31, 2011	449,829	418	219,572	229,839
Balance (in shares) at Dec. 31, 2011		41,817
Increase (Decrease) in Stockholders' Equity
Net income	48,828			48,828
Issuance of common stock	1,442	1	1,441
Issuance of common stock (in shares)		91
Dividends paid on common stock ($0.630, $0.615 and $0.595 per share for the years ended December 31, 2012, 2011 and 2010 respectively)	(26,387)			(26,387)
Balance at Dec. 31, 2012	$ 473,712	$ 419	$ 221,013	$ 252,280
Balance (in shares) at Dec. 31, 2012		41,908

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OTHER INCOME AND EXPENSES

12 Months Ended

Dec. 31, 2012

OTHER INCOME AND EXPENSES

OTHER INCOME AND EXPENSES

3 OTHER INCOME AND EXPENSES

        The Company conducts various non-regulated activities as reflected in the table below.

	2012					2011				2010
	Revenue		Expense			Revenue		Expense		Revenue		Expense
Operating and maintenance	$	9,938	$	10,976		$	9,176	$	9,689	$	9,237	$	9,713
Meter reading and billing		1,255		882			1,212		944		1,207		990
Leases		1,956		153			1,892		330		2,162		877
Design and construction		1,407		1,135			1,689		1,420		1,306		1,041
Interest income		41		—			75		—		28		—
Change in value of life insurance contracts (gain) loss		—		(2,504	)		—		1,876		—		(2,641	)
Other non-regulated income and expenses		2,089		911			2,116		1,563		2,053		2,332
Total	$	16,686	$	11,553		$	16,160	$	15,822	$	15,993	$	12,312

        Operating and maintenance services and meter reading and billing services are provided for water and wastewater systems owned by private companies and municipalities. The agreements call for a fee-per-service or a flat-rate amount per month. Leases have been entered into with telecommunications companies for cellular phone antennas placed on the Company's property. Design and construction services are for the design and installation of water mains and other water infrastructure for others outside the Company's regulated service areas. Third-party insurance program revenues are included in other non-regulated income and expenses.

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STOCK BASED COMPENSATION PLANS (Details) (USD $) In Thousands, except Share data, unless otherwise specified		12 Months Ended					12 Months Ended					12 Months Ended
	Dec. 31, 2012 plan	Dec. 31, 2012 Long-Term Incentive Plan Options	Dec. 31, 2012 Equity Incentive Plan	Dec. 31, 2011 Equity Incentive Plan	Dec. 31, 2010 Equity Incentive Plan	Apr. 27, 2005 Equity Incentive Plan	Dec. 31, 2012 Equity Incentive Plan Outside directors	Dec. 31, 2012 Equity Incentive Plan Restricted Stock Awards (RSAs)	Dec. 31, 2011 Equity Incentive Plan Restricted Stock Awards (RSAs)	Dec. 31, 2012 Equity Incentive Plan Restricted Stock Awards (RSAs) Director	Dec. 31, 2012 Equity Incentive Plan Restricted Stock Awards (RSAs) Outside directors	Dec. 31, 2012 Equity Incentive Plan Restricted Stock Awards (RSAs) Restricted stock awards to employees	Dec. 31, 2012 Equity Incentive Plan Stock Appreciation Rights (SARs)	Dec. 31, 2009 Equity Incentive Plan Stock Appreciation Rights (SARs) Y
STOCK-BASED COMPENSATION PLANS
Number of stockholder-approved stock-based compensation plans	2
Stock-based Compensation
Options vested on anniversary date (as a percent)		25.00%
Vesting period		4 years					12 months			12 months		48 months	48 months
Expiration period of award (in years)		P10Y											P10Y
Shares authorized to be issued under the plan						2,000,000
Awards granted (in shares)								101,236	85,426
Awards cancelled (in shares)								10,050					27,500
Weighted average grant date fair value (in dollars per share)								$ 17.97	$ 17.44
Percentage of RSAs granted to outside directors expected to vest											100.00%
Assumptions utilized to determine the grant-date fair value
Expected dividend yield (as a percent)														3.07%
Expected volatility (as a percent)														22.10%
Risk-free interest rate (as a percent)														2.84%
Expected holding period (in years)														6.75
SARs outstanding and RSAs
Stock Appreciation Rights (SAR) outstanding													333,856
Exercisable (in shares)													325,602
Weighted average fair value of shares exercisable (in dollars per share)													$ 3.66
Compensation expense
Recorded compensation costs for the RSAs and SARs			$ 1,442	$ 1,300	$ 1,077
Unrecognized future compensation expense for the RSAs and SARs			$ 1,913

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INTANGIBLE ASSETS (Tables)

12 Months Ended

Dec. 31, 2012

INTANGIBLE ASSETS

Schedule of intangible assets that will continue to be amortized and those not amortized

