1SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549FORM 10-K
FOR ANNUALREPORTAND TRANSITION REPORTS
PURSUANT TOSECTIONSECTIONS 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934FOR THE FISCAL YEAR ENDED DECEMBER 31, 1999 COMMISSION REGISTRANT AND STATE OF INCORPORATION IRS EMPLOYE FILE NO. ADDRESS AND TELEPHONE NUMBER IDENTIFICATION NO. ------------- ------------------------------------- ------------------ 333-47647 American States Water Company 95-4676679 (A California Corporation) 630 East Foothill Boulevard San Dimas, California 91773-9016 909-394-3600 000-01121 Southern California Water Company 95-1243678 (A California Corporation) 630 East Foothill Boulevard San Dimas, California 91773-9016 909-394-3600(Mark One)
x Annual Report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 for the fiscal year ended December 31, 2003 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 Registrant, State of Incorporation IRS Employer File Number Address and Telephone Number Identification No. 333-47647 American States Water Company
(Incorporated in California)
630 East Foothill Boulevard, San Dimas 91773
(909) 394-360095-4676679 000-01121 Southern California Water Company
(Incorporated in California)
630 East Foothill Boulevard, San Dimas 91773
(909) 394-360095-1243678 Securities registered pursuant to Section 12(b) of the Act:
AMERICAN STATES WATER COMPANY COMMON SHARES, $2.50 STATED VALUE NEW YORK STOCK EXCHANGE - -------------------------------------- --------------------------------------
Title of Each Class Name of Each Exchange on Which Registered American States Water Company Common Shares
Rights to Purchase Junior Participating Preferred StockNew York Stock Exchange Securities registered pursuant to Section 12(g) of the Act:
NONENoneIndicate by check mark whether Registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that Registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
American States Water Company Yes
[x]x No[ ]o
Southern California Water Company Yes[x]x No[ ]oIndicate 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'sRegistrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form10-K [ ]10-K.oIndicate by check mark whether the Registrant is an accelerated filer (as defined in Rule 12b-2 of the Act.).
American States Water Company Yesx Noo
Southern California Water Company Yeso NoxThe aggregate market value of the total voting common stock held by non-affiliates of American States Water Company was approximately $415,019,000 and $377,022,000 on June 30, 2003 and March 18, 2004, respectively. The closing price per Common Share on March 18, 2004, as quoted in the Western Edition ofThe Wall Street Journal, was $24.75. As of March 18, 2004, the number of Common Shares of American States Water Company, outstanding was 15,233,227. As of that same date, American States Water Company owned all 110 outstanding Common Shares of Southern California Water Company. The aggregate market value of the total voting stock held by non-affiliates of
American StatesSouthern California Water Company wasapproximately $263,068,000zero on June 30, 2003 and March20, 2000. The closing price per Common Share on that date, as quoted in18, 2004.Documents Incorporated by Reference:
Portions of the
Western Edition of The Wall Street Journal, was $29-3/8. Voting Preferred SharesProxy Statement of American States Water Companyfor which there is no established market, were valued on March 20, 2000 at $1,793,000 based on a yield of 4.80%. As of March 20, 2000, the number of Common Shares of American States Water Company, $2.50 Stated Value, outstanding was 8,957,671. As of that same date, all 100 outstanding Common Shares of Southern California Water Company were owned by American States Water Company. DOCUMENTS INCORPORATED BY REFERENCE Portions of the Proxy Statementwill be subsequently filed with the Securities and Exchange Commission as to Part III, Item Nos. 10, 11, 12, 13 and13,14, in each case as specifically referenced herein.2AMERICAN STATES WATER COMPANY
AND
and
SOUTHERN CALIFORNIA WATER COMPANYFORM 10-K
INDEX
3 ITEMPART I
Item 1.
BUSINESSBusinessThis annual report on Form 10-K is a combined report being filed by two separate Registrants: American States Water Company (hereinafter
"AWR"“AWR”) and Southern California Water Company (hereinafter"SCW"“SCW”). References in this report to"Registrant"“Registrant” are to AWR and SCW, collectively, unless otherwise specified. SCW makes no representations as to the information contained in this report relating to AWR and its subsidiaries, other than SCW.GENERALAWR
wasmakes its periodic reports, Form 10-Q and Form 10-K, and current reports, Form 8-K, available free of charge through its website, www.aswater.com, as soon as material is electronically filed with or furnished to the Securities and Exchange Commission (SEC). Such reports are also available on the SEC’s internet website at http://www.sec.gov. AWR also makes available free of charge its code of business conduct and ethics, its corporate governance guidelines and the charters of its corporate governance/nominating committee, its compensation committee and its audit committee through its website or by calling (800) 999-4033. AWR has filed the certification officers required by Section 302 of the Sarbanes-Oxley Act as Exhibit 31 to its Form 10-K for the year ended December 31, 2003.General
AWR, incorporated in 1998, is engaged in
connection withtheformationbusiness ofaholding,company by SCW and became a public company on July 1, 1998. AWR has no material assets other thanfor investment, thecommonstock primarily of utility companies. AWR’s principal investment is the stock of SCW. SCW is a California public utility company engaged principally in the purchase, production, distribution and sale of water (SIC No. 4941). SCW also distributes electricity in one customer service area (SIC No. 4911). SCW is regulated by theCaliforniaPublic Utilities Commission of the State of California (CPUC) and was incorporated on December 31,1929 under the laws of the State of California. AWR has another subsidiary, American States Utility Services, Inc. (ASUS) which contracts to lease, operate and maintain governmentally owned water and wastewater systems and to provide other services to local governments to assist them in the operation and maintenance of their water and wastewater systems. Neither AWR nor ASUS are regulated by the CPUC.1929. SCW is organized intothree regions andone electric customer service area and three water service regions operating within 75 communities in 10 counties in the State of California and provides water service in 21 customer service areas. Region I incorporates 7 customer service areas in northern and central California; Region II has 4 customer service areas located in LosAngeles;Angeles County; Region III incorporates 10 water customer serviceareas.areas in eastern Los Angeles County, and in Orange, San Bernardino and Imperial counties. SCW also provides electric service to the City of Big Bear Lake and surrounding areas in San BernardinoCounty. All electric energy sold by SCW to customers inCounty through its Bear Valley Electriccustomerservicearea was purchased under an energy brokeragedivision.AWR also owns two other subsidiaries. American States Utility Services, Inc. (ASUS). ASUS performs nonregulated, water related services and operations on a contract
with Sempra Energy Corporationbasis ranging fromMarch 26, 1996services, such as billing and meter reading, toMay 1, 1999, and with Illinova Energy Partners, currently under the namefull operation ofDynegy Energy Services resulting from the merger of Dynegy and Illinova, since May 1, 1999. SCW served 244,086watercustomers and 21,181 electric customers at December 31, 1999, or a total of 265,267 customers, compared with 263,499 total customers at December 31, 1998. ACQUISITION OF PEERLESS WATER CO. In December 1999, Registrant agreed to acquire Peerless Water Co., a privately owned water company in Bellflower, California, subject to satisfaction of certain conditions, including CPUC approval. The number of Common Shares to be issued will be determined at the closing, but will in no event be greater than 131,036 shares nor less than 107,538 shares. ACQUISITION OF CHAPARRAL CITY WATER COMPANY On March 10, 2000, Registrant entered into an agreement to acquire the common stock ofutility related systems. Chaparral City Water Companya privately operated water(CCWC) is an Arizona public utility company servingapproximately 10,000 customers inthe town of Fountain Hills, Arizona andportionsa portion of the City of Scottsdale, Arizonafor an aggregate value of $31.2 million, including assumption of approximately $12 million in debt. Chaparral City Water Company was purchased from MCO Properties Inc., a wholly-owned subsidiary of MAXXAM Inc. This marks the first acquisition outside of California for Registrant.(SIC No. 4941). Thesale of Chaparral City Water Company requires notification to theArizona Corporation Commission (ACC) regulates CCWC. Neither AWR nor ASUS is directly regulated by either the CPUC or the ACC.SCW served 250,082 water customers and
other conditions customary22,276 electric customers at December 31, 2003, or a total of 272,358 customers, compared with 270,498 total customers at December 31, 2002. CCWC served 12,171 water customers as of December 31, 2003, compared with 11,834 customers at December 31, 2002. ASUS has approximately 90,000 billing accounts under contract.Certain financial information for each of AWR’s principal business units, water distribution, electric distribution and nonregulated contract services is set forth in
transactionsNote 14 to the Notes to Consolidated Financial Statements ofthis type. The approvalAmerican States Water Company and its Subsidiaries. None ofRegistrant's shareholders is not required. It is anticipated thatthetransaction will close within one year. 14 COMPETITIONCompany’s business segments are dependent upon a single or only a few customers.The business of each of the Company’s business segments is seasonal. The impact of seasonality on the Company’s businesses is discussed in more detail in Item 7 – “Management’s Discussion and Analysis of Financial Condition and Results of Operation-Risk Factors”.
The Company does not have any material capital expenditures for specific environmental control facilities or measures. However, groundwater contamination and environmental regulation have increased our operating costs and expenses. Additional information on the impact of environmental issues on our business is discussed in more detail in Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operation-Environmental Matters” and “Risk Factors”.
1
Competition
The businesses of SCW
isand CCWC are substantially free from direct and indirect competition with other public utilities, municipalities and other public agencies.AWR'sAWR’s other subsidiary, ASUS, actively competes for business with other investor-owned utilities, other third party providers of water and wastewater services, and governmental entities on the basis of price and quality of service.EMPLOYEE RELATIONS RegistrantEmployee Relations
SCW had
492500 employees as of December 31,19992003 as compared to470488 at December 31,1998. Seventeen2002. Sixteen positions inSCW'sSCW’s Bear Valley Electric customer service area are covered by a collective bargainingunionagreement, whichexpires in 2002,will expire on December 31, 2005, with the International Brotherhood of ElectricalWorkers. SixtyWorkers (IBEW). Fifty-five positions inSCW's MetropolitanSCW’s Region II ratemaking district are covered by a collective bargainingunitagreement, which expires in2001,2004, with the Utility Workers ofAmerica. RegistrantAmerica (UWOA). SCW has no other unionized employees.ITEMCCWC had fifteen employees as of December 31, 2003, all of whom are non-union. ASUS had five employees as of December 31, 2003, all of whom are non-union.
Item 2 -
PROPERTIES FRANCHISES AND CONDEMNATION OF PROPERTIES SCW holds franchises from incorporated communities and counties which it serves.PropertiesFranchises
SCW holds certificates of public convenience and necessity granted by the CPUC in each of the ratemaking districts it serves.
SCW'sCCWC holds certificates of public convenience and necessity granted by the ACC for the areas in which it serves. Both SCW and CCWC hold franchises, easements andsimilarrights of way pursuant to the terms of agreements that must periodically be renewed. These agreements are subject toalteration,suspension orrepealtermination in certain circumstances if SCW or CCWC, as applicable, violate the terms of the agreements.Electric Properties
SCW’s electric properties are all located in the Big Bear area of San Bernardino County in California. As of December 31, 2003, SCW operated 29 miles of overhead 34.5 kv transmission lines, 1 mile of underground 34.5 kv transmission lines, 174 miles of 4.16 kv or 2.4 kv distribution lines, 42 miles of underground cable and 14 sub-stations. Demand for energy in SCW’s Bear Valley Electric customer service area generally has been increasing. SCW is constructing a natural gas-fueled 8.4 MW generation facility to be owned by SCW as a means of meeting these increasing demands for energy. It is expected that the
respective governmental authorities having jurisdiction.generator will be on line during the second quarter of 2004.Office Buildings
Registrant’s general headquarters are housed in a single-story office building located in San Dimas, California. The land and the building are owned by SCW. SCW also owns and/or leases certain facilities housing regional, district and customer service offices. CCWC owns its primary office space. ASUS leases an office facility in Sacramento under a 12-month lease arrangement.
Water Properties
As of December 31, 2003, SCW’s physical properties consisted of water transmission and distribution systems which included 2,672 miles of pipeline together with services, meters and fire hydrants and approximately 430 parcels of land, generally less than 1 acre each, on which are located wells, pumping plants, reservoirs and other water utility facilities, including five surface water treatment plants.
As of December 31, 2003, SCW owned 280 wells. Certain wells have been removed from service due to water quality problems. For further information, see the section entitled “Environmental Matters” included in Part II, Item 7 in Management’s Discussion and Analysis of Financial Condition and Results of Operation. All wells are equipped with pumps with an aggregate capacity of approximately 275 million gallons per day. SCW has 58 connections to the water distribution facilities of the Metropolitan Water District of Southern California (MWD) and other municipal water agencies. SCW’s storage reservoirs and tanks have an aggregate capacity of approximately 109 million gallons. SCW owns no dams in its customer service areas. The following table provides, in greater detail, selected water utility plant of SCW for each of its water ratemaking districts:
2
Pumps Distribution Facilities Reservoirs District Well Booster Mains Services Hydrants Tanks Capacity Arden Cordova 24 17 93 15,064 1,207 5 9,500 Barstow 23 36 163 8,572 994 13 7,525 Bay Point 3 15 31 4,876 343 7 4,046 Calipatria 0 8 25 1,170 130 8 13,241 Claremont 25 32 152 10,587 1,270 12 6,689 (1) Clearlake 0 13 37 2,112 75 3 1,220 Desert 17 20 90 3,507 564 11 1,477 Los Osos 11 11 38 3,224 173 8 1,422 Metro 70 75 947 99,837 8,257 33 25,930 Ojai 5 14 45 2,825 350 5 1,494 Orange 31 38 417 41,909 4,610 15 11,900 San Dimas 11 38 222 15,930 1,603 15 10,147 San Gabriel 18 8 94 12,024 809 3 1,520 Santa Maria 32 25 183 12,836 783 8 3,076 Simi 2 25 97 13,186 891 8 8,250 Wrightwood 8 5 38 2,652 242 7 1,546
Total 280 380 2,672 250,311 22,301 161 108,983
Capacity is measured in thousands of gallons. Mains are in miles.
(1) SCW has additional reservoir capacity through a right to use an 8 MG reservoir owned by Three Valleys Municipal Water District.
As of December 31, 2003, CCWC’s physical properties consisted of water transmission and distribution systems, which included 180 miles of pipeline, together with services, meters, fire hydrants, wells, reservoirs with a combined storage capacity of 7.05 million gallons and other water utility facilities including a surface water treatment plant, which treats water from the Central Arizona Project.
Mortgage and Other Liens
As of December 31, 2003, SCW had no mortgage debt outstanding, and its properties were substantially free of any encumbrances or liens securing indebtedness. For further information, see the section entitled “Contractual, Obligations and Other Commitments”in Part II, Item 7 in Management’s Discussion and Analysis of Financial Condition and Results of Operation.
As of December 31, 2003, substantially all of the utility plant of CCWC was pledged to secure its Industrial Development Authority Bonds, which among other things, restricts CCWC’s ability to incur debt and make liens, sell, lease or dispose of assets, or merge with another corporation, and pay dividends.
As of December 31, 2003, neither AWR nor ASUS had any mortgage debt or liens securing indebtedness outstanding.
Condemnation of Properties
The laws of the State of California and the State of Arizona provide for the acquisition of public utility property by governmental agencies through their power of eminent domain, also
knownknow ascondemnation.condemnation, where doing so is in the public interest. In addition, however, the laws of the State of California also provide: (1) that the owner of the utility property may contest whether the condemnation is actually in the public interest; and (2) that the owner is entitled to receive the fair market value of its property if the property is ultimately taken. Although the City of Claremont, California located in SCW’s Region III, has not initiated the formal condemnation process pursuant to California law, the City has hired a consultant to perform an appraisal of the value of Registrant’s water system serving that city. SCW intends to vigorously defend itself against any condemnation action if initiated by the City. Except for the City of Claremont, Registrant has not been, within the last three years, involved in activities related to the condemnation of any of its water customer service areas or in its Bear Valley Electric customer service area.ELECTRIC PROPERTIES SCW's electric properties are all located in the Big Bear area of San Bernardino County. As of December 31, 1999, SCW operated 28.7 miles of overhead 34.5 KV transmission lines, 0.6 miles of underground 34.5 KV transmission lines, 173.1 miles of 4.16 KV or 2.4 KV distribution lines, 41.7 miles of underground cable and 14 sub-stations. There are no generating plants in SCW's system. OFFICE BUILDINGS Registrant's general offices are housed in a single-story office building located in San Dimas, California. The land and the building, which was completed and occupied in early 1990, are owned by Registrant. The Registrant also owns and occupies certain facilities housing regional, district and customer service offices while other such facilities are housed in leased premises. WATER PROPERTIES As of December 31, 1999, SCW's physical properties consisted of water transmission and distribution systems which included 2,742 miles of pipeline together with services, meters and fire hydrants and 436 parcels of land, generally less than 1 acre each, on which are located wells, pumping plants, reservoirs and other water utility facilities including five surface water treatment plants. 25 As of December 31, 1999, SCW owned 297 wells. Certain wells have been removed from service due to water quality problems. (See Environmental Matters to the Management's Discussion and Analysis) All wells are equipped with pumps with an aggregate capacity of approximately 240 million gallons per day. SCW has 40 connections to the water distribution facilities of the Metropolitan Water District of Southern California (MWD) and other municipal water agencies. SCW's storage reservoirs and tanks have an aggregate capacity of approximately 97 million gallons. SCW owns no dams in its customer service areas. The following table provides, in greater detail, selected water utility plant of SCW for each of its water ratemaking districts:
Pumps Distribution Facilities Reservoirs ------------------------ ---------------------------------------------------- ------------------------ District Well Booster Mains Meters Services Hydrants Tanks Capacity - ------------- ---------- ---------- ---------- ---------- ---------- ---------- ---------- ----------Arden Cordova 27 17 476,694 3,392 8,452 1,186 3 4,000 Barstow 24 37 873,447 13,734 10,784 1,013 13 8,025 Bay Point 3 14 161,504 5,295 3,465 341 7 4,046 Calipatria 0 8 139,180 1,200 1,664 84 1 150 Claremont 28 35 721,021 14,139 11,184 1,176 13 16,061 Clearlake 0 13 192,298 2,743 954 75 4 847 Desert 16 20 750,004 7,492 4,570 575 13 1,477 Los Osos 8 10 201,408 3,973 1,466 167 5 1,134 Metro 79 83 4,799,404 171,815 109,478 7,719 41 25,209 Ojai 5 12 234,319 5,168 3,436 348 4 1,490 Orange 33 38 2,202,610 66,503 41,712 4,534 16 11,755 San Dimas 11 38 1,491,515 34,485 8,096 879 16 10,149 San Gabriel 23 8 553,449 11,298 13,073 792 3 1,520 Santa Maria 30 24 961,541 22,367 7,648 775 9 3,173 Simi 2 23 503,632 14,522 10,138 873 8 6,250 Wrightwood 8 5 216,809 5,464 680 76 7 1,546 - ------------- ---------- ---------- ---------- ---------- ---------- ---------- ---------- ---------- Total 297 385 14,478,835 383,590 236,800 20,613 163 96,832Capacity is measured in thousands of gallons MORTGAGE AND OTHER LIENS As of December 31, 1999, Registrant had no mortgage debt outstanding, and its properties were free of any encumbrances or liens securing indebtedness. ITEM3
Item 3 -
LEGAL PROCEEDINGS WATER QUALITY-RELATED LITIGATIONLegal ProceedingsWater Quality-Related Litigation
SCW is a defendant in
eleventwenty-two lawsuits involving claims pertaining to water quality.NineNineteen of the lawsuits involve customer service areas located in Los AngelescountyCounty that have been filed in Los Angeles Superior Court: Robert Arenas, et al. v. Suburban Water Systems, Inc., et al., Case No. KC037559, Anthony John Bell, et al. v. City of Pomona, et al., Case No. KC038796, Adler, et al. v. Southern California Water Company, et al., Case No. BC169892, Santamaria, et al. v. Suburban Water Systems, et al., Case No. KC025995, Georgianna Dominguez et al. v. Southern California Water Company, et al., Case No. GC021657, Anderson, et al. v. Suburban Water Company, et al., Case No. KC028524, Abarca, et al. v. City of Pomona, et al., Case No. K027795, Celi, et al. v. San Gabriel Valley Water Company, Case No. GC020622, Boswell et al. v. Suburban Water Systems, et al., Case No. KC027318, Demciuc et al. v. Suburban Water Systems, et al., Case No. KC028732, Antoinette Adejare, et al. v. City of Pomona, et al., Case No. KC031096, Almelia Brooks, et al. v. Suburban Water System, et al., Case No. KC032915, Lori Alexander, et al. v. Suburban Water Systems, et al., Case No. KC031130, David Arnold, et al. v. City of Pomona, et al., Case No. KC034636, Gilda Ambrose-Dubre, et al. v. City of Pomona, et al., Case No. KC032906, Melissa Garrity Alvarado, et al. v. Suburban Water Systems et al., Case No. KC034953 , Charles Alexander, et al. v. City of Pomona, et al., Case No KC035526, Criner, et al. v. San Gabriel Valley Water Company, et al., Case No. GC021658, and Donerson, et al. v. City of Pomona, et al., Case No. KC035987. The lawsuits filed in Los Angeles County Superior Court are based on thesouthern portionallegations that SCW and the other defendants have provided and continue to provide plaintiffs with contaminated water from its wells, several of which are located in an area of theStateSan Gabriel Valley that has been designated a federal superfund site, that the maintenance ofCalifornia; twothis contaminated well water has resulted in contamination of the soil, subsurface soil and surrounding air with solvents and other substances, and that plaintiffs have been injured and their property damaged as a result. Three of the lawsuits involve a customer service area located in Sacramentocounty in northern California. See the section entitled "Risk Factor Summary" for more information. On September 1, 1999, the First District Court of Appeal in San Francisco, in a published opinion entitled Hartwell Corporation v. The Superior Court of VenturaCountyheldthatthe CPUC had pre-emptive jurisdiction over regulated public utilities and ordered dismissal of a series of lawsuits pertaining to water quality filed against water utilities, including SCW. Seven out of eleven lawsuits against SCWhave beenordered for dismissal by the state Court of Appeals -- the Adler (Case No. 1), Santamaria (Case No. 2), Anderson (Case No. 3), Dominguez (Case No. 4), Celi (Case No. 5), Boswell (Case No. 6), and Demciuc (Case No. 7) Matters. On October 11, 1999, one group of plaintiffs has 36 appealed to the California Supreme Court. The Supreme Court has accepted the petition. Management can not predict whether the plaintiffs will be successful in the appeal. On December 3, 1998, SCW was named as a defendant in a complaint in multiple counts, styled Abarca, et al. v. City of Pomona, et al. (Case No. 8),filed inLos AngelesSacramento County SuperiorCourt which seeks recovery for negligence, wrongful death, strict liability, permanent trespass, continuing trespass, continuing nuisance, permanent nuisance, negligence per se, absolute liability for ultrahazardous activity, fraudulent concealment, conspiracy/fraudulent concealment, battery and unfair business practices on behalf of 383 plaintiffs (the Abarca Matter). Plaintiffs seek damages, including general and special damages according to proof, punitive and exemplary damages, as well as attorney's fees, costs of suit and other unspecified relief. SCW was served on June 18, 1999. SCW was named as a defendant, along with the City of Pomona, California and Xerox Corporation in the matter styled Adejare, et al. v. Southern California Water Company, et al. (Case No. 9), filed on July 22, 1999 in Los Angeles Superior Court which seeks recovery for wrongful death, battery and fraudulent concealment (the Adejare Matter). Plaintiffs seek damages, including general and special damages according to proof, punitive and exemplary damages, as well as attorney's fees, costs of suit and other unspecified relief. In December 1997 SCW was named a defendant in the matter ofCourt: Nathaniel Allen, Jr. v. Aerojet-General Corporation, et al., Case No. 97AS06295, Daphne Adams, et al. v. Aerojet-General Corporation, et al.(Case, Case No.10)98AS01025, and Wallace Andrew Pennington et al. v. Aerojet-General Corporation, et al.,which wasCase No. 00AS02622. The lawsuits filed in Sacramento County SuperiorCourt. The complaint makes claimsCourt are based onwrongful death, personal injury, property damage as a result of nuisance and trespass, medical monitoring, and diminution of property values (the Allen Matter). Plaintiffs allegethe allegations that SCW and other defendants have delivered water to plaintiffswhich allegedly is, or has been in the past,that are contaminated with a number of chemicals, includingTCE, PCE,trichloroethylene, perchloroethylene, carbon tetrachloride, perchlorate, Freon-113, hexavalent chromium and other unnamedchemicals. SCW filed Demurrerschemicals andMotionthat plaintiffs have been injured and their property damaged as a result.On September 1, 1999, the Court of Appeals in San Francisco held that the CPUC had preemptive jurisdiction over regulated public utilities with respect to
Strike inwater quality matters and ordered dismissal of a series of these lawsuits. On October 11, 1999, one group of plaintiffs appealed thismatter on June 5, 1998. On August 31, 1998, the judge assigneddecision to theAllen Matter, acting on the Court's own motion, issued a stay of all proceedings in the Allen matter pending the outcome of the CPUC's Order Instituting Investigation (OII) proceeding. The plaintiffs petitioned the Third District Court of Appeal for a Writ of Mandamus to overrule the stay. The Court denied the petition. Plaintiff's then petitionedCalifornia Supreme Court. On February 4, 2002, the California Supreme Courtforconcluded that (i) the CPUC had preemptive jurisdiction over claims seeking injunctive relieffrom the Appellate Court's ruling. The California Supreme Court denied plaintiff's petition. Thus the stay in the Allen Matter remains in effect. In March 1998, SCW was named a defendant in the matter of Daphne Adams, et al. v. Aerojet General, et al. (Case No. 11) which was filed in Sacramento Superior Court (the Adams Matter). The complaint makesand claims based onnegligence, strict liability, trespass,the theory that a publicnuisance, private nuisance, negligence per se, absolute liability for ultrahazardous activity, fraudulent concealment, violationutility regulated by the CPUC provided unsafe drinking water even though it had complied with federal and state drinking water standards, but (ii) the CPUC did not have preemptive jurisdiction over damage claims based on allegations ofCalifornia Businessviolations of federal andProfessions Code section 17200 et seq., intentional inflictionstate drinking water standards by public utilities regulated by the CPUC. As a result, damage claims based on allegations ofemotional distress, intentional spoilageviolations ofevidence, negligent destruction of evidence needed for prospective civil litigation, wrongful deathfederal andmedical monitoring. Plaintiffs seek damages, including general, punitive and exemplary damages, as well as attorney's fees, costs of suit, injunctive and restitutionary relief, disgorged profits and civil penalties, medical monitoring according to proof andstate drinking water standards may proceed while the otherunspecified relief. SCW filed its Demurrers and Motion to Strike in this matter on June 5, 1998. On August 31, 1998, the judge assigned to the Adams Matter, acting on the Court's own motion, issued a stay of all proceedings in the Adams matter pending the outcome of the CPUC's OII proceeding. The plaintiff's petitioned the Third District Court of Appeal for a Writ of Mandamus to overrule the stay. The Court denied the petition. Plaintiff's then petitioned the California Supreme Court for relief from the Appellate Court's ruling. The California Supreme Court denied plaintiff's petition. Thus the stay in the Adams Matter remains in effect.claims must be dismissed.In light of the breadth of
plaintiffs'plaintiff’s claims,in these matters,the lack of factual information regardingplaintiffs'plaintiffs’ claims and injuries, if any, the impact of the California Supreme Court decision on plaintiffs’ claims and the fact thatno discovery has yet been completed,investigation is presently underway, SCW is unable at this time to determine what, if any, potential liability it may have with respect to these47claims. Based upon the information currently available to it, Registrant believestherethat these claims areno merits to these claimswithout merit and intends to vigorously defend againstthem. ORDER INSTITUTING INVESTIGATIONthese claims.SCW is subject to self-insured retention provisions in its applicable insurance policies and has either expensed the self-insured amounts or has reserved against payment of these amounts as appropriate. SCW’s various insurance carriers have, to date, provided reimbursement for costs incurred above the self-insured amounts for defense against these lawsuits, subject to a reservation of rights.
4
Order Instituting Investigation (OII)
In March 1998, the CPUC issued an OII to regulated water utilities in the state of California, including SCW. The purpose of the OII
iswas to determine whether existing standards and policies regarding drinking water quality adequately protect the public health and whether those standards and policiesarewere being uniformly complied with by those water utilities.The OII delineates the constitutional and statutory jurisdiction ofOn November 2, 2000, a final decision from the CPUC concluded that the CPUC has the jurisdiction to regulate the service of water utilities with respect to the health and safety of that service; that the California Department of Health Services(DOHS) in establishing and enforcing adherence torequirements governing drinking water qualitystandards. The CPUC's jurisdiction provides foradequately protect theestablishmentpublic health and safety; and that, based on an extensive review ofrates which permit water utilities to furnish water service meeting the established25 years of water qualitystandards at prices which are both affordable and allow the utility to earn a reasonable return on its investment. SCW has provided its response to a series of questions dealing with the adequacy of current drinking water standards, compliance by water utilities with such standards, appropriate remedies for failure to comply with safe drinking water standards and whether increased enforcement and additional drinking water standards are necessary. On June 10, 1999, the CPUC issued an interim order which established that the CPUC has jurisdiction to conduct the investigation regarding matters related to water quality over those water utilities subject to its authority. The Administrative Law Judge assigned to the OII has issued a draft decision finding thatrecords, regulated water utilities, including SCW, have satisfactorily complied withDOHS regulationpast andrequirements.present drinking water quality requirements, except for one small unrelated water utility in Northern California.The CPUC had previously authorized establishment of memorandum accounts to capture expenses related to the OII. Under the memorandum account procedure, SCW
is unablemay recover litigation costs from ratepayers topredict whetherthedraft decision will be approved in part or in its entiretyextent authorized by the CPUC. As of December 31, 2003, SCWanticipateshad incurred afinalnet cost of $890,000 related to the OII. In a decision issued by the CPUC on March 16, 2004 on SCW’s filing for its Region III and general office functions, SCW is allowed to recover the cost through a special condition surcharge over a twelve-month period.Other Water Quality Litigation
On October 25, 1999, SCW filed a lawsuit against the State of California and its State Water Resources Control Board, Central Valley Regional Water Quality Control Board, and Department of Toxic Substances Control (collectively, the State) alleging that the State had substantially participated in a project to inject chemical pollution into portions of the Sacramento County groundwater basin and that pollution is progressively destroying the groundwater supply in SCW’s Rancho Cordova water system. SCW and the State have entered into a comprehensive $2,475,000 settlement for all of SCW’s claims against the State, contingent upon the court’s approval of the good faith of the settlement, which SCW received in full during the third quarter of 2003.
In a separate case, also filed on October 25, 1999, SCW sued Aerojet-General Corporation (Aerojet) for causing the contamination of eastern portions of the Sacramento County groundwater basin. A cross complaint filed by Aerojet against SCW for negligence and constituting a public nuisance was voluntarily dismissed by Aerojet in October 2002. On October 10, 2003 Registrant entered into a confidential memorandum of understanding (MOU) with the Aerojet-General subsidiary of GenCorp, Inc. for the settlement of legal actions brought by SCW. The MOU sets forth the present financial terms and the structure of a settlement to cover, over time, capital and litigation related costs incurred by SCW resulting from the contamination. The MOU and the settlement embodied therein was found to be binding by the Sacramento Superior Court on January 18, 2004. Further documentation incorporating the terms of the MOU is presently underway. However, documentation is not complete and management is presently unable to predict when a comprehensive set of settlement documents will be completed.
Based on the financial terms in the MOU, SCW established a receivable from Aerojet in an amount of $16.7 million for capital project and purchased water reimbursements at the end of 2003, of which $8.7 million has been received in early 2004 and is recorded in current “Other Accounts Receivable” on the balance sheets. The remainder of the costs is subject to further settlement documentation Reimbursements received from Aerojet have been applied directly to reduce SCW’s costs of utility plant and purchased water. Prior to the MOU, Aerojet had reimbursed SCW $4.3 million in capital costs and $171,000 for additional water supply.
In an action related to the draft settlement agreement, Registrant and Aerojet have signed three separate agreements requiring Aerojet to pay for certain infrastructure and upgrades to Registrant’s Coloma Treatment Plant as a contingency plan should additional wells be impacted prior to the high summer demand period of 2004. The value of the three agreements approximates $6.8 million in capital improvements. In addition, SCW is in negotiations with the County of Sacramento regarding a replacement of water supply.
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The CPUC has previously authorized memorandum accounts to allow for recovery, from customers, of costs incurred by SCW in prosecuting the suits filed against the State and Aerojet, less any recovery from the defendants or others. As of December 31, 2003, approximately $16.2 million in legal and consulting related costs has been recorded as deferred charges and included as “Regulatory Assets” on the balance sheets. The CPUC has authorized SCW to increase rates, effective April 28, 2001, for recovery over a six-year period of approximately $1.8 million in expenses that were incurred on or before August 31, 2000, in the Aerojet matter. As part of an abbreviated application for SCW’s Region I, SCW requested a long-term amortization of the balance of costs included in the Aerojet litigation memorandum account, net of any reimbursement amount. The draft agreement also addresses the possible recovery of SCW’s deferred charges through revenues in new development areas. Management believes these costs are recoverable either through rates or the settlement agreement with Aerojet. See the section entitled “Regulatory Matters” and “Environmental Matters” in Part II, Item 7 in Management’s Discussion and Analysis of Financial Conditions and Results of Operation.
The compound MTBE has been detected in a well serving SCW’s Los Osos water system. For some time SCW has been working with the Regional Water Quality Control Board as well as the owner of a service station. Although the owner of the service station has attempted remediation with funds provided through the California Underground Storage Tank Fund (“CUSTF”), it appears there will be insufficient funds from the CUSTF to complete remediation sufficient to return the well to service. In order to prevent the running of the statute of limitations, on August 12, 2002 SCW filed suit in the Superior Court of the State of California for the County of San Luis Obispo against the operators and owners of the service station facility, and Chevron USA Products, Inc., the supplier. A settlement with Chevron has been reached and a filing has been made for dismissal by the Court. SCW has dismissed all other parties. The impacted well may need to be removed permanently from service and the settlement with Chevron is expected to afford SCW sufficient funds to commence site development and construction of a replacement well.
Perchlorate and/or Volatile Organic Compounds (VOC) have been detected in five wells servicing SCW’s San Gabriel System. SCW filed suit, along with two other affected water purveyors and the San Gabriel Basin Water Quality Authority (WQA), in the federal court against some of those responsible for the contamination. Some of the other potential defendants settled with SCW, other water purveyors and the WQA on VOC related issues prior to the filing of the lawsuit. In response to the filing of the Federal lawsuit, the Potentially Responsible Party (PRP) defendants filed motions to dismiss the suit or strike certain portions of the suit. The judge issued a ruling on April 1, 2003 granting in part and denying in part the defendant’s motions. A key ruling of the court was that the water purveyors, including the Registrant, by virtue of their ownership of wells contaminated with hazardous chemicals are themselves PRPs under the Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA). Registrant has, pursuant to permission of the court, amended its suit to claim certain affirmative defenses as an “innocent” party under CERCLA. Registrant is presently unable to predict the outcome of this ruling on its ability to fully recover from the PRPs the future costs associated with the treatment of these wells.
On August 29, 2003, the US Environmental Protection Agency issued Unilateral Administrative Orders (“UAO”) against 41 parties deemed responsible for polluting the groundwater in that portion of the San Gabriel Valley from which SCW’s two impacted wells draw water. SCW was not named as a party to the UAO. The UAO requires that these parties remediate the contamination. As a result of the issuance of the UAO, these parties have begun settlement discussions regarding the Federal lawsuits with SCW, the other two affected water purveyors and WQA. Registrant is presently unable to predict the ultimate outcome of these settlement discussions.
MCO Properties, Inc., a real estate developer (MCO), has filed a complaint against AWR and CCWC in the Superior Court of Maricopa County (CV 2003-011184) on June 6, 2003 alleging breach of contract, breach of the implied covenant of good faith and fair dealing, interference with prospective economic advantage, negligence and negligent misrepresentation and seeking a declaratory judgment. The complaint arises out of allegations by MCO that AWR has failed to comply with the terms of the Stock Purchase Agreement between MCO and AWR pursuant to which AWR acquired CCWC from MCO and has thereby interfered with MCO’s ability to develop its real property in the Town of Fountain Hills. A revised complaint was filed on December 12, 2003 further alleging that CCWC has not maintained its designation of assured supply as required in the Stock Purchase Agreement. Similar allegations have been filed by MCO against CCWC with the Arizona Corporation Commission (Docket No. W-02113A-3-0383). There have been settlement discussions seeking to resolve these issues. In addition, CCWC has undertaken actions that it believes will enable it to continue to maintain its assured water supply designation in a manner that will enable CCWC to provide water service to new real estate developments in the Town of Fountain Hills, including properties owned by MCO. AWR and Arizona Department of Water Resources (“ADWR”) have also agreed that the Town of Fountain Hills may approve and record final parcel plats for subdivisions for which CCWC has entered into written commitments to provide water service, conditional on (i) ADWR sending a notification to the Town that ADWR has approved a
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modification to CCWC’s designation or otherwise has determined that CCWC has enough water for current and committed demands including the subdivision, and (ii) MCO not submitting a request to the State Real Estate Commissioner for a public report for the subdivision in advance of ADWR’s issuance of the notification to the Town. For further information on CCWC’s assured water supply designation, see “Item 7. Management’s Discussion and Analysis of Financial Conditions and Results of Operation-Water Supply-CCWC’s Water Supply”.
Electric Service Litigation
SCW has been, in conjunction with the Southern California Edison (Edison) unit of Edison International, planning to upgrade transmission facilities to 115kv (the 115kv Project) in order to meet increased energy and demand requirements for SCW’s Bear Valley Electric service area. On December 27, 2000, SCW filed a lawsuit against Edison for declaratory relief and seeking damages for breach of contract as a result of delays in the 115kv Project, violations of good faith and fair dealing, negligent misrepresentation, intentional misrepresentation and unjust enrichment. Subsequently Edison filed a cross-complaint against SCW for breach of contract, anticipatory breach, and quantum meruit. SCW has also sought declaratory relief from Edison’s claims. To date, SCW has spent approximately $3.4 million in this matter, all of which has been expensed. A settlement has been reached between SCW and Edison, in
2000. See Note 8which (i) SCW is to pay Edison $5.0 million as theNotescost of abandoning and terminating the 115kv Project, (ii) Edison shall make a filing with the Federal Energy Regulatory Commission (FERC) toFinancial Statements. OTHER LITIGATIONinclude the cost in a FERC rate schedule under the Transmission Service Agreement between SCW and Edison, and (iii) Edison is to sell the Goldhill substation and associated transmission line to SCW at its book value. Management believes that the FERC’s approval on Edison’s filing is probable and this cost is within the meaning of the CPUC’s Code of “Abandonment Fee” which is recoverable through the supply cost balancing account. As a result, the $5.0 million obligation to Edison arising from the settlement was recorded as a liability and a regulatory asset in the fourth quarter of 2003. A final settlement agreement was reached on March 17, 2004.Other Litigation
Registrant is also subject to ordinary routine litigation incidental to its business. Other than as disclosed above, no other legal proceedings are pending,
except such incidental litigation, to which Registrant is a party or of which any of its properties is the subjectwhich are believed to be material.ITEMManagement believes that rate recovery, proper insurance coverage and reserves are in place to insure against property, general liability and workers’ compensation claims incurred in the ordinary course of business.Item 4.
SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERSSubmission of Matters to a Vote of Security HoldersNo matter was submitted during the fourth quarter of the fiscal year covered by this report to a vote of security holders through the solicitation of proxies or otherwise.
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PART II
ITEMItem 5.
MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS (a) MARKET INFORMATION RELATING TO COMMON SHARESMarket for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity SecuritiesMarket Information Relating to Common Shares-
Common Shares of American States Water Company are traded on the New York Stock Exchange (NYSE) under the symbol AWR. The intra-day high and low NYSE prices on the Common Shares for each quarter during the past two years were:
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Stock Prices ----------------------------------- High Low -------------- ---------------1999 First Quarter $ 30 $ 23 9/16 Second Quarter 29 1/4 22 3/16 Third Quarter 37 1/8 28 3/8 Fourth Quarter 39 3/4 31 3/4 1998 First Quarter $ 26 $ 23 1/16 Second Quarter 27 1/8 21 1/8 Third Quarter 27 23 1/4 Fourth Quarter 29 1/4 24 7/8All
Stock Prices High Low First Quarter $ 24.60 $ 21.57 Second Quarter 28.95 23.45 Third Quarter 27.99 23.01 Fourth Quarter 25.75 23.65 First Quarter $ 25.06 $ 21.94 Second Quarter 28.00 23.38 Third Quarter 27.55 20.25 Fourth Quarter 27.20 23.15 Approximate Number of
theHolders of Common Sharesof Southern California Water Company and American States Utility Services are owned by American States Water Company. Hence, there is no market for the Common Shares of either entity. (b) APPROXIMATE NUMBER OF HOLDERS OF COMMON SHARES -As of March
6, 2000,18, 2004, there were3,5193,450 holders of record of Common Shares of American States Water Company.AllAWR owns all of the authorized and outstanding Common Shares ofSouthern California Water Company are owned by American States Water Company. (c) FREQUENCY AND AMOUNT OF ANY DIVIDENDS DECLARED AND DIVIDEND RESTRICTIONSSCW, CCWC and ASUS.Frequency and Amount of Any Dividends Declared and Dividend Restrictions
For the last three years,
RegistrantAWR has paid dividends on its Common Shares on March 1, June 1, September 1 and December 1. The following table lists the amount of dividends paid on Common Shares of American States Water Company, adjusted by the 3-for-2 stock split completed on June 7, 2002, forthe last two years:
1999 1998 --------------- --------------First Quarter $ 0.32 $ 0.315 Second Quarter 0.32 0.315 Third Quarter 0.32 0.315 Fourth Quarter 0.32 0.315 =============== ============== Total $ 1.28 $ 1.260 =============== ==============Registrant is2002:
2003 2002 First Quarter $ 0.221 $ 0.217 Second Quarter 0.221 0.217 Third Quarter 0.221 0.217 Fourth Quarter 0.221 0.221
Total $ 0.884 $ 0.872
AWR and ASUS are not subject to any contractual restriction on their ability to pay dividends, except the requirement in the $75 million Credit Facility to maintain compliance with all covenants. SCW’s maximum ability to pay dividends is restricted by certain Note Agreements to the sum of $21 million plus 100% of consolidated net income plus the aggregate net cash proceeds received from capital stock offerings or other instruments convertible into capital stock from various dates. Under the most restrictive of the Note Agreements, $154.9 million was available to pay dividends to AWR. For further information, see (3) of the section entitled “Contractual Obligations and Other Commitments” included in Part II, Item 7 in Management’s Discussion and Analysis of Financial Conditions and Results of Operation.
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The ability of AWR, ASUS and SCW to pay dividends is also restricted by California law. Under restrictions of the California tests, approximately $84.8 million of AWR’s retained earnings was available to pay dividends to Common Shareholders at December 31, 2003. Approximately $82.7 million was available from the retained earnings of SCW to pay dividends to AWR. At December 31, 2003, ASUS was not allowed to pay dividends to AWR under the California tests.
CCWC is subject to contractual restrictions on its ability to pay dividends.
6CCWC’s maximum ability to distribute dividends is limited to maintenance of no more than 55% debt in the capital structure for the quarter immediately preceding the distribution. The ability of CCWC to pay dividends is also restricted under Arizona law. Under restrictions of the Arizona tests, approximately $4.4 million was available to pay dividends to AWR at December 31, 2003. See (8) of the section entitled “Contractual Obligations and Other Commitments” included in Part II, Item 7 in Management’s Discussion and Analysis of Financial Conditions and Results of Operation. AWR paid $13.4 million in common dividends to shareholders for the year ended December 31, 2003, as compared to $13.2 million for the year ended December 31, 2002. A total of $28,702 in preferred dividends was paid in 2002. No preferred dividends were paid in 2003 since all outstanding preferred shares were redeemed in June 2002. SCW paid dividends of $15.4 and $14.6 million to AWR in 2003 and 2002, respectively. CCWC did not pay any dividends to AWR in 2003 or 2002.
Other Information
The material features of all equity compensation plans under which equity securities of AWR are authorized for issuance have been approved by shareholders of AWR. AWR did not issue any unregistered equity securities during 2003.
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ITEMItem 6.
SELECTED FINANCIAL DATA
1999 1998 1997 1996 1995 -------- -------- -------- -------- -------- ( in thousand, except per share amounts)INCOME STATEMENT INFORMATION Total Operating Revenues $173,421 $148,060 $153,755 $151,529 $129,813 Total Operating Expenses 144,907 122,999 130,297 128,100 108,425 Operating Income 28,514 25,061 23,458 23,429 21,388 Other Income 532 769 758 531 336 Interest Charges 12,945 11,207 10,157 10,500 9,559 Net Income 16,101 14,623 14,059 13,460 12,165 Preferred Dividends 88 90 92 94 96 Earnings Available for Common Shareholders 16,013 14,533 13,967 13,366 12,069 Basic Earnings per Common Share $ 1.79 $ 1.62 $ 1.56 $ 1.69 $ 1.54 Dividends Declared per Common Shares $ 1.28 $ 1.26 $ 1.25 $ 1.23 $ 1.21 Average Shares Outstanding 8,958 8,958 8,957 7,891 7,845 BALANCE SHEET INFORMATION Total Assets $533,181 $484,671 $457,074 $430,922 $406,255 Common Shareholders' Equity 158,846 154,299 151,053 146,766 121,576 Long-Term Debt 167,363 120,809 115,286 107,190 107,455 Preferred Shares-Not subject to Mandatory 1,600 1,600 1,600 1,600 1,600 Preferred Shares-Mandatory Redemption 360 400 440 480 520 Total Capitalization 328,169 $277,108 $268,379 $256,036 $231,151 Book Value per Common Share $ 17.73 $ 17.23 $ 16.86 $ 16.52 $ 15.50 OTHER INFORMATION Ratio of Earnings to Fixed Charges 3.27% 3.21% 3.35% 3.26% 3.19% Ratio of Earnings to Total Fixed Charges 3.23% 3.17% 3.30% 3.21% 3.14% Return on Average Common Equity 10.2% 9.6% 9.5% 10.7% 10.3%ITEMSelected Financial Data
AWR (1) (in thousands, except per share amounts) 2003 2002 2001 2000 1999 Total Operating Revenues $ 212,669 $ 209,205 $ 197,514 $ 183,960 $ 173,421 Total Operating Expenses 179,064 171,557 159,813 149,708 144,960 Operating Income 33,605 37,648 37,701 34,252 28,461 Other Income (Loss) (3,643 ) 390 (510 ) (99 ) 532 Interest Charges 18,070 17,699 15,735 14,122 12,945 Net Income 11,892 20,339 21,456 20,031 16,048 Preferred Dividends — (29 ) (84 ) (86 ) (88 ) Earnings Available for Common Shareholders $ 11,892 $ 20,310 $ 21,372 $ 19,945 $ 15,960 Basic Earnings per Common Share $ 0.78 $ 1.34 $ 1.41 $ 1.42 $ 1.19 Dividends Declared per Common Share $ 0.884 $ 0.872 $ 0.867 $ 0.857 $ 0.853 Average Shares Outstanding 15,200 15,144 15,120 14,070 13,437 Average Number of Diluted Shares Outstanding 15,227 15,157 15,122 14,070 13,437 Fully Diluted Earnings per Common Share $ 0.78 $ 1.34 $ 1.41 $ 1.42 $ 1.19 Total Assets $ 757,475 $ 700,553 $ 681,829 $ 616,646 $ 533,181 Common Shareholders’ Equity 212,487 213,279 204,654 196,386 160,564 Long-Term Debt 229,799 231,089 245,692 176,452 167,363 Preferred Shares-Not Subject to Mandatory Redemption — — 1,600 1,600 1,600 Preferred Shares-Mandatory Redemption — — 280 320 360 Total Capitalization $ 442,286 $ 444,368 $ 452,226 $ 374,758 $ 329,888 Book Value per Common Share $ 13.97 $ 14.05 $ 13.54 $ 12.99 $ 11.95 (1) On October 10, 2000, AWR completed the acquisition of the common stock of Chaparral City Water Company (CCWC) for an aggregate value of $31.2 million. CCWC’s operating revenues represent about 3% of AWR’s total operating revenues. CCWC’s total assets are less than 1% of AWR’s consolidated total assets.
SCW (in thousands) 2003 2002 2001 2000 1999 Total Operating Revenues $ 205,517 $ 202,202 $ 190,455 $ 181,895 $ 173,031 Total Operating Expenses 170,912 164,664 154,416 147,582 144,306 Operating Income 34,605 37,538 36,039 34,313 28,725 Other Income (Loss) (3,660 ) 318 (624 ) (140 ) 509 Interest Charges 17,060 16,636 14,577 14,350 12,945 Net Income 13,885 21,220 20,838 19,823 16,289 Total Assets $ 705,563 $ 649,018 $ 632,689 $ 566,529 $ 532,494 Common Shareholder’s Equity 206,047 207,562 200,972 168,664 161,741 Long-Term Debt 221,996 222,725 236,804 167,062 167,363 10
Item 7.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONManagement’s Discussion and Analysis of Financial Condition and Results of OperationUnless specifically noted, the following discussion and analysis provides information on
AWR'sAWR’s consolidated operations and assets.There areFor the year ended December 31, 2003, there is generally no materialdifferencesdifference between the consolidated operations and assets of AWR and the operations and assets of SCW.FORWARD-LOOKING INFORMATIONHowever, where necessary, the following discussion and analysis includes references specifically to AWR’s other subsidiaries – CCWC and ASUS.Forward-Looking Information
Certain matters discussed in this report (including the documents incorporated herein by reference) are forward-looking statements intended to qualify for the
"safe harbor"“safe harbor” from liability established by the Private Securities Litigation Reform Act of 1995. These forward-looking statements can generally be identified as such because the context of the statement will include words such as Registrant"believes," "anticipates," "expects"“believes,” “anticipates,” “expects” or words of similar import. Similarly, statements that describeRegistrant'sRegistrant’s future plans, objectives, estimates or goals are also forward-looking statements. Such statements address future events and conditions concerning capital expenditures, earnings, litigation, rates, water quality and other regulatory matters, adequacy of water supplies, SCW’s ability to recover electric and water supply costs from ratepayers, liquidity and capital resources,opportunities related to operations of municipally-owned water systemsand accounting matters. Actual results in each case could differ materially from those currently anticipated in such statements, by reason of factors such as changes in utilityrestructuring,regulation, including ongoing local, state and federal activities; future economic conditions, including710changes in customerdemand;demand and changes in water and energy supply cost; future climatic conditions; and legislative, regulatory and other circumstances affecting anticipated revenues and costs.RESULTS OF OPERATIONS YEARS ENDED DECEMBER11
Consolidated Results of Operations – Years Ended December 31,
1999 AND 1998 Basic earnings2003 and 2002
YEAR YEAR ENDED ENDED $ % 12/31/2003 12/31/2002 CHANGE CHANGE OPERATING REVENUES Water $ 187,163 $ 187,061 $ 102 0.1 % Electric 24,492 21,298 3,194 15.0 % Other 1,014 846 168 19.9 %
Total operating revenues 212,669 209,205 3,464 1.7 %
OPERATING EXPENSES Water purchased 40,538 42,859 (2,321 ) -5.4 % Power purchased for resale 13,867 15,818 (1,951 ) -12.3 % Power purchased for pumping 10,232 10,576 (344 ) -3.3 % Unrealized (gain) loss on purchased power contracts (638 ) 2,530 (3,168 ) -125.2 % Groundwater production assessment 7,344 7,416 (72 ) -1.0 % Supply cost balancing accounts 6,590 (3,406 ) 9,996 293.5 % Other operating expenses 18,264 16,983 1,281 7.5 % Administrative and general expenses 35,726 30,010 5,716 19.0 % Depreciation and amortization 19,792 18,302 1,490 8.1 % Maintenance 9,932 9,839 93 0.9 % Taxes on income 9,167 12,949 (3,782 ) -29.2 % Other taxes 8,250 7,681 569 7.4 %
Total operating expenses 179,064 171,557 7,507 4.4 %
Operating income 33,605 37,648 (4,043 ) -10.7 %
OTHER INCOME — NET (3,643 ) 390 (4,033 ) -1034.1 %
INTEREST CHARGES 18,070 17,699 371 2.1 %
NET INCOME $ 11,892 $ 20,339 $ (8,447 ) -41.5 %
Net income for the year ended December 31, 2003 decreased 41.5% to $11.9 million, equivalent to $0.78 per
Common Share in 1999 increased by 10.5% to $1.79 percommon shareason a basic and fully diluted basis, compared to$1.62$20.3 million or $1.34 per share for thecomparable periodyear ended December 31, 2002. The decreases in recorded results reflect primarily the continued lack of1998.timely approval of revenue increases by the CPUC, cooler weather conditions experienced this year in the Company’s service areas as compared to the same time last year resulting in a decrease in water demand, the recording of $6.2 million refund of water right lease revenues pursuant to a CPUC order issued on March 16, 2004, the recording of a probable refund of $3.5 million to customers during the fourth quarter of 2003, increased operating expenses, reversal of $6.5 million in 2002 for potential non-recovery of electric power costs incurred to serve customers at SCW’s Bear Valley Electric customer service area, and various other reasons as discussed below.Operating Revenues
For the year ended December 31, 2003, revenues from water operations increased slightly by 0.1% to $187.2 million compared to $187.1 million for the year ended December 31, 2002. Higher water revenues reflect two rate increases for SCW’s Region II that were effective on January 21, 2003 and February 4, 2003, respectively. These rate increases are expected to generate additional water revenues of approximately $6.2 million annually. The rate increases were offset by a decrease of 3.0% in water consumption resulting from wetter and cooler temperatures in most of SCW’s service areas. Differences in temperature and rainfall in Registrant’s service areas impact sales of water to customers causing fluctuations in Registrant’s revenues and earnings between comparative periods.
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For the year ended December 31, 2003, revenues from electric operations increased by 15.0% to $24.5 million compared to $21.3 million for the year ended December 31, 2002. The increase reflects rate increases in July 2002 authorized by the
recorded results primarily reflects higherCPUC to cover purchased power costs under various power supply agreements which resulted in increased revenuesatof approximately $3 million, and a slight increase in kilowatt-hour consumption.Other operating revenues consist of nonregulated water related services and operations on a contract basis ranging from services, such as billing and meter reading, to full operation of water utility related systems, all performed by AWR’s subsidiary, American States Utility Services, Inc. (“ASUS”). For the
SCW unit during 1999 as is more fully discussed below. Wateryear ended December 31, 2003, other operating revenues increased by18.5% in 199919.9% to$159.7$1.0 millionfromcompared to $846,000 for the$134.8 million reported in 1998. Water sales volumes in 1999 were 9.0% higher than 1998 due primarily to the much drier and warmer weather conditions throughout Southern California in 1999 than in 1998. Additional increases in revenues wereyear ended December 31, 2002 due to thegeneraladdition of a new billing contract with the City of Chino Hills which increased revenues by approximately $100,000. ASUS is pursuing growth and new business development for AWR, most specifically in the area of privatization of water and wastewater systems at military bases. As such, ASUS has carefully reviewed growth opportunities and exercised prudence in the pursuit of increased revenues and earnings from contract operations that are congruent with AWR’s core competencies. During 2003, ASUS was an active participant in the privatization of military bases, currently with 9 active bids for such opportunities. To date, ASUS has received preliminary notification that it will be awarded a 50-year contract to own and operate the water and wastewater systems at Ft. Bliss, located near El Paso, Texas. ASUS plans to continue to bid on and negotiate for other military bases during 2004. Also in 2003, ASUS worked to develop an operating contract for the water and wastewater services in the rapidly developing area presently served by a mutual water company in northern California. ASUS anticipates signing definitive agreements in 2004 and expect development to take place in this area beginning in 2005.Registrant relies upon rate increases for water and electric services approved by regulatory bodies in
six of Registrant's customer service areas effective January 1, 1999, which were applicableCalifornia and Arizona in order to65% of SCW's water customers. Electricrecover operating expenses and provide for a return on invested and borrowed capital used to fund utility plant. Without such adequate rate relief granted in a timely manner, revenuesof $13.3 million were 1.0% higherand earnings can be negatively impacted. Applications for rate increases that are currently pending are discussed under“Regulation-Pending Rate Changes”in1999 as compared to 1998 due to a 2.7% increase in kilowatt-hour sales, primarily by industrial power users. The sales increase was partially offset by the lower billing rates of industrial customers relative to residential customers. Other revenues increased from $65,000 to $390,000 in 1999 due to increased management fees resulting from new ASUS service contracts established in the year and increased activities with existing contracts. Purchased water costs in 1999 increased to $36.1 million as compared to $30.8 million in 1998 due to a 12.1% increase in volumes purchased. The increase also reflects reduced reimbursements in 1999 from potentially responsible parties related to groundwater contamination in SCW's Culver City customer service area of approximately $570,000, compared with reimbursements of $1.7 million in 1998. SeePart II, Item 7Management's Discussionin “Management’s Discussions and Analysis of Financial Condition and Results ofOperation - Environmental Matters - Matters RelatingOperation”.Operating Expenses
For the year ended December 31, 2003, purchased water costs decreased by 5.4% to
Culver City System. Costs$40.5 million compared to $42.9 million for the year ended December 31, 2002. The decrease is due primarily to: (i) approximately $1.4 million incurred in connection with the purchasing and trucking of water in SCW’s Wrightwood customer service area due to a sudden and unexplained drop in groundwater level in the area during the early part of the third quarter of 2002 (the water hauling ended in January 2003); (ii) a $735,000 reimbursement from Aerojet on water purchased from the Sacramento Municipal Utility District (SMUD) pursuant to the Memo of Understanding entered into in October 2003; (iii) approximately $680,000 of refunds from Metropolitan Water District member agencies relating to the 2003 water year; and (iv) overall lower consumption. The decrease is offset by: (i) an increase in the costs of water rights pumped in SCW’s Region II and (ii) additional purchased water in the current year necessary to replace pumped water supply lost due to wells being temporarily removed from service as a result of water quality issues and mechanical problems, particularly in SCW’s Foothill district. Registrant has had to take a number of wells out of service from time-to-time due to various causes, including contamination by third parties. Changes in the water resource mix between water supplied from purchased sources and that supplied from Registrant’s own wells can increase actual supply-related costs relative to the supply-related costs approved for recovery through rates, thereby impacting earnings either negatively or positively. Registrant has the opportunity to change the supply-related costs recovered through rates by application to the appropriate regulatory body. Registrant believes that its applications for recovery of supply-related costs accurately reflect the water supply situation as it is known at the time. However, it is impossible to adequately protect earnings from adverse changes in supply costs related to unforeseen contamination. For the year ended December 31, 2003, 43% of our supply mix was purchased water as compared to 41% purchased water for the year ended December 31, 2002.For the year ended December 31, 2003, cost of power purchased for pumping decreased by 3.3% to $10.2 million compared to $10.6 million for the year ended December 31, 2002 due to lower consumption and additional wells down for maintenance and water quality issues. The effect of wells being offline was partially offset by increased
by 5.5% to $7.4 millionpower rates and resulted in1999 chiefly as a result ofan increase inpumped groundwater in SCW'spurchased watersupply mix due to increased sales volumes. Costsas discussed above.13
For the year ended December 31, 2003, cost of power purchased for resale to customers in
1999 increased by 42.0% to $7.1 million from the $5.0 million recorded in 1998 due primarily to additional energy demand charges from the energy supplier serving SCW'sSCW’s Bear Valley ElectricService unitdivision decreased by 12.3% to $13.9 million compared to $15.8 million for the year ended December 31, 2002. This decrease is due to the upfront payments received from PWCC which result in1999. As described below, mostlower power costs at a price ofthis increase has been$74.65 per megawatt hour (MWh) effective November 2002 under SCW’s power supply agreements with Pinnacle West Capital Corporation (PWCC) as compared to $95 per MWh for energy purchased from Mirant Americas Energy Marketing, LLP (Mirant Marketing) under then existing contracts in the same period of 2002. Effective November 2002, SCW entered into a series of purchase power contracts with PWCC. Under the agreements, SCW will exchange 15 MWs of electric energy with PWCC that results in an upfront payment of $20.35 per MWh for 15 MWs over the period beginning November 1, 2002 through December 31, 2006. This upfront payment is being recorded as a reduction of purchased power costs which are included in the supply cost balancingaccountaccount.Unrealized gain and
that Registrantloss on purchased power contracts represents gains and losses recorded for SCW’s purchased power agreements, with PWCC, which qualify as derivative instruments under Statement of Financial Accounting Standards (SFAS) No. 133,“Accounting for Derivative Instruments and Hedging Activities”. The $638,000 pre-tax unrealized gain on purchased power contracts for the year ended December 31, 2003 is due to an increase in the current forward market prices since December 31, 2002. There is no cash flow impact from the unrealized gains and losses on the purchased power contracts. Unrealized gains and losses at Bear Valley Electric willseekcontinue torecover these in future rate increases. Groundwaterimpact earnings during the life of the contract with PWCC.For the year ended December 31, 2003, groundwater production assessments decreased slightly by
5.3%1.0% to$7.2.$7.3 millionin 1999 from $7.6compared to $7.4 millionin 1998for the year ended December 31, 2002 due toreduced quantitya decrease in pumped water, offset by increases in assessment ratesin SCW's Metropolitan and San Dimas customer service areas.levied against groundwater production effective July 2003.A positive entry for the provision for supply cost balancing accounts reflects recovery of previously under-collected supply costs. Conversely, a negative entry for the provision for supply cost balancing accounts reflects an under-collection of previously incurred supply costs.
In 1999, recoveryAn increase ofpreviously under-collected supply costs was lower than 1998 due to$10.0 million during thepreviously discussed increase in energy demand charges, the effect of which was partially offset by new rates effective January 1999 authorized to implement new supply costs and to increase collection of previously under-collected costs. 811 The balancing account mechanism insulates earnings from changesyear ended December 31, 2003 in theunitprovision for supply costof supply costs which are outside of the immediate control of Registrant. However, thebalancingaccount is not designed to insulate earnings against changes in the actual supply mixaccounts as compared tothat mix authorized for recovery in rates. In 1999, SCW's overall supply mix improved favorably over that mixthe year ended December 31, 2002 primarily reflects (i) new rates authorized inrates resultingJuly 2002 to recover electric power costs which resulted inadditional income. There is no assurance thatapproximately $3 million of revenues to recover electric power costs, (ii) thefavorable mix canapproval on June 19, 2003 of the pre-November 29, 2001 water supply balancing accounts totaling $1.6 million, which SCW will besustainedamortizing over 24 months, and (iii) the recording of a probable refund of $3.5 million to customers representing the net proceeds received from the PRP’s with respect to the Charnock Basin contamination, pursuant to the proposed decision issued by the CPUC infuture periods since actual results are affected by availability and quality of water, both purchased and produced from SCW's wells. SeeDecember 2003.For the
section entitled "Water Supply." Otheryear ended December 31, 2003, other operating expenses increased by7.8% from7.5% to $18.3 million compared to $17.0 million for the$14.5 million recorded in 1998year ended December 31, 2002 due primarily toincreased costs for(i) higher labor, chemicals and water treatment costs which increased by almost $545,000, (ii) approximately $165,000 of refunds for a sewer service overpayment in June 2002 for which there was no counterpart in 2003; andhigher uncollectible provisions as a result(iii) reimbursements totaling $205,000 received during the year ended December 31, 2002 from settling parties for expenses incurred in the San Gabriel basin to meet water quality standards compared to recovery ofincreased revenues. Administrative2002 expenses of $68,000 in 2003.For the year ended December 31, 2003, administrative and general expenses increased by
30.0%19.0% to$28.6$35.7 million compared to $30.0 million for the year ended December 31, 2002 due primarily to (i) approximately $2.5 million increase in1999 fromoutside legal and consulting services incurred in connection with new business development, most specifically in the$22.0 million recordedarea of privatization of water and wastewater systems at military bases, and in1998. Thedefense of the Edison lawsuit for Bear Valley Electric, (ii) approximately $775,000 increaseisin pensions and benefits due tocosts associated withactuarial assumption changes in the discount rate and expected long-term rate of return on plan assets, and increases in variousacquisition projects, increased employeebenefit costs, andadditional amounts(iii) the reversal of the remaining reserve of $6.5 million in 2002 for potential non-recovery of electric power costs incurred to serve customers at SCW’s Bear Valley Electric customer service area. The reserve was established in 2001 to offset future impacts to earnings for the difference between authorized rates and SCW’s actual electric power costs. There is no similar reversal in 2003. The increases are partially offset by the reversal of certain reserves based on a CPUC decision issued on March 16, 2004. On this date, the CPUC approved a special condition surcharge in rates to amortize the water quality Order Instituting Investigation (OII) memorandum account balance which SCW had previously reserved, and SCW is authorized to establish a memorandum account to accumulate costs to comply with certain contamination remediation requirements. Based on the decision, SCW reversed its $890,000 OII reserve and $1.0 million in water quality related reserves into income during the fourth quarter of 2003. Registrant believes that prudent administrative expenses incurred in the operation and management of its regulated subsidiaries will be recovered through water and electric rates.14
Registrant plans through its non-regulated subsidiary, American State Utility Services, Inc., to continue with the analysis and preparation of bids for
certain legal proceedings. In 1999,submission to the Department of Defense (“DOD”) pursuant to DOD’s initiative to privatize the water and wastewater assets and operations of military bases. The analysis and preparation of these bids is an extensive process and, as such, Registrant expects to incur approximately $2 million in 2004 for such efforts due to the volume of Requests for Proposals available from the DOD. Registrant expects that it will be awarded its first privatization of a military base during 2004 and will enter into negotiations for several other bases as well.For the year ended December 31, 2003, depreciation expense increased by 8.1% to $19.8 million compared to $18.3 million for the year ended December 31, 2002 reflecting, among other things, the effects of recording approximately $51 million in utility plant during 2002, depreciation on which began in January 2003. Registrant anticipates that depreciation expense will continue to increase due to Registrant’s on-going construction program at its regulated subsidiaries. Registrant believes that depreciation expense related to property additions approved by the appropriate regulatory bodies will be recovered through water and electric rates.
For the year ended December 31, 2003, maintenance expense increased slightly by 0.9% to
the$9.9 million compared to $9.8 millionlevel compared tofor therecorded $7.3 million in 1998year ended December 31, 2002 due principally to increased maintenance onRegistrant'sSCW’s water supply sources andcosts incurredmaintenance of water mains.For the year ended December 31, 2003, taxes on
main replacements. The wet weather conditions during the first part of 1998 also hampered planned maintenance activities, thereby reducing maintenance expense in 1998. Depreciation expense in 1999 increasedincome decreased by8.9%29.2% to$13.7$9.2 millionreflectingcompared to $12.9 million for year ended December 31, 2002 due primarily to lower pre-tax operating income and the effects ofrecording approximately $38.2 million in net plant additions during 1998, depreciationflow-through true-up adjustments comparing estimated accrual with actual tax return amounts. SFAS No. 109 requires that rate-regulated enterprises record deferred income taxes for temporary differences accorded flow-through treatment at the direction of a regulatory commission. Such items (including flow-through adjustments thereof) have a direct impact onwhich began in 1999. Taxes on incomeRegistrant’s effective rate.For the year ended December 31, 2003, other taxes increased by 7.4% to $8.3 million compared to $7.7 million for the year ended December 31, 2002 reflecting additional property taxes resulting from higher assessed values, and increases in payroll taxes based on increased labor costs.
Other Income (Loss)
For the year ended December 31, 2003, other income decreased to $3.6 million loss compared to $390,000 income for the year ended December 31, 2002. The net decrease reflects a CPUC decision on March 16, 2004 that ordered SCW to refund 70 percent of the total amount of lease revenues received form the City of Folsom since 1994, plus interest, to customers. Pursuant to the order, for the year ended December 31, 2003 SCW recorded a $6.2 million charge against non-operating income (less $2.5 million of taxes). Management intends to appeal the decision and will vigorously defend its position. Other income (loss) also decreased due to the sale of a parcel of non-operating property in Region II of SCW in the first quarter of 2002 for which there was a gain of approximately
31.7%$506,000.Interest Charges
For the year ended December 31, 2003, interest expense increased by 2.1% to
$13.3$18.1 million compared to $17.7 million for the year ended December 31, 2002 due primarily to higher short-term borrowings incurred to finance capital expenditures. Registrant anticipates that interest costs will increase in1999future periods due to the need for additional external capital to fund its construction program and to the likelihood that interest rates will increase at some future point. Registrant believes that costs associated with capital used to fund construction at its regulated subsidiaries will continue to be recovered in water and electric rates charged to customer.15
Consolidated Results of Operations - Years Ended December 31, 2002 and 2001
YEAR YEAR ENDED ENDED $ % 12/31/2002 12/31/2001 CHANGE CHANGE OPERATING REVENUES Water $ 187,061 $ 181,474 $ 5,587 3.1 % Electric 21,298 15,251 6,047 39.6 % Other 846 789 57 7.2 %
Total operating revenues 209,205 197,514 11,691 5.9 %
OPERATING EXPENSES Water purchased 42,859 37,609 5,250 14.0 % Power purchased for resale 15,818 19,662 (3,844 ) -19.6 % Power purchased for pumping 10,576 9,592 984 10.3 % Unrealized loss on purchased power contracts 2,530 — 2,530 100.0 % Groundwater production assessment 7,416 6,847 569 8.3 % Supply cost balancing accounts (3,406 ) (14,681 ) 11,275 76.8 % Other operating expenses 16,983 17,162 (179 ) -1.0 % Administrative and general expenses 30,010 35,108 (5,098 ) -14.5 % Depreciation and amortization 18,302 17,951 351 2.0 % Maintenance 9,839 8,640 1,199 13.9 % Taxes on income 12,949 14,370 (1,421 ) -9.9 % Other taxes 7,681 7,553 128 1.7 %
Total operating expenses 171,557 159,813 11,744 7.3 %
Operating income 37,648 37,701 (53 ) -0.1 %
OTHER INCOME (LOSS) - NET 390 (510 ) 900 -176.5 %
INTEREST CHARGES 17,699 15,735 1,964 12.5 %
NET INCOME $ 20,339 $ 21,456 $ (1,117 ) -5.2 %
Net income for the year ended December 31, 2002 decreased 5.2% to $20.3 million, equivalent to $1.34 per common share on a basic and fully diluted basis, respectively, compared to $21.5 million or $1.41 per share for the year ended December 31, 2001. The decreases in the recorded results primarily reflect the lack of timely approval of revenue increases by the CPUC, and the impact of the removal of balancing account treatment for supply costs enacted by the CPUC in November 2001. Partially offsetting these items was the reversal in 2002 of a reserve established in 2001 for potentially unrecoverable purchased power costs and various other reasons as discussed below.
Operating Revenues
Water operating revenues increased by 3.1% in 2002 to $187.1 million from the $181.5 million reported in 2001 due to an increase of 3.3% in consumption due to drier weather conditions as compared to the
$10.1 million in 1998 due to a 24.5% increase in pre-tax income and a higher effective tax rate in 1999 resulting from the turn-around of depreciation related temporary differences, the benefits of which were previously flowed-through for ratemaking purposes. Property and other taxes increased by 7.2% in 1999 to $6.6 million due primarily to increased franchise fees resulting from higher revenues, and increased payroll taxes from higher wages and additional personnel. Other income decreased by 30.8% in 1999 due primarily to the flow-through of tax benefits related to refinancing of long-term debt in December 1998 for which thereprior year. There were nosimilar benefits in 1999. Interest expense increased by 15.5% to $12.9 million primarily due to the issuance of $40 million in long-term debt in January 1999, partially offset by the retirement of $10 million of 10.10% Notes in December 1998. YEARS ENDED DECEMBER 31, 1998 AND 1997 Basic earnings per Common Share in 1998 increased by 3.8 % to $1.62 per share as compared to $1.56 per share in 1997. Although wet weather significantly impacted revenues in 1998, lower supply costs and modest increases in other operating expenses partially offset the decline in revenues. Water operating revenues decreased by 4.3% in 1998 to $134.9 million from the $141.0 million reported in 1997. Water sales volumes in 1998 were 9.9% lower than 1997 due to extremely wet weather during the first half of the year. The decrease in sales was partially offset bysignificant water rate increases effective during1998. 9122002. Differences in temperature and rainfall in Registrant’s service areas will impact sales of water to customers and may cause fluctuations in Registrant’s revenues and earnings between comparative periods.16
Electric
operatingrevenuesof $13.2increased by 39.6% to $21.3 millionwere 3.4% higherin19982002 as compared to1997$15.3 million in 2001. The increases reflected (i) a rate increase of 12.5% effective May 24, 2001 and an additional 14.8% increase effective August 23, 2001 authorized by the CPUC to recover previously under-collected energy costs, (ii) rate increases in July 2002 authorized by the CPUC to cover purchased power costs under various power supply agreements, and (iii) an increase of 3.9% in kilowatt-hour consumption, primarily due to heavier use of snow making machines at ski resorts in theimpactarea in the fourth quarter of 2002.Registrant relies upon rate increases for water and electric services approved by regulatory bodies in California and Arizona in order to recover operating expenses and provide for a
generalreturn on invested and borrowed capital used to fund utility plant. Without such adequate rateincrease effective January 1998, as well asrelief granted in a2.0% increase in kilowatt-hour sales.timely manner, revenues and earnings can be negatively impacted.Operating Expenses
Purchased water costs
decreasedin19982002 increased by 14.0% to$30.8$42.9 million as compared to$38.3$37.6 million in19972001, reflecting an increase in purchased water volume resulting from (i) higher water consumption, (ii) additional purchased water necessary in 2002 to replace pumped water supply lost due to wells being removed from service as a result of water quality issues and mechanical problems, particularly in SCW’s Orange County and San Dimas customer service areas, (iii) refunds received from SCW’s wholesale water suppliers during 2001 of approximately $777,000 for which there was no counterpart in 2002, and (iv) costs of approximately $1.4 million, incurred most significantly in connection with the trucking of water, in SCW’s Wrightwood customer service area due to a20.8% decreasesudden and unexplained drop involumesgroundwater level in the area during the early part of the third quarter of 2002. For the years ended December 31, 2002 and 2001, 41% of our supply mix was purchased water.Registrant has had to take a number of wells out of service from time-to-time due to various causes, including contamination by third parties. Changes in the water resource mix between water supplied from purchased sources and
refunds receivedthat supplied fromRegistrant's wholesaleRegistrant’s own wells can increase actual supply-related costs relative to the supply-related costs approved for recovery through rates, thereby impacting earnings either negatively or positively. Registrant has the opportunity to change the supply-related costs recovered through rates by application to the appropriate regulatory body. Registrant believes that its applications for recovery of supply-related costs accurately reflect the watersupplier during 1998 of approximately $1.4 million. Refunds of $2.0 million were receivedsupply situation as it is known at the time. However, it is impossible to adequately protect earnings from adverse changes in1997.supply costs related to unforeseen contamination.Costs of power purchased for pumping
decreasedincreased by7.2%10.3% to$7.0$10.6 million in1998 chiefly2002 as compared to $9.6 million recorded in 2001, due to the rate increases implemented in 2001 by SCW’s energy suppliers, in particular Southern California Edison Company and Pacific Gas and Electric Company. In 2001, the CPUC approved aresultportion ofreduced energySCW’s advice letters to increase revenues by approximately $1.4 million annually to recover the costsfrom Registrant's suppliers.of purchased power for certain of its water ratemaking districts. A gain of $440,000 recorded in the fourth quarter of 2001 for the sale of groundwater in the Chino Basin also impacted the comparison. There was no such sale in 2002.Costs of power purchased for resale to customers in
1998SCW’s Bear Valley Electric division in 2002 decreased by3.4%19.6% to$5.0$15.9 million from the$5.2$19.7 million recorded in19972001 due primarily to lower power costs in the first quarter of 2002 under SCW’s power supply agreements to cover peak winter demand as compared to the costs for energy purchased on the spot market in the same period of 2001. Offsetting the decrease was a one-time sale of energy on the spot market that generated a $644,000 gain in April 2001. The gain is the subject of a complaint filed at the Federal Energy Regulatory Commission by Mirant Marketing where Mirant Marketing, the purchaser of the energy, is seeking to be refunded all or a portion of the gain. FERC is scheduled to take up the issue at their public meeting by the end of March 2004. The sale of excess energy on the spot market in 2001 resulted from a one-month overlap of energy purchase agreements.Unrealized gain and loss on purchased power contracts represents gains and losses recorded for SCW’s power purchase agreements, with PWCC, which qualify as derivative instruments under Statement of Financial Accounting Standards (SFAS) No. 133,“Accounting for Derivative Instruments and Hedging Activities”. The $2.5 million pre-tax unrealized loss on purchased power contracts for the year ended December 31, 2002 is due to
reduced costsactual contract prices being higher than the current forward market prices as of December 31, 2002. There is no cash flow impact fromRegistrant's energy providers offset bytheeffects of increased kilowatt-hour sales volumes recordedunrealized gains and losses on the purchased power contracts. Unrealized gains and losses at Bear Valley Electric will continue to impact earnings during theyear.life of the contract with PWCC.17
Groundwater production assessments increased by
10.5%8.3% to$7.6$7.4 million in19982002 from $6.8 million in1997 due to2001. The increase reflects (i) an increase in well production and higher assessments levied against production for the water year 2002/2003 as compared with the previous year in SCW’s Metropolitan customer service area, and (ii) increasedamounts ofpumpedwatercosts inRegistrant's supply mix as well as additional assessments associated with increased pumping in Registrant's Metropolitan andSCW’s Orange County customer serviceareas.area due to an in-lieu program implemented by the Metropolitan Water District of Southern California (MWD) to help preserve groundwater levels in the area, which allows SCW to purchase treated water from MWD essentially at SCW’s groundwater pumping costs. The increases were partially offset by revenues from leases of unused water rights to third parties in SCW’s Barstow customer service area in 2002.A positive entry for the provision for supply cost balancing accounts reflects recovery of previously under-collected supply costs. Conversely, a negative entry for the provision for supply cost balancing accounts reflects an under-collection of previously incurred supply costs.