	Weighted Average Amortization Period (years)	2012						2011
		Gross Carrying Value		Accumulated Amortization		Net Carrying Value		Gross Carrying Value		Accumulated Amortization		Net Carrying Value
Amortized intangible assets:
Water pumping rights	usage	$	1,084	$	79	$	1,005	$	1,084	$	14	$	1,070
Water planning studies	12		11,894		4,322		7,572		11,087		3,413		7,674
Leasehold improvements and other	21		1,140		249		891		1,086		345		741
Total	13	$	14,118	$	4,650	$	9,468	$	13,257	$	3,772	$	9,485
Unamortized intangible assets:
Perpetual water rights and other		$	4,495	$	—	$	4,495	$	3,229	$	—	$	3,229

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012 M D	Dec. 31, 2011
Revenue
Maturity period of commercial paper (in days)	90
Period within which revenues and associated costs reported as net regulatory balancing accounts related to the WRAM and MCBA that are deferred, are not expected to be collected (in months)	12
Expected collection period for operating income reported as net regulatory balancing accounts related to the WRAM and MCBA that are deferred (in months)	24
Unearned revenue liability	$ 1,708	$ 1,871
Operating Revenues
Net WRAM and MCBA deferral at the beginning of the period	12,864
Reversal of deferred amounts during the period	(12,864)
Deferred amounts added during the period	882
Net WRAM and MCBA deferral at the end of the period	882
Operating Costs
Net WRAM and MCBA deferral at the beginning of the period	10,492
Reversal of deferred amounts during the period	(10,492)
Deferred amounts added during the period	719
Net WRAM and MCBA deferral at the end of the period	719
Income Before Income Taxes
Net WRAM and MCBA deferral at the beginning of the period	2,372
Reversal of deferred amounts during the period	(2,372)
Deferred amounts added during the period	163
Net WRAM and MCBA deferral at the end of the period	163
Regulatory Assets and Liabilities
Net short-term receivable	34,020	21,680
Net long-term receivable	344,419	319,898
Total receivable	344,419	319,898
Net short-term payable	5,018	2,655
Total payable	35,720	28,037
Minimum
Regulatory Assets and Liabilities
Expected collection period for undercollected net WRAM and MCBA receivables (in months)	12
Maximum
Regulatory Assets and Liabilities
Expected collection period for undercollected net WRAM and MCBA receivables (in months)	18
Net WRAM and MCBA accounts payable
Regulatory Assets and Liabilities
Net short-term payable	371	543
Net long-term payable	119	145
Total payable	490	688
Net WRAM and MCBA accounts receivable
Regulatory Assets and Liabilities
Net short-term receivable	34,020	19,357
Net long-term receivable	12,051	30,268
Total receivable	$ 42,071	$ 49,625

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FAIR VALUE OF FINANCIAL INSTRUMENTS

12 Months Ended

Dec. 31, 2012

FAIR VALUE OF FINANCIAL INSTRUMENTS

FAIR VALUE OF FINANCIAL INSTRUMENTS

13 FAIR VALUE OF FINANCIAL INSTRUMENTS

        The accounting guidance for fair value measurements and disclosures provides a single definition of fair value and requires certain disclosures about assets and liabilities measured at fair value. A hierarchal framework for disclosing the observability of the inputs utilized in measuring assets and liabilities at fair value is established by this guidance. The three levels in the hierarchy are as follows:

Level 1—Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. The types of assets and liabilities included in Level 1 are highly liquid and actively traded instruments with quoted prices.

Level 2—Pricing inputs are other than quoted prices inactive markets, but are either directly or indirectly observable as of the reporting date. The types of assets and liabilities included in Level 2 are typically either comparable to actively traded securities or contracts, or priced with discounted cash flow or option pricing models using highly observable inputs.

Level 3—Significant inputs to pricing have little or no observability as of the reporting date. The types of assets and liabilities included in Level 3 are those valued with models requiring significant management judgment or estimation.

        Specific valuation methods include the following:

        Cash equivalents, accounts receivable and accounts payable carrying amounts approximated the fair value because of the short-term maturity of the instruments.

        Long-term debt fair values were estimated using the published quoted market price, if available, or the discounted cash flow analysis, based on the current rates available using a risk-free rate (a U.S. Treasury securities yield curve) plus a risk premium of 1.19%.

        Advances for construction fair values were estimated using broker quotes from companies that frequently purchase these investments.

	December 31, 2012
			Fair Value
	Cost		Level 1		Level 2		Level 3		Total
Long -term debt, including current maturities	$	481,250	$	—	$	613,211	$	—	$	613,211
Advances for construction		187,584		—		70,914		—		70,914
Total	$	668,834	$	—	$	684,125	$	—	$	684,125

	December 31, 2011
			Fair Value
	Cost		Level 1		Level 2		Level 3		Total
Long -term debt, including current maturities	$	488,165	$	—	$	625,202	$	—	$	625,202
Advances for construction		187,278		—		69,952		—		69,952
Total	$	675,443	$	—	$	695,154	$	—	$	695,154