In 1998, recoveryThe negative entries for 2001 and 2002 primarily reflect untimely-recovery ofpreviouslyelectric power costs discussed previously. An increase of $11.3 million during the year ended December 31, 2002 in the provision for supply cost balancing accounts as compared to the year ended December 31, 2001 primarily reflects the new rates authorized in July 2002 to recover electric power costs. At December 31, 2002, SCW had a combined net under-collectedsupply costs was lower than 1997position of $27.5 million in both its water and electric balancing accounts, primarily due to theexpiration,increases inJanuary 1998, of a surcharge designed to recover thoseenergy costs.The new rates, effective January 1999, increased collection of these under-collected costs. The balancing account mechanism insulates earnings from changes in the unit cost of supply costs which are outside of the immediate control of Registrant. However, the balancing account is not designed to insulate earnings against changes in supply mix, as occurred during the first eight months of 1997.Other operating expenses
increased by 10.6%decreased slightly in 2002 to $17.0 million as compared with $17.2 million in 2001 due primarily to (i) a refund for a sewer service overpayment, (ii) reimbursement received during 2002 from the$13.1 million recordedsettling parties for expenses incurred in1997 duethe San Gabriel basin toemployee time charged to this category. Reversals in 1997 of costs associated with recovery ofmeet water qualityexpenditures throughstandards for which there was no counterpart in 2001, and (iii) a decrease in theCPUC's memorandum account mechanism also contributed to the increase. There were no such reversalsaccrual for bad debt, net ofequal magnitude in 1998.increased water treatment costs, chemical costs and higher labor costs.Administrative and general expenses decreased
slightlyby0.7%14.5% in 2002 to$22.0$30.0 millionin 1998fromthe $22.1$35.1 million recorded in1997.2001 reflecting reversal of the remaining reserve of $6.5 million for potential non-recovery of electric power costs incurred to serve customers at SCW’s Bear Valley Electric customer service area. The reserves were established in 2001 to offset future impacts to earnings for the difference between authorized rates and SCW’s actual electric power costs under its supply agreements. SCW charged off $1.7 million against this reserve in July 2002 against the balancing accounts. The decreaseis duewas partially offset by increased reserves for self-insured worker’s compensation liabilities, higher labor and benefits related costs, and increased outside service expenses. Registrant anticipates that administrative and general costs will continue tostability inincrease reflecting, among other things, normal wage increases, increased costs for health, property and casualty insurance premiums, employee benefit programs, additional administrative and staff personnel, and costs associated withhealth insurance, post-retirement medical benefits, pensionpursuit of additional business lines not subject to regulation. Registrant believes that prudent administrative expenses incurred in the operation and401(k) plan costsmanagement of its regulated subsidiaries will be recovered through water andto a reduction of time charged by employees to this category. In 1998, maintenance expense remained at approximately the $7.3 million level recorded in 1997 due principally to the wet weather conditions during the first part of 1998 that hampered planned maintenance activity.electric rates.Depreciation expense in
19982002 increased by14.5%2.0% to$12.5$18.3 million reflecting, among other things, the effects of recording approximately$38$38.0 million innetutility plant additions during1997,2001, depreciation on which began in1998.January 2002. Registrant anticipates that depreciation expense will continue to increase due to Registrant’s on-going construction program at its regulated subsidiaries. Registrant believes that depreciation expense related to property additions approved by the appropriate regulatory bodies will be recovered through water and electric rates. The comparison was also impacted by the elimination, effective January 1, 2002, of amortization of the goodwill recorded in AWR’s acquisition of CCWC. During 2001, amortization of this goodwill was $331,073. Pursuant to Financial and Accounting Standards Board No. 142, AWR has determined that this goodwill was not impaired at January 1, 2002 and January 1, 2003.As compared to 2001, maintenance expense increased by 13.9% to $9.8 million due principally to the termination of SCW’s Cash Preservation Program (“CPP”) in August 2002 following the CPUC’s approval of rate increases permitting SCW to begin recovery of power costs incurred during the energy crisis of 2000-2001 to serve customers of its Bear Valley Electric division. The CPP was initially implemented in 2001 to control costs and temporarily limit capital and maintenance expenditures principally to those projects that were believed necessary to meet public safety and health requirements or otherwise provide for continued service. The CPP impacted both the electric and water businesses of SCW. In addition
amortizationto maintenance routinely performed on Registrant’s facilities at its regulated subsidiaries, maintenance expense can be impacted by water main breaks or other incidents related to older infrastructure. Registrant’s construction program is in part designed to minimize the impact the aging infrastructure has on maintenance costs.Taxes on income decreased by 9.9% to $12.9 million in 2002 as compared to $14.4 million in 2001 due to an approximately 9.5% decrease in pre-tax operating income. Registrant estimates its taxes payable and exposure based on a variety of
start-upfactors andorganizational costsjudgments applied by management.18
Property and other tax expense increased slightly by 1.7% in 2002 to $7.7 million reflecting principally increased property taxes due to higher property valuation assessments, and higher payroll taxes based on increased labor costs.
Other Income (Loss)
As compared to 2001, the change in other income reflects (i) the sale of a parcel of non-operating property in SCW’s Metropolitan customer service area in the first quarter of 2002 for which there was no equivalent sale in 2001 and resulted in a gain of approximately $506,000, and (ii) the write-off of expenses associated with the
formationtermination ofAWR is reflectedthe acquisition of Peerless Water Co. in1998 and there were no similar amortization costs in 1997. Taxes on incomethe fourth quarter of 2001.Interest Charges
Interest expense increased by
approximately 3.1%12.5% in 2002 to$10.1$17.7 millionin 1998as compared to $15.7 million recorded in 2001 due to the$9.8issuance of $50 million in1997 due to a 5.7% increaselong-term debt by SCW inoperating incomeDecember 2001, partially offset by alower effective tax rate.reduction in short-term borrowing costs. Registrant anticipates that interest costs will increase in future periods due to the need for additional external capital to fund its construction program and to the likelihood that interest rates will increase at some future point. Registrant believes that costs associated with capital used to fund construction at its regulated subsidiaries will continue to be recovered in water and electric rates charged to customer.Critical Accounting Policies
Critical accounting policies are those that are important to the portrayal of AWR’s financial condition, results of operations and cash flows, and require the most difficult, subjective or complex judgments of AWR’s management. The need to make estimates about the effect of items that are uncertain is what makes these judgments difficult, subjective and/or complex. Management makes subjective judgments about the accounting and regulatory treatment of many items. The following are accounting policies that are critical to the financial statements of AWR. For more information regarding the significant accounting policies of Registrant, see Note 1 of “Notes to Financial Statements”included in Part II, Item 8 in Financial Statements and Supplementary Data.
Accounting for Rate Regulation
• Management believes that regulation and the effects of regulatory accounting have the most significant impact on the financial statements. When either SCW or CCWC file for adjustments to rates, the capital assets, operating costs and other matters are subject to review, and disallowances could occur. Regulatory disallowances in the past have not been frequent but have on occasion significantly impacted AWR’s results of operations. For example, Registrant recorded a $3.5 million pre-tax charge to earnings in the fourth quarter of 2003 to reflect a Proposed Decision issued by the CPUC on December 19, 2003. The Proposed Decision requires SCW to refund to customers approximately $3.5 million in net proceeds received from potentially responsible parties since 1998 for the contamination of the Company’s groundwater supply. Management believes the refund is probable and as a result, SCW established a regulatory liability as of December 31, 2003. In addition, Registrant recorded a $6.2 million pre-tax charge to non-operating income to reflect a decision issued by the CPUC on March 16, 2004. The decision ordered SCW to refund 70 percent of the total amount of lease revenues received by the City of Folsom since 1994, plus interest, to customers. Management disagrees with the decision and will pursue the necessary appeals. • The utility subsidiaries, SCW and CCWC, have incurred various costs and received various credits reflected as regulatory assets and liabilities. Accounting for such costs and credits as regulatory assets and liabilities is in accordance with Statement of Financial Accounting Standards No. 71“Accounting for the Effects of Certain Types of Regulation”(SFAS 71). This statement sets forth the application of generally accepted accounting principles for those companies whose rates are established by or are subject to approval by an independent third-party regulator. Under SFAS 71, 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 rate making process in a period different from the period in which they would have been reflected in income by an unregulated company. These deferred regulatory assets and liabilities are then reflected in the income statement in the period in which the same amounts are reflected in the rates charged for service. If rate recovery is no longer probable, Registrant is required to write off 19
the related regulatory asset. At December 31, 2003, the consolidated balance sheet included regulatory assets, less regulatory liabilities, of $53.4 million. Management continually evaluates the anticipated recovery of regulatory assets, liabilities, and revenue subject to refund and will provide for allowances and/or reserves as deemed necessary. • Registrant’s income tax calculations require estimates due principally to the regulated nature of the operations of SCW and CCWC, the multiple states in which Registrant operates, and potential future tax rate changes. Registrant uses the asset and liability method of accounting for income taxes under which 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. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. A change in the regulatory treatment, or significant changes in tax-related estimates or assumptions or changes in law, could have a material impact on the financial position and results of operations of Registrant. • Depreciation is computed at composite rates based on depreciable plant at the beginning of each year and considered sufficient to amortize costs over the estimated remaining lives of assets. Depreciation studies are performed periodically and prospective changes in rates are estimated to make up for past differences. These studies are reviewed and approved by either the CPUC or the ACC. Changes in estimates of depreciable lives or changes in depreciation rates mandated by regulations could impact results of operations of Registrant in periods subsequent to the change. Depreciation is computed on the straight-line, remaining-life basis. • As prescribed by the CPUC under its Uniform System of Accounts for Water Utilities, SCW is allowed to capitalize a portion of general costs such as engineering, supervision, general office salaries and expenses, legal expenses, insurance, injuries and damages, pensions and benefits, and taxes, as overhead construction costs included in SCW’s Utility Plant. All overhead construction costs are charged to jobs on the basis of the amounts of such overhead expenses reasonably applicable thereto, so that each job bears its equitable proportion of such costs and its direct costs. Accounting for Supply Costs
As permitted by the CPUC, SCW has historically maintained water supply balancing accounts prior to November 29, 2001 and electric supply balancing accounts to account for under-collections and over-collections of revenues designed to recover such costs. Costs have been recorded in income and charged to balancing accounts when such costs were incurred. The balancing accounts were reversed when such costs were recovered through rate adjustments or through refunds of previously incurred costs. SCW accrues interest on its supply cost balancing accounts at the rate prevailing for 90-day commercial paper. CCWC does not maintain a supply cost balancing account.
On November 29, 2001, the CPUC ordered water utilities with existing water supply balancing accounts to cease booking amounts to such accounts. In its place, water utilities are now required to establish a memorandum supply cost account. The over- or under-collection of water supply costs is recorded in this memorandum account in a manner similar to the balancing account. However, the income statements of SCW no longer include entries reflecting differences between authorized water supply unit costs included in rates and actual water supply costs. As a result, any changes in water supply costs as well as any future revenue increases or decreases that may be authorized for supply expenses may directly impact earnings.
In a decision issued on June 19, 2003 related to the memorandum supply cost account, the CPUC concluded that (i) if a utility is within its 3-year rate case cycle and does not earn in excess of its authorized rate of return, the utility is entitled to recover its costs in the memorandum supply cost account, subject to a reasonableness review by the CPUC; (ii) if a utility is either within or outside of its rate case cycle and earns in excess of its authorized rate-of-return, the utility’s recovery of expenses from the memorandum supply cost account will be reduced by the amount exceeding the authorized rate-of-return, and (iii) a utility is required to seek review of under and over collections by filing an advice letter annually by March 31. Pursuant to the resolution, SCW filed advice letters on September 12, 2003 seeking recovery of an under-collected balance of $2.6 million for the period November 29, 2001 through December 31, 2002. The CPUC has rejected all water utilities’ filings, including SCW’s, and conducted workshops for more discussion and directions. SCW is in the process of preparing the filings. Upon receiving approval from the CPUC, SCW will recognize the authorized under-collected amount as supply cost balancing accounts on its books. As of December 31, 2003, SCW had an under-collection of approximately $5.5 million in its memorandum supply cost account, including
20
the $2.6 million filed with the CPUC. SCW intends to file advice letters annually by March 31. Amounts included in the memorandum supply cost account are not capitalized until a rate order is received from the CPUC. For more information, see the sections entitled “Regulatory Matters” included in Part II, Item 7 in Management’s Discussion and Analysis of Financial Condition and Results of Operation.
With respect to pre-November 29, 2001 water supply balancing accounts, SCW has a net under-collection position of $1.7 million recorded at December 31, 2003, the majority of which was approved for recovery in rates on June 19, 2003 over 24 months.
Electric power costs incurred by SCW’s Bear Valley Electric division continue to be charged to its electric supply cost balancing account. The under-collection in the electric balancing account is $22.7 million at December 31, 2003. The CPUC has authorized SCW to collect a surcharge from its customers of 2.2¢ per kilowatt hour for a period through 2011 to enable SCW to recover the under-collection. SCW sold 132,849,639, 131,826,314 and 126,910,985 kilowatt hours of electricity to its Bear Valley Electric division customers for the twelve months ended December 31, 2003, 2002 and 2001, respectively. SCW anticipates electricity sales to be sufficient during a ten year period for it to recover the amount of the under-collection. SCW is only allowed to include up to a weighted annual energy purchase cost of $77 per MWh each year for 10
13 Propertyyears in its electric supply cost balancing account. To the extent that actual weighted average annual cost for power purchased exceeds the $77 per MWh amount, SCW will not be able to include these amounts in its balancing account and such amounts will be expensed. During the years ended December 31, 2003 and 2002, approximately $240,000 and $718,000, respectively, was expensed. For further information, see the sections entitled “Regulatory Matters” and “Electric Energy Situation in California” included in Part II, Item 7 in Management’s Discussion and Analysis of Financial Condition and Results of Operation.Accounting for Derivative Instruments
In June 1998, the FASB issued SFAS No. 133,“Accounting for Derivative Instruments and Hedging Activities”as amended by SFAS Nos. 138 and 149. A derivative financial instrument or other contract derives its value from another investment or designated benchmark. SFAS No. 133 requires companies to record derivatives on the balance sheet as assets and liabilities, and to measure those instruments at their fair value. SCW is a party to various block-forward purchase power contracts. Certain of these contracts qualify as an exception provided under the SFAS No. 133 for activities that are considered normal purchases and normal sales. These contracts are reflected in the statements of income at the time of contract settlement. Contracts that do not qualify for the normal purchases and normal sales exception have been recognized at fair market value on the balance sheet as an asset or liability and an unrealized gain or loss against earnings. On a quarterly basis, the related asset or liability will be adjusted to reflect the fair market value at the end of the quarter. As these contracts are settled, the realized gains or losses will be recorded in power purchased for resale, and the unrealized loss will be reversed. This resulted in a pre-tax unrealized gain of $638,000 and a pre-tax unrealized loss of $2.5 million, respectively, for the years ended December 31, 2003 and 2002.
Accounting for Asset Retirement Obligations
SFAS No. 143,“Accounting for Asset Retirement Obligations,”requires businesses to record the fair value of a liability for a legal obligation to retire an asset in the period in which the liability is incurred. A legal obligation is a liability that a party is required to settle as a result of an existing or enacted law, statute, ordinance or contract. When the liability is initially recorded, the entity capitalizes the cost by increasing the carrying amount of the related long-lived asset. Over time, the liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. Upon settlement of the liability, an entity either settles the obligation for its recorded amount or incurs a gain or loss upon settlement. Registrant adopted SFAS No. 143 on January 1, 2003, as required. Registrant’s legal obligations for retirement reflect principally the retirement of wells, which by law need to be destroyed and filled at the time of removal. As such, the regulated subsidiaries of Registrant incur asset retirement obligations. Retirement cost has historically been recovered through rates at the time of retirement. As a result, the cumulative effect upon adoption was reflected as a regulatory asset or liability. Accordingly, Registrant will also reflect the gain or loss at settlement as a regulatory asset or liability on the balance sheet. With regards to other long-lived assets, such assets either have indefinite lives or there is no legal obligation to retire the asset.
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Upon adoption on January 1, 2003, Registrant recorded an asset retirement obligation of $13.2 million at its net present value of $2.7 million, increased depreciable assets by $0.4 million for asset retirement costs, increased regulatory assets by $2.5 million and increased accumulated depreciation by $0.2 million. Amounts recorded under SFAS No. 143 are subject to various assumptions and determinations, such as determining whether a legal obligation exists to remove assets, and estimating the fair value of the costs of removal, when final removal will occur and the credit-adjusted risk-free interest rates to be utilized on discounting future liabilities. Changes that may arise over time with regard to these assumptions will change amounts recorded in the future. Estimating the fair value of the costs of removal were determined based on third party costs.
Accounting for Pension and Other Postretirement Benefits
Registrant records plan assets, obligations and expenses related to its pension and other
taxes decreasedpostretirement benefit plans based on actuarial valuations. Key assumptions in these valuations include discount rates, expected returns on plan assets, compensation increases and health care cost trend rates. Registrant believes that the assumptions utilized in recording obligations under the plans are reasonable based on prior experience and market conditions. Net periodic pension cost increased from $1.8 million for the plan year ended December 31, 2002 to $3.0 million for the year ended December 31, 2003 due to actuarial assumption changes in discount rate and expected long-term rate of return on plan assets. Postretirement benefit cost also increased by2.5%approximately $150,000 or 17%. The increases are generally recovered through rates. Net periodic pension and postretirement benefit costs for 2003 were computed using a discount rate and expected long-term rate of return on plan assets of 6.75% and 7.0%, respectively, as compared to 7.25% and 8.0% in19982002. Both pension and postretirement liabilities, and future pension and postretirement expense increase as the discount rate is reduced. In addition, pension and postretirement expense increase as the expected rate of return on plan assets decreases.At December 31, 2003, Registrant’s pension plan included a $58.9 million projected benefit obligation (PBO), $47.9 million in accumulated benefit obligation (ABO) and $46.7 million in plan assets. A 1% decrease in the discount rate would increase the PBO by approximately $6 million, with a corresponding change in the ABO. A 1% decrease in the expected rate of return on plan assets would increase pension expense by approximately $500,000.
At December 31, 2003, Registrants other postretirement benefit plan included $9.6 million in PBO and $3.3 million in plan assets. Total expense for the plan was approximately $1.0 million for 2003. Increasing the health care cost trend rate by one-percentage point would increase the accumulated obligation as of December 31, 2003 by $750,000 and annual aggregate service and interest costs by $72,000. Decreasing the health care cost trend rate by one-percentage point would decrease the accumulated obligation as of December 31, 2003 by $641,000 and annual aggregate service and interest costs by $61,000.
Unbilled Revenues
SCW and CCWC record water and electric utility operating revenues when the service is provided to
$6.1customers. Operating revenues include unbilled revenues which are earned (service has been provided) but not billed by the end of each accounting period. By using the billed revenues based on the last meter reading and billed customer numbers, an average amount billed per customer is used to estimate the unbilled revenues for estimated average remaining days to the end of the reporting period. Unbilled revenues are recorded for both monthly and bi-monthly customers.22
Liquidity and Capital Resources
AWR
Net cash provided by operating activities was $46.8 million for the year ended December 31, 2003 as compared to $25.8 million for the year ended December 31, 2002. The increase of $21.0 million was primarily attributable to new electric rates and surcharges to decrease under-collected electric supply cost balancing account balances, as well as the timing of cash receipts and disbursements related to working capital items.
Net cash used in investing activities was $57.2 million for the year ended December 31, 2003 as compared to $40.7 million for the year ended December 31, 2002 due to higher capital expenditures consistent with budgeted increases.
Net cash provided by financing activities was $4.8 million for the year ended December 31, 2003 as compared to $2.8 million for the year ended December 31, 2002. The increase was due primarily to
reduced franchise tax payments directly attributable to reduced revenues. Other income increased by 1.5%(i) the redemption of preferred shares totaling $1.9 million in1998 due principally2002, (ii) an increase of $6 million in short-term bank borrowing against its revolving credit, (iii) increases of $4.9 million in receipt of advances for and contributions in aid of construction, and (iv) the receipt of $1.8 million of cash related to theflow-throughfinancing portion oftax benefits related to refinancing of long-term debt whichSCW’s purchased power contracts with PWCC. The increase was partially offset byan increase in reserves against costs associated withthe retirement of anon-regulated joint venture. Interest expense increased by 10.3% to $11.2$12.5 millionprimarily due to increased short-term bank borrowing and the issuance of $15 million inlong-termdebt in March 1998. LIQUIDITY AND CAPITAL RESOURCESnote.AWR funds its operating expenses and pays dividends on its outstanding Common
and PreferredSharesand makes its mandatory sinking fund payments, principallyprimarily through dividends from its subsidiaries, principally SCW. AWR hasfileda Registration Statement on file with the Securities and Exchange Commission (SEC) for issuance, from time to time, of up to $60 million in Common Shares, Preferred Shares and/or debt securities.The proceeds will be used primarilyAs of December 31, 2003, approximately $31.1 million remained forinvestment in its subsidiaries. No securities had been issuedissuance under this RegistrationStatement asStatement.During 2001, AWR maintained a $25 million credit facility, $20 million of which was outstanding at December 31, 2001. This credit facility expired on January 2, 2002. In June 2002, AWR established a $75 million revolving credit facility, which matures in June 2005. Up to $15 million of this facility may be used for letters of credit. As of December 31,
1999.2003, an aggregate of $56 million in cash borrowing and approximately $7.5 million of letters of credit were outstanding under this facility.During 2002, AWR completed the redemption of all of its outstanding 4%, 41/4% and 5% series of preferred shares.
SCW
Net cash provided by operating activities was $47.4 million for the year ended December 31, 2003 as compared to $24.6 million for the year ended December 31, 2002. The increase of $22.8 million in cash provided by operations was primarily attributable to new electric rates and surcharges to decrease under-collected electric supply cost balancing account balances, as well as the timing of cash receipts and disbursements related to working capital items.
Net cash used in investing activities increased to $53.6 million for the year ended December 31, 2003 as compared to $39.5 million for the same period of 2002 due to increased capital expenditures consistent with budgeted increases.
Net cash provided by financing activities was $2.9 million for the year ended December 31, 2003 as compared to $535,000 for the year ended December 31, 2002, reflecting primarily an increase of $5.3 million in receipt of advances for and contributions in aid of construction, the receipt of $1.8 million of cash related to the financing portion of SCW’s purchased power contracts with PWCC, and an $8.0 million increase in inter-company borrowings, offset by the retirement of a $12.5 million long-term note in October 2003.
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SCW funds the majority of its operating expenses,
interestpayments on its debt, and dividends on its outstanding Common Shares through internal sources. Internal sources of cash flow are provided primarily by retention of a portion of earnings from operating activities. Internal cash generation is influenced by factors such as weather patterns, environmental regulation, litigation, changes in supply costs and regulatory decisions affecting SCW’s ability to recover these supply costs, and timing of rate relief. For further information, see the sections entitled “Risk Factors” and “Electric Energy Situation in California” included in Part II, Item 7 in Management’s Discussion and Analysis of Financial Condition and Results of Operation.SCW
continues to relyalso relies on external sources, including equity investments and short-termbank borrowing,borrowings from AWR, long-term debt, contributions-in-aid-of-construction, advances for construction and install-and-convey advances, to fund the majority of its construction expenditures.BecauseIn January 2001, SCW issued $20 million of long-term debt in a public offering with theseasonal nature of its water and electric operations, SCW utilizes its short-term borrowing capacityproceeds used tofinance current operating expenses. The aggregate short-term borrowing capacity available to SCW under its threereduce banklines of credit was $47borrowings. On March 30, 2001, AWR made an additional $25 millionas of December 31, 1999, of which a total of $21 million was outstanding. SCW routinely employs short-term bank borrowing as an interim financing source prior to funding capital expenditures on a long-term basis. In 1998,equity investment in SCW. On November 14, 2001, SCW filed a Registration Statement with the SEC for issuance, from time to time, of up to$60$100 million inlong-term debt.debt securities. InJanuary 1999,December 2001, SCW issued$40$50 million of long-term debtpursuant tounder this Registration Statementleaving $20that initially reduced bank borrowings incurred to fund capital expenditures and purchased power costs.CCWC
CCWC funds the majority of its operating expenses, payments on its debt and dividends, if any, through internal sources. CCWC also relies on external sources, including long-term debt, contributions-in-aid-of-construction, advances for construction and install-and-convey advances, to fund the majority of its construction expenditures.
ASUS
ASUS funds its operating expenses primarily through contractual management fees and investments by or loans from AWR.
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Contractual Obligations and Other Commitments
In addition to contractual maturities, Registrant has certain debt instruments that contain annual sinking fund or other principal payments. Registrant believes that it will be able to refinance debt instruments at their maturity through public issuance, or private placement, of debt or equity. Annual principal interest payments are generally made from cash flow from operations. In the case of the $12,500,000 in notes that were due October 2003, SCW used proceeds from short-term borrowings, which it intends to repay or refinance through the issuance of notes in the public or private markets.
The following table reflects Registrant’s contractual obligations and commitments to make future payments pursuant to contracts as of December 31, 2003. All obligations and commitments are obligations and commitments of SCW unless otherwise noted.
($ in thousands) Payments/Commitments Due by Period(1) Total Less than 1 Year 1-3 Years 4-5 Years After 5 Years $ 173,100 — — — $ 173,100 28,000 — — — 28,000 18,886 76 163 189 18,458 2,270 183 430 459 1,198 77,154 3,025 5,314 4,500 64,315 59,949 12,014 23,973 23,962 — 12,458 12,458 — — — 6,162 2,013 3,009 1,136 4 16,141 3,541 5,925 6,675 — 57,493 — — — — 8,363 560 938 580 6,285
TOTAL $ 459,976 $ 33,870 $ 39,752 $ 37,501 $ 291,360
(1) Excludes interest, dividends, commitment, and facility fees. (2) The Notes and Debentures are issued under an Indenture dated as of September 1, 1993. The Notes and Debentures do not contain any financial covenants that Registrant believes to be material, or cross default provisions. (3) �� The private placement notes are issued pursuant to the terms of Note Agreements with substantially similar terms. The Note Agreements contain restrictions on the payment of dividends, minimum interest coverage requirements, maximum debt to capitalization ratio and a negative pledge. Pursuant to the Note Agreements, SCW must maintain a minimum interest coverage ratio of two times interest expense. SCW does not currently have any outstanding mortgages or other encumbrances on its properties. (4) Consists of obligations under a loan agreement supporting $8 million in debt issued by the California Pollution Control Financing Authority, $6 million in obligations supporting $6 million in certificates of participation issued by the Three Valleys Municipal Water District and $5.5 million of obligations incurred by SCW with respect to its 500 acre foot entitlement to water from the State Water Project (SWP). These obligations do not contain any financial covenants believed to be material to Registrant or any cross default provisions. SCW’s obligations with respect to the certificates of participation issued by the Three Valleys Municipal Water District are supported by a letter of credit issued by Wells Fargo Bank. In regards to its SWP entitlement, SCW has entered into agreements with various developers for 422 acre-feet, in aggregate, of its 500 acre-foot entitlement to water from the SWP. (5) Consists of $1.5 million outstanding under a fixed rate obligation incurred to fund construction of water storage and delivery facilities with the Three Valleys Municipal Water District, $0.6 million outstanding under a variable rate obligation incurred to fund construction of water delivery facilities with the Three Valleys Municipal Water District and an aggregate of $0.4 million outstanding under capital lease obligations. These obligations do not contain any financial covenants believed to be material to Registrant or any cross default provisions. (6) Advances for construction represent annual contract refunds to developers for the cost of water systems paid for by the developers. The advances are generally refundable at rates ranging from 10% to 22% of the revenue received from the installation for which funds were advanced or in equal annual installments over periods of time ranging from 10 to 40-year periods. (7) Consists of the remaining balance of the $59.9 million purchased power contracts from November 2002 to December 2008. (8) Consists of noncancelable commitments primarily for capital projects under signed contracts. (9) Reflects Registrant’s future minimum payments under non-cancelable operating leases. 25
(10) Registrant’s expected contributions (all by employer) for its pension and postretirement plans are approximately $2,676,000 and $865,000, respectively, for the year ended December 31, 2004. These amounts are subject to change based on, among other things, the limits established for federal tax deductibility (pension plan). In addition, for years after 2004, Registrant has included as an obligation the estimated minimum required contributions to its pension plan computed by its actuary. These amounts are subject to change based on the significant impact that returns on plan assets and changes in discount rates might have on such amounts. (11) Other commitments of Registrant consist of (i) $75 million syndicated revolving credit facility, expiring in June 2005 of which $56.0 million is outstanding as of December 31, 2003, (ii) an amount of $296,000 with respect to a $6,296,000 irrevocable letter of credit issued by Wells Fargo Bank to support the certificates of participation of Three Valleys Municipal Water District (the other $6,000,000 is reflected under tax-exempt obligations), (iii) an irrevocable letter of credit in the amount of $600,000 that expires on October 2004 for the deductible in Registrant’s business automobile insurance policy (v) an irrevocable letter of credit that expires March 31, 2005 for its energy scheduling agreement with Automated Power Exchange as security for the purchase of power; the amount of the credit is $585,000 for the months from November to March, and $270,000 to cover the months from April to October, and (vi) outstanding performance bonds of $11,450 to secure performance under franchise agreements with governmental agencies. All of the letters of credit are issued pursuant to the syndicated revolving credit facility. The syndicated revolving credit facility contains restrictions on prepayments, deposition of property, mergers, liens and negative pledges, indebtedness and guaranty obligations, transactions with affiliates, minimum interest coverage requirements, a maximum debt to capitalization ratio, and a minimum debt rating. Pursuant to the Credit Agreement, AWR must maintain a minimum interest coverage ratio of 3.25 times interest expense, a maximum total funded debt ratio of 0.65 to 1.00 and a minimum debt rating of Baa1 or BBB+. (12) Consists of $7.9 million of obligations under a loan agreement supporting Industrial Development Revenue Bonds due in 2006 and a $1.0 million repayment obligation to the United States Bureau of Reclamation. The loan agreement contains provisions that establishes a maximum of 65% debt in the capital structure, limits cash distributions when the percentage of debt in the capital structure exceeds 55% and requires a debt service coverage ratio of two times. The Bureau of Reclamation obligation does not contain any financial covenants believed to be material to Registrant or any cross default provisions. Under the terms of its power purchase contracts with Mirant Marketing and PWCC, SCW is required to post security, at the request of the seller, if SCW is in default under the terms of the contract and the future value of the contract is greater than the future value of contracts of a similar term on the date of default. SCW will be in default under the terms of these contracts if its debt is rated less than BBB- by Standard & Poor’s Ratings Service (“S&P”) or Fitch, Inc. (“Fitch”) or less than Baa3 by Moody’s Investor Services, Inc (“Moody’s”). SCW currently has a rating of A+ by S & P and A2 by Moody’s. Fitch does not rate SCW.
S&P debt ratings range from AAA (highest rating possible) to D (obligation is in default). Moody’s debt ratings range from Aaa (best quality) to C (lowest quality). Securities ratings are not recommendations to buy, sell or hold a security and are subject to change or withdrawal at any time by the rating agency.
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Electric Energy Situation in California
Background Information
On January 17, 2001, the Governor of the State of California proclaimed a state of emergency in California due to shortages of electricity available to certain of California’s utilities (resulting in blackouts), the unanticipated and dramatic increases in electricity prices and the insufficiency of electricity available from certain of California’s utilities to prevent disruption of electric service in California. The Federal Energy Regulatory Commission (“FERC”) also implemented a number of changes to the tariff for the California Independent Operator System (“Cal ISO”) beginning in December 15, 2000 in an attempt to stabilize the market. The reasons for the high cost of energy are under investigation but are reported to include, among other things, limited supply caused by a lack of investment in new power plants to meet growth in demand, planned and unplanned outages of power plants, decreased availability of hydroelectric power from the Pacific Northwest due to lower than usual precipitation and higher demand for electricity in the region, transmission line constraints, increased prices for natural gas, the fuel used in many of the power plants serving the region, a dysfunctional power market and market manipulation through the withholding of generation and a variety of “gaming” strategies.
As of December 31, 2003, SCW had accrued $22.7 million in under-collected power costs that SCW mostly incurred during the energy crisis in connection with providing service to its Bear Valley Electric customers. In addition, SCW established $7.9 million in reserves in 2001 for potential non-recovery of these power costs. In 2002, SCW charged $1.7 million against the reserves to the balancing accounts due to its inability to recover all of its costs associated with entering into a long-term power contract with Mirant Marketing in March 2001. In the fourth quarter of 2002, SCW reversed the remaining reserves due to various new contracts entered into with PWCC in September 2002.
On July 17, 2002, the FERC extended and modified the mitigation measures that were set to expire on September 30, 2002, citing delays in construction of new generation resources in California and throughout the West, delays in adopting a new market design and market rules by the Cal ISO, transmission line constraints, constraints on natural gas pipeline capacity and continuing dysfunctions in the California power market. It remains unclear how long the FERC will leave its mitigation measures in place. The premature termination of such mitigation measures could result in substantial increases in spot market prices and the prices of long-term contracts for
issuancepower and capacity. In addition, FERC is considering a number of market reforms, some of which could materially increase SCW’s costs for power. Increased costs would be included in SCW’s electric supply cost balancing account. However, as mentioned previously, SCW is only allowed to include up to a weighted annual energy purchase cost of $77 per MWh each year for 10 years in its electric supply cost balancing account. To the extent that actual weighted average annual cost for power purchased exceeds the $77 per MWh amount, SCW will not be able to include these amounts in its balancing account and such amounts will be expensed, unless the CPUC approves adjustments caused by the FERC.Power Supply Arrangements at SCW’s Bear Valley Electric Service Area
All electric energy sold by SCW to customers in its Bear Valley Electric customer service area is purchased from others. Under the terms of contracts with Dynegy that expired on April 30, 2001, Dynegy provided electric energy to SCW, acted as scheduling coordinator and provided other ancillary services. Various disputes arose between the parties regarding the services provided by Dynegy and the amounts charged by Dynegy. As a result of these disputes, SCW withheld payment from Dynegy of certain amounts invoiced by Dynegy. On November 1, 2002, Dynegy accepted $3.5 million from SCW as payment in full for the disputed amounts.
SCW entered into a five-year and nine-month, block forward purchase contract with Mirant Marketing for 15 MWs of electric energy at a
later date.price of $95 per MWh beginning April 1, 2001 through December 31, 2006. On December 20, 2001, SCW filed a complaint with FERC seeking to reduce the amount charged by Mirant Marketing under the terms of this contract to a just and reasonable price. In June 2003, the FERC issued a final order denying SCW’s complaint. On November 10, 2003, the FERC denied SCW’s rehearing request. SCW is currently reviewing its options with respect to the FERC’s latest order denying rehearing and is determining if it will appeal the decision in Federal Court. On July 14, 2003, Mirant Marketing announced that, to facilitate its financial restructuring, it filed voluntary petitions for reorganization under Chapter 11 of the U.S. Bankruptcy Code. At this time, Registrant expects no interruption in the delivery of electric energy under the Mirant Marketing contract.27
In June 2001, SCW executed an agreement with PWCC for an additional 8 MWs of electric energy to meet peak winter demands. The
funds were used primarilycontract provided for pricing of $75 per MWh from November 1, 2001 torepay short-term bank borrowings, afterMarch 31, 2002, $48 per MWh from November 1, 2002 to March 31, 2003, and $36 per MWh from November 1, 2003 to March 31, 2004.In September 2002, SCW entered into a series of purchased power contracts with PWCC. Under the agreements, SCW will sell 15 MWs to PWCC of electric energy at a price of $95 per MWh beginning November 1, 2002 through December 31, 2006, and the 8 MWs of electric energy covered under the energy purchase agreement with PWCC discussed previously. In return, PWCC will supply SCW with 15 MWs of electric energy at a price of $74.65 per MWh beginning November 1, 2002 through December 31, 2008, and an additional 8 MWs at $74.65 per MWh beginning on November 1, 2002 through March 31, 2003 and each succeeding November 1 through March 31 period through March 31, 2008, and for the period November 1, 2008 through December 31, 2008. These contracts have been recognized at fair market value on the balance sheet as a liability of $1.9 million at December 31, 2003 with the recording of an unrealized gain of $638,000 for the year ended December 31, 2003.
The average minimum monthly load at SCW’s Bear Valley Electric customer service area has been approximately 12 MWs. The average winter load has been 18 MWs with a winter peak of 39 MWs when the snowmaking machines at the ski resorts are operating. In addition to the power purchase contracts, SCW buys additional energy from the spot market to meet peak demand and sells surplus power to the spot market as well. The average cost of power purchased, including the transactions in the spot market, was approximately $78.60 per MWh for the twelve months ended December 31, 2003 as compared to $95.40 per MWh for the same period of 2002 due to the new purchased power contract with PWCC as discussed. SCW’s average energy costs will be impacted by pricing fluctuations on the spot market.
Transmission Constraints
Demand for energy in SCW’s Bear Valley Electric customer service area generally has been increasing. However, the ability of SCW to deliver purchased power to these customers is limited by the ability of the transmission facilities owned by Southern California Edison Company (Edison) to transmit this power. On December 27, 2000, SCW filed a lawsuit against Edison for breach of contract as a result of delays in upgrading these transmission facilities as well as for violations of good faith and fair dealing, negligent misrepresentation, intentional misrepresentation and unjust enrichment. A draft settlement is underway between SCW and Edison, in which
capital expenditures were funded. Registrant has no derivative financial instruments, financial instruments(i) SCW is to pay $5 million project abandonment fee to Edison, (ii) Edison will file an application to the FERC for approval of the entire $5.0 million settlement payment as abandoned project costs to be in Edison’s wholesale rate to SCW over a 15 year period, and (iii) Edison is to sell the Goldhill substation and associated transmission line to SCW at its book value. Management believes that the FERC’s approval of Edison’s filing is probable and the abandonment costs included in Edison’s wholesale rate to SCW are recoverable through rates. As a result, the $5.0 million obligation to Edison arising from this draft settlement was recorded as a liability and a regulatory asset in the fourth quarter of 2003. A final settlement agreement was reached on March 17, 2004.New Generation Facility
As a means of meeting these increasing demands for energy, SCW is constructing a natural gas-fueled 8.4 MW generation facility to be owned by SCW. A Certificate of Public Convenience and Necessity filed with
significant off-balance sheet risks or financial instruments with concentrationsthe CPUC seeking authorization for construction ofcredit risk. CONSTRUCTION PROGRAM A program forthe generation facility was approved on July 10, 2003. It is expected that the generator will be on line during the second quarter of 2004, and should assist SCW in controlling its spot purchase prices, as discussed above.Southern California Wild Fires
The October 2003 wild fires in Southern California had limited impact on SCW. While various of the firestorms approached several water
pipeline replacement is on-goingcustomer service areas, SCW experienced minimal damage to its water facilities. In SCW’s Bear Valley Electric area, located in the mountains north of Los Angeles, electric service was maintained throughout the22fire event in spite of isolated damage to certain electric distribution facilities. SCW will be filing with the CPUC for recovery of the extra expenses incurred in meeting these community needs. These costs are being accumulated in Catastrophic Event Memorandum Accounts and will be amortized pursuant to prescribed procedures after review by the CPUC.28
Construction Program
SCW maintains an ongoing water distribution main replacement program throughout its customer service areas based on the priority of leaks detected, fire protection
enhancementsenhancement and a reflection of the underlying replacement schedule. In addition,generalSCW upgradesin SCW'sits electric and water supply facilitiesare anticipated to be on-going. SCW's boardin accordance with industry standards, local requirements and CPUC requirements. SCW’s Board ofdirectorsDirectors has approved anticipated net capital expenditures of$55.4approximately $61.7 millionin 2000. Neitherfor 2004 principally reflecting water supply related projects such as drilling and equipping of new wells, building a new reservoir, and distribution and street improvement projects. As of December 31, 2003, SCW has unconditional purchase obligations for capital projects of approximately $12.5 million.CCWC’s Board of Directors has approved a net capital budget of $3.1 million for 2004 primarily reflecting a new treatment plant addition and distribution improvements to its Golden Eagle Plant.
AWR
norand ASUS have no material capitalcommitments; however,commitments. However, ASUS actively seeks opportunities to own, lease or operatemunicipalwater and wastewater systems for governmental entities, which may involve significant capital commitments.1114 REGULATORY MATTERSRegistrant does not have any material capital expenditures for specific environmental control facilities or measures.
Registrant has formalized procedures in place, covering the bidding of capital projects. These procedures are designed to achieve the lowest bid price from qualified contractors as well as to promote diversity among contractors. The procedures also provide for bypass of a formal bid process for emergency situations. Registrant has recently discovered that a greater than anticipated percentage of contracts in certain areas were being awarded on an emergency basis and to fewer than anticipated contractors. Certain of those contracts are being further scrutinized by Registrant. In addition, two executives involved in awarding such capital contracts have been terminated, in part, for perceived failures to adequately follow Registrant’s procedures. Registrant is evaluating its bidding procedures for capital projects as a part of its review of internal controls in preparation for compliance with Section 404 of the Sarbanes-Oxley Act of 2002 and may, based on the results of this review, modify those procedures in order to ensure that the Company’s objectives are being met in a consistent manner.
Regulatory Matters
Rate Regulation
SCW is subject to regulation by the CPUC, which has broad powers with respect to service and facilities, rates, classifications of accounts, valuation of properties, the purchase, disposition and mortgaging of properties necessary or useful in rendering public utility service, the issuance of securities, the granting of certificates of public convenience and necessity as to the extension of services and facilities and various other matters. CCWC is subject to regulation by the ACC.
Rates that SCW and CCWC are authorized to charge are determined by the CPUC and the ACC, respectively, in general rate cases and are derived using rate base, cost of service and cost of capital, as projected for a future test year in California and using an historical test year, as adjusted in Arizona. Rates charged to customers vary according to customer class and rate jurisdiction and are generally set at levels allowing for recovery of prudently incurred costs, including a return on rate base. Rate base generally consists of the original cost of utility plant in service, plus certain other assets, such as working capital and inventory, less accumulated depreciation on utility plant in service, deferred income tax liabilities and certain other deductions.
Neither AWR
andnor ASUS arenotdirectly regulated by the CPUC. The CPUC does, however, regulate certain transactions between SCW and itsnon-regulatedaffiliates. The ACC also regulates certain transactions between CCWC and its affiliates.29
For rate-making purposes, the 22 customer service areas
(CSAs)of SCW are grouped into169 water districts and 1 electricdistrict for ratemaking purposes.district. Water rates vary among the169 water ratemaking districts due to differences in operating conditions and costs. SCW monitors operations on a regional basis in each of these districts so that applications for rate changes may be filed, when warranted. Under theCPUC'sCPUC’s practices, rates may be increased by three methods: (i) general rate case increases(GRC's)(GRC’s), (ii) offsets for certain expense increases including but not limited to supply cost offset and balancing account amortization, and (iii) advice letter filings related to certain plantadditions. GRC'sadditions and other operating cost increases. GRC’s are typically for three-year periods, which include step increases for the second and third year. Rates are based on a forecast of expenses and capital costs.GRC'sGRC’s have a typical regulatory lag of one year. Offset rate increases and advice letter filings typically have a two to four month regulatory lag.Changes in Rates
The following table lists information on estimated annual rate changes for SCW as approved by the CPUC during
1999, 19982003, 2002 and1997.2001.
($ in 000's) Supply Balancing General Cost Account and Step Advice Year Offset Amortization Increases Letters Total - ------------ ---------- ------------ ----------- ---------- ----------1999 $23 $1,349 $15,175 $657 $17,204 1998 $786 ($2,852) $3,590 $713 $2,237 1997 $183 $64 $1,332 ($126) $1,453
($ in 000’s) Supply Balancing General Cost Account and Step Advice Year Offset Amortization Increases Letters Total 2003 — $ 689 $ 219 $ 6,263 7,171 2002 — (1,926 ) 322 6,029 4,425 2001 1,364 4,422 6,943 595 13,324 New water rates with an annual increase of approximately $2.5 million for
sixseven ratemaking districts in SCW’s Region I and step increases ofSCW's customer service areas and recoveryapproximately $1.7 million for SCW’s Region III were effective in January 2001. An attrition increase ofcosts associated with SCW's general office functionsapproximately $2.8 million for Region II was in effect from February 2001. Step increases of approximately $321,600 for four of seven ratemaking districts in SCW’s Region I were implemented in January1999. Step2002.On January 16, 2003, the CPUC approved rate increases of approximately $2.7 million annually, effective January 22, 2003, in SCW’s Metropolitan district to recover costs associated with an increase in Region II rate base due to SCW’s 2002 infrastructure replacement program and, additionally, to recover general increases in operating expenses. On January 31, 2003, the CPUC also approved SCW’s Advice Letter filed for the 2003 infrastructure replacement program with rate increases of $3.5 million annually effective February 4, 2003.
In March 2001, the CPUC approved SCW’s Advice Letters to recover increased costs of purchased power by $761,351 incurred to pump water for its water customers included in base water rates for
Arden-Cordova, Bay Point and Los Osos CSAs were also effective in January, 1999. Applicationseach of its ratemaking districts. In April 2001, SCW filed additional Advice Letters by ratemaking areas to increase water rates by approximately $2.3 million company-wide to recover additional electric base rate increases, authorized by the CPUC for the Southern California Edison Company and the Pacific Gas and Electric Company. The CPUC approved in the fourth quarter of 2001 increases of approximately $672,900 in base water rates. The remaining Advice Letters filed by SCW to recover increased power costs used for pumping were rejected by the CPUC due to the change in procedures for collections of water supply costs on November 29, 2001. See the section entitled “Accounting for Supply Costs” included in Part II, Item 7 in Management’s Discussion and Analysis of Financial Condition and Results of Operation.In October 2002, SCW filed an application to increase water rates in the customer service areas that comprise Region III. SCW also filed a concurrent application requesting a rate increase applicable to SCW’s entire customer base to recover costs associated with the general office functions of SCW. On March 16, 2004, the CPUC issued its decision, under which (i) the new water rates will generate an initial annual increase in revenues of approximately $8.9 million, (ii) SCW will file advice letters for
fourrate increases for certain capital projects upon completion, (iii) a special condition surcharge in rates is approved to amortize the waterratemaking districtsquality OII memorandum account balance, and (iv) SCW is authorized to establish a memorandum account to accumulate costs to comply with certain contamination remediation requirements. Based on the decision, SCW reversed $890,000 OII reserve and $1.0 million water quality related reserves into income during the fourth quarter of 2003.30
In 1994, SCW entered a contract to lease, to the City of Folsom, 5,000 acre-feet per year of water rights to the American River and has included all associated revenues in
SCW'sa non-operating income account. The issue was raised by the ORA in the Region IIIinproceeding. In a decision issued on March1999. A draft decision has been issued by the Administrative Law Judge assigned to this matter that supports the settlement on all issues reached between SCW and16, the CPUCStaff.determined that SCWhasfailed to seek the CPUC’s approval to effectuate the lease and is to pay a net fine of $180,000. The decision also orders SCW to refund 70 percent of the total amount of lease revenues since 1994, plus interest, to customers. Pursuant to the order, SCW recorded $6.2 million as a regulatory liability with a corresponding charge against income (less taxes) during the fourth quarter of 2003. Management disagrees with the CPUC’s decision and intends to appeal the decision in which it will vigorously defend its position.As of December 31, 2003, SCW had accrued approximately $22.7 million in under-collected purchased power costs included in the electric balancing account. In 2001, the CPUC approved two Advice Letters which allow SCW to collect $11.1 million in aggregate over five years, equivalent to 2.2¢ per kilowatt hour, for recovery of its under-collection in the electric balancing account.
On August 17, 2001, SCW filed an application with the CPUC seeking recovery of an average cost of $87 per megawatt hour (MWh) for electric energy purchased pursuant to
combine tariff schedulespower purchase contracts with Mirant Marketing and PWCC. On July 17, 2002, CPUC approved a settlement agreement reached among SCW, all intervening parties and the Office of Ratepayer Advocates (ORA). The authorization permits SCW to recover $77 per MWh of purchased power costs through rates. SCW is allowed to include its actual purchased power costs up to an average annual weighted cost of $77 per MWh each year, through August 2011, in its balancing account. To the extent SCW’s actual average annual weighted cost for purchased power is less than $77 per MWh, the differential would offset amounts included in the electric supply balancing account. Conversely, to the extent that actual average annual weighted costs for power purchased exceed the $77 per MWh amount, SCW would not be able to include these amounts in its balancing account and such amounts would be expensed against income.The CPUC settlement also extended the previously approved surcharges of 2.2¢ per kilowatt hour for an additional five years through August of 2011 to allow SCW an opportunity to collect amounts remaining in its electric cost balancing account. SCW anticipates that electricity sales will be sufficient to enable SCW to fully recover the under-collection in its balancing account during this period.
SCW previously established approximately $7.9 million in reserves against potential non-recovery of electric power costs. In 2002, $1.7 million in the balancing accounts was written off against the reserve based on the settlement with the CPUC as previously discussed. In September 2002, SCW entered into
regionalvarious agreements with PWCC, which enable SCW to purchase energy at a lower cost. As a result, the remaining reserve of $6.5 million was reversed into income in 2002.The CPUC settlement requires SCW to pursue its complaint filed with FERC in which SCW has requested FERC to reduce the prices in its power purchase contract with Mirant Marketing to a just and reasonable price. If FERC rules a price reduction, SCW is required, based on the settlement, to file an Advice Letter to notify the CPUC within 30 days of the ruling. On December 19, 2002, the FERC Administrative Law Judge issued an initial decision denying SCW’s request to reduce the charges under the contract. SCW has appealed the initial decision which results in the complaint being reviewed by all member commissioners at the FERC. On November 10, 2003, the FERC denied SCW’s rehearing request. SCW is currently reviewing its options with respect to the FERC’s latest order denying rehearing and is determining if it will appeal the decision in Federal Court. On July 14, 2003, Mirant Marketing announced that, to facilitate its financial restructuring, it filed voluntary petitions for reorganization under Chapter 11 of the U.S. Bankruptcy Code. At this time, Registrant expects no interruption in the delivery of electric energy under the Mirant Marketing contract.
See the section entitled “Electric Energy Situation in California” included in Part II, Item 7 in Management’s Discussion and Analysis of Financial Condition and Results of Operation.
31
Pending Rate Changes
On July 10, 2003, the CPUC approved the Certificate of Public Convenience and Necessity (CPCN) filed by SCW in March 2002 seeking authorization to construct an 8.4 MW natural gas-fueled generation facility on a portion of its property in the City of Big Bear Lake. The capital cost of the generating facility is estimated to be approximately $13 million. The CPUC’s order authorizes construction and enables SCW to file a rate application to generate an annual revenue increase of about $2.4 million. SCW will file for increased rates
forusing a special filing called a “Major Adjustment Clause” or “MAC” filing that should result in at least 75% of the revenue requirement related to this facility being included in rates. The remainder will be subject to recovery in a general rate case filing.Registrant filed an application to increase water rates in the Region II customer service areas
that make up SCW's Region III.on September 11, 2003, which was accepted by the CPUC on October 6, 2003. The new water rates in this filing, if approved, would generate an initial annual increase in revenues of $15.4 million. A decision is not expected until the third quarter of 2004. Due to delays in the CPUC’s review of this GRC application which have delayed the processing of the application, SCW sought authority for interim rate relief by motion filed on December 23, 2003. The Administrative Law Judgeassignedat the CPUC in a ruling issued in February 2004 granted SCW’s motion for interim rate relief and ordered SCW tothis matter hasfile an advice letter implementing interim rates for Region II, commencing January 1, 2004, subject to refund. The interim rates would generate additional approximately $1.4 million annual revenues. Management expects no refunds will be made.On October 30, 2003, SCW also filed an abbreviated application to the CPUC to request an inflationary increase in three of the Region I customer services areas, totaling $388,500 annually. As part of the Region I filing, SCW requested a long-term amortization of the balance of costs included in the Aerojet litigation memorandum account, net of any reimbursement amount. For more information, see the section entitled “Other Water Quality Litigations” included in Part I, Item 3 in Legal Proceedings.
An Interim Decision issued
a draft decision that supports SCW's application. A final decision fromby the CPUC onboth issuesMay 8, 2003 approved a settlement between the City of Santa Monica (City) and SCW. The settlement agreement conveyed SCW water rights to the City and relieved SCW from its participation in a number of pending lawsuits related to the Charnock Groundwater Basin. A Proposed Decision (PD) issued on December 19, 2003 proposing the ratemaking treatment of the settlement proceeds and the treatment of contamination payments made to SCW by Potentially Responsible Parties (PRPs) since 1998. In summary, the PD directs SCW to (i) invest all net settlement proceeds received from the City in infrastructure improvements within eight years, and (ii) refund to ratepayers the net proceeds received from PRPs, for which $3.5 million was recorded as a liability in December 2003. SCW will book the net settlement proceeds from the City as a gain, if the PD isanticipatedapproved and the settlement agreement with the City of Santa Monica is finalized. For more information, see the section entitled “Environmental Matters” included in Part II, Item 7 in Management’s Discussion and Analysis of Financial Condition and Results of Operation.In 1993, the
second quarterCPUC disallowed $1.6 million of2000. GRC step increasecosts incurred in construction of a water treatment facility in SCW’s Clearlake customer service area and Registrant wrote off the disallowed amount at that time. Based on new water quality standards, in 2000, SCW re-applied to the CPUC forMetropolitan CSA and General Office Allocation step increases for Arden-Cordova, Bay Point, Simi Valley and Santa Maria CSAs were effective beginning January, 2000. Attrition increases for Arden-Cordova and Bay Point CSAs were alsoinclusion of the disallowed amount ineffect beginning January, 2000.rate base. ANotice of Intent to increase water rates by approximately $5.8 million for ratemaking districts in SCW's Region I as well as to combine those tariff schedules into regional rates were filed in February 2000. The application will be submitted by end ofdraft decision issued on March2000. The new rates, if authorized in total or in part30, 2001 by the CPUC would have allowed SCW to include $500,000 of the $1.6 million in the regulated rate base. An alternate draft decision issued by one of the CPUC Commissioners proposed to deny the relief sought by SCW in its application. An Administrative Law Judge subsequently reopened the proceeding in August 2001 requiring additional information. Registrant cannot predict when the final order will beeffective January 1, 2001. 1215 An advice letter was filed withissued, nor can it give assurance that the CPUC will ultimately allow recovery of all or any of the remaining costs through rates.Other Regulatory Matters
On November 29, 2001, the CPUC adopted an Order Instituting Rulemaking (OIR) to (i) evaluate existing rate making practices and policies, (ii) determine whether new procedures or policies for processing offset rate increases and balancing accounts should be made and (iii) determine whether the new memorandum account procedures adopted on November 29, 2001 should be made permanent.
Pursuant to a resolution issued by the CPUC on December 17, 2002, SCW filed advice letters on March
1, 200017, 2003 requesting recovery of $2.2 million under-collections remaining in the balancing accounts for water supply costs incurred prior to November 29, 2001. On June 19, 2003, the CPUC authorized increases in rates in total of $2.1 million, effective June 24, 2003, for SCW to recover the pre-November 29, 2001 balances.32
In a decision issued on June 19, 2003, the CPUC concluded that (i) if a utility is within its rate case cycle and does not earn over its authorized rate of return, the utility shall recover its costs in the memorandum supply cost account subject to reasonableness review by the CPUC; (ii) if a utility is either within or outside of its rate case cycle and earns over the authorized return, the utility’s recovery of expenses from the memorandum supply cost account will be reduced by the amount exceeding the authorized rate of return; and (iii) a utility is required to seek review of under and over collections by filing an advice letter annually by March 31. Pursuant to the resolution, SCW filed advice letters, on September 12, 2003, seeking recovery for under-collected balance of
capital expenditures associated with Y2K readiness, not already$2.6 million for the period of November 29, 2001 through December 31, 2002. The CPUC has rejected all water utilities’ filings, including SCW’s, and conducted workshops for more discussion and directions. SCW is in the process of preparing the filings. For more information, see the section entitled “Accounting for Supply Costs” included inRegistrant's water rates. See Note 13Part II, Item 7 in Management’s Discussion and Analysis of Financial Condition and Results of Operation.CCWC is planning to file its next rate case with the
Notes to Financial Statements. On April 22, 1999, the CPUC issued an order denying SCW's application seeking approval ofArizona Corporation Commission in 2004. Currently, there are no active regulatory proceedings affecting CCWC or itsrecovery through rates of costs associated with its participation in the Coastal Aqueduct Extension of the State Water Project (SWP). SCW's participation in the SWP commits it to a 40-year entitlement. SCW's investment of approximately $9.5 million in SWP is currently included in Other Property and Investments. The remaining balance of the related liability of approximately $7 million is recorded as other long-term debt. SCW intends to recover its investment in SWP through contributions from developers on a per-lot or other basis, or the sale of its 500 acre-foot entitlement in SWP. See Note 8 to the Notes to Financial Statements. ENVIRONMENTAL MATTERSoperations.Environmental Matters
1996 Amendments to Federal Safe Drinking Water Act
On August 6, 1996, amendments (the 1996 SDWA amendments) to the Safe Drinking Water Act (the SDWA) were signed into law.The
1996 SDWA revised the 1986 amendments to the SDWA with a new process for selecting and regulating contaminants. The U. S.U.S. Environmental Protection Agency (EPA) can only regulate contaminants that may have adverse health effects, are known or likely to occur at levels of public health concern, and the regulation of which will provide"aa meaningful opportunity for health risk reduction."The EPA has published a list of contaminants for possible regulation and must update that list every five years. In addition, every five years, the EPA must select at least five contaminants on that list and determine whether to regulate them.The newThis law allows the EPA to bypass the selection process and adopt interim regulations for contaminants in order to address urgent health threats.Current regulations, however, remain in place and are not subject to the new standard-setting provisions.TheDOHS,California Department of Health Services (DOHS), acting on behalf of the EPA, administers theEPA'sEPA’s program in California. The1996 SDWA amendments allow theArizona Department of Environmental Quality (ADEQ) administers EPA’s program in Arizona.The EPA
for the first time tomay base primary drinking water regulations on risk assessment and cost/benefit considerations and on minimizing overall risk. The EPA must base regulations on best available, peer-reviewed science and data from best available methods. For proposed regulations that involve the setting of maximum contaminant levels(MCL's)(MCL’s), the EPA must use, and seek public comment on, an analysis of quantifiable and non-quantifiable risk-reduction benefits andcostcosts for each such MCL.SCW and CCWC currently
tests itstest their wells and water systems according to requirements listed in theSDWA.Safe Drinking Water Act (“SDWA”). Water from wells found to contain levels of contaminants above the establishedMCLsMCL’s is treated to reduce contaminants to acceptable levels before it is delivered to customers. If treatment is not possible, the wells are shut down. Since the SDWA became effective, SCWhasand CCWC have experienced increased operating costs for testing to determine the levels, if any, of the constituents inSCW'stheir sources of supply and additional expense to lower the level of any contaminants in order to meet the MCL standards. Such costs and the costs of controlling any other contaminants may cause SCW and/or CCWC to experience additional capital costs as well as increased operating costs.Registrant is currently unable to predict the ultimate impact that the 1996 SDWA amendments might have on its financial position or its results of operation.The CPUC and ACC ratemakingprocess providesprocesses provide SCW and CCWC with the opportunity to recover prudently incurred capital and operating costs associated with water quality. Management believes that such incurred and expected future costswillshould be authorized for recovery by theCPUC. 1316 ProposedCPUC and ACC, as applicable.Enhanced Surface Water Treatment Rules
The EPA has adopted the Enhanced Surface Water Treatment Rule
On July 29, 1994, the EPA proposed an Enhanced Surface Water Treatment Rule(ESWTR), whichwould requirerequired increased surface-water treatment to decrease the risk of microbial contamination.The EPA has proposed several versions of the ESWTR for promulgation. The version selected for promulgation will be determined based on data collected by certain water suppliers and forwarded to the EPA pursuant to EPA's Information Collection Rule, which requires such water suppliers to monitor microbial and other contaminants in their water supplies and to conduct certain tests in respect of such contaminants. The EPA has adopted an Interim ESWTR applicable only to systems serving greater than 10,000 persons. The long-term ESWTR, in any of the forms currently proposed, wouldThese rules apply to each ofSCW'sSCW’s five surface water treatment plants and CCWC’s surface water treatment plant. Registrant anticipates that all plants will achieve compliance within the three-year to five-year time frames identified by EPA. Registrant isexpectedrequired to bepromulgatedin compliance byNovember 2000. However, because itJune 1, 2006. SCW has initiated phased construction of a new treatment plant in the Calipatria-Niland customer service area (see further discussion below underRegulation of Disinfectant/Disinfection By-Products) to bring that facility into compliance. Once this project isimpossible to predictcompleted, all theversion of the ESWTR that willsurface water plants in SCW and CCWC should bepromulgated, Registrant is unable to predict what additional costs, if any, will be incurred to complyin compliance withthe ESWTR.these rules.33
Regulation of Disinfection/Disinfection By-Products
Registrant isSCW and CCWC are also subject to
the newregulations concerning disinfection/disinfection by-products(DBP's),(DBP’s). Stage I ofwhichthe regulationswerewas effective in November 1998 with full compliance required for systems serving 10,000 or more persons by2001.2002 and for systems serving fewer than 10,000 persons by 2004. Stage I requires reduction oftri-halomethanetrihalomethane contaminants from 100 micrograms per liter to 80 micrograms per liter.Two of SCW's systems are immediately impacted by this rule.SCW has already implemented modifications to the treatment process in its Bay Point and Cordovasystems. Itsystems to achieve compliance and the Calipatria plant isanticipated that both systemsundergoing treatment modifications, which willbealso address the requirements under the ESWTR, infull complianceorder to comply with the DBP’s by2001. The EPA must adopt Stage II rules pertaining to DBPs, according to a negotiated schedule by 2000.2004.The EPA is not allowed to use the
newcost/benefit analysis provided for in the 1996 SDWA amendments for establishing the Stage II rules applicable toDBPsDBP’s but may utilize the regulatory negotiating process provided for in the 1996 SDWA amendments to develop the Stage II rule. The final rule is not expectedby 2002.until later this year.The Stage 2 Disinfectants/Disinfection By-Products Rule (DBPR) and the Long-Term 2 Enhanced Surface Water Treatment Rule (LT2ESWTR)
The LT2ESWTR proposal was published in theFederal Registeron August 11, 2003, and the Stage 2 DBPR was published shortly thereafter on August 18. These proposed Rules are very complex and EPA has asked for comments on hundreds of technical issues. EPA will likely publish the final rules in early to mid-2005, since the close of public comments was in January 2004, and it typically takes EPA 12-18 months to finalize rules after the close of the comment period. Registrant is currently waiting for the EPA to finalize these proposed rules to determine the impact.
Ground Water Rule
On May 10, 2000, the EPA published the proposed Ground Water Rule
By Spring 2000,(GWR), which establishes multiple barriers to protect against bacteria and viruses in drinking water systems that use ground water. The proposed rule will apply to all U.S. public water systems that use ground water as a source. The proposed GWR includes system sanitary surveys conducted by theEPA is scheduledstate topropose regulations requiring disinfectionidentify significant deficiencies; hydrogeologic sensitivity assessments for undisinfected systems; source water microbial monitoring by systems that do not disinfect and draw from hydrogeologically sensitive aquifers or have detected fecal indicators within a distribution system; corrective action; and compliance monitoring for systems which disinfect to ensure that they reliably achieve 4-log (99.99%) inactivation or removal ofcertain groundwater systems and provide guidance on determining which systems must provide disinfection facilities. The EPA may utilize the cost/benefit analysis provided in the 1996 SDWA amendments to establish such regulations.viruses. Itiswas anticipated that theregulations will apply to severalGWR would be issued as a final regulation by the end ofSCW's systems using groundwater supplies.2003, but this has been delayed until later this year. While no assurance can be given as to the nature and cost of any additional compliance measures, if any,Registrant doesSCW and CCWC do not believe that such regulations will impose significant compliance costs, sinceSCWthey already currentlyengagesengage in disinfection ofitsthe majority of their groundwater systems.Regulation of Radon and Arsenic
Registrant expects to be subject to new regulations regarding radon and arsenic. It is anticipatedOn October 31, 2001, EPA announced that the
EPA will propose a reductionarsenic standard inthe federal standard on arsenic from 50drinking water would be 10 parts per billion (ppb)to 5 ppb. This proposed arsenic rule is expected to be released in March or April of 2000, with a 60-day comment period. It is anticipated that EPA will propose 5 ppb as the lead regulatory option, but will take comments on 3 ppb and 10 ppb options as well.. Compliance with an MCL of510 ppb will requireRegistrant to implement costly well-headimplementation of wellhead treatment remediessuch as ion exchange or, alternatively,for eight affected wells in SCW’s system and two wells in CCWC’s system. The effective date for utilities topurchase additional and more expensive water supplies alreadycomply with the standard is January 2006. In California, the Office of Environmental Health Hazard Assessment (OEHHA) issued a Public Health Goal for arsenic of 4 parts per trillion incompliance,March 2003 that may result in California adopting a lower MCL forblending with well sources.arsenic.The EPA has proposed new radon regulations following a National Academy of Sciences risk assessment and study of risk-reduction benefits associated with various mitigation measures. The National Academy of Sciences study is in agreement with much of
EPA'sEPA’s original findings but has1417slightly reduced the ingestion risk initially assumed by EPA. EPA established an MCL of 300picoCuriesPico Curies per liter based on the findings and has also established an alternative MCL of 4000picoCuriesPico Curies per liter, based upon potential mitigation measures for overall radon reduction.The final rule will be effective in August, 2000. TheRegistrant is currentlyconducting studieswaiting for the EPA to establish a MCL to determine thebest treatment for affected wells.impact.34
Voluntary Efforts to
ExceedProvide Treated Surface Water Below Minimum Surface Water TreatmentStandardsRequirementsSCW is a voluntary member of the
EPA's "PartnershipEPA’s Partnership for SafeWater",Water, a national program designed to further protect the public from diseases caused by cryptosporidium and other microscopic organisms. As a volunteer in the program, SCW commits toexceed current regulationstreat surface water to levels much lower than the minimum operating requirements governing surface water treatment, optimize surface water treatment plant operations and seeks toensure thathave its surface water treatment facilitiesare performingperform as efficiently as possible.Unregulated Contaminants Monitoring Rule
EPA has revised the Unregulated Contaminant Monitoring Rule (UCMR). The data generated by the UCMR will be used to evaluate and prioritize contaminants on the Drinking Water Contaminant Candidate List, a list of contaminants EPA is considering for possible new drinking water standards. This data will help to ensure that future decisions on drinking water standards are based on sound science.
A tiered approach will be utilized with the three monitoring lists to provide the maximum capability to monitor up to the statutory limit of no more than 30 contaminants in any 5-year monitoring cycle. Therefore, as List 3 contaminants are found to occur in public water systems, they may move up to List 2, and likewise, List 2 contaminants may move up to List 1, in 2004, when the UCMR is revised again. The law requires that EPA publish a new contaminant-monitoring list every 5 years.When the EPA adds contaminants to their list, they will also include a compliance date. Registrant will evaluate the impact and necessary actions as additions are made to the contaminant lists.
Fluoridation of Water Supplies
RegistrantSCW is
subjectrequired toState of California Assembly Bill 733 which requires fluoridation offluoridate water supplies for public water systems serving more than 10,000 serviceconnections. Although the bill requires affected systems to install treatment facilities only when publicconnections if funds have been made available to cover capital and operatingcosts, the bill requires thecosts. The CPUC is required to authorize cost recovery through rates shouldpublicfunds for the operation ofthefluoridation facilities, once installed, become unavailable in futureyears. Matters Relatingyears.Currently, funds have been made available toArden-Cordova Systempublic agencies only. SCW has not been offered any funding and has not installed any fluoridation facilities.Perchlorate Action Level Activities
In January
1997, SCW was notified that ammonium perchlorate in amounts above2002, DOHS reduced thestate-determinedaction levelhad been detected in three of its 27 wells serving its Arden-Cordova system. Aerojet-General Corp. has, in the past, used ammonium perchlorate in their processing as an oxidizer of rocket fuels. SCW took the three wells detected with ammonium perchlorate out of service at that time. Although neither the EPA nor the DOHS has establishedfrom 18 ppb to adrinking water standard for ammonium perchlorate, DOHS has established an actionlevel of18 parts per billion (ppb) which required4 ppb, based upon new reference dose for health risk information from EPA. California has a law requiring DOHS to establish an MCL for perchlorate by January 1, 2004. This has been delayed due to the lack of a final Public Health Goal. SCWto notify customershas removed eight wells from service in itsArden-Cordova customer service area of detection of ammoniumRancho Cordova system and six additional wells in various other systems since they contained perchlorate in amounts in excess of this reduced actionlevel. In April, 1997,level of 4 ppb. On December 6, 2002, the OEHHA published a revised draft perchlorate Public Health Goal (PHG) of 2 to 6 ppb. This is the first step in the establishment of an MCL in California. The PHG of 6 ppb was adopted in the first quarter of 2004. SCWfound ammonium perchlorate in three additional wells and, at that time, removed those wells from service until it was determined that the levels were below the state-determined action level. Those wells were returnedis continuing toservice. SCWperiodicallymonitors thesemonitor all of its wells to determine that levels of perchlorate are below the action level currently in effect. Perchlorate is known to be used in oxidizing rocket fuels.Nitrosodimethylamine (NDMA) Action Level
In February
1998, SCW was informed that nitrosodimethylamine (NDMA) had been detected in amounts in excess2002, DOHS increased the action level from 2 parts per trillion (ppt) to 10 ppt. NDMA is an additional by-product from the production and use ofthe EPA reference dosage for health risks inrocket fuels.Matters Relating to SCW’s Arden-Cordova Water System
In SCW’s Rancho Cordova system, four
of itswellsin its Arden-Cordova system. Each of the wells has been removed from service. Another well was alsohave been removed from servicein end of September, 1999and destroyed due to contamination from perchlorate. The supply has been replaced for three of these wells. An additional three wells are currently out of service due to perchlorate levels above thecontamination.reduced action level of 4 ppb, and two wells are out of service due to detectable levels of NDMA above the action level. SCW continues to monitor all of its active groundwater wells in the Rancho Cordova system for perchlorate and NDMA. Aerojet-General Corp. (Aerojet) has, in the past, used ammonium perchlorate in oxidizing rocket fuels. NDMA is an additional by-product from the production of rocketfuelfuels and it is believed that such contamination is also related to the activities of Aerojet. SCW has filed suit against Aerojet for contamination of SCW’s ground water supply in its Rancho Cordova system.35
On October 10, 2003 Registrant entered into a confidential memorandum of understanding (MOU) with the Aerojet-General
Corp. Aerojet-General Corp.subsidiary of GenCorp, Inc. for the settlement of legal actions brought by SCW. The MOU sets forth the present financial terms and the structure of a settlement to cover all SCW’s costs incurred resulting from the contamination. The MOU and the settlement embodied therein was found to be binding by the Sacramento Superior Court on January 18, 2004. Further documentation incorporating the terms of the MOU is presently underway. However, documentation is not complete and management is presently unable to predict when a comprehensive set of settlement documents will be completed.To date, Aerojet has reimbursed SCW for constructing a pipeline to interconnect with the City of Folsom water system to provide an alternative
source(s)source of water supply inSCW's Arden-CordovaSCW’s Rancho-Cordova customer service area and has reimbursed SCW for a portion of the costs associated with the drilling and equipping oftwonew wells. Aerojet had, prior to the MOU, reimbursed SCWand Aerojet-General Corp. are in negotiations on other matters related to procedures to address cleanup$4.3 million of thecontaminated wells,approximately $20 million in capital costsassociated withSCW has incurred, and $171,000 for additional water supply costs. Based on thecleanup, increased costsfinancial terms in the MOU, SCW established a receivable from Aerojet in an amount ofpurchased water as compared to pumped sources and costs associated with developing new sources$16.7 million at the end ofgroundwater supply. SCW and Aerojet-General Corp. are attempting to negotiate an agreement on these matters. As2003, ofDecember 31, 1999, Aerojet-General Corp has reimbursed Registrant $4.5 million.which $8.7 million was received in early 2004. The remainder of the costs is subject to furtherreimbursement, including interest. The reimbursementsettlement documentation. Reimbursements received fromAerojet-General Corp. reduces SCW'sAerojet have been applied directly to reduce SCW’s costs of utility plant andcosts ofpurchased water.1518 On October 25, 1999, SCW filed a lawsuit againstManagement believes these costs are recoverable either through rates or theCalifornia Regionalsettlement agreement with Aerojet. For further information regarding litigation related to contamination of ground water in Sacramento County, see the section entitled “Other Water QualityControl Board (CRWQCB) alleging that the CRWQCB has willfully allowed portions of the Sacramento County Groundwater Basin to be injected with chemical pollution that is destroying the underground water supplyLitigation” included inSCW's Rancho Cordova customer service area. In a separate case, also filed on October 25, 1999, SCW sued Aerojet General Corp. for causing the contamination. Registrant is unable to predict what actions, if any, the CRWQCB or Aerojet General Corp. will take in response to the lawsuits.Part I, Item 3, Legal Proceedings.Matters Relating to SCW’s Culver City Water System
The compound, methyl tertiary butyl ether (MTBE), an oxygenate used in reformulated fuels, has been detected in the Charnock Basin, located in the
cityvicinity of the City of Santa Monica and withinSCW'sSCW’s Culver City customer service area.MTBE is an oxygenate used in reformulated fuels.At the request of the Regional Water Quality Control Board, the City of Santa Monica and the California Environmental Protection Agency, SCW removed two of its wells in the Culver City water system from service in October 1996 to help in efforts to avoid further spread of the MTBE contamination plume. Neither of these wells has been found to be contaminated with MTBE. SCW is purchasing water from theMWDMetropolitan Water District of Southern California (MWD) at an increased cost to replace the water supply formerly pumped from the two wells removed from service.On September 22, 1999, the U.S. EPA and the Los Angeles Regional Water Quality Control Board ordered Shell Oil Company, Shell Oil Products Company,
andEquilon Enterprises LLC and others to provide replacement drinking water to both SCW and the City of Santa Monica due to MTBE contamination in the Charnock Basin. The EPA has ordered Shell Oil and others to reimburse SCW for water replacement costs. In March 2002, SCW reached a settlement agreement with the City of Santa Monica, in which SCW assigned its rights against all the potentially responsible parties, who stored, transported and dispensed gasoline containing methyl tertiary butyl ether (MTBE) in underground storage tanks, pipelines or other related infrastructure, and its water rights in the Charnock Basin to the City of Santa Monica and Santa Monica took over the prosecution against the potentially responsible parties in exchange for an assignment payment. On May 8, 2003, the CPUC issued a decision approving the settlement agreement. Pursuant to the resolution, SCW has subsequently filed a report that sets forth specific details as to SCW’s plans to reinvest the net proceeds from the settlement agreement with the City of Santa Monica. A Proposed Decision (PD) issued on December 19, 2003 proposes the ratemaking treatment of theCharnock Sub-Basin drinking water.settlement proceeds and the treatment of contamination payments made to SCW by Potentially Responsible Parties (PRPs) since 1998. In summary, the PD directs SCW to (i) invest all net settlement proceeds received from the City in infrastructure improvements within eight years, and (ii) refund to ratepayers the net proceeds received from PRPs, for which $3.5 million was recorded as a liability in December 2003. We will book the net settlement proceeds from the City as a gain, if the PD is approved and settlement agreement with the City of Santa Monica is finalized. For more information, see the section entitled “Regulatory Matters” included in Part II, Item 7 in Management’s Discussion and Analysis of Financial Condition and Results of Operation.Matters Relating to SCW’s Yorba Linda Water System
The
agenciescompound MTBE has been detected in three wells serving SCW’s Yorba Linda water system. Two of the wells arecontinuingcurrently inactive, and toinvestigatedate thecausesthird well has not shown MTBE above the DOHS secondary standard ofMTBE pollution5.0 ppb. SCW has constructed an interconnection with the Metropolitan Water District of Southern California to provide for the needed supply for this system in the event the third well experiences levels of detection in excess of the DOHS standard.36
SCW has met with the Regional Water Quality Control Board, the Orange County Water District, (OCWD), the City of Anaheim, the DOHS and
intend to ensure that allthree potentially responsible partiescontribute(PRPs) to define the extent of the MTBE contamination plume and assess the contribution from the PRP’s. The PRP’s have voluntarily initiated a work plan for regional investigation. While there have not been significant disruptions to the water supply in Yorba Linda at this point in time, no assurances can be given that MTBE contamination will not increase in the future. In December 2003, a settlement was reached between SCW and the PRPs. Under the settlement agreement, the PRPs are to pay SCW (i) $581,250 for reimbursement of costs related to the issue, and (ii) up to $260,000 per year for five years for incremental supply costs should the MTBE level in the third well exceed the DOHS action level. SCW received payment of the $581,250 in January 2004.Matters Relating to SCW’s Los Osos Water System
The compound MTBE has been detected in a well serving SCW’s Los Osos water system. For some time SCW has been working with the Regional Water Quality Control Board as well as the owner of a service station. Although the owner of the service station has attempted remediation with funds provided through the California Underground Storage Tank Fund (“CUSTF”), it appears there will be insufficient funds from the CUSTF to complete remediation sufficient to return the well to service. In order to prevent the running of the statute of limitations, on August 12, 2002 SCW filed suit in the Superior Court of the State of California for the County of San Luis Obispo against the operators and owners of the service station facility, and Chevron USA Products, Inc., the supplier. A settlement with Chevron has been reached and fully executed. The impacted well may need to be removed permanently from service and the settlement payment from Chevron is expected to afford SCW sufficient funds to commence site development and construction of a replacement well.
Matters Relating to SCW’s San Gabriel Water Systems
Perchlorate and/or Volatile Organic Compounds (VOC) have been detected in five wells servicing SCW’s San Gabriel System. SCW filed suit, along with two other affected water purveyors and the San Gabriel Basin Water Quality Authority (WQA), in federal court against some of those responsible for the contamination. Some of the other potential defendants settled with SCW, other water purveyors and the WQA on VOC related issues prior to the filing of the lawsuit resulting in reimbursement to SCW of the $1 million in capital cost of VOC treatment facilities and contribution of approximately $380,000 towards future operating and maintenance (O&M) costs of the facilities.
In response to the filing of the Federal lawsuit, the Potentially Responsible Party (PRP) defendants filed motions to dismiss the suit or strike certain portions of the suit. Following a hearing on these motions on March 31, 2003, the judge issued a ruling on April 1, 2003 granting in part and denying in part the defendant’s motions. A key ruling of the court was that the water purveyors, including the Registrant, by virtue of their ownership of wells contaminated with hazardous chemicals are themselves PRPs under the Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA). Registrant has, pursuant to permission of the court, amended its
clean up.suit to claim certain affirmative defenses as an “innocent” party under CERCLA. Registrant is presently unable to predict the outcome of this ruling on its ability to fully recover from theEPA's enforcement efforts. PursuantPRPs future costs associated with the treatment of these wells.On August 29, 2003, the US Environmental Protection Agency (EPA) issued Unilateral Administrative Orders (UAO) against 41 parties deemed responsible for polluting the groundwater in that portion of the San Gabriel Valley from which SCW’s two impacted wells draw water. SCW was not named as a party to
an agreementthe UAO. The UAO requires that these parties remediate the contamination. As a result of the issuance of the UAO, these parties have begun settlement discussions regarding the Federal lawsuits with SCW, the other two affected water purveyors, WQA and, separately, EPA. Registrant is presently unable to predict the ultimate outcome of these settlement discussions.Three other wells serving customers in
December, 1998, two of theSCW’s San Gabriel customer service area are also impacted by VOC contamination. A settlement with several potentially responsible parties(the Participants) have reimbursed SCW's legal and consulting costs related to this matter and for increased costs incurredtogether with federal funds administered bySCWWQA resulted inpurchasing replacement water. However, a noticereimbursement oftermination from the "Participants" to the settlement agreement and a conditional termination from one100% of theresponsible parties was received$1.1 million inOctober, 1999. SCWcapital costs, $205,000 of past operations andsuch parties are currentlymaintenance costs and 100% of future operations and maintenance costs for a period of up to 30 years for VOC treatment facilities at these wells.37
Bark Beetle Infestation in
the process of negotiation. No assurances can be given that current or future negotiations will result in complete restoration of SCW's water rights or that continued reimbursement of SCW's costs will be forthcoming. Bear Valley Electric SCW has been, in conjunction with the Southern California Edison unit of Edison International, planning to upgrade transmission facilities to 115kv (the 115kv Project) in order to meet increased energy and demand requirements. The 115kv Project is subject to an environmental impact report (EIR) and delays in approval of the EIR may impact service in SCW'sSCW’s Bear Valley Electric Servicecustomer service area.AreaIn a Proclamation issued on March 7, 2003 former Governor Gray Davis declared a State of Emergency with respect to a severe fire risk caused by dead and dying trees plagued by drought and a major bark beetle infestation in the counties of Riverside, San Bernardino, and San Diego of the State of California. The threat is continuing and shows no sign of abating. On April 3, 2003, the CPUC issued an order requiring Southern California Edison Company, San Diego Gas & Electric Company and Bear Valley Electric to take all reasonable and necessary actions to mitigate the increased fire hazard by removing dead, dying or diseased trees from falling or contacting distribution and transmission lines within their rights of way and to ensure compliance with existing vegetation clearance statutes and regulations. The utilities, including Bear Valley Electric, are authorized to make annual advice letter filings requesting recovery of the costs of removal and mitigation. SCW has
however, takendetermined the scope and magnitude of the bark beetle infestation in its Bear Valley Electric service territory to date and has formulated a course of action to mitigate the fire potential in its rights-of-way. Estimated costs of dead tree removal totals $620,000 based on experiences with othermeasures, including some measuresutility vegetation management programs and current information gathered and assessed for the Big Bear Lake area. These costs represent only the cost of addressing the problem to date. If the drought continues, the infestation will likely spread and mitigation costs may increase. SCW expects that current and future costs incurred in remediation of Bark Beetle Infestation will beenacted on an emergency basis,recoverable in rates through the annual Advice Letter filings, as the April 2003 order issued by the CPUC contained cost recovery provisions.Security Issues
Since the tragic events of September 11, 2001, water utilities, including Registrant, have been advised to
meet load growthincrease security at key facilities in order to avoid contamination of water supplies andmitigate delaysother disruptions of service. In compliance with“The Public Health Security and Bioterrorism Preparedness Act of 2002” (HR 3448),Registrant has continued to implement measures to increase security, which includes a vulnerability assessment of its large systems. In addition to large system assessments, all systems operated by Registrant were assessed to identify potential areas requiring enhancements. These assessments resulted inapprovala prioritized listing of recommended facility upgrades to enhance the safety of water system operations. Costs associated with capital improvements identified as a result of theEIR. WATER SUPPLYassessment process, of approximately $15 million, have been included in an application filed with the CPUC in October 2002.Water Supply
SCW’s Water Supply
During
1999, Registrant2003, SCW supplied a total of195,886 acre feet85,204,000 CCF ofwater.water, or approximately 175 million gallons per day, on average. Of this amount, approximately58.2%53.2% came from pumped sources and40.2%43.2% was purchased from others, principally the Metropolitan Water District of Southern California (MWD). The remainingamountwas surface water principally supplied by the Bureau of Reclamation (the Bureau) under a no-costcontract.contract and by the Sacramento Municipal Utility District (SMUD), cost of which is reimbursed by Aerojet-General Corp. pursuant to a Memorandum of Understanding. For more information, please see the section entitled “Environmental Matters” included in Part II, Item 7 in Management’s Discussion and Analysis of Financial Condition and Results of Operation. During1998, Registrant2002, SCW supplied179,927 acre feet87,910,000 CCF of water,60.7%55.7% of which came from pumped sources,39.0%41.4% was purchased, and theremainder wasBureau and SMUD suppliedbytheBureau.remainder.The MWD is a water district organized under the laws of the State of California for the purpose of delivering imported water to areas within its jurisdiction. Registrant has
5258 connections to the water distribution facilities of MWD and other municipal water agencies. MWD imports water from two1619principal sources: the Colorado River and theState Water Project (SWP).SWP. Available water supplies from the Colorado River and the SWP have historically been sufficient to meet most ofMWD's requirementsMWD’s requirements.On October 17, 2003 Federal government, State government, and
MWD's supplies from these sources are anticipatedfour Southern California water agency officials, including the MWD, met toremain adequate through 2000. MWD's importsign the Quantification Settlement Agreement (QSA) which divides up each state’s share ofwater fromthe Colorado River. Under the QSA, MWD will have access (as in the past) to Colorado Riveris expectedwater and up todecrease in future years1.6 million acre feet of additional water that the Imperial Irrigation District proposes to conserve and sell to the state. With the signing of this agreement California once again has access to excess Colorado River water for the next 13 years. However for the near term, excess water may not be available due to therequirements ofrecent drought in theCentral Arizona Project. In response,Colorado watershed. MWD hastakenalso publicly stated that it is stepping up a number ofsteps to secure additionalefforts including desalination, conservation, recycling, transfer and storage,capacity andto increaseavailablewatersupplies, by effecting transfers of water rights from other sources. Registrant'ssupplies.38
SCW’s water supply and revenues are significantly affected, both in the short-run and the long run, by changes in meteorological conditions.
New research data releasedThe 2003 water year, October 2002 to September 2003, has been wetter than the 2002 water year. California had 112% of normal precipitation and experienced the third wettest April inJanuary 2000 show80 years of recorded history. The slightly cooler and wetter conditions of thePacific Ocean may be undergoing a dramatic climate shift, known2003 water year have improved our water condition. California snowpack is at 115% of average asthe Pacific Decadal Oscillation, that could alter global weather patterns and perhaps lead Southerncompared to 100% last year. Statewide precipitation has been 89% of normal with northern Californiainto decades of drier than normal weather. The changes signal that the Pacific is shifting to a "cool phase" could last for decades, bring far more rain than usual to the Pacific Northwest and less to Southland. Water sales volumes have been impacted during the last two years by the El Nino/La Nina Southern Oscillation phenomena. El Nino brings substantial rainfall to Southern Californiaover 100% and theopposite, La Nina, often means diminished rainfall. During the '80sColorado River basin at 32%. Reservoir storage is at 100% of average with most northern California levels above 100% and'90s, El Nino increased precipitation as much as 250% of normal for some Southernsouthern CaliforniaWater Company service areas, while La Nina conditions decreased rain levels 50% to 30% of normal. In 1999, after the 1997-1998 El Nino heavy rain season, La Nina moved rainfall to the North and substantially reduced rainfall in SCW's service areas with some systems experiencing less than 32% of normal rainfall. In spite of the anticipated La Nina conditions, the 2000 water year supply outlook remains adequate. As of January 2000, California reservoirs stood at 125% of average. This positive outlook is due to the fact that reservoirs are still holding some of the El Nino surplus and groundwater levels are usually not diminished by a single year of below normal precipitation.around 85%.Although overall groundwater conditions remain at adequate levels, certain of
SCW'sSCW’s groundwater supplies have been affected to varying degrees by various forms of contamination which, in some cases,havehas causedincreasedSCW to increase its reliance on purchased water in its supply mix.BUSINESS SEGMENTS AWR currently has two principal business units:For further information, see Part I, Item 3 in Legal Proceedings.A sudden and unexplained drop in groundwater water supply severely impacted SCW’s Wrightwood customer service area in the third quarter of 2002. In response to this emergency situation, SCW undertook a number of steps to provide water service, including trucking water into the area from nearby sources, bringing a formerly shut down well into service, taking steps to increase capacity at existing wells and
electric distribution utility operations conducted through itsexpediting the drilling and equipping of a new well. SCWsubsidiary, and its non-regulated activities through its ASUS subsidiary. All activities of Registrant currently are geographically located within the State of California, except for one contract for providing customer service and billing services to a utility located in the state of Arizona. SCW is a regulated utility which operates both water and electric systems. On a stand alone basis, AWR has no material assets other than its investments in its subsidiaries. See Note 11 to the Notes to Financial Statements. ACQUISITION OF CHAPARRAL CITY WATER COMPANY On March 10, 2000, Registrant entered into an agreement to acquire the common stock of Chaparral City Water Company, a privately operated water company serving approximately 10,000 customers in the town of Fountain Hills, Arizona and portions of Scottsdale, Arizona for an aggregate value of $31.2 million, including assumption of approximately $12 million in debt. Chaparral City Water Company was purchased from MCO Properties Inc., a wholly-owned subsidiary of MAXXAM Inc. This marks the first acquisition outside of California for Registrant. The sale of Chaparral City Water Company requires notification to the Arizona Corporation Commission and other conditions customary 1720 in transactions of this type. The approval of Registrant's shareholders is not required. It is anticipated that the transaction will close within one year. YEAR 2000 ISSUE Registrant has no Y2K incidents, business disruptions, failures or legal proceedings to report. There were no actual or anticipated effects or changes to Registrant'sexperienced increased operatingtrends or revenue patterns as a result of the transition from December, 1999 to January, 2000. SCW formally announced its 100% Y2K Ready status when it filed its Compliance Report with the CPUC on November 1, 1999. Registrant's general process for addressing the Y2K issue was (i) to inventory all systems that may have a potential Y2K impact, (ii) to determine the materiality of these non-Y2K ready systems, (iii) to replace and test, correct and test, or prepare for the failure of material items that have been determined to be non-Y2K ready, and (iv) to prepare contingency plans, which included, among other things, increased staffing during critical periods, manual back-up for automated systems and the use of portable generators capable of providing power during a black-out. Not all Y2K problems were necessarily expected to surface in early 2000. Registrant does not have, and may never fully have, sufficient information about the Y2K exposure of third parties to adequately predict the risks posed by them to Registrant. If the third parties later discover any Y2K problems that are not remedied, resulting problems could include loss of utility services and disruption of water supplies. Costs incurred to address Y2K issues are estimated to be $7.5 million. Registrant has incurred $4.8 million incosts associated withY2K readinessthe trucking of water of approximately $1.4 million (approximately $1.26 million was incurred in 2002 and $166,000 in the first quarter of 2003). Due to the actions of SCW and conservation efforts of consumers, the situation has stabilized and the water hauling ceased at end of January2000, $4.0 million2003. Management is unable to predict the extent to which additional costs may be incurred or the extent to which additional problems may be encountered. An additional well and filtration equipment has been installed during the past 12 months and, along with voluntary conservation by the community, water supplies have been sustained throughout 2003 even though water levels in Wrightwood are still low. We will be evaluating other alternatives to secure water supply. The cause of the unexplained and sudden drop in groundwater supply has not been identified, but it is partially drought-related.CCWC’s Water Supply
Arizona’s precipitation levels for the 2003 water year from October 2002 to September 2003 were between 70% and 89% of normal with the Colorado River area getting 82%. However this was a marked improvement over 2002 when precipitation was almost nonexistent. Currently, the Colorado River basin continues to experience drought conditions with precipitation at 32% of normal. Lake Powell and Lake Mead storage levels are currently at 68% of average. So far this water year inflow to Lake Powell has been 1,366,200 acre feet with outflow at 1,254,500 acre feet which is 72% of average. The April-July inflow to Lake Powell is forecast to be 6,800,000 acre feet, which is 86% of normal. Snowpack above Lake Powell is 95% of average.
The Arizona Water Banking Authority (AWBA) was created to store Arizona’s unused Colorado River water entitlement in
capital investments.western, central and southern Arizona to develop long-term storage credits to: (i) firm existing water supplies for municipal and industrial users during Colorado River shortages or Central Arizona Project (CAP) service interruptions; (ii) help meet the water management objectives of the Arizona Groundwater Code; and (iii) assist in the settlement of American Indian water rights claims. The ABWA successfully recharged more than 209,000 acre-feet in 2003 allowing for the second year in a row for Arizona’s to use its full allocation of Colorado River entitlement of 2.8 million acre-feet. This banked water can be used as a hedge against future drought conditions. Further, the first curtailment of CAP deliveries in the event of shortage would occur to non-Indian agricultural users. Such users accounted for a third of CAP deliveries in 2003, creating a buffer for users such as CCWC. Though it is difficult to predict drought conditions with certainty, the activities of AWBA, and the priority for users of CAP, such as CCWC, provides an improved outlook for CCWC supplies.CCWC obtains its water supply from two operating wells and from Colorado River water delivered by the CAP. The majority of CCWC’s water supply is obtained from its CAP allocation and well water is used for peaking capacity in excess of treatment plant capability, during treatment plant shutdown, and to keep the well system in optimal operating condition.
CCWC has an Assured Water Supply designation, by decision and order of the Arizona Department of Water Resources (ADWR), providing in part that, subject to its requirements, CCWC has a sufficient supply of ground water and CAP water which is physically, continuously and legally available to satisfy current and committed demands of its customers, plus at least two years of predicted demands, for 100 years.
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CCWC has, however, received a letter from the ADWR stating that the current and committed demand for water in CCWC’s service area has exceeded CCWC’s supply of water in its proven assured water supply account by 400 acre-feet per year. ADWR’s letter requires CCWC to make up this accounting deficit by securing additional water supplies and/or providing information to ADWR that would allow ADWR to issue a new decision that CCWC’s current and committed demands are within the proven available supplies in CCWC’s assured water supply account.
The ADWR letter is part of a routine administrative review of all water providers. ADWR’s review will have no impact on CCWC’s ability to deliver water to its existing customers. CCWC has submitted an application to the ADWR to modify its designation of assured supply on February 11, 2004. If there are no objections to the application to modify CCWC’s designation of assured supply by ADWR, they may proceed to modify CCWC’s designation, subject to CCWC obtaining membership in the Central Arizona Groundwater Replenishment District.
Notwithstanding an assured water supply designation, CCWC’s water supply may be subject to interruption or reduction, in particular owing to interruption or reduction of CAP water. In the event of interruption or reduction of CAP water, CCWC can currently rely on its well water supplies for short-term periods. However, in any event, the quantity of water CCWC supplies to some or all of its customers may be interrupted or curtailed, pursuant to the provisions of its tariffs. CCWC also has the physical capability to deliver water far in excess of that which is currently accounted for in CCWC’s assured water supply account.
Risk Factor Summary
You should carefully read the risks described below and other information in this Form 10-K in order to understand certain of the risks of our business.
Our liquidity and earnings could be adversely affected by changes in water supply costs
Prior to November 29, 2001, we recovered certain water supply costs through a balancing account mechanism. Water supply costs include the cost of purchased water and power and groundwater production assessments. Changes in the unit costs did not directly affect earnings. The balancing account was not, however, designed to insulate our earnings against changes in supply mix. As a result, we were not permitted to recover increased costs due to increased use of purchased water, which is generally more expensive than groundwater, through the balancing account mechanism. Increased costs of this nature were only recoverable, on a prospective basis, through the filing of a general rate case.
On
March 1, 2000, Registrant filed an advice letter withNovember 29, 2001, the CPUC ordered us to suspend the use of the current water balancing account, and instead start a memorandum account forrecoveryeach offsettable expense ofY2K related costs. Registrant believes that generally these capital expenditurespurchased water, purchased power and pump tax for our water service areas. Changes in water supply costs compared to the authorized amount, as well as any future authorized offset increases may directly affect our earnings. In June 2003, we received theremaining Y2K-related investmentsCPUC’s authorization to increase our rates to recover the pre November 29, 2001 balance in our supply costs balancing account.In a decision issued on June 19, 2003 for memorandum supply accounts, the CPUC concluded that our recovery of deferred water supply costs for providing water service will be reduced if we are earning more than our authorized rate of return. Pursuant to the resolution, we filed advice letters, on September 12, 2003, seeking recovery for under-collected balance of $2.6 million for the period of November 29, 2001 through December 31, 2002. Future recovery of the under-collected balances is subject to the earning tests and the CPUC’s review of the reasonableness of the cost. For more information, see the section entitled “Accounting for Supply Costs” included in Part II, Item 7 in Management’s Discussion and Analysis of Financial Condition and Results of Operation
Our liquidity, and in certain circumstances, earnings, could be adversely affected by increases in electricity prices in California
Under California law, we are permitted to file for a rate increase to recover electric power costs not being recovered in current rates. Increases in electric power costs generally have no direct impact on profit margins, unless recovery of these costs is disallowed, but do affect cash flows and can therefore impact the amount of our capital resources. Electric power costs increased substantially in California during the fall of 2000 until the summer of 2001. On July 17, 2002, the FERC extended and modified the mitigation measures that were set to expire on September 30, 2002, citing delays in construction of new generation resources in California and throughout the West, delays in adopting a new market design and market rules by the Cal ISO, transmission line constraints, constraints on natural gas pipeline capacity and continuing dysfunctions in the power market. It remains unclear how long the FERC will leave its mitigation measures in place. The premature termination of such mitigation measures could result in a substantial
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increase in spot market prices and the prices of long-term contracts for power and capacity. In addition, a number of market reforms are under consideration at FERC. Certain of these reforms, if adopted, could result in significantly increased electric supply reserve requirements that have the potential for further cost increases.
On July 17, 2002, the CPUC approved a settlement authorizing us to include $0.077 per kilowatt-hour (KWh) in rates to recover electric power costs at our Bear Valley Electric operation. If our actual annual costs exceed this amount, we cannot recover the excess and the amount will be expensed against income. If our actual annual energy costs are less than $0.077 per KWh, we can use this difference to collect amounts previously included in the balancing account. The CPUC also has authorized SCW to collect a surcharge from its customers of 2.2¢ per Kwh for a period through
rates, but can give no assuranceAugust 2011, to enable SCW to recover the under-collection in its balancing account arising out of the energy crisis. SCW anticipates that theCPUC2.2¢ surcharge on its electricity sales during this period willauthorize recoverybe sufficient to enable SCW to recover the amount ofall or somethis under-collection, with interest.In March 2001, SCW entered into a five-year nine-month, block forward purchase contract with Mirant Marketing to supply its Bear Valley Electric customer service area with 15 MWs of
these costs. See Note 13electric energy at a price of $95 per MWh beginning April 1, 2001 through December 31, 2006. Effective November 2002, SCW entered into a series of purchase power contracts with PWCC. The purchased power agreements with PWCC enable SCW to purchase a contractual volume of power at $74.65 per megawatt hour (MWh). SCW also buys additional energy from the spot market to meet peak demand and sell surplus power to theNotesspot market from time toFinancial Statements. RISK FACTOR SUMMARY This section (writtentime. SCW should be able to recover these costs up to the annual recovery cap of $77 per MWh, unless the CPUC determines that the costs incurred by SCW for purchasing power are not reasonable. The CPUC has not yet reviewed the purchased power agreements with PWCC or SCW’s spot market practices for reasonableness.Significant claims have been asserted against us in
plain English to comply with certain SEC Standards) summarizes certain risks of our business that may affect our future financial results. We also periodically file with the Securitieswater quality litigationSCW and
Exchange Commission documents that include more information on these risks. It is important for investors to read these documents. Litigation SCW has recentlyothers have been sued ineleven water-qualitytwenty-two water quality relatedlawsuits: - a suit filed on April 24, 1997 alleging personal injury and property damage as a result of the sale of water from wells located in an area of the San Gabriel Valley that has been designated a federal superfund site - a suit filed on July 29, 1997 alleging personal injury and property damage as a result of the sale of water; few of our systems are located in the geographical area covered by this suit - a suit filed on December 8, 1997lawsuits alleging personal injury and property damage as a result of the delivery ofcontaminatedwaterin SCW's Arden-Cordova service area - a suit filed on February 2, 1998 alleging personal injury and property damage as a result of the sale of water from wells located in an area of the San Gabriel Valleythathas been designated a superfund site 1821 - a suit filed on February 4, 1998 alleging personal injury and property damage as a result of the sale of water from wells located in an area of the San Gabriel Valley that has been designated a superfund site - a suit filed in March 2, 1998 alleging personal injury and property damage as a result of the delivery of contaminated water in SCW's Arden-Cordova service area - a suit filed on June 29, 1998 alleging personal injury and property damage as a result of the sale of water from wells located in an area of the San Gabriel Valley that has been designated a superfund site - two suits filed on July 30, 1998 alleging personal injury and property damage as a result of the sale of water from wells located in an area of the San Gabriel Valley that has been designated a superfund site - a suit filed on December 3, 1998 alleging personal injury and property damage as a result of the sale of water from wells located in an area of the San Gabriel Valley that has been designated a superfund site - a suit filed in July 22, 1999 alleging personal injury and property damage as a result of the sale of water from wells located in an area of the San Gabriel Valley that has been designated a superfund site On September 1, 1999, the First District Court of Appeal in San Francisco, held that the CPUC had preemptive jurisdiction over regulated public utilities and ordered dismissal of a series of lawsuits against water utilities, including sevenwas allegedly contaminated. Nineteen of the lawsuitsagainst SCW. On October 11, one group ofinvolve plaintiffsappealed the decision to the California Supreme Court which has accepted the petition. Management can not predict the outcome of the proceeding.who received water from two groundwater basins in Los Angeles County. The other lawsuits involve plaintiffs in Sacramento County.In March 1998, the CPUC issued an
order instituting investigation (the OII)Order Instituting Investigation as a result ofthese types of suitswater quality lawsuits being filed against water utilities in California.TheOn November 2, 2000, the CPUCis seekingissued a final order concluding that (i) the CPUC has jurisdiction todetermine: - whether existing standardsregulate the service of water utilities with respect to the health andpolicies regardingsafety of that service; (ii) DOHS requirements governing drinking water quality adequately protect the public health- whether water utilities are following existing standards The Administrative Law Judge assigned to the OII has issued a draft decision finding thatand safety; and (iii) regulated water utilities, including SCW, have satisfactorily complied withDOHS regulationpast and present drinking water quality requirements.On February 5, 2002, the California Supreme Court ruled that water utilities regulated by the CPUC may only be sued for damages based on allegations and ultimate proof that the utility failed to comply with federal and state safe drinking water requirements. As a result, plaintiffs may proceed on their claims against SCW
is unabletopredict whetherthedraft decision willextent that these claims are based on violations of federal and state law.Persons that are potentially responsible for causing the contamination of groundwater supplies have also been increasingly asserting claims against water distributors on a variety of theories and have thus far successfully brought them within the class of potentially responsible parties thereby increasing the costs of seeking recovery from the potentially responsible parties and the risks associated with seeking recovery of these costs. Management believes that rate recovery, proper insurance coverage and reserves are in place to insure against these claims.
Our operating costs have increased and are expected to continue to increase as a result of groundwater contamination
Our operations have been impacted by groundwater contamination in certain of our service territories. We have taken a number of steps to address this contamination, including the removal of wells from service, the construction of water treatment facilities and securing alternative sources of supply from other areas not affected by the contamination.
In some cases, potentially responsible parties have reimbursed us for our costs. In other cases, we have taken legal action against parties that we believe to be
approved in part or in its entirety. Thepotentially responsible for the contamination. To date, the CPUC hasauthorized aalso permitted SCW to establish memorandumaccountaccounts forlegal expenses incurred by water utilities, including SCW, in the water quality lawsuits. Under the memorandum account procedure, SCW may recover litigationrecovery of these types of costs, but actual recovery of these costs from ratepayers has been limited tothe extent authorized by the CPUC. The CPUCfiling only with a General Rate Case, generally every 3 years.41
Environmental regulation has
not yet authorizedincreased, and is expected to continue to increase our operating costsSCW
to recover any of its litigation costs. As of December 31, 1999, Registrant had incurred $860,120 in the OII-related memorandum account. Environmental Regulation SCW isand CCWC are subject to increasingly stringent environmental regulations that will result in increasing capital and operating costs. These regulations include:- the
• The 1996 amendments to the Safe Drinking Water Act that require increased testing and treatment of water to reduce specified contaminants to maximum contaminant levels • Approved regulations requiring increased surface-water treatment to decrease the risk of microbial contamination; these regulations affect SCW’s five surface water treatment plants and two CCWC plants • Additional regulation of disinfection/disinfection byproducts • Additional regulations requiring disinfection of certain groundwater systems • Regulation of arsenic and radon • Changes in the action level and the proposed adoption of maximum contamination levels for perchlorate and other by products of the production of rocket fuel SCW and
treatment of water to reduce specified contaminants to minimum containment levels 1922 - interim regulations expected to be adopted before the end of 2000 requiring increased surface-water treatment to decrease the risk of microbial contamination; these regulations will affect SCW's five surface water treatment plants - additional regulation of disinfection/disinfection byproducts expected to be adopted before the end of 2002; these regulations will potentially affect two of SCW's systems - additional regulations expected to be adopted before the end of 2000 requiring disinfection of certain groundwater systems; these regulations will potentially impact several of SCW's systems using groundwater supplies - potential regulation of radon and arsenic - new California requirements to fluoridate public water systems serving over 10,000 customers SCWCCWC may be able to recover costs incurred to comply with these regulations through the ratemakingprocess for our regulated systems.process. We may also be able to recover certain of these costs under our contractual arrangements with municipalities. In certain circumstances, we may be able to recover costs from parties responsible or potentially responsible forcontamination. Rates and Regulation SCW is subject to regulation by the CPUC. AWR and ASUS are not directly subject to CPUC regulation. The CPUC may, however, regulate transactions between SCW and AWR, including the manner in which overhead costs are allocated between SCW and AWR and the pricing of services rendered by SCW to AWR. SCW's revenues depend substantially on the rates that it is permitted to charge its customers. SCW may increase rates in three ways: - by filing for a general rate increase - by filing for recovery of certain expenses - by filing an "advice letter" for certain plant additions, thereby increasing rate base In addition, SCW recovers certain supply costscontamination, either voluntarily or througha balancing account mechanism. Supply costs include the cost of purchased water and power and groundwater production assessments. The balancing account mechanism is intended to insulate SCW's earnings from changes in supply costs that are beyond SCW's control. The balancing account is not, however, designed to insulate SCW's earnings against changes in supply mix. As a result, SCW may not recover increased costs due to increased use of purchased water through the balancing account mechanism. In addition, balancing account adjustments, if authorized by the CPUC, may result in either increases or decreases in revenues attributable to supply costs incurred in prior periods, depending upon whether there has been an undercollection or overcollection of supply costs. There are also a number of matters pending before the CPUC that may affect our future financial results. These matters include: - applications filed by SCW to increase rates in 4 of its 16 rate-making jurisdictions; a final decision is not expected until second quarter of 2000 although a tentative settlement has been worked out - an application filed to consolidate the rate-making jurisdictions located in SCW's Region III area into a single tariff - the OII - new guidelines under consideration by the CPUC for the acquisition and merger of water utilities and for privatization transactions 2023 Adequacy of Water Suppliesspecific court action.The adequacy of our water supplies depends upon a variety of factors beyond our control
The adequacy of our water supplies varies from year to year depending upon a variety of factors,
including - rainfall - the amount of water stored in reservoirs - the amount used by our customers and others - water quality, and - legal limitations on use. As a result of heavier than normal rainfall in the winter of 1998-1999, most of California's reservoirs remain at or near capacity and the outlook for water supply in the near term is generally favorable.including:
• Rainfall • Availability of Colorado River water and imported water from northern California • The amount of water stored in reservoirs and groundwater basins • The amount of water used by our customers and others • Water quality • Legal limitations on use Population growth and increases in the amount of water used have
however,increased limitations on use to preventoverdraftingover-drafting of groundwater basins. Theimportimportation of water from the Colorado River, one ofourSCW’s important sources of supply, is expected to decrease in future years due to the requirements of the Central ArizonaProject.Project (“CAP”) and other limitations on the amount of water that the Metropolitan Water District of Southern California is entitled to take from the Colorado River. Wealsohavein recent yearsalso taken wells out of service due to groundwater contamination. MWD is expected to increase its efforts to secure additional supplies from conservation, desalination and waterquality problems.exchanges with the agricultural water users.CCWC obtains its water supply from operating wells and from the Colorado River through the CAP. CCWC’s water supply may be subject to interruption or reduction if there is an interruption or reduction in CAP water. In addition, CCWC’s ability to provide water service to new real estate developments is dependent upon CCWC’s ability to meet the requirements of the Arizona Department of Water Resources regarding its assured water supply account.
Water shortages
could be caused by the above factors andmay affect us inseverala variety of ways:- they adversely affect supply mix by causing Registrant to rely on more expensive purchased water - they adversely affect operating costs - they may result in an increase in capital expenditures for building pipelines to connect to alternative sources of supplies and reservoirs and other facilities to conserve or reclaim water
• They adversely affect supply mix by causing us to rely on more expensive purchased water. • They adversely affect operating costs. • They may result in an increase in capital expenditures for building pipelines to connect to alternative sources of supplies and reservoirs and other facilities to conserve or reclaim water. We may be able to recover increased operating and construction costs for our regulated systems through the ratemaking process.
RegistrantWe may also be able to recover certain ofthese costs under the terms of our contractual agreements with municipalities. In certain circumstances, we may recoverthese costs from third parties that may be responsible, or potentially responsible, for groundwater contamination.42
Our earnings are greatly affected by weather during different seasons
The demand for water and electricity varies by season. Therefore, the results of operations for one period may not indicate results to be expected in another period. For instance, most water consumption occurs during the third quarter of each year when weather tends to be hot and dry. On warm days, use of water by residential and commercial customers may be significantly greater than on cold days because of the increased use of water for outdoor landscaping. Likewise the demand for electricity in our Bear Valley Electric service area is greatly affected by winter snows. An increase in winter snows reduces the use of snow making machines at ski resorts in the Big Bear area and, as a result reduces electric revenues. Likewise, unseasonably warm weather during a skiing season may result in temperatures too high for snowmaking conditions which also reduces electric revenues.
Variability of weather from normal temperatures or changes in snow or rainfall can materially impact results of operations. As a result, weather has been and will continue to be one of the dominant factors in our financial performance.
Our business is heavily regulated and, as a result, decisions by regulatory agencies and changes in laws and regulations can significantly affect our business
Our revenues depend substantially on the rates that we are permitted to charge our customers and our ability to recover our costs in these rates on a timely basis, including the ability to recover the costs of purchased water, groundwater assessments and electric power costs in rates. We
are currently negotiating with Aerojet General Corporation regardinghave filed for increased water rates to recover operating costs from customers in all our water regions as well as for costs associated with general office activities, but have been experiencing increasing delays in thecleanupprocessing of our applications. In addition, we will be seeking CPUC authorization to recover in rates for constructing an 8.4 MW natural gas-fueled generator facility to meet increasing demand in our Bear Valley customer service area.The CPUC’s resolution ordering SCW to suspend the use of the
groundwatercurrent water balancing account, and instead to start a memorandum account for its supply costs has and will directly impact our earnings since the recovery of deferred water supply costs is reduced if we are earning an amount in excess of our authorized rate of return. We have also been adversely affected by electric restructuring in California and the limitations that have been placed on our ability to recover these costs in rates.Our costs have increased as a result of increasing environmental regulation, requirements to increase security at our water facilities and requirements to mitigate fire hazard risks in our Bear Valley Electric service area arising out of the drought and a major bark beetle infestation.
The regulatory authority’s decision can impact prospective revenues and earnings as well as overturning past decisions.
Our business requires significant capital expenditures
The utility business is capital intensive. On an annual basis, we spend significant sums for
our Arden-Cordova Systemadditions to or replacement of property, plant and equipment. During calendar years 2003, 2002 and 2001, we spent $56,506,000, $40,655,000, and $47,570,000, respectively, for these purposes. Our budgeted capital expenditures for calendar year 2004 for these purposes are approximately $70,356,000. There is no capital expenditure for environmental control facilities budgeted for 2004.We obtain funds for these capital projects from operations, contributions by developers and others and advances from developers (which must be repaid). We also periodically borrow money or issue equity for these purposes. In addition, we secured a syndicated bank facility that we can use for these purposes. We cannot assure you that these sources will continue to be adequate or that the
increased costscost ofpurchasing water and developing new sourcesfunds will remain at levels permitting us to earn a reasonable rate ofgroundwater supply.return.New Accounting Pronouncements
We are
also negotiating with two participants on matterssubject to newly issued as well as changes in existing requirements issued by the Financial Accounting Standard Board. Differences in financial reporting between periods could occur unless and until the CPUC and the ACC approve such changes for conformity through regulatory proceedings. SeeNote 1 of Notes to Consolidated Financial Statements.43
Item 7A. Quantitative and Qualitative Disclosures About Market Risk
Registrant is exposed to certain market risks, including fluctuations in interest rates, and commodity price risk primarily relating to
the clean-up and purchase of replacement waterchanges in theCharnock Basin locatedmarket price of electricity. Market risk is the potential loss arising from adverse changes in prevailing market rates and prices.Interest Rate Risk
A significant portion of our capital structure is comprised of fixed-rate debt and some long-term variable debt. Market risk related to our fixed-rate debt is deemed to be the potential increase in fair value resulting from a decrease in interest rates. At December 31, 2003, the fair value of Registrant’s long-term debt was $277.4 million. A hypothetical ten percent decrease in market interest rates would have resulted in a $20.7 increase in the
citiesfair value ofSanta Monica and Culver City. These two potentially responsible parties have previously reimbursed us for replacement water andRegistrant’s long-term debt.Market risk related to our variable-rate debt is estimated as the potential decrease in pre-tax earnings resulting from an increase in interest rates. The interest rates applicable to variable-rate debt are based on weekly market rates. At December 31, 2003, the rate was approximately 1%. Based on $6.5 million of variable-rate debt outstanding as of December 31, 2003, a hypothetical one percent rise in interest rates would not result in a material impact to earnings.
At December 31, 2003, Registrant did not believe that its short-term debt was subject to interest rate risk, due to the fair market value being approximately equal to the carrying value.
Commodity/Derivative Risk
Registrant is exposed to commodity price risk primarily relating to changes in the market price of electricity. To manage its exposure to energy price risk, Registrant has certain
legal and consulting expenses. The Charnock Basin is in SCW's service territory. ACCOUNTING STANDARDS In June 1998, the FASB issuedblock-forward purchase power contracts that qualify as derivative instruments under SFAS No. 133,"Accounting“Accounting for Derivative Instruments and HedgingActivities," which establishesActivities.”A derivative financial instrument or other contract derives its value from another investment or designated benchmark. SCW is anew modelparty to various block-forward purchase power contracts. Power purchase contracts with Mirant Marketing and PWCC executed in 2001 qualify foraccountingthe exception provided under SFAS No. 133 forderivativeactivities that are considered normal purchases andhedging activities,normal sales. These contracts are reflected in the statements of income at the time of contract settlement. Contracts with PWCC executed in September 2002, however, are not treated as normal purchases andsupersedesnormal sales and,amendsas anumberresult, have been recognized at fair market value on the balance sheet as ofexisting standards. AdoptionDecember 31, 2003. This resulted in a pre-tax unrealized gain of $638,000 and a pre-tax unrealized loss of $2.5 million, respectively, for the years ended December 31, 2003 and 2002. On a quarterly basis, the related asset or liability will be adjusted to reflect the fair market value at the end of each quarter. As thisstatement,contract is settled, the realized gains or losses will be recorded and the unrealized gains or losses will be reversed. Under the terms of its power purchase contracts withan extended effective dateMirant Marketing and PWCC, SCW is required to post security, at the request of the seller, if SCW is in default under the terms of the applicable contract. In addition, SCW’s liquidity, and in certain circumstances, earnings could be adversely affected by increases in electricity prices in California. In addition, decreases in electricity prices will also result in increased unrealized losses to the Registrant under SFAS No. 133 forfiscal years beginning after December 15, 1999, will not have a significant impact on financial position or results of operation. 2124 ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISKthe contracts with PWCC.Except as discussed above, Registrant has no other derivative financial instruments, financial instruments with significant off-balance sheet risks or financial instruments with concentrations of credit risk.
The disclosure required is, therefore, not applicable. 2225 ITEM44
Item 8.
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA American States Water Company Consolidated Balance Sheets - December 31, 1999 and 1998 Consolidated Statements of Capitalization - December 31, 1999 and 1998 Consolidated Statements of Income - for the years ended December 31, 1999, 1998 and 1997 Consolidated Statements of Changes in Common Shareholders' Equity - for the years ended December 31, 1999, 1998 and 1997 Consolidated Statements of Cash Flows - for the years ended December 31, 1999, 1998 and 1997 Southern California Water Company Balance Sheets - December 31, 1999 and 1998 Statements of Capitalization - December 31, 1999 and 1998 Statements of Income - for the years ended December 31, 1999, 1998 and 1997 Statements of Changes in Common Shareholders' Equity - for the years ended December 31, 1999, 1998 and 1997 Statements of Cash Flows - for the years ended December 31, 1999, 1998 and 1997 Notes toFinancial StatementsReport of Independent Public Accountants 2326and Supplementary Data
American States Water Company Consolidated Balance Sheets - December 31, 2003 and 2002 Consolidated Statements of Capitalization - December 31, 2003 and 2002 Consolidated Statements of Income - for the years ended December 31, 2003, 2002 and 2001 Consolidated Statements of Changes in Common Shareholders’ Equity - for the years ended December 31, 2003, 2002 and 2001 Consolidated Statements of Cash Flows - for the years ended December 31, 2003, 2002 and 2001 Southern California Water Company Balance Sheets - December 31, 2003 and 2002 Statements of Capitalization - December 31, 2003 and 2002 Statements of Income - for the years ended December 31, 2003, 2002 and 2001 Statements of Changes in Common Shareholder’s Equity - for the years ended December 31, 2003, 2002 and 2001 Statements of Cash Flows - for the years ended December 31, 2003, 2002 and 2001 Notes to Consolidated Financial Statements Report of Management Report of Independent Auditors Schedule I – Condensed Financial Information of Parent 45
AMERICAN STATES WATER COMPANY
CONSOLIDATED BALANCE SHEETS
December 31, ------------------------- 1999 1998 --------- --------- (in thousands)ASSETS UTILITY PLANT, AT COST Water $ 532,007 $ 482,989 Electric 36,349 35,171 --------- --------- 568,356 518,160 Less - Accumulated depreciation (151,733) (138,423) --------- --------- 416,623 379,737 Construction work in progress 32,972 35,016 --------- --------- Net utility plant 449,595 414,753 --------- --------- OTHER PROPERTY AND INVESTMENTS 10,583 1,077 CURRENT ASSETS Cash and cash equivalents 2,189 620 Accounts receivable-Customers, less reserves of $487 in 1999; $403 in 1998 10,135 7,626 Other account receivable 4,347 5,301 Unbilled revenue 11,345 9,303 Materials and supplies, at average cost 1,153 994 Supply cost balancing accounts 4,774 4,300 Prepayments 4,851 5,988 Accumulated deferred income taxes - net 5,546 5,156 --------- --------- Total current assets 44,340 39,288 --------- --------- DEFERRED CHARGES Unamortized debt expense and redemption premium 6,811 6,635 Regulatory tax-related assets 19,941 21,506 Other 1,911 1,412 --------- --------- Total deferred charges 28,663 29,553 --------- --------- TOTAL ASSETS $ 533,181 $ 484,671 ========= =========
December 31, (in thousands) 2003 2002 Water $ 726,811 $ 693,949 Electric 42,711 41,017
769,522 734,966 Less – accumulated depreciation (222,567 ) (206,873 )
546,955 528,093 Construction work in progress 55,343 35,218
Net utility plant 602,298 563,311
22,120 22,670 Cash and cash equivalents 12,775 18,397 Accounts receivable-customers (less allowance for doubtful accounts of $831 in 2003 and $769 in 2002) 11,758 10,833 Unbilled revenue 12,714 12,277 Other accounts receivable 10,649 2,411 Taxes receivable — 557 Materials and supplies, at average cost 1,346 936 Regulatory assets – current 5,331 4,303 Prepayments 3,786 3,220 Deferred income taxes – current — 914
Total current assets 58,359 53,848
Regulatory assets 57,704 49,347 Other accounts receivable 8,000 3,370 Other 8,994 8,007
Total regulatory and other assets 74,698 60,724
$ 757,475 $ 700,553
The accompanying notes are an integral part of these consolidated financial statements.
46
AMERICAN STATES WATER COMPANY
CONSOLIDATED BALANCE SHEETS
December 31, (in thousands) 2003 2002 Common shareholders’ equity $ 212,487 $ 213,279 Long-term debt 229,799 231,089
Total capitalization 442,286 444,368
Notes payable to banks 56,000 35,000 Long-term debt – current 820 13,305 Accounts payable 18,774 11,600 Taxes payable 2,784 — Accrued employee expenses 3,925 5,105 Accrued interest 1,681 1,941 Deferred income taxes – current 1,217 472 Other 10,697 10,552
Total current liabilities 95,898 77,975
Advances for construction 77,154 70,208 Contributions in aid of construction – net 64,297 47,751 Deferred income taxes 53,243 54,259 Unamortized investment tax credits 2,700 2,791 Accrued pension and other postretirement benefits 4,584 2,017 Regulatory liabilities 9,642 — Other 7,671 1,184
Total other credits 219,291 178,210
$ 757,475 $ 700,553
The accompanying notes are an integral part of these consolidated financial statements.
47
AMERICAN STATES WATER COMPANY
CONSOLIDATED STATEMENTS OF CAPITALIZATION
December 31, (in thousands) 2003 2002 Common Shares, no par value, no stated value: Authorized: 30,000,000 shares Outstanding: 15,212,278 shares in 2003 and 15,180,835 shares in 2002 $ 127,699 $ 25,341 Additional paid-in capital — 101,606 Earnings reinvested in the business 84,788 86,332
212,487 213,279
Notes/Debentures: 5.82% notes due 2003 — 12,500 6.64% notes due 2013 1,100 1,100 6.80% notes due 2013 2,000 2,000 6.87% notes due 2023 5,000 5,000 7.00% notes due 2023 10,000 10,000 7.55% notes due 2025 8,000 8,000 7.65% notes due 2025 22,000 22,000 6.81% notes due 2028 15,000 15,000 6.59% notes due 2029 40,000 40,000 7.875% notes due 2030 20,000 20,000 7.23% notes due 2031 50,000 50,000 Private Placement Notes: 9.56% notes due 2031 28,000 28,000 Tax-Exempt Obligations: 5.50% notes due 2026 7,920 7,945 Variable Rate Obligation due 2014 6,000 6,000 State Water Project due 2035 4,967 5,508 Other Debt Instruments: 8.50% fixed rate obligation due 2013 1,419 1,530 Variable Rate Obligation due 2018 521 554 Capital lease obligations 329 368 Chaparral City Water Company: 4% to 4.85% serial bonds due 2007 900 1,100 5.20% term bonds due 2011 1,000 1,000 5.40% term bonds due 2022 4,610 4,610 4.65% term bonds due 2006 115 150 5.30% term bonds due 2022 1,015 1,015 3.34% repayment contract due 2006 723 1,014
230,619 244,394 Less: Current maturities (820 ) (13,305 )
229,799 231,089
$ 442,286 $ 444,368
The accompanying notes are an integral part of these consolidated financial statements.
48
AMERICAN STATES WATER COMPANY
CONSOLIDATED STATEMENTS OF INCOME
For the years ended December 31, (in thousands, except per share amounts) 2003 2002 2001 Water $ 187,163 $ 187,061 $ 181,474 Electric 24,492 21,298 15,251 Other 1,014 846 789
Total operating revenues 212,669 209,205 197,514
Water purchased 40,538 42,859 37,609 Power purchased for resale 13,867 15,818 19,662 Power purchased for pumping 10,232 10,576 9,592 Unrealized (gain) loss on purchased power contracts (638 ) 2,530 — Groundwater production assessment 7,344 7,416 6,847 Supply cost balancing accounts 6,590 (3,406 ) (14,681 ) Other operating expenses 18,264 16,983 17,162 Administrative and general expenses 35,726 30,010 35,108 Depreciation and amortization 19,792 18,302 17,951 Maintenance 9,932 9,839 8,640 Taxes on income 9,167 12,949 14,370 Property and other taxes 8,250 7,681 7,553
Total operating expenses 179,064 171,557 159,813
33,605 37,648 37,701
Refund of water right lease revenues, net of taxes (3,660 ) — — Other income (loss) – net 17 390 (510 )
Total other income (loss) (3,643 ) 390 (510 )
Interest on long-term debt 16,812 16,972 13,497 Other interest and amortization of debt expense 1,258 727 2,238
Total interest charges 18,070 17,699 15,735
11,892 20,339 21,456 Dividends on Preferred Shares — (29 ) (84 )
$ 11,892 $ 20,310 $ 21,372
15,200 15,144 15,120 $ 0.78 $ 1.34 $ 1.41 15,227 15,157 15,122 $ 0.78 $ 1.34 $ 1.41 $ 0.884 $ 0.872 $ 0.867 The accompanying notes are an integral part of these consolidated financial statements.
49
AMERICAN STATES WATER COMPANY
CONSOLIDATED STATEMENTS OF CHANGES
IN COMMON SHAREHOLDERS’ EQUITY
Common Shares Earnings Number Additional Reinvested of Paid-in in the (in thousands, except per share data) Shares Amount Capital Business Total 15,119 $ 25,199 $ 100,239 $ 70,948 $ 196,386 Add: Net income 21,456 21,456 Deduct: Dividends on Preferred Shares 84 84 Dividends on Common Shares-$0.867 per share 13,104 13,104
15,119 25,199 100,239 79,216 204,654 Add: Net income 20,339 20,339 Issuance of Common Shares 62 142 1,367 1,509 Deduct: Dividends on Preferred Shares 29 29 Dividends on Common Shares-$0.872 per share 13,194 13,194
15,181 25,341 101,606 86,332 213,279 Add: Net income 11,892 11,892 Reclassification adjustment due to the elimination of stated value 101,606 (101,606 ) Issuance of Common Shares 31 752 752 Deduct: Dividends on Common Shares-$0.884 per share 13,436 13,436
15,212 $ 127,699 — $ 84,788 $ 212,487
The accompanying notes are an integral part of these consolidated financial statements.
50
AMERICAN STATES WATER COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the years ended December 31, (in thousands) 2003 2002 2001 Net income $ 11,892 $ 20,339 $ 21,456 Adjustments for non-cash items: Depreciation and amortization 19,792 18,302 17,951 Deferred income taxes and investment tax credits 3,196 3,222 7,642 Unrealized (gain) loss on purchased power contracts (638 ) 2,530 — Refund of water right lease revenues, net of taxes 3,660 — — Other – net 1,024 2,306 1,557 Changes in assets and liabilities: Accounts receivable – customers (925 ) (276 ) (76 ) Unbilled revenue (437 ) (136 ) (778 ) Other accounts receivable (162 ) (475 ) (73 ) Materials and supplies (410 ) 34 146 Prepayments (566 ) (727 ) 1,592 Regulatory assets - supply cost balancing accounts 6,590 (3,406 ) (14,681 ) Other assets (3,784 ) (6,209 ) (3,693 ) Accounts payable 7,174 (1,486 ) 2,465 Taxes payable 3,341 (961 ) (1,741 ) Other liabilities (2,989 ) (7,276 ) 6,085
Net cash provided 46,758 25,781 37,852
Construction expenditures (57,211 ) (40,655 ) (47,570 )
Net cash used (57,211 ) (40,655 ) (47,570 )
Proceeds from issuance of Common Shares 752 1,509 — Proceeds from issuance of long-term debt — — 70,000 Receipt of advances for and contributions in aid of construction 11,920 7,024 6,738 Refunds on advances for construction (3,391 ) (3,557 ) (3,409 ) Cash received on financing portion of purchased power contracts 1,761 — — Retirement or repayments of long-term debt (13,775 ) (2,098 ) (735 ) Redemption of Preferred Shares — (1,880 ) — Net change in notes payable to banks 21,000 15,000 (25,000 ) Common and preferred dividends paid (13,436 ) (13,223 ) (13,188 )
Net cash provided 4,831 2,775 34,406
(5,622 ) (12,099 ) 24,688 Cash and cash equivalents, beginning of year 18,397 30,496 5,808
$ 12,775 $ 18,397 $ 30,496
The accompanying notes are an integral part of these consolidated financial statements.
51
SOUTHERN CALIFORNIA WATER COMPANY
BALANCE SHEETS
December 31, (in thousands) 2003 2002 Water $ 688,079 $ 656,331 Electric 42,711 41,017
730,790 697,348 Less – accumulated depreciation (211,424 ) (196,660 )
519,366 500,688 Construction work in progress 51,354 33,705
Net utility plant 570,720 534,393
7,471 8,018
Cash and cash equivalents 8,306 11,677 Accounts receivable-customers (less allowance for doubtful accounts of $797 in 2003 and $729 in 2002) 11,487 10,609 Unbilled revenue 12,484 12,060 Inter-company receivable 445 1,044 Other accounts receivable 10,516 2,234 Materials and supplies, at average cost 1,322 905 Regulatory assets – current 5,331 4,303 Prepayments 3,638 3,005 Deferred income taxes - current — 1,018
Total current assets 53,529 46,855
Regulatory assets 57,624 49,307 Other accounts receivable 8,000 3,370 Other 8,219 7,075
Total regulatory and other assets 73,843 59,752
$ 705,563 $ 649,018
The accompanying notes are an integral part of these financial statements
2427 AMERICAN STATES WATER COMPANY CONSOLIDATED BALANCE SHEETS
December 31, ---------------------- 1999 1998 -------- -------- (in thousands)CAPITALIZATION AND LIABILITIES CAPITALIZATION Common shareholders' equity $158,846 $154,299 Preferred Shares 1,600 1,600 Preferred Shares - mandatory redemption 360 400 Long-term debt 167,363 120,809 -------- -------- Total capitalization 328,169 277,108 -------- -------- CURRENT LIABILITIES Notes payable to banks 21,000 38,000 Long-term debt and Preferred Shares - current 340 260 Accounts payable 13,777 10,218 Taxes payable 5,432 5,900 Accrued interest 1,584 1,405 Other 12,832 7,985 -------- -------- Total current liabilities 54,965 63,768 -------- -------- OTHER CREDITS Advances for construction 57,485 54,743 Contributions in aid of construction 38,895 36,530 Accumulated deferred income taxes - net 48,302 46,902 Unamortized investment tax credits 3,064 3,155 Regulatory tax-related liability 1,861 1,906 Other 440 559 -------- -------- Total other credits 150,047 143,795 ======== ======== TOTAL CAPITALIZATION AND LIABILITIES $533,181 $484,671 ======== ========The accompanying notes are an integral part of these financial statements 2528 AMERICAN STATES WATER COMPANY CONSOLIDATED STATEMENTS OF CAPITALIZATION
December 31, ------------------------- 1999 1998 --------- --------- (in thousands)COMMON SHAREHOLDERS' EQUITY: Common Shares, $2.50 stated value-- Authorized 31,071,408 shares Outstanding 8,957,671 in 1999 and 1998 $ 22,394 $ 22,394 Additional paid-in capital 74,937 74,937 Earnings reinvested in the business 61,515 56,968 --------- --------- 158,846 154,299 --------- --------- PREFERRED SHARES: $25 PAR VALUE Authorized 64,000 shares Outstanding 32,000 shares, 4% Series 800 800 Outstanding 32,000 shares, 4-1/4% Series 800 800 --------- --------- 1,600 1,600 --------- --------- PREFERRED SHARES SUBJECT TO MANDATORY REDEMPTION Requirements: $25 par value Authorized and outstanding 16,000 shares in 1999 and 17,600 shares in 1998, 5% Series 400 440 Less: Preferred Shares to be redeemed within one year (40) (40) --------- --------- 360 400 --------- --------- LONG-TERM DEBT 5.82% notes due 2003 12,500 12,500 6.64% notes due 2013 1,100 1,100 6.80% notes due 2013 2,000 2,000 8.50% fixed rate obligation due 2013 1,798 1,882 Variable rate obligation due 2014 6,000 6,000 Variable rate obligation due 2018 650 630 6.87% notes due 2023 5,000 5,000 7.00% notes due 2023 10,000 10,000 7.55% notes due 2025 8,000 8,000 7.65% notes due 2025 22,000 22,000 5.50% notes due 2026 8,000 8,000 6.81% notes due 2028 15,000 15,000 6.59% notes due 2029 40,000 -- 9.56% notes due 2031 28,000 28,000 State Water Project due 2035 7,028 -- Other 587 917 --------- --------- 167,663 121,029 Less: Current maturities (300) (220) --------- --------- 167,363 120,809 ========= ========= TOTAL CAPITALIZATION $ 328,169 $ 277,108 ========= =========The accompanying notes are an integral part of these financial statements 2629 AMERICAN STATES WATER COMPANY CONSOLIDATED STATEMENTS OF INCOME
For the years ended December 31, ----------------------------------------- 1999 1998 1997 --------- --------- --------- (in thousands, except per share amounts)OPERATING REVENUES Water $ 159,693 $ 134,794 $ 140,988 Electric 13,338 13,201 12,767 Other 390 65 -- --------- --------- --------- Total operating revenues 173,421 148,060 153,755 --------- --------- --------- OPERATING EXPENSES Water purchased 36,143 30,833 38,318 Power purchased for resale 7,119 5,013 5,188 Power purchased for pumping 7,394 7,009 7,554 Groundwater production assessment 7,170 7,567 6,847 Supply cost balancing accounts (473) 28 2,813 Other operating expenses 15,594 14,459 13,074 Administrative and general expenses 28,600 21,987 22,138 Depreciation 13,650 12,538 10,952 Maintenance 9,799 7,311 7,301 Taxes on income 13,345 10,130 9,830 Property and other taxes 6,566 6,124 6,282 --------- --------- --------- Total operating expenses 144,907 122,999 130,297 --------- --------- --------- OPERATING INCOME 28,514 25,061 23,458 --------- --------- --------- OTHER INCOME Total other income - net 532 769 758 --------- --------- --------- Income before interest charges 29,046 25,830 24,216 --------- --------- --------- INTEREST CHARGES Interest on long-term debt 11,294 9,612 8,821 Other interest and amortization of debt expense 1,651 1,595 1,336 --------- --------- --------- Total interest charges 12,945 11,207 10,157 --------- --------- --------- NET INCOME 16,101 14,623 14,059 Dividends on Preferred Shares (88) (90) (92) --------- --------- --------- EARNINGS AVAILABLE FOR COMMON SHAREHOLDERS $ 16,013 $ 14,533 $ 13,967 BASIC EARNINGS PER COMMON SHARE $ 1.79 $ 1.62 $ 1.56 WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING 8,958 8,958 8,957The accompanying notes are an integral part of these financial statements 2730 AMERICAN STATES WATER COMPANY CONSOLIDATED STATEMENTS OF CHANGES IN COMMON SHAREHOLDERS' EQUITY
Common Shares Earnings -------------------- Additional Reinvested Number Paid-in in the of Shares Amount Capital Business ------- ------- ------- ------- (in thousands)BALANCES AT DECEMBER 31, 1996 8,886 $22,215 $73,645 $50,906 Add: Net Income 14,059 Issuance of Common Shares for public offering 72 179 1,292 Deduct: Dividends on Preferred Shares 92 Dividends on Common Shares - $1.245 per share 11,151 ------- ------- ------- ------- BALANCES AT DECEMBER 31, 1997 8,958 $22,394 $74,937 $53,722 Add: Net Income 14,623 Deduct: Dividends on Preferred Shares 90 Dividends on Common Shares - $1.26 per share 11,287 ------- ------- ------- ------- BALANCES AT DECEMBER 31, 1998 8,958 $22,394 $74,937 $56,968 Add: Net Income 16,101 Deduct: Dividends on Preferred Shares 88 Dividends on Common Shares - $1.28 per share 11,466 ------- ------- ------- ------- BALANCES AT DECEMBER 31, 1999 8,958 $22,394 $74,937 $61,515 ======= ======= ======= =======The accompanying notes are an integral part of these financial statements 2831 AMERICAN STATES WATER COMPANY CONSOLIDATED STATEMENTS OF CASH FLOWS
For the years ended December 31, -------------------------------------- 1999 1998 1997 -------- -------- -------- (in thousands)CASH FLOWS FROM OPERATING ACTIVITIES: Net income $ 16,101 $ 14,623 $ 14,059 Adjustments for non-cash items: Depreciation and amortization 14,364 15,368 11,170 Deferred income taxes and investment tax credits 2,440 5,241 826 Other - net 1,066 1,394 873 Changes in assets and liabilities: Customer receivables (1,555) 918 (673) Supply cost balancing accounts (474) (14) 1,987 Accounts payable 3,559 (1,552) (1,095) Taxes payable (468) (3,215) 3,338 Other - net 3,977 438 341 -------- -------- -------- Net cash provided 39,010 33,201 30,826 -------- -------- -------- CASH FLOWS FROM INVESTING ACTIVITIES: Construction expenditures (57,823) (43,623) (36,799) -------- -------- -------- Net cash used (57,823) (43,623) (36,799) -------- -------- -------- CASH FLOWS FROM FINANCING ACTIVITIES: Issuance of Common Shares -- -- 1,472 Issuance of long-term debt and lease obligations 47,028 15,000 8,000 Receipt of advances for and contributions in aid of construction 5,300 3,381 1,302 Refunds on advances for construction (2,957) (2,651) (2,957) Retirement or repayments of long-term debt and redemption of Preferred Shares - net (435) (9,488) (198) Net change in notes payable to banks (17,000) 12,000 10,000 Common and preferred dividends paid (11,554) (11,386) (11,243) -------- -------- -------- Net cash provided 20,384 6,856 6,376 -------- -------- -------- NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS 1,569 (3,566) 403 Cash and Cash Equivalents, Beginning of Year 620 4,186 3,783 -------- -------- -------- CASH AND CASH EQUIVALENTS, END OF YEAR $ 2,189 $ 620 $ 4,186 -------- -------- -------- TAXES AND INTEREST PAID: Income taxes paid $ 12,137 $ 5,430 $ 6,338 Interest paid 11,834 11,391 9,451 -------- -------- -------- NON-CASH TRANSACTIONS: Property installed by developers and conveyed to Company $ 4,096 $ 1,797 $ 2,082 ======== ======== ========The accompanying notes are an integral part of these financial statements 293252
SOUTHERN CALIFORNIA WATER COMPANY
BALANCE SHEETS
December 31, ------------------------- 1999 1998 --------- --------- (in thousands)ASSETS UTILITY PLANT, AT COST Water $ 532,007 $ 482,989 Electric 36,349 35,171 --------- --------- 568,356 518,160 Less - Accumulated depreciation (151,733) (138,423) --------- --------- 416,623 379,737 Construction work in progress 32,972 35,016 --------- --------- Net utility plant 449,595 414,753 --------- --------- OTHER PROPERTY AND INVESTMENTS 10,233 763 --------- --------- CURRENT ASSETS Cash and cash equivalents 2,020 524 Accounts receivable-Customers, less reserves of $487 in 1999; $403 in 1998 10,135 7,498 Other 4,275 5,272 Intercompany receivable -- 104 Unbilled revenue 11,345 9,303 Materials and supplies, at average cost 1,153 994 Supply cost balancing accounts 4,774 4,300 Prepayments 4,851 5,988 Accumulated deferred income taxes - net 5,573 5,173 --------- --------- Total current assets 44,126 39,156 --------- --------- DEFERRED CHARGES Regulatory tax-related assets 19,941 21,506 Other 8,599 7,997 --------- --------- Total deferred charges 28,540 29,503 --------- --------- TOTAL ASSETS $ 532,494 $ 484,175 ========= =========The accompanying notes are an integral part of these financial statements 3033 SOUTHERN CALIFORNIA WATER COMPANY BALANCE SHEETS
December 31, ------------------------ 1999 1998 -------- -------- (in thousands)CAPITALIZATION AND LIABILITIES CAPITALIZATION Common shareholders' equity $160,023 $155,721 Preferred shares -- -- Preferred shares - mandatory redemption -- -- Long-term debt 167,363 120,809 -------- -------- Total capitalization 327,386 276,530 -------- -------- CURRENT LIABILITIES Notes payable to banks 21,000 38,000 Long-term debt and preferred shares - current 340 260 Accounts payable 13,615 10,054 Intercompany payable 4 -- Taxes payable 5,700 6,147 Accrued interest 1,584 1,405 Other 12,818 7,984 -------- -------- Total current liabilities 55,061 63,850 -------- -------- OTHER CREDITS Advances for construction 57,485 54,743 Contributions in aid of construction 38,895 36,531 Accumulated deferred income taxes - net 48,302 46,901 Unamortized investment tax credits 3,064 3,155 Regulatory tax-related liability 1,861 1,907 Other 440 558 -------- -------- Total other credits 150,047 143,795 ======== ======== TOTAL CAPITALIZATION AND LIABILITIES $532,494 $484,175 ======== ========The accompanying notes are an integral part of these financial statements 3134 SOUTHERN CALIFORNIA WATER COMPANY STATEMENTS OF CAPITALIZATION
December 31, --------------------------- 1999 1998 --------- --------- (in thousands)COMMON SHAREHOLDERS' EQUITY: Common shares, no par value Outstanding 100 in 1998 and 1999 $ 98,391 $ 98,391 Additional paid-in capital -- -- Earnings reinvested in the business 61,632 57,330 --------- --------- 160,023 155,721 --------- --------- LONG-TERM DEBT 5.82% notes due 2003 12,500 12,500 6.64% notes due 2013 1,100 1,100 6.80% notes due 2013 2,000 2,000 8.50% fixed rate obligation due 2013 1,798 1,882 Variable rate obligation due 2014 6,000 6,000 Variable rate obligation due 2018 649 630 6.87% notes due 2023 5,000 5,000 7.00% notes due 2023 10,000 10,000 7.55% notes due 2025 8,000 8,000 7.65% notes due 2025 22,000 22,000 5.50% notes due 2026 8,000 8,000 6.81% notes due 2028 15,000 15,000 6.59% notes due 2029 40,000 -- 9.56% notes due 2031 28,000 28,000 State Water Project due 2035 7,028 -- Other 588 917 --------- --------- 167,663 121,029 Less: Current maturities (300) (220) --------- --------- 167,363 120,809 ========= ========= TOTAL CAPITALIZATION $ 327,386 $ 276,530 ========= =========The accompanying notes are an integral part of these financial statements 3235 SOUTHERN CALIFORNIA WATER COMPANY STATEMENTS OF INCOME
For the years ended December 31, --------------------------------------------- 1999 1998 1997 --------- --------- --------- ($ in thousands, except per share amounts)OPERATING REVENUES Water $ 159,693 $ 134,794 $ 140,988 Electric 13,338 13,201 12,767 --------- --------- --------- Total operating revenues 173,031 147,995 153,755 --------- --------- --------- OPERATING EXPENSES Water purchased 36,145 30,833 38,318 Power purchased for resale 7,119 5,013 5,188 Power purchased for pumping 7,394 7,009 7,554 Groundwater production assessment 7,170 7,567 6,847 Supply cost balancing accounts (473) 28 2,813 Other operating expenses 15,475 14,434 13,074 Administrative and general expenses 28,077 21,884 22,138 Depreciation 13,516 12,270 10,952 Maintenance 9,794 7,311 7,301 Taxes on income 13,473 10,360 9,830 Property and other taxes 6,563 6,124 6,282 --------- --------- --------- Total operating expenses 144,253 122,833 130,297 --------- --------- --------- OPERATING INCOME 28,778 25,162 23,458 --------- --------- --------- OTHER INCOME Total other income - net 509 1,231 758 --------- --------- --------- Income before interest charges 29,287 26,393 24,216 --------- --------- --------- INTEREST CHARGES Interest on long-term debt 11,294 9,612 8,821 Other interest and amortization of debt expense 1,651 1,595 1,336 --------- --------- --------- Total interest charges 12,945 11,207 10,157 --------- --------- --------- NET INCOME 16,342 15,186 14,059 Dividends on Preferred Shares -- (46) (92) EARNINGS AVAILABLE FOR COMMON SHAREHOLDERS $ 16,342 $ 15,140 $ 13,967 BASIC EARNINGS PER COMMON SHARE $ 163,420 $ 151,400 $ 139,670 WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING 100 100 100
December 31, (in thousands) 2003 2002 Common shareholder’s equity $ 206,047 $ 207,562 Long-term debt 221,996 222,725
Total capitalization 428,043 430,287
Long-term debt – current 260 12,780 Accounts payable 17,312 10,576 Inter-company payable 34,111 13,000 Taxes payable 4,382 1,099 Accrued employee expenses 3,828 5,033 Accrued interest 1,581 1,843 Deferred income taxes – current 1,057 472 Other 10,376 10,259
Total current liabilities 72,907 55,062
Advances for construction 66,827 59,640 Contributions in aid of construction – net 64,023 47,480 Deferred income taxes 50,277 51,741 Unamortized investment tax credits 2,700 2,791 Accrued pension and other postretirement benefits 4,584 2,017 Regulatory liabilities 9,642 — Other 6,560 —
Total other credits 204,613 163,669
$ 705,563 $ 649,018
The accompanying notes are an integral part of these financial statements.
All information has been adjusted to reflect formation of holding company in 1998. 333653
SOUTHERN CALIFORNIA WATER COMPANY
STATEMENTS OFCHANGES IN COMMON SHAREHOLDERS' EQUITYCAPITALIZATION
Common Shares Earnings ------------------------ Additional Reinvested Number Paid-in in the of Shares Amount Capital Business --------- ------- ------- ------- (in thousands)BALANCES AT DECEMBER 31, 1996 8,886 $22,215 $73,645 $50,906 Add: Net Income 14,059 Issuance of Common Shares for public offering 72 179 1,292 Deduct: Dividends on Preferred Shares 92 Dividends on Common Shares - $1.245 per share 11,151 ------- ------- ------- ------- BALANCES AT DECEMBER 31, 1997 8,958 $22,394 $74,937 $53,722 Add: Transfer Preferred Shares & Investments $ 1,060 Net Income 15,186 Deduct: Dividends on Preferred Shares 46 Dividends on Common Shares - $.63 per share for 8,957,671 shares 5,643 Dividends on Common Shares - $58,890 per share for 100 shares 5,889 ------- ------- ------- ------- BALANCES AT DECEMBER 31, 1998 100 $22,394 $75,997 $57,330 Add: Net Income 16,342 Deduct: Dividends on Preferred Shares -- Dividends on Common Shares - $30,900 per share 3,090 Dividends on Common Shares - $30,500 per share 3,050 Dividends on Common Shares - $29,000 per share 2,900 Dividends on Common Shares - $30,000 per share 3,000 ======= ======= ======= ======= BALANCES AT DECEMBER 31, 1999 100 $22,394 $75,997 $61,632 ======= ======= ======= =======
December 31, (in thousands) 2003 2002 Common shares, no par value Outstanding: 110 shares in 2003 and 2002 $ 123,391 $ 123,391 Earnings reinvested in the business 82,656 84,171
206,047 207,562
Notes/Debentures: 5.82% notes due 2003 — 12,500 6.64% notes due 2013 1,100 1,100 6.80% notes due 2013 2,000 2,000 6.87% notes due 2023 5,000 5,000 7.00% notes due 2023 10,000 10,000 7.55% notes due 2025 8,000 8,000 7.65% notes due 2025 22,000 22,000 6.81% notes due 2028 15,000 15,000 6.59% notes due 2029 40,000 40,000 7.875% notes due 2030 20,000 20,000 7.23% notes due 2031 50,000 50,000 Private Placement Notes: 9.56% notes due 2031 28,000 28,000 Tax-Exempt Obligations: 5.50% notes due 2026 7,920 7,945 Variable Rate Obligation due 2014 6,000 6,000 State Water Project due 2035 4,967 5,508 Other Debt Instruments: 8.50% fixed rate obligation due 2013 1,419 1,530 Variable rate obligation due 2018 521 554 Capital lease obligations 329 368
222,256 235,505 Less: Current maturities (260 ) (12,780 )
221,996 222,725
$ 428,043 $ 430,287
The accompanying notes are an integral part of these financial
statements 3437statements.54
SOUTHERN CALIFORNIA WATER COMPANY
STATEMENTS OFCASH FLOWSINCOME
For the years ended December 31, ------------------------------------------ 1999 1998 1997 -------- -------- -------- (in thousands)CASH FLOWS FROM OPERATING ACTIVITIES: Net income 16,342 15,185 $ 14,059 Adjustments for non-cash items: Depreciation and amortization 14,229 15,100 11,170 Deferred income taxes and investment tax credits 2,430 5,224 826 Other - net 1,308 1,077 873 Changes in assets and liabilities: Customer receivables (1,640) 1,046 (673) Prepayments (1,137) 660 (743) Supply cost balancing accounts (474) (14) 1,987 Accounts payable 3,561 (1,716) (1,095) Taxes payable (447) (2,968) 3,338 Unbilled revenue (2,042) (197) 3,490 Accrued Interest 179 (463) 96 Other - net 7,074 362 (2,502) -------- -------- -------- Net cash provided 39,383 33,296 30,826 -------- -------- -------- CASH FLOWS FROM INVESTING ACTIVITIES: Construction expenditures (57,823) (43,623) (36,799) -------- -------- -------- Net cash used (57,823) (43,623) (36,799) -------- -------- -------- CASH FLOWS FROM FINANCING ACTIVITIES: Issuance of Common Shares -- -- 1,472 Issuance of long-term debt and lease obligations 47,028 15,000 8,000 Receipt of advances for and contributions in aid of construction 3,883 3,381 1,302 Refunds on advances for construction (1,540) (2,651) (2,957) Repayments of long-term debt and redemption of Preferred Shares - net (395) (9,488) (198) Net change in notes payable to banks (17,000) 12,000 10,000 Common and preferred dividends paid (12,040) (11,577) (11,243) -------- -------- -------- Net cash provided 19,936 6,665 6,376 -------- -------- -------- NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS 1,496 (3,662) 403 Cash and Cash Equivalents, Beginning of Year 524 4,186 3,783 -------- -------- -------- CASH AND CASH EQUIVALENTS, END OF YEAR 2,020 524 4,186 -------- -------- -------- TAXES AND INTEREST PAID: Income taxes paid $ 12,241 $ 5,430 $ 6,338 Interest paid 11,834 11,391 9,451 -------- -------- -------- NON-CASH TRANSACTIONS: Property installed by developers and conveyed to Company $ 4,096 $ 1,797 $ 2,082 ======== ======== ========
For the years ended December 31, (in thousands) 2003 2002 2001 Water $ 181,025 $ 180,904 $ 175,204 Electric 24,492 21,298 15,251
Total operating revenues 205,517 202,202 190,455
Water purchased 39,811 42,182 37,112 Power purchased for resale 13,867 15,818 19,662 Power purchased for pumping 9,761 10,167 9,169 Unrealized (gain) loss on purchased power contracts (638 ) 2,530 — Groundwater production assessment 7,344 7,416 6,847 Supply cost balancing accounts 6,590 (3,406 ) (14,681 ) Other operating expenses 16,985 15,823 16,111 Administrative and general expenses 30,160 26,174 33,929 Depreciation and amortization 18,864 17,384 16,710 Maintenance 9,591 9,603 8,411 Taxes on income 10,674 13,605 14,057 Property and other taxes 7,903 7,368 7,089
Total operating expenses 170,912 164,664 154,416
34,605 37,538 36,039
Refund of water right lease revenues, net of taxes (3,660 ) — — Other income (loss) – net — 318 (624 )
Total other income (loss) (3,660 ) 318 (624 )
Interest on long-term debt 16,368 16,520 13,015 Other interest and amortization of debt expense 692 116 1,562
Total interest charges 17,060 16,636 14,577
$ 13,885 $ 21,220 $ 20,838
The accompanying notes are an integral part of these financial
statements 3538statements.55
SOUTHERN CALIFORNIA WATER COMPANY
STATEMENTS OF CHANGES IN
COMMON SHAREHOLDER’S EQUITY
Common Shares Number Earnings of Reinvested (in thousands, except share and per share data) Shares Amount in the Business Total 100 $ 98,391 $ 70,273 $ 168,664 Add: Net income 20,838 20,838 Issuance of common shares 10 25,000 25,000 Deduct: Dividends on common shares-$123,000 per share 13,530 13,530
110 123,391 77,581 200,972 Add: Net income 21,220 21,220 Deduct: Dividends on common shares-$133,000 per share 14,630 14,630
110 123,391 84,171 207,562 Add: Net income 13,885 13,885 Deduct: Dividends on common shares-$140,000 per share 15,400 15,400
110 $ 123,391 $ 82,656 $ 206,047
The accompanying notes are an integral part of these financial statements.
56
SOUTHERN CALIFORNIA WATER COMPANY
STATEMENTS OF CASH FLOWS
For the years ended December 31, (in thousands) 2003 2002 2001 Net income $ 13,885 $ 21,220 $ 20,838 Adjustments for non-cash items: Depreciation and amortization 18,864 17,384 16,710 Deferred income taxes and investment tax credits 2,692 2,742 7,171 Unrealized (gain) loss on purchased power contracts (638 ) 2,530 — Refund of water right lease revenues, net of taxes 3,660 — — Other – net 871 2,702 (308 ) Changes in assets and liabilities: Accounts receivable – customers (878 ) (381 ) (157 ) Unbilled revenue (424 ) (120 ) (577 ) Other accounts receivable (206 ) (402 ) (105 ) Materials and supplies (417 ) (22 ) 156 Prepayments (633 ) (695 ) 1,446 Regulatory assets - supply cost balancing accounts 6,590 (3,406 ) (14,681 ) Other assets (3,801 ) (6,249 ) (3,660 ) Accounts payable 6,736 (2,153 ) 2,726 Inter-company receivable/payable 710 (1,070 ) (4,344 ) Taxes payable 3,283 (95 ) (767 ) Other liabilities (2,930 ) (7,434 ) 7,582
Net cash provided 47,364 24,551 32,030
Construction expenditures (53,614 ) (39,488 ) (47,029 )
Net cash used (53,614 ) (39,488 ) (47,029 )
Proceeds from issuance of Common Shares — — 25,000 Proceeds from issuance of long-term debt — — 70,000 Receipt of advances for and contributions in aid of construction 12,255 6,912 6,315 Refunds on advances for construction (3,488 ) (3,188 ) (3,019 ) Cash received on financing portion of purchased power contracts 1,761 — — Repayments of long-term debt (13,249 ) (1,559 ) (233 ) Net change in inter-company borrowings 21,000 13,000 — Net change in notes payable to banks — — (45,000 ) Common dividends paid (15,400 ) (14,630 ) (13,530 )
Net cash provided 2,879 535 39,533
(3,371 ) (14,402 ) 24,534 Cash and cash equivalents, beginning of year 11,677 26,079 1,545
$ 8,306 $ 11,677 $ 26,079
The accompanying notes are an integral part of these financial statements.
57
AMERICAN STATES WATER COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTSNote 1 - Summary of Significant Accounting Policies
Nature of Operations: American States Water Company (AWR) is the parent company of Southern California Water Company (SCW)
and, American States Utility Services, Inc. (ASUS) and Chaparral City Water Company (CCWC). SCW is a public utility engaged principally in the purchase, production, distribution and sale of wateras well asinthe distribution ofCalifornia serving approximately 250,000 water customers. SCW also distributes electricity in several California mountaincommunities. SCW is regulated by thecommunities serving approximately 22,000 electric customers. The California Public Utilities Commission(CPUC) as to its(“CPUC”) regulates SCW’s water and electric business, including properties, rates, services, facilities and other matters. CCWC is a public utility regulated by the Arizona Corporation Commission (“ACC”) serving approximately 12,100 customers in the town of Fountain Hills, Arizona and a portion of the City of Scottsdale, Arizona. ASUS performsnon-regulated,nonregulated, water related services and operations on a contract basis. There is no direct regulatory oversight by either the CPUC or the ACC of ASUS or AWR. The consolidated financial statements include the accounts of AWR, SCW, ASUS andASUS . Virtually all of AWR'sCCWC. AWR’s assets, revenues andrevenuesoperations are primarily those of SCW.NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIESBasis of Presentation: The consolidated financial statements of AWR include the accounts of AWR and its wholly-owned subsidiaries SCW, ASUS and
ASUS collectivelyCCWC (collectively referred to asRegistrant.Registrant or the Company) and are prepared in conformity with accounting principles generally accepted in the United States of America. Inter-company transactions and balances have been eliminated.The accounting records for SCW are maintained in accordance with the Uniform System of Accounts prescribed by the CPUC.The preparation of these financial statements required the use of certain estimates by management in determiningRegistrant'sRegistrant’s assets, liabilities, revenues and expenses. Actual results could differ from those estimates. Certain prior year amounts have been reclassified to conform to current year presentation. None of these reclassifications had an impact on Registrant’s Shareholders’ Equity or Net Income.Utility Accounting: Registrant’s accounting policies conform to accounting principles generally accepted in the United States of America, including the accounting principles for rate-regulated enterprises, which reflect the rate-making policies of the CPUC, ACC and the Federal Energy Regulatory Commission (FERC). The utility subsidiaries, SCW and CCWC, have incurred various costs and received various credits reflected as regulatory assets and liabilities. Accounting for such costs and credits as regulatory assets and liabilities is in accordance with Statement of Financial Accounting Standards (“SFAS”) No. 71“Accounting for the Effects of Certain Types of Regulation". This Statement sets forth the application of accounting principles generally accepted in the United States of America for those companies whose rates are established by or are subject to approval by an independent third-party regulator. Under SFAS No. 71, rate regulated entities 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 rate making process in a period different from the period in which they would have been reflected in income by an unregulated company. These deferred regulatory assets and liabilities are then reflected in the income statement in the period in which the same amounts are reflected in the rates charged for service. The amounts included as regulatory assets and liabilities that will be collected over a period exceeding one year are classified as long-term assets and liabilities as of December 31, 2003 and 2002.
Property and Depreciation:
Registrant capitalizes,SCW and CCWC capitalize, as utility plant, the cost of additions, betterments and replacements of retirement units. Such cost includes labor, material and certain indirect charges. Depreciation is computed on the straight-line, remaining-lifebasis.basis, based on depreciable plant as of the beginning of each year in accordance with Registrant’s rate making process. For the years1999, 19982003, 2002 and19972001 the aggregate provisions for depreciation for SCW approximated2.91%3.0% for its water distribution unit, and approximately 4.0%,2.79%,3.8% and2.77%4.1% for its electric unit for the years 2003, 2002, 2001, respectively. The aggregate provision for depreciation for CCWC was 2.5% for each of thebeginningsame three years. Expenditures for maintenance and repairs are expensed as incurred. Replaced or retired property costs are charged to the accumulated provision for depreciation.Estimated useful lives of Registrant’s utility plant, as authorized by the CPUC, are as follows:
Source of water supply 30 years to 50 years Pumping 25 years to 40 years Water treatment 20 years to 35 years Transmission and distribution 25 years to 50 years Other plant 7 years to 40 years 58
Note 1 - Summary of Significant Accounting Policies (Continued)
Impairment of Long-Lived Assets: Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be fully recoverable. In August 2001, the Financial Accounting Standards Board (“FASB”) issued SFAS No. 144,“Accounting for the Impairment or Disposal of Long-Lived Assets,”which supercedes SFAS No. 121, “Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed Of.”This Statement retains the fundamental provisions of SFAS No. 121 for the measurement and recognition of the impairment of long-lived assets to be held and used, as well as the measurement of long-lived assets to be disposed of by sale. SFAS No. 144 resolves implementation issues related to SFAS No. 121, and retains the amendments in SFAS No. 121 pertaining to regulatory assets under SFAS No. 71 and SFAS No. 90,“Regulated Enterprises – Accounting for Abandonments and Disallowances of Plant Costs.”Effective January 1, 2002, Registrant adopted SFAS No. 144. The adoption of SFAS No. 144 did not have an impact on Registrant’s consolidated financial statements.
Goodwill: At December 31, 2003 and 2002, Registrant had approximately $12.3 million of goodwill included in “Other Property and Investments”. The goodwill represents the difference between the aggregate purchase price and the fair value of CCWC’s net assets acquired at the time of closing, and was being amortized over a period of 40 years. Effective January 1, 2002, Registrant adopted SFAS No. 142,“Goodwill and Other Intangible Assets”and the provisions of SFAS No. 141,“Business Combinations,”which were required to be adopted concurrent with the adoption of SFAS No. 142. Pursuant to SFAS No. 142, AWR completed its transitional goodwill impairment evaluation and determined that none of the recorded goodwill was impaired. As a result of the adoption of SFAS No. 142, the amortization of this goodwill ceased effective January 1, 2002. In accordance with SFAS No. 142, goodwill is tested for impairment at least annually and more frequently if circumstances indicate that it may be impaired. The goodwill impairment model is a two-step process. First, it requires a comparison of the book value of net assets to the fair value of the related operations that have goodwill assigned to them. If the fair value is determined to be less than book value, a second step is performed to compute the amount of the impairment. In this process, a fair value for goodwill is estimated, based in part on the fair value of the operations used in the first step, and is compared to its carrying value. The amount by which carrying value exceeds fair value represents the amount of goodwill impairment. Current year
depreciable plant, respectively.analysis indicated no impairment.The following table reflects Registrant’s earnings available for Common Shareholders and earnings per share adjusted to reflect the discontinuance of periodic goodwill amortization for the years ended December 31, 2003, 2002 and 2001, respectively:
2003 2002 2001 As reported $ 11,892 $ 20,310 $ 21,372 Add back goodwill amortization, net of tax — — 191
As adjusted $ 11,892 $ 20,310 $ 21,563
As reported $ 0.78 $ 1.34 $ 1.41 Add back goodwill amortization, net of tax — — 0.01
As adjusted $ 0.78 $ 1.34 $ 1.42
As reported $ 0.78 $ 1.34 $ 1.41 Add back goodwill amortization, net of tax — — 0.01
As adjusted $ 0.78 $ 1.34 $ 1.42
Cash and Cash Equivalents: Cash and cash equivalents include short-term cash investments with an original maturity of three months or less. At times, cash and cash equivalent balances may be in excess of federally insured limits. The Company’s cash and cash equivalents are held with financial institutions with high credit standings.
Interest: Interest is generally not capitalized for financial reporting purposes as such
procedurepolicy isusuallynot followedfor rate-making purposes.in Registrant’s ratemaking process. Interest expense is fully recovered through the regulatory process as incurred.59
Note 1 - Summary of Significant Accounting Policies (Continued)
Revenues: Revenues include amounts billed to customers for services provided and
an amount ofunbilledrevenuerevenues representing estimated amounts to be billed for usage from the last meter reading date to the end of the accounting period.Basic Earnings Per Common Share: Basic
Earningsearnings per Common Share are based upon the weighted average number of Common Shares outstanding and net income after deducting preferred dividend requirements.There are no dilutive securities. Accordingly, dilutedFully Diluted Earnings Per Common Share: Diluted earnings per
share is not calculated. Supply Cost Balancing Accounts: As permittedCommon Share are based upon the weighted average number of Common Shares including both outstanding and shares potentially issued in connection with stock options granted under Registrant’s 2000 Stock Incentive Plan, and net income after deducting preferred dividend requirements. At December 31, 2003, 2002 and 2001, there were 333,679, 237,610 and 135,970 options outstanding, respectively. Outstanding stock options issued by theCPUC,Registrantmaintains waterrepresent the only dilutive effect reflected in diluted weighted average shares outstanding. The difference between basic andelectric supply cost balancing accountsdiluted EPS is the effect of stock options that, under the treasury share method, give rise toaccount for under-collections and over-collections of revenues designed to recover such costs. Recoverability of such costs is recorded in income and charged to balancing accounts when such costs are incurred. The balancing accounts are reversed when such costs are recovered through rate adjustments. Registrant accrues interest on its supply cost balancing accounts at the rate prevailing for 90-day commercial paper.common stock equivalents.Debt
Issue ExpenseIssuance Costs and Redemption Premiums: Original debtissue expensesissuance costs are capitalized and amortized over the lives of the respective issues. Premiums paid on the early redemption of debt, which is reacquired through refunding, are deferred and amortized over the life of the debt issued to finance the refunding.The redemption premium on debt reacquired without refunding is amortized over the remaining period the debt would have been outstanding. 3639Other
Credits: AdvancesCredits and Liabilities: For SCW, advances for construction represent amounts advanced by developers, which are generally refundable ateither a rate ofrates ranging from 10% to 22% of the revenue received from the installations for which funds were advanced or in equal annual installments overaperiods of time ranging from 10 to 40-yearperiod.periods. Contributions-in-aid of construction are similar to advances, but require no refunding and are amortized over the useful lives of the related property.CashFor CCWC, advances for construction represent amounts advanced by developers which are refundable over 10 to 20 years. Refund amounts under the contracts are based on annual revenues from the extensions.In October 2003, Registrant entered into a Premium Finance Agreement with a third-party to finance the Company’s annual insurance premiums for the 2003-2004 policy year. Total amount financed was approximately $2.0 million and
Cash Equivalents: For purposesis payable in nine equal monthly installments beginning on November 1, 2003, and bears an annual interest rate of 2.4%. As of December 31, 2003, approximately $1.3 million remained outstanding under this agreement and has been included in “Other” current liabilities on the balance sheets.Derivative Instrument: Registrant has certain block-forward purchase power contracts that are subject to SFAS No. 133,“Accounting for Derivative Instruments and Hedging Activities", as amended by SFAS Nos. 138 and 149. A derivative financial instrument or other contract derives its value from another investment or designated benchmark. SFAS No. 133 requires companies to record derivatives on the balance sheet as assets and liabilities, and to measure those instruments at their fair value. Certain of these contracts qualify as an exception provided under the Statement for activities that are considered normal purchases and normal sales. These contracts are reflected in the statements of income at the time of contract settlement. This Statement, as amended, became effective for Registrant’s financial statements at the beginning of fiscal year 2001. This Statement did not have any impact on Registrant’s financial statements at the time of adoption.
During 2002, SCW became a party to block-forward purchase power contracts that qualify as derivative instruments under SFAS No. 133. Contracts with Pinnacle West Capital Corporation (PWCC) which became effective in November 2002 have not been designated as normal purchases and normal sales and, as a result, have been recognized at fair market value on the balance sheets as of December 31, 2003 and 2002. This resulted in a pre-tax unrealized gain of $638,000 and a pre-tax unrealized loss of $2.5 million in 2003 and 2002, respectively. On a quarterly basis, the related asset or liability is adjusted to reflect the fair market value at the end of the
Statementsquarter. As this contract is settled, the realized gains or losses will be recorded in power purchased for resale, and the unrealized gains or losses will be reversed. The market prices used to determine the fair value for this derivative instrument were estimated based on independent sources such as broker quotes and publications.60
Note 1 - Summary of
Cash Flows, cashSignificant Accounting Policies (Continued)Under the terms of its power purchase contracts with Mirant Americas Energy Marketing, LP (“Mirant Marketing”) and
cash equivalents include short-term cash investments with an original maturityPWCC, SCW is required to post security, at the request ofthree monthsthe seller, if SCW is in default under the terms of the contract and the future value of the contract is greater than the future value of contracts of a similar term on the date of default. SCW will be in default under the terms of these contracts if its debt is rated less than BBB- by Standard & Poor’s Ratings Service (“S&P”) orless. Financial Instrument Risk: RegistrantFitch, Inc. (“Fitch”) or less than Baa3 by Moody’s Investor Services, Inc (“Moody’s”). SCW currently has a rating of A+ by S & P and A2 by Moody’s. Fitch does notcarry anyrate SCW.Except as discussed above, Registrant has no other derivative financial instruments, financial instruments with off-balance sheet risk
nor does its operations result inor financial instruments with concentrations of credit risk.Fair Value of Financial Instruments: For cash and cash equivalents, accounts receivable, accounts payable and short-term debt, the carrying amount is assumed to approximate fair value due to the short-term nature of the amounts. The table below estimates the fair value of
each represented class of financial instrument. For cash and cash equivalents, accounts receivable and short-termlong-term debtthe carrying amount is used. Otherwise, ratesheld by Registrant. Rates available to Registrant at December 31,19992003 and19982002 for debt with similar terms and remaining maturities were used to estimate fair value for long-term debt. Changes in the assumptions will produce differing results.
1999 1998 ------------------------- ---------------------------- CARRYING AMOUNT FAIR VALUE Carrying
2003 2002 (dollars in thousands) Carrying Amount Fair Value Carrying Amount Fair Value Financial liabilities: Long-term debt–SCW $ 222,256 $ 269,081 $ 235,505 $ 280,877 Long-term debt-CCWC 8,363 8,305 8,889 8,779
Total AWR $ 230,619 $ 277,386 $ 244,394 $ 289,656
Stock Options: Registrant has a Stock Incentive Plan, which is described more fully in Note 10. Registrant applies Accounting Principles Board Opinion (APB) No. 25,“Accounting for Stock Issued to Employees", in accounting for its stock options which uses the intrinsic value method. Accordingly, no compensation expense for the Plan has been recognized for options granted at fair value at the date of grant. Registrant has also adopted the “disclosure-only” requirements of SFAS No. 123,“Accounting for Stock-Based Compensation". If Registrant had elected to adopt the optional recognition provisions of SFAS No. 123 for its stock options, net income and earnings per share applicable to common shareholders would have been changed to the pro forma amounts indicted below.
2003 2002 2001 As reported $ 11,892 $ 20,310 $ 21,372 Add: Stock-based compensation expense included in reported net income, net of tax — — — Less: Stock-based compensation expense determined under the fair-value accounting method, net of tax (288 ) (258 ) (139 )
Pro forma $ 11,604 $ 20,052 $ 21,233
As reported $ 0.78 $ 1.34 $ 1.41 Pro forma $ 0.76 $ 1.32 $ 1.40
As reported $ 0.78 $ 1.34 $ 1.41 Pro forma $ 0.76 $ 1.32 $ 1.40
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Note 1 - Summary of Significant Accounting Policies (Continued)
New Accounting Pronouncements: The following are recent accounting pronouncements that were adopted effective January 1, 2003 or will be effective in 2004:
- Effective January 1, 2003, Registrant adopted SFAS No. 143,“Accounting for Asset Retirement Obligations”, which requires businesses to record the fair value of a liability for an asset retirement obligation in the period in which it is incurred. When the liability is initially recorded, the entity capitalizes a cost by increasing the carrying amount
Fair value -------- --------- --------------- ---------- (dollars in thousands)Financial assets: Cash $ 2,189 $ 2,189 $ 620 $ 620 Accounts receivable 25,827 25,827 22,230 22,230 Financial liabilities: Short-term debt 21,000 21,000 38,000 38,000 Long-term debt $167,663 $161,843 $120,809 $135,092 -------- -------- -------- --------NOTE 2 - CAPITAL STOCK Allof theseriesrelated long-lived asset. Over time, the liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life ofPreferred Shares outstandingthe related asset. Upon settlement of the liability, an entity either settles the obligation for its recorded amount or incurs a gain or loss upon settlement. Registrant’s legal obligations for retirement reflect principally the retirement of wells, which by law need to be destroyed and filled at the time of removal. As such, the regulated subsidiaries of AWR incur asset retirement obligations. Retirement costs have historically been recovered through rates at the time of retirement. Accordingly, at implementation of SFAS No. 143, the cumulative effect has been reflected as a regulatory asset. Registrant will also reflect the gain or loss at settlement as a regulatory asset or liability on the balance sheet. With regards to other long-lived assets, such assets either have indefinite lives or there is no legal obligation to retire the asset.Upon adoption of SFAS No. 143 on January 1, 2003, Registrant recorded the fair value of the asset retirement obligation of $13.2 million at its net present value of $2.7 million, increased depreciable assets by $0.4 million for asset retirement costs, increased regulatory assets by $2.5 million and increased accumulated depreciation by $0.2 million. Amounts recorded under SFAS No. 143 are subject to various assumptions and determinations, such as determining whether a legal obligation exists to remove assets, and estimating the fair value of the costs of removal, when final removal will occur and the credit-adjusted risk-free interest rates to be utilized on discounting future liabilities. Changes that may arise over time with regard to these assumptions will change amounts recorded in the future. Estimating the fair value of the costs of removal were determined based on third party costs
The following is a reconciliation of the beginning and ending aggregate carrying amount of the asset retirement obligations (“ARO”) which is included in “Other Credits” on the balance sheets as of December 31, 2003 (in thousands):
Year Ended December 31, 2003 Balance at Adoption Liabilities Liabilities Balance At January 1, 2003 Incurred Settled Accretion December 31, 2003 ARO – SCW $ 2,700 $ 21 — $ 239 $ 2,960 ARO– CCWC 18 20 — 3 41
Total AWR $ 2,718 $ 41 — $ 242 $ 3,001
If SFAS No. 143 had been in place on January 1, 2002, Registrant’s ARO as of that date would not have differed significantly from amounts recorded as of January 1, 2003 upon adoption. If the standard had been applied retroactively for the years ended December 31, 2002 and 2001, it would not have had any impact on Registrant’s results of operations.
- SFAS No. 145, “Rescission of SFAS Nos. 4, 44, and 64, Amendment of SFAS No. 13, and Technical Corrections”: Among other things, SFAS No. 145 rescinds various pronouncements regarding early extinguishment of debt and allows extraordinary accounting treatment for early extinguishment only when the provisions of APB No. 30,“Reporting the Results of Operations – Reporting the Effects of Disposal of a Segment of Business, and Extraordinary, Unusual and Infrequently Occurring Events and Transactions”,are met. This Statement also amends SFAS No. 13 to require sale-leaseback accounting for certain lease modifications that have economic effects that are similar to sale-leaseback transactions. SFAS No. 145 provisions were effective for fiscal years beginning after May 15, 2002. The adoption of SFAS No. 145 did not have any impact on Registrant’s financial position, results of operations or cash flows.
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Note 1 - Summary of Significant Accounting Policies (Continued)
- SFAS No. 146, “Accounting for Costs Associated with Exit or Disposal Activities”: This Statement addresses significant issues regarding the recognition, measurement, and reporting of costs associated with exit or disposal activities, and supercedes Emerging Issues Task Force Issue No. 94-3,“Liability Recognition for Certain Employee Termination Benefits and Other Costs to Exit an Activity (including Certain Costs Incurred in a Restructuring).”Costs addressed by SFAS No. 146 include costs to terminate a contract that is not a capital lease, costs of involuntary employee termination benefits pursuant to a one-time benefit arrangement, costs to consolidate facilities, and costs to relocate employees. This Statement was effective for exit or disposal activities that were initiated after December 31, 2002. The adoption of SFAS No. 146 did not have an effect on Registrant’s financial position, results of operations or cash flows as Registrant did not exit, discontinue or restructure any of its operations. However, unknown at this time, the timing of expense recognition in Registrant’s financial statements for future restructuring, exit or disposal activities could differ significantly.
- SFAS No. 148, “Accounting for Stock-Based Compensation-Transition and Disclosure”:This Statement amends SFAS No. 123,“Accounting for Stock-Based Compensation,”to provide alternative methods of transition for a voluntary change to the fair value based method of accounting for stock-based employee compensation. In addition, SFAS No. 148 amends the disclosure requirements of SFAS No. 123 to require prominent disclosures in both annual and interim financial statements about the method of accounting for stock-based employee compensation and the effect of the method used on reported results. Although Registrant is required to comply with the requirements of SFAS No. 148 beginning January 1, 2003, the Company has elected to continue to apply the recognition and measurement provisions of APB No. 25. Therefore, SFAS No. 148 did not have any impact on Registrant’s financial position, results of operations or cash flows. Registrant adopted the “disclosure-only” requirements of SFAS No. 148, which are included in Note 1 above.
- In April 2003, the FASB issued SFAS No. 149,“Amendment of Statement 133 on Derivative Instruments and Hedging Activities”. This Statement amends and clarifies financial accounting and reporting for derivative instruments, including certain derivative instruments embedded in other contracts and for hedging activities under SFAS No. 133,“Accounting for Derivative Instruments and Hedging Activities”. This Statement is effective for contracts entered into or modified after June 30, 2003 and for hedging relationships designated after June 30, 2003. All provisions of this Statement will be applied prospectively. Registrant has not entered into or modified any contracts or designated any hedging relationships after June 30, 2003. This Statement also requires that any financing element of a derivative contract should be included in cash flows from financing activities in the Statement of Cash Flows. For the year ended December 31, 2003, Registrant has reflected in its Statement of Cash Flows approximately $1.8 million related to the financing portion of the purchased power contracts with PWCC.
- In June 2003, the FASB issued SFAS No. 150,“Accounting for Certain Financial Instruments with Characteristics of Both Liabilities and Equity”. This Statement specifies that instruments within its scope embody obligations of the issuer and that, therefore, the issuer must classify them as liabilities. This Statement was effective July 1, 2003. Registrant does not have any financial instruments with characteristics of both liabilities and equity.
- FASB Interpretation No. 45: “Guarantor’s Accounting and Disclosure Requirements for Guarantees, Including Indirect Guarantees of Indebtedness of Others”. This interpretation elaborates on the disclosures to be made by a guarantor in its interim and annual financial statements about its obligations under certain guarantees that it has issued and requires that they be recorded at fair value. The initial recognition and measurement provisions of this interpretation are to be applied only on a prospective basis to guarantees issued or modified after December 31, 2002. The adoption of FIN 45 did not have any impact on Registrant’s financial position, results of operations or cash flows.
- FASB Interpretation No. (FIN) 46, “Consolidation of Variable Interest Entities”– This interpretation expands upon existing guidance that addresses when a company should include in its financial statements the assets and liabilities of another entity. The primary objectives of FIN 46 are to provide guidance on the identification of entities for which control is achieved through means other than through voting rights (“variable interest entities”) and to determine when and which business enterprise should consolidate the variable interest entity (the “primary beneficiary”). FIN 46 requires that both the primary beneficiary and all other enterprises with a significant variable interest make additional disclosures. In December 2003, the FASB deliberated a partial deferral of and certain proposed modifications to FIN 46 to address certain implementation issues. The FASB decided that all of the proposed modifications will be incorporated directly into a revised FIN 46 (FIN 46-R), rather than into a new interpretation that amends FIN 46. FIN 46-R will incorporate much of the guidance previously issued in FIN 46. FIN 46 and FIN 46-R are effective by March 15, 2004. The adoption of FIN 46 and FIN 46-R is not expected to have a material impact on Registrant’s financial position, results of operations or cash flows.
63
Note 1 - Summary of Significant Accounting Policies (Continued)
-SFAS No. 132 (Revised), “Employers’ Disclosures About Pensions and Other Postretirement Benefits – An Amendment of FASB Statements Nos. 87, 88, and 106 and a revision of FASB Statement No. 132”: This statement revises employers’ disclosures about pension plans and other postretirement benefits plans. It does not change the measurement or recognition of those plans. The new disclosures were generally effective for 2003 calendar year-end financial statements. Registrant has included the new disclosures in Note 9.
Note 2 – Regulatory Matters
In accordance with accounting principles for rate-regulated enterprises, Registrant records regulatory assets, which represent probable future revenue associated with certain costs that will be recovered from customers through the rate-making process, and regulatory liabilities, which represent probable future reductions in revenue associated with amounts that are to be credited to customers through the rate-making process. Regulatory assets, less regulatory liabilities, included in the consolidated balance sheets are as follows:
As of December 31, (In thousands) 2003 2002 Supply cost balancing accounts $ 24,432 $ 27,470 Costs deferred for future recovery on Aerojet case 16,177 13,660 Flow-through taxes, net (Note 8) 10,690 10,817 Transmission line abandonment costs 5,000 — Asset retirement obligations 2,729 — Low income balancing accounts 1,462 993 Refund of water right lease revenues (6,177 ) — Revenues subject to refund (3,465 ) — Other regulatory assets 2,465 670
Total SCW $ 53,313 $ 53,610
Asset retirement obligations $ 40 $ — Other regulatory assets 40 40
Total AWR $ 53,393 $ 53,650
Supply Cost Balancing Accounts:
As permitted by the CPUC, SCW has historically maintained water supply balancing accounts prior to November 29, 2001 and electric supply balancing accounts to account for under-collections and over-collections of revenues designed to recover such costs. Costs are recorded in income and charged to balancing accounts when such costs are incurred. The balancing accounts are reversed when such costs are recovered through rate adjustments or through refunds of previously incurred costs. SCW accrues interest on its supply cost balancing accounts at the rate prevailing for 90-day commercial paper. CCWC does not maintain a supply cost balancing account.
Water Balancing Account –On November 29, 2001, the CPUC ordered water utilities with existing water supply balancing accounts to cease booking amounts to such accounts. In its place, water utilities are now required to establish a memorandum supply cost account. The over- or under-collection of water supply costs is recorded in this memorandum account in a manner similar to the balancing account. The income statements of SCW will no longer include entries reflecting differences between authorized water supply unit costs included in rates and actual water supply costs. As a result, any changes in water supply costs as well as any future authorized revenue increases for supply expenses may directly impact earnings.
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Note 2 – Regulatory Matters (Continued)
In a decision issued on June 19, 2003 related to the memorandum supply cost account, the CPUC concluded that (i) if a utility is within its 3-year rate case cycle and does not earn in excess of its authorized rate of return, the utility is entitled to recover its costs in the memorandum supply cost account, subject to a reasonableness review by the CPUC; (ii) if a utility is either within or outside of its rate case cycle and earns in excess of its authorized rate-of-return, the utility’s recovery of expenses from the memorandum supply cost account will be reduced by the amount exceeding the authorized rate-of-return, and (iii) a utility is required to seek review of under and over collections by filing an advice letter annually by March 31. Pursuant to the resolution, SCW filed advice letters on September 12, 2003 seeking recovery of an under-collected balance of $2.6 million for the period November 29, 2001 through December 31, 2002. Upon receiving approval from the CPUC, SCW will recognize the authorized under-collected amount as supply cost balancing accounts on its books. As of December 31, 2003, SCW has an under-collection of approximately $5.5 million in its memorandum supply cost account, including the $2.6 million filed with the CPUC. SCW intends to file advice letters annually by March 31. Amounts included in the memorandum supply cost account are not capitalized until a rate order is received from the CPUC.
With respect to pre-November 29, 2001 water supply balancing accounts, SCW has a net under-collection amount of $1.7 million recorded at December 31,
19992003, the majority of which has been included in rates authorized on June 19, 2003.Electric Balancing Account– Electric power costs incurred by SCW’s Bear Valley Electric division continue to be charged to its electric supply cost balancing account. The under-collection in the electric balancing account is $22.7 million at December 31, 2003. The CPUC has authorized SCW to collect a surcharge from its customers of 2.2¢ per kilowatt hour through August 2011, to enable SCW to recover the under-collection. SCW sold 132,849,639, 131,826,314 and 126,910,985 kilowatt hours of electricity to its Bear Valley Electric division customers for the years ended December 31, 2003, 2002 and 2001, respectively. SCW anticipates electricity sales to be sufficient during this period for it to recover the amount of the under-collection. SCW is allowed to include only up to a weighted annual energy purchase cost of $77 per MWh each year through August 2011 in its electric supply cost balancing account. To the extent that actual weighted average annual cost for power purchased exceeds the $77 per MWh amount, SCW will not be able to include these amounts in its balancing account and such amounts will be expensed. During the years ended December 31, 2003 and 2002, approximately $240,000 and $718,000, respectively, were expensed.
CCWC, subject to regulation by the ACC, does not maintain balancing accounts and increases in costs are
redeemablenormally expensed as incurred and recovered through adjustments in general rate case applications.Costs Deferred for Future Recovery:
As discussed in Note 12, SCW sued Aerojet-General Corporation (“Aerojet”) for causing the contamination of the Sacramento County Groundwater Basin servicing SCW wells. On a related matter, SCW also filed a lawsuit against the State of California. The CPUC authorized memorandum accounts to allow for recovery, from customers, of costs incurred by SCW in prosecuting the cases against Aerojet and the State, less any recovery from the defendants or others. As of December 31, 2003 and 2002, approximately $16.2 million and $13.7 million, respectively, has been recorded as a non-yielding regulatory asset representing primarily legal costs incurred to date in connection with prosecuting the cases. At this time, management believes these costs are recoverable either through rates or a settlement agreement with Aerojet, but cannot give assurance that the CPUC will ultimately allow recovery of all or any of these costs.
Transmission Line Abandonment Costs:
The ability of SCW to deliver purchased power to customers in its Bear Valley Electric service area is limited by the ability of the transmission facilities owned by Southern California Edison Company (Edison) to transmit this power. As more fully discussed in Note 11, SCW filed a lawsuit against Edison in 2000 for breach of contract as a result of delays in upgrading these transmission facilities as well as for other reasons. A settlement has been reached between SCW and Edison, in which SCW is to pay a $5 million project abandonment fee to Edison. Edison will then file an application to the FERC for approval of the entire $5 million settlement payment as abandoned project costs to be included in Edison’s wholesale rate charged to SCW over a 15 year period which will be recovered through the supply cost balancing account. Management believes that the FERC’s approval of Edison’s filing is probable and the abandonment costs included in Edison’s wholesale rate to SCW are recoverable through rates. As a result, the $5 million obligation to Edison arising from the settlement was recorded as a regulatory asset during the fourth quarter of 2003.
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Note 2 – Regulatory Matters (Continued)
Asset Retirement Obligations:
As more fully discussed in Note 1, effective January 1, 2003, Registrant adopted SFAS No. 143,“Accounting for Asset Retirement Obligations”.Because retirement costs have historically been recovered through rates at the time of retirement, at implementation of SFAS No. 143, the cumulative effect has been reflected as a regulatory asset. Registrant will also reflect the gain or loss at settlement as a regulatory asset or liability on the balance sheet.
Low Income Balancing Accounts:
This regulatory asset reflects primarily the costs of implementing the California Alternate Rates for Water (“CARW”) program in SCW’s Region II and Region III to date. This program mandated by the CPUC provides a 15% discount for qualified low-income individuals. The low income balancing account was established in May 2002 to track all the discounts and costs related to this program for future recovery in rates. The Company anticipates the discounts for low income families will eventually be incorporated in SCW’s base rates to customers.
Refund of Water Right Lease Revenues:
In 1994, SCW entered into a contract to lease to the City of Folsom, 5,000 acre-feet per year of water rights to the American River, and has included all associated revenues in a non-operating income account. The issue was raised by the Office of Ratepayer Advocates (“ORA”) in SCW’s Region III proceedings. In a decision issued on March 16, 2004, the CPUC determined that SCW failed to seek the CPUC’s approval to effectuate the lease and is to pay a fine of $180,000. The decision also ordered SCW to refund 70 percent of the total amount of lease revenues received since 1994, plus interest, to customers. Pursuant to the order, SCW recorded a $6.2 million regulatory liability with a corresponding charge against non-operating income (less $2.5 million of taxes) during the fourth quarter of 2003. Management disagrees with the CPUC’s decision and intends to file an appeal to the decision in which it will vigorously defend its position.
Revenues Subject to Refund:
Registrant recorded a $3.5 million pre-tax charge to earnings in the fourth quarter of 2003 to reflect a Proposed Decision issued by the CPUC. As required by the Proposed Decision issued by the CPUC on December 19, 2003, SCW will be required to refund to customers approximately $3.5 million in net proceeds received from potentially responsible parties since 1998 for the contamination of the Company’s groundwater supply. Management believes the refund is probable and as a result, SCW established a regulatory liability as of December 31, 2003.
Changes in Rates:
Step increases of approximately $321,600 for four of seven ratemaking districts in SCW’s Region I were implemented in January 2002. Region I also received attrition increases of $219,400 effective January 2003.
On January 16, 2003, the CPUC approved rate increases of approximately $2.7 million annually, effective January 22, 2003, in SCW’s Metropolitan district to recover costs associated with an increase in Region II rate base associated with SCW’s 2002 infrastructure replacement program and, additionally, to recover general increases in operating expenses. On January 31, 2003, the CPUC also approved SCW’s Advice Letter filed for the Region II 2003 infrastructure replacement program with rate increases of $3.5 million annually, effective February 4, 2003.
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Note 2 – Regulatory Matters (Continued)
On August 17, 2001, SCW filed an application with the CPUC seeking recovery of an average cost of $87 per megawatt hour (MWh) for electric energy purchased pursuant to power purchase contracts with Mirant Marketing and PWCC. On July 17, 2002, CPUC approved a settlement agreement reached among SCW, all intervening parties and the Office of Ratepayer Advocates. As discussed earlier, the authorization permits SCW to recover $77 per MWh of purchased power costs through rates. SCW is allowed to include its actual purchased power costs up to an average annual weighted cost of $77 per MWh each year, through August 2011, in its balancing account. To the extent SCW’s actual average annual weighted cost for purchased power is less than $77 per MWh, the differential would offset amounts included in the electric supply balancing account. Conversely, to the extent that actual average annual weighted costs for power purchased exceed the $77 per MWh amount, SCW would not be able to include these amounts in its balancing account and such amounts would be expensed against income.
In October 2002, SCW filed an application to increase water rates in the customer service areas that comprise Region III. SCW also filed a concurrent application requesting a rate increase applicable to SCW’s entire customer base to recover costs associated with the general office functions of SCW. On March 16, 2004, the CPUC issued its decision under which the new approved water rates will generate an initial annual increase in revenues of approximately $8.9 million.
Note 3 – Utility Plant
The following table shows Registrant’s utility plant by major class (in thousands):
SCW AWR December 31, December 31, 2003 2002 2003 2002 Land $ 8,998 $ 7,909 $ 9,270 $ 8,181 Source of water supply 37,099 33,288 40,564 36,746 Pumping 84,819 82,058 86,142 83,299 Water treatment 30,794 26,478 36,472 32,079 Transmission and distribution 450,279 434,611 476,863 460,512 General 76,090 71,987 77,500 73,132
688,079 656,331 726,811 693,949
Transmission and distribution 38,089 36,846 38,089 36,846 General 4,622 4,171 4,622 4,171
42,711 41,017 42,711 41,017 Less - accumulated depreciation (211,424 ) (196,660 ) (222,567 ) (206,873 ) Construction work in progress 51,354 33,705 55,343 35,218
Net utility plant $ 570,720 $ 534,393 $ 602,298 $ 563,311
Note 4 - Capital Stock
During the 2003 Annual Meeting of shareholders held on May 20, 2003, shareholders approved the elimination of all references to stated value in the Company’s Articles of Incorporation. As a result, a reclassification adjustment of $101.6 million was made that eliminated Registrant’s additional paid-in capital.
All Preferred Shares, including the 4%, 41/4% and 5% Series, were fully redeemed at the option of
Registrant.AWR during 2002. At December 31,1999, the2003 and 2002, there were no Preferred Shares outstanding. The redemption price per share for each series of $25 Preferred Shares was $27.00, $26.50 and $25.25 for the 4%,4 1/41/4% and 5% Series,respectively. To each of the redemption prices must be addedrespectively, plus accrued and unpaid dividends to the redemption date.The $2567
Note 4 - Capital Stock (Continued)
On June 7, 2002, Registrant completed a 3-for-2 stock split of Common Shares for the holders of record on May 15, 2002. Earnings per share and number of shares have been retroactively restated for all periods presented to reflect the stock split.
AWR has a Registration Statement on file with the Securities and Exchange Commission for issuance, from time to time, of up to $60 million in aggregate in Common Shares, Preferred Shares
5% Series, are subject to mandatory redemption provisionsand/or debt securities. As of1,600 shares per year. The annual aggregate mandatory redemption requirements for this Series for the five years subsequent toDecember 31,1999 is $40,000 each year. In 1996, Registrant issued 1,000,000 Common Shares through a secondary public offering. In January 1997, Registrant issued 71,500 Common Shares through a secondary public offering. The net proceeds from2003, approximately $31,080,000 remained for issuance under thissale were used to repay a portion of short-term debt then outstanding. ForRegistration Statement.During the
yearsyear ended December 31,1999, December 31, 19982003, Registrant issued 14,295 andDecember 31, 1997, all shares issued14,735 Common Shares underRegistrant'sthe Registrant’s Common Share Purchase and Dividend Reinvestment Plan (DRP) andthe401(k) Plan,were purchased on the open market.respectively. There are500,000695,084 and571,40849,171 Common Sharesreserved for issuanceauthorized but unissued under the DRP and the 401(k) Plan, respectively, at December 31,1999.2003. Shares reserved for the 401(k) Plan are in relation tocompanyCompany matching contributions and for investment purposes by participants.As ofDuring the year ended December 31,1999 there2002, Registrant issued 30,180 and 31,211 Common Shares under the Registrant’s DRP and 401(k) Plan, respectively. For the year ended December 31, 2001, all shares issued under Registrant’s DRP and the 401(k) Plan wereno retained earnings restricted, under any of Registrant's debt instruments, as topurchased on thepayment of cash dividends on Common Shares. 3740open market.In 1998, the
boardBoard ofdirectorsDirectors adopted a Shareholder Rights Plan (Rights Plan) and authorized a dividend distribution of one right (a Right) to purchase 1/1000th1000th of Junior Participating Preferred Share for each outstanding Common Share. The Rights Plan became effective in September 1998 and will expire in September 2008. The Rights Plan is designed to provideshareholders'shareholders’ protection and to maximize shareholder value by encouraging a prospective acquirer to negotiate with theboard.Board of Directors.Each Right represents a right to purchase 1/
1000th1000th of Junior Participating Preferred Share at the price of $120, subject to adjustment (the Purchase Price). Each Junior Participating Preferred Share is entitled to receive a dividend equal to 1000 times any dividend paid on each Common Share and 100 votes per share in any shareholder election. The Rights become exercisable upon occurrence of a DistributionDate.Date event. A Distribution Date event occurs if (i) any person accumulates 15% of the then outstanding Common Shares, (ii) any person presents a tender offer which caused theperson'sperson’s ownership level to exceed 15% and the board determines the tender offer not to be fair toAWR'sAWR’s shareholders, or (iii) the board determines that a shareholder maintaining a 15% interest in the CommonsharesShares could have an adverse impact on AWR or could attempt to pressure AWR to repurchase theholder'sholder’s shares at a premium.Until the occurrence of a Distribution Date, each Right trades with the Common Share and is not separately transferable. When a Distribution Date occurs, AWR would distribute separately Rights Certificates to Common
Shareholders and theShareholders. The Rights would subsequently tradeseparateseparately from the Common Shares and each holder of a Right, other than the acquiring person whose Rights will thereafter be void, will have the right to receive upon exercise at its then current Purchase Price that number of Common Shares having a market value of two times the Purchase Price of the Right. If AWR merges into the acquiring person or enters into any transaction that unfairly favors the acquiring person or disfavorsAWR'sAWR’s other shareholders, the Right becomes a right to purchase Common Shares of the acquiring person having a market value of two times the Purchase Price.The
boardBoard ofdirectorsDirectors may determine that, in certain circumstances, a proposal, which would cause aDistribution Datedistribution of the Rights, is in the best interest ofAWR'sAWR’s shareholders. Therefore, theboardBoard ofdirectorsDirectors may, at its option, redeem the Rights at a redemption price of $0.01 per Right.NOTENote 5 – Dividend Limitations
On February 3,
- COMPENSATING BALANCES AND BANK DEBT At2004, AWR declared a regular quarterly dividend of $0.221 per common share. The dividend, totaling approximately $3.4 million, was paid on March 1, 2004 to common shareholders of record at the close of business on February 9, 2004. In 2003, 2002 and 2001, AWR paid quarterly dividends to the shareholders, totaling approximately $13.4 million or $0.884 per share, $13.2 million or $0.872 per share, and $13.1 million or $0.867 per share, respectively. AWR’s ability to pay cash dividends on common stock outstanding depends primarily upon cash flows from its SCW subsidiary.68
Note 5 – Dividend Limitations
SCW is subject to contractual restrictions on its ability to pay dividends. SCW’s maximum ability to pay dividends is restricted by certain Note Agreements to the sum of $21 million plus 100% of consolidated net income plus the aggregate net cash proceeds received from capital stock offerings or other instruments convertible into capital stock from various dates. Under the most restrictive of the Note Agreements, $154.9 million was available to pay dividends to AWR as of December 31,
1999, SCW maintained $47 million in aggregate borrowing capacity with three commercial banks with no compensating balances required. Of this amount, $21 million was outstanding at year-end. Loans can be obtained at the option of SCW and bear interest at rates based on floating prime borrowing rates or at money market rates. Short-term borrowing activities for the last three years were as follows:
December 31, --------------------------------------- 1999 1998 1997 ------- ------- ------- (in thousands, except percent)Balance Outstanding at December 31, $21,000 $38,000 $26,000 Interest Rate at December 31, 7.35% 5.86% 6.39% Average Amount Outstanding 8,775 19,309 $15,678 Weighted Average Annual Interest Rate 5.11% 6.78% 6.27% Maximum Amount Outstanding $21,000 $39,000 $32,000 ------- ------- -------3841 NOTE 4 - LONG TERM DEBT In March 1998, SCW sold the remaining $15 million under its Series B Medium Term Note Program and in December 1998, SCW redeemed all of its outstanding 10.10% Notes. In January 1999, $40 million of Series C Medium Term Notes were sold. The funds were used initially to repay short-term bank borrowings and, after that, to fund construction expenditures. Registrant has no mortgage debt, and leases and other similar financial arrangements are not material. SCW has posted an Irrevocable Letter of Credit, which expires July 31, 2000,2003. Dividends in the amount of$646,631$15,400,000, $14,630,000 and $13,530,000, were paid to AWR by SCW in 2003, 2002 and 2001, respectively.The ability of AWR, ASUS and SCW to pay dividends is also restricted by California law. Under restrictions of the California tests, approximately $84.8 million of retained earnings for AWR was available to pay dividends to Common Shareholders at December 31, 2003. Approximately $82.7 million was available from the retained earnings of SCW to pay dividends to AWR. At December 31, 2003, ASUS was not allowed to pay dividends to AWR under the California tests.
CCWC is subject to contractual restrictions on its ability to pay dividends. CCWC’s maximum ability to distribute dividends is limited to the maintenance of no more than 55% debt in the capital structure for the quarter immediately preceding the distribution. The ability of CCWC to pay dividends is also restricted by Arizona law. Under restrictions of the Arizona tests, approximately $4.4 million was available to pay dividends to AWR at December 31, 2003. Dividends in an amount of $1,003,000 were paid to AWR in 2001 by CCWC. There were no dividends distributed from CCWC to AWR in 2003 or 2002.
Note 6 - Bank Debt
AWR paid off a $25 million non-revolving credit facility on January 2, 2002. In June 2002, AWR established a new $75 million syndicated credit facility. Under the terms of this facility, either AWR or SCW may obtain letters of credit for up to an aggregate of $15 million. At December 31, 2003, $56 million in cash borrowings was outstanding under this facility, $19 million of which was used to fund AWR’s activities, $34 million was used to fund SCW’s operations and is included in inter-company payables on SCW’s balance sheets as
security for its self-insured workers' compensation plan.of December 31, 2003, and $3.0 million was used to fund ASUS activities. Additionally, SCW hasalso provided an Irrevocable Letterobtained letters ofCredit,credit, in the amount of $7,481,000 in aggregate, including (1) a letter of credit with a fee of 0.625%, which expiresNovember 14, 2000,February 6, 2005, in the amount of $6,296,000 to a trustee with respect to the variable rate obligation issued by the Three Valleys Municipal WaterDistrict.District, (2) a letter of credit with an annual fee of 0.625%, which expires on October 1, 2004, in the amount of $600,000 as security for the deductible in the Company’s business automobile insurance policy, and (3) a letter of credit with a fee of 0.625%, which expires March 31, 2005 in an amount, which varies from $270,000 to $585,000 during the year as security for the purchase of power. There were no compensating balances required. Loans can be obtained at the option of Registrant and bear interest at rates based on credit ratings and Euro rate margins.Registrant’s short-term borrowing activities (excluding Letters of Credit) for the last three years were as follows:
December 31, (in thousands, except percent) 2003 2002 2001 Balance Outstanding at December 31, $ 56,000 $ 35,000 $ 20,000 Interest Rate at December 31, 1.78 % 2.16 % 2.82 % Average Amount Outstanding $ 34,638 $ 6,811 $ 34,748 Weighted Average Annual Interest Rate 1.84 % 2.49 % 4.65 % Maximum Amount Outstanding $ 56,000 $ 35,000 $ 50,000
There were no short-term borrowing activities at CCWC.
69
Note 7 – Long-Term Debt
Registrant’s long-term debt consists primarily of Notes and Debentures. The Company summarizes its long-term debt in the Statements of Capitalization. No new long-term debt was issued in 2003 and 2002. In October 2003, the 5.82% Notes totaling $12,500,000 matured. Proceeds from short-term bank borrowings were used to repay the Notes. SCW has no mortgage debt, and leases and other similar financial arrangements are not material. Redemption of certain of the long-term debt issues outstanding as of December 31, 2003 and 2002 can be made in whole or in part at the option of SCW subject to redemption schedules embedded in the agreements particular to each issue. With the exception of the 9.56% Notes, the redemption premiums in effect for 2003 range up to 7% of par value. The 9.56% Notes are subject to a make-whole premium based on 55 basis points above the applicable Treasury Yield if redeemed prior to 2021. After 2021, the maximum redemption premium is 3% of par value.
CCWC has long-term Industrial Development Authority Bonds (IDA Bonds) and a repayment contract due 2006. Substantially all of the utility plant of CCWC is pledged as collateral for its IDA Bonds. The Bond Agreement, among other things, (i) requires CCWC to maintain certain financial ratios, (ii) restricts CCWC’s ability to incur additional debt, make liens, sell, lease or dispose of assets, merge with another corporation, and pay dividends, and (iii) requires CCWC to establish a debt service reserve fund held in trust for future payments, which totaled $655,760 and $658,774 as of December 31, 2003 and 2002, respectively.
AWR - - Annual maturities of all long-term debt, including capitalized leases, amount to
$303,356, $231,559, $246,528, $262,036approximately $820,000, $887,000, $646,000, $608,000, $620,000 and$278,644$227,038,000 for the five years ending December 31,20002004 through 2008 and thereafter, respectively.SCW - - Annual maturities of all long-term debt, including capitalized leases, amount to approximately $260,000, $289,000, $305,000, $328,000, $320,000 and $220,754,000 for the five years ending December 31, 2004 through 2008 and thereafter, respectively.
NOTE 570
Note 8 -
TAXES ON INCOMETaxes on IncomeRegistrant provides deferred income taxes for temporary differences under
Statement of Financial Accounting StandardsSFAS No. 109,"Accounting“Accounting for IncomeTaxes" (SFAS No. 109),Taxes,”for certain transactions which are recognized for income tax purposes in a period different from that in which they are reported in the financial statements. The most significant items are the tax effects of accelerated depreciation, the supply cost balancing accounts and advances for, andcontributions-in-aid-of-construction.contributions-in-aid-of-, construction. SFAS No. 109 also requires that rate-regulated enterprises record deferred income taxes for temporary differences accorded flow-through treatment at the direction of a regulatory commission. The resulting deferred tax assets and liabilities are recorded at the expected cash flow to be reflected in future rates.SinceGiven that the CPUC has consistently permitted the recovery ofpreviouslyflowed-through tax effects, SCW has established regulatory liabilities and assets offsetting such deferred tax assets andliabilities.liabilities (Note 2). Deferred investment tax credits arebeingamortized ratably toother income ratablythe nonoperating deferred tax provision over the lives of the property giving rise to the credits.The significant components of the deferred tax assets and
deferred taxliabilities as reflected in the balance sheetsand the accumulated net deferred income tax liabilitiesat December 31,19992003 and19982002 were:
December 31, ------------------------- 1999 1998 -------- -------- (dollars in thousands)Deferred tax assets: Balancing accounts $ (175) $ 33 State tax effect 5,721 5,123 -------- -------- 5,546 5,156 -------- -------- Deferred tax liabilities Depreciation (44,939) (43,442) Advances and contributions 15,862 16,694 Other property related (10,007) (11,488) Other non-property related (9,218) (8,666) -------- -------- (48,302) (46,902) -------- -------- Accumulated deferred income taxes - net $(42,756) $(41,746) -------- --------3942
AWR SWC December 31, December 31, (dollars in thousands) 2003 2002 2003 2002 Deferred tax assets: Regulatory-liability-related: ITC and excess deferred taxes $ 2,088 $ 2,054 $ 2,088 $ 2,054 Accrued regulatory liabilities 3,929 — 3,929 — Unrealized loss 771 863 771 863 Contributions and advances 9,575 9,076 9,945 9,446 California state tax 975 1,970 1,158 2,091
$ 17,338 $ 13,963 $ 17,891 $ 14,454
Deferred tax liabilities: Fixed assets $ (42,555 ) $ (38,818 ) $ (41,049 ) $ (37,359 ) Regulatory-asset-related: depreciation and other (12,778 ) (12,828 ) (12,778 ) (12,828 ) Other property related (957 ) (779 ) (957 ) (778 ) Other nonproperty related (1,136 ) (736 ) (69 ) (65 ) Balancing accounts (10,554 ) (11,679 ) (10,554 ) (11,679 ) Deferred charges (3,818 ) (2,940 ) (3,818 ) (2,940 )
(71,798 ) (67,780 ) (69,225 ) (65,649 )
Accumulated deferred income taxes - net $ (54,460 ) $ (53,817 ) $ (51,334 ) $ (51,195 )
The current and deferred components of income tax expense were as follows:
AWR Year Ended December 31, (dollars in thousands) 2003 2002 2001 Current Federal $ 3,285 $ 6,709 $ 4,569 State 2,785 1,769 1,387
Total current tax expense 6,070 $ 8,478 $ 5,956
Deferred – Federal and State: Accelerated depreciation 4,935 4,509 3,335 Balancing accounts (1,125 ) 1,156 6,436 California privilege year franchise tax 995 (1,128 ) (1,015 ) Accrued regulatory liabilities (3,929 ) — — Other (194 ) 207 (657 )
Total deferred tax expense 682 $ 4,744 $ 8,099
Total income tax expense $ 6,752 $ 13,222 $ 14,055
Income taxes included in operating expenses $ 9,167 $ 12,949 $ 14,370 Income taxes included in other income and expenses – net (2,415 ) 273 (315 )
Total income tax expense $ 6,752 $ 13,222 $ 14,055
71
Note 8 - Taxes on Income (Continued)
SCW Year Ended December 31, (dollars in thousands) 2003 2002 2001 Current Federal $ 4,846 $ 8,085 $ 4,337 State 3,225 2,092 1,303
Total current tax expense 8,071 $ 10,177 $ 5,640
Deferred – Federal and State: Accelerated depreciation 4,769 4,409 3,230 Balancing accounts (1,125 ) 1,156 6,436 California privilege year franchise tax 933 (1,176 ) (985 ) Accrued regulatory liabilities (3,929 ) — — Other (470 ) (706 ) (650 )
Total deferred tax expense 178 $ 3,683 $ 8,031
Total income tax expense $ 8,249 $ 13,860 $ 13,671
Income taxes included in operating expenses $ 10,674 $ 13,605 $ 14,057 Income taxes included in other income and expenses – net (2,425 ) 255 (386 )
Total income tax expense $ 8,249 $ 13,860 $ 13,671
The reconciliations of the effective tax rates to the federal statutory rate are as follows:
December 31, ------------------------------------------ 1999 1998 1997 -------- -------- -------- (dollars in thousands)Current Federal $ 9,360 $ 5,219 $ 7,205 State 2,799 1,727 2,287 -------- -------- -------- Total current tax expense 12,159 6,946 9,492 -------- -------- -------- Deferred - Federal and State: Accelerated depreciation 3,405 3,319 2,996 Balancing accounts (207) 6 (871) Advances and contributions -- -- (210) California privilege year franchise tax (970) (544) (617) Other (664) (398) (566) -------- -------- -------- Total deferred tax expense 1,564 2,383 732 -------- -------- -------- Total income tax expense 13,723 9,329 10,224 -------- -------- -------- Income taxes included in operating expenses 13,345 10,130 9,830 Income taxes included in other income and expenses - net 378 (801) 394 -------- -------- -------- Total income tax expense $ 13,723 $ 9,329 $ 10,224 -------- -------- --------Additional information regarding taxes on income is set forth in the following table:
December 31, ------------------------------------------ 1999 1998 1997 -------- -------- -------- (dollars in thousands, except percent)Federal taxes on pre-tax income at statutory rates $ 10,438 $ 8,470 $ 8,451 Increase (decrease) in taxes resulting from: State income tax expense 2,605 1,654 1,864 Depreciation 1,184 944 853 Federal benefit of state taxes (912) (579) (652) Adjustments to prior years' provisions 433 (97) (143) Payment of premium on redemption 66 (813) -- Other - net (91) (250) (149) -------- -------- -------- Total income tax expense $ 13,723 $ 9,329 $ 10,224 -------- -------- -------- Pre-tax income $ 29,824 $ 23,952 $ 24,145 -------- -------- -------- Effective income tax rate 46.0% 38.9% 42.3% -------- -------- --------NOTE 6
AWR Year Ended December 31, (dollars in thousands, except percent) 2003 2002 2001 Federal taxes on pre-tax income at statutory rate $ 6,525 $ 11,746 $ 12,426 Increase (decrease) in taxes resulting from: State income tax, net of federal benefit 1,000 1,859 1,885 Flow through on fixed assets (94 ) 169 166 Investment tax credit (91 ) (91 ) (91 ) Other – net (588 ) (461 ) (331 )
Total income tax expense $ 6,752 $ 13,222 $ 14,055
Pre-tax income 18,644 $ 33,561 $ 35,511
Effective income tax rate 36.2 % 39.4 % 39.6 %
SCW Year Ended December 31, (dollars in thousands, except percent) 2003 2002 2001 Federal taxes on pre-tax income at statutory rate $ 7,747 $ 12,278 $ 12,078 Increase (decrease) in taxes resulting from: State income tax, net of federal benefit 1,299 1,949 1,737 Flow through on fixed assets (94 ) 169 166 Investment tax credit (91 ) (91 ) (91 ) Other – net (612 ) (445 ) (219 )
Total income tax expense $ 8,249 $ 13,860 $ 13,671
Pre-tax income 22,134 $ 35,080 $ 34,509
Effective income tax rate 37.3 % 39.5 % 39.6 %
72
Note 9 -
EMPLOYEE BENEFIT PLANSEmployee Benefit PlansPension and Postretirement Plans:
Registrant maintains a pension plan (the
Plan) which“Plan”) that provides eligible employees (thoseageaged 21 and older, with one year of service) monthly benefits upon retirement based on average salaries and length of service. The normal retirement benefit is equal to 2% of the five highest consecutive years average earnings multiplied by the number of years of credited service, up to a maximum of 40 years, reduced by a percentage of primary social security benefits. There is also an early retirementoption.option; however, for terminations on or after January 1, 2004, the early retirement provisions changed increasing benefits under the Plan for employees who retire prior to age 65. The eligibility requirements for early retirement are age 55 and 5 years of vesting service. This Plan amendment is expected to increase Registrant’s annual pension cost by approximately 5%. Annual contributions are made to the Plan, which comply with the funding requirements of the Employee Retirement Income Security Act (ERISA).At December 31, 1999, Registrant had 713 participants in the Plan, 54 of these are employees covered by collective bargaining agreements, the earliest of which expires in 2001.Registrant also provides all active employees medical, dental and vision care benefits through a medical insurance
plan.plan (“Other Postretirement Benefits”). Eligible employees, who retired prior to age 65, and/or their spouses, were able to retain the benefits under the active plan until reaching age 65. Eligible employees upon reaching age 65,4043and those employees retiring at or after age 65, and/or their spouses, receive coverage through a Medicare supplement insurance policy paid for by Registrant subject to an annual cap limit. Registrant’s postretirement medical plan does not provide prescription drug benefits to Medicare-eligible employees and is not affected by the Medicare Prescription Drug Improvement and Modernization Act of 2003.The CPUC
hasissued a decision, which provides for the recovery in rates of tax-deductible contributions made to aseparately trusteedseparate trust fund. In accordance with that decision,SCWRegistrant established two separate trusts in 1995, one for those retirees who were subject to a collective bargaining agreement and another for all other retirees.Registrant'sRegistrant’s funding policy is to contribute annually an amount at least equal to the revenues authorized to be collected through rates forpost-retirementpostretirement benefit costs.Post-retirementPostretirement benefit costs for 1993, 1994 and 1995 were estimated at a total of $1.6 million and have been recorded as a regulatory asset for recovery over a20 year20-year period. The unamortized balance at December 31,19992003 and 2002 wasapproximately $610,000.$324,852 and $386,676, respectively.At December 31, 2003, Registrant had 782 participants in the Plan, 73 of these are employees covered by collective bargaining agreements. One collective bargaining agreement expires in 2004 and one should have expired in 2002, but has been extended by mutual consent of the parties involved until a new contract is ratified.
At December 31, 2003, the accumulated benefit obligation of the Plan exceeded the related plan assets at the measurement date. In accordance with accounting standards, Registrant’s balance sheets include an additional minimum liability, with a corresponding charge to an intangible asset. The following table sets forth the
Plan'sPlan’s funded status and amounts recognized inRegistrant'sRegistrant’s balance sheets and the components of net pension cost and accruedpost-retirementpostretirement liability at December 31,19992003 and1998:2002:73
Note 9 - Employee Benefit Plans (Continued)
Other Postretirement Pension Benefits Benefits (dollars in thousands) 2003 2002 2003 2002 Benefit Obligation at beginning of year $ 49,073 $ 43,830 $ 8,160 $ 4,939 Service Cost 2,180 2,091 347 294 Interest Cost 3,200 3,061 556 507 Actuarial Loss/(Gain) 4,859 1,797 851 2,703 Plan Amendment 1,377 — — — Benefits Paid (1,770 ) (1,706 ) (291 ) (283 )
Benefit Obligation at end of year $ 58,919 $ 49,073 $ 9,623 $ 8,160
Fair Value of Plan Assets at beginning of year $ 39,758 $ 42,004 $ 2,682 $ 2,192 Actual Return of Plan Assets 6,195 (2,058 ) 22 32 Employer Contributions * 2,494 1,518 885 741 Benefits Paid (1,770 ) (1,706 ) (291 ) (283 )
Fair Value of Plan Assets at end of year $ 46,677 $ 39,758 $ 3,298 $ 2,682
* Registrant expects to contribute $2,676,000 and $865,000 to pension and postretirement plans in 2004, respectively. Funded Status ($ 12,242 ) ($ 9,315 ) ($ 6,325 ) ($ 5,478 ) Unrecognized Transition Obligation — — 4,610 5,030 Unrecognized Net Loss/(Gain) 10,458 9,358 2,584 1,627 Unrecognized Prior Service Cost 1,646 320 (2,429 ) (2,629 )
Prepaid/(Accrued) Pension Cost ($ 138 ) $ 363 ($ 1,560 ) ($ 1,450 )
Prepaid benefit cost — $ 363 — — Accrued benefit liability ($ 1,208 ) — ($ 1,560 ) ($ 1,450 ) Intangible assets 1,070 — N/A N/A Accumulated other comprehensive income — — N/A N/A
Net amount recognized ($ 138 ) $ 363 ($ 1,560 ) ($ 1,450 )
Projected benefit obligation $ 58,919 $ 49,073 $ 9,623 $ 8,159 Accumulated benefit obligation 47,886 39,126 N/A N/A Fair value of plan assets 46,677 39,758 3,298 2,682 Discount rate 6.25 % 6.75 % 6.25 % 6.75 % Rate of compensation increase 4.00 % 4.00 % N/A N/A 74
Note 9 - Employee Benefit Plans (Continued)
The components of net periodic pension and postretirement benefits cost for 2003, 2002, 2001 are as follows:
Other Postretirement Pension Benefits Benefits (dollars in thousands) 2003 2002 2001 2003 2002 2001 Service Cost $ 2,180 $ 2,091 $ 1,868 $ 347 $ 294 $ 115 Interest Cost 3,200 3,061 2,877 556 507 335 Expected Return on Plan Assets (2,715 ) (3,365 ) (3,548 ) (209 ) (196 ) (177 ) Amortization of Transition — — — 419 419 419 Amortization of Prior Service Cost 52 52 44 (199 ) (199 ) (199 ) Amortization of Actuarial (gain) loss 278 — — 81 22 (72 )
Net Periodic Pension Cost $ 2,995 $ 1,839 $ 1,241 $ 995 $ 847 $ 421
Discount Rate 6.75 % 7.25 % 7.25 % 6.75 % 7.25 % 7.25 % Expected long-term return on Plan assets 7.00 % 8.00 % 8.00 % * * * Rate of compensation increase 4.00 % 4.00 % 4.00 % N/A N/A N/A
Pension Benefits Other Benefits -------------------------- ------------------------ 1999 1998 1999 1998 -------- -------- ------- ------- (dollars* 7.0% for union plan, 4.2% for non-union, net of income taxes in thousands)CHANGE IN BENEFIT OBLIGATION: Benefit Obligation at beginning of year $ 38,572 $ 33,410 $ 4,363 $ 4,503 Service Cost 1,963 1,597 125 112 Interest Cost 2,538 2,278 305 283 Actuarial Loss/(Gain) (6,255) 2,514 (171) (368) Benefits Paid (1,305) (1,227) (191) (167) -------- -------- ------- ------- Benefit Obligation at end of year $ 35,513 $ 38,572 $ 4,431 $ 4,363 CHANGES IN PLAN ASSETS: Fair Value of Plan Assets at beginning of year $ 39,541 $ 33,433 $ 1,442 $ 1,104 Actual Return of Plan Assets 8,277 6,051 25 44 Employer Contributions 1,264 1,284 484 461 Benefits Paid (1,305) (1,227) (191) (167) -------- -------- ------- ------- Fair Value of Plan Assets at end of year $ 47,777 $ 39,541 $ 1,760 $ 1,442 RECONCILIATION OF FUNDED STATUS: Funded Status $ 12,263 $ 969 $(2,671) $(2,921) Unrecognized Transition Obligation 57 114 6,288 6,707 Unrecognized Net Loss/(Gain) (10,683) 677 (1,869) (1,860) Unrecognized Prior Service Cost 355 400 (3,228) (3,427) -------- -------- ------- ------- Prepaid/(Accrued) Pension Cost $ 1,992 $ 2,160 $(1,480) $(1,501) WEIGHTED-AVERAGE ASSUMPTIONS AS OF DECEMBER 31: Discount Rate 7.75% 6.50% 7.75% 6.50% Long-term Rate of Return 8.00% 8.00% 8.00% 8.00% Salary Assumption 4.00% 4.00% -- --2003, and 8.0% in 2002 and 2001A sliding scale for assumed health care cost increases was used for
boththe periodsstartingpresented. In 2003 and 2002, health care cost increases started at8%12.0% grading down to 5.0% in199910 years for those under age 65, and at 14.0% grading down to 4.5% in 10 years for post 65. In 2001, health care cost increases started at 8.5% thenremaining at 6% thereafter. The componentsgraded down ½ percentage point each year to the ultimate rate ofnet periodic post-retirement benefits cost for 1999 and 1998 are as follows: 41445% after 6 years.
Pension Benefits Other Benefits ----------------------- -------------------- (dollars in thousands) 1999 1998 1999 1998 ------- ------- ----- -----COMPONENTS OF NET PERIODIC BENEFITS COST Service Cost $ 1,963 $ 1,597 $ 125 $ 112 Interest Cost 2,538 2,278 305 283 Actual Return on Plan Assets (8,277) (6,051) (25) (44) Net Amortization 5,207 3,476 58 67 ------- ------- ----- ----- Net Periodic Pension Cost $ 1,431 $ 1,300 $ 463 $ 418Assumed health care cost trend rates have a significant effect on the amounts reported for the health care plans. A one-percentage-point change in assumed health care cost trend rates would have the following effects:
1-Percentage-Point 1-Percentage-Point (dollars in thousands) Increase Decrease -------- --------Effect on Total of Service and Interest Cost Components $ 13 $ (12) Effect on Postretirement Benefit Obligation 177 (156)
1-Percentage-Point 1-Percentage-Point (dollars in thousands) Increase Decrease Effect on Total of Service and Interest Cost Components $ 72 ($ 61 ) Effect on Postretirement Benefit Obligation $ 750 ($ 641 ) Plan Assets:
Registrant’s pension and postretirement plan weighted-average asset allocations at December 31, 2003 and 2002, by asset category are as follows:
Pension Benefits Other Postretirement Benefits Asset Category 2003 2002 2003 2002 Equity securities 41 % 31 % 0 % 0 % Debt securities 51 % 58 % 0 % 0 % Cash equivalents 0 % 0 % 100 % 100 % All other 8 % 11 % 0 % 0 %
Total 100 % 100 % 100 % 100 %
Equity securities include AWR’s stock in the amount of $738,450 (1.6% of total plan assets) and $683,805 (1.7% of total plan assets) as of December 31, 2003 and 2002, respectively.
75
Note 9 - Employee Benefit Plans (Continued)
Target Asset Allocations for 2004: Pension Benefits Other Postretirement Benefits Equity securities 40 % 40 % Debt securities 60 % 60 %
Total 100 % 100 %
Determination of the Expected Long-Term Rate of Return on Assets:
To develop the expected long-term rate of return on assets assumption for the pension plan, Registrant considered the historical returns and the future expectations for returns for each asset class, as well as the target asset allocation of the pension portfolio. This resulted in the selection of the 7.0% long-term rate of return on assets assumption.
Registrant’s policy is to fund the medical benefit trusts based on actuarially determined amounts as allowed in rates. Registrant may invest such funds in qualified instruments to achieve the desired return objective and minimize recovery through rates. During 2004, the Registrant intends to invest the funds in the postretirement trusts that will achieve a desired return and minimize amounts necessary to recover through rates. The mix is expected to provide for a return on asset similar to the pension plan and to achieve Registrant’s targeted allocation. This resulted in the selection of the 7% long-term rate of return on assets assumption.
Supplemental Executive Retirement Plan:
Registrant has a Supplemental Executive Retirement Plan (“SERP”) that provides additional retirement benefits to certain key employees and officers of the Company by making up benefits, which are limited by Sections 415 and 401(a)(17) of the Internal Revenue Code of 1986, as amended. As of December 31, 2003 and 2002, the benefits are unfunded.
During 2003, amendments affecting the SERP were approved which increased the related benefit obligation. The increase was primarily due to an amendment related to a change in the early retirement provisions. At December 31, 2003, the accumulated benefit obligation of the SERP exceeded the related plan assets at the measurement date. In accordance with accounting standards, Registrant’s balance sheets include an additional minimum liability, with a corresponding charge to an intangible asset.
The following provides a reconciliation of benefit obligations, funded status of the SERP, as well as a summary of significant estimates at December 31, 2003 and 2002:
(dollars in thousands) 2003 2002 Benefit Obligation at beginning of year $ 567 $ 513 Service Cost 39 27 Interest Cost 43 27 Actuarial Loss/(Gain) 92 — Plan Amendment 1,220 — Benefits Paid (2 ) —
Benefit Obligation at end of year $ 1,959 $ 567
Funded Status ($ 1,959 ) ($ 567 ) Unrecognized Actuarial (Gain) Loss (499 ) — Unrecognized Prior Service Cost 1,762 —
Prepaid/(Accrued) Pension Cost ($ 696 ) ($ 567 )
Accrued benefit liability ($ 1,285 ) ($ 567 ) Intangible assets 589 —
Net amount recognized ($ 696 ) ($ 567 )
76
Note 9 - Employee Benefit Plans (Continued)
The components of SERP expense for 2003, 2002, and 2001 are as follows:
(dollars in thousands) 2003 2002 2001 Service Cost $ 39 $ 27 $ 24 Interest Cost 43 27 24 Amortization of Prior Service Cost 49 — —
Net Periodic Pension Cost $ 131 $ 54 $ 48
Discount Rate 6.25 % 7.25 % 7.25 % Salary Assumption 4.00 % 4.00 % 4.00 % 401(k) Investment Incentive Program
Registrant has a 401(k) Investment Incentive Program under which employees may invest a percentage of their pay, up to a maximum investment prescribed by law, in an investment program managed by an outside investment manager. Company contributions to the 401(k) are based upon a percentage of individual employee contributions and, for
1999, 19982003, 2002 and1997,2001, totaled$920,340, $874,113,$1,031,793, $975,687 and$785,687,$953,938, respectively.NOTE 7Directors Plan
Registrant has a Retirement Plan for Non-Employee Directors. This Non-Employee Directors Plan provides annual benefits to an eligible director in an amount equal to the annual retainer in effect at the director’s date of retirement. Benefits are payable in monthly installments for a period equal to the shortest of (a) the period he or she was a director or (b) 10 years. Benefits are payable to directors after the age of 62 and after retirement from the Board. As of December 31, 2003, liability recorded for this plan totaled $530,500.
77
Note 10 – Stock Compensation Plan
Registrant established a 2000 Stock Incentive Plan (the “2000 Plan”) adopted at the Shareholders’ Annual Meeting in 2000 to provide stock-based incentives as a means of promoting the success of the Company by attracting, retaining and aligning the interests of employees with those of shareholders generally. There are 750,000 Common Shares reserved for issuance under the 2000 Plan.
All stock options are granted at the fair market value of the underlying stock on the date of the grant, accordingly, no compensation expense was recognized during the years ended December 31, 2003, 2002 and 2001. The fair value of stock options used to compute pro forma net income and earnings per share disclosures discussed in Note 1, is the estimated fair value at grant date using the Black-Scholes option-pricing model with the following assumptions:
December 31, 2003 2002 2001 Weighted-average fair value of option granted $ 4.91 $ 4.98 $ 4.82 Risk-free rate of return 3.10 % 4.30 % 4.86 % Dividend yield 3.60 % 3.90 % 4.30 % Expected volatility 29.80 % 28.14 % 27.84 % Expected life 5 5 5 Stock option transactions relating to the 2000 Stock Incentive Plan are summarized below:
2003 2002 2001 Option Weighted Option Weighted Option Weighted Shares Price Shares Price Shares Price Options outstanding at beginning of year 237,610 $ 22.66 135,970 $ 22.03 67,985 $ 20.83 Granted 150,400 23.15 116,775 23.43 68,985 23.21 Exercised — — — — — — Cancelled (54,331 ) 22.78 (15,135 ) 23.03 (1,000 ) 22.02
Options outstanding at end of year 333,679 $ 22.86 237,610 $ 22.66 135,970 $ 22.03
Options exercisable at end of year 166,436 22.45 65,118 $ 21.62 22,662 $ 20.83
One-third of the stock options granted become exercisable on each of the first three anniversaries of the grant date, but may be exercised earlier if there is a change in control of the Company. The stock options generally expire ten years from the date of grant. Weighted average remaining contractual life at December 31, 2003 is 7.97 years. Exercise prices of options outstanding at December 31, 2003 ranged from $20.83 to $23.43 per share.
78
Note 11 -
BUSINESS RISKS AND CONCENTRATION OF SALES Registrant'sBusiness Risks and CommitmentsRegistrant’s utility operations are engaged in supplying water and electric service to the public.
SCWRegistrant is required to provide service and grant credit to customers within its defined service areas. Although Registrant has a diversified base of residential, industrial and other customers, revenues derived from commercial and residential water customers accounted for approximately90%91% of total water revenues in19992003, which is about the same percentage as in 2002 and91% in 1998.2001. Registrant faces additional risks associated with weather conditions, adequacy and quality of water supplies, regulatory decisions, pronouncements and laws, water-related litigation, and general business conditions. Cooler and wetter weather conditionsand condemnation Approximately 40%experienced in 2003 in most ofthe SCW'sSCW’s service areas as compared to 2002 resulted in a decrease in water demand.SCW’s Water Supply
During 2003, approximately 43.2% of SCW’s water supply
iswas purchased from wholesalers of imported water, with the remainder produced fromcompanyCompany wells. The long-term availability of imported water supplies is dependent upon, among other things, drought conditions throughout the state of California, increases in population, water quality standards,andlegislation that may potentially reduce water supplies and issues related to California’s allocation of Colorado River water. Reservoir storage in California statewide stood at 100% of normal in February of 2004.CCWC’s Water Supply
Arizona’s precipitation levels for the 2003 water year were between 70% and 89% of normal with the Colorado River area getting 82%. However this was a marked improvement over 2002 when precipitation was almost nonexistent. The Colorado River basin continues to experience drought conditions with precipitation at 32% of normal. Lake Powell and Lake Mead storage levels are currently at 68% of average. So far this water year inflow to Lake Powell has been 1,366,200 acre feet with outflow at 1,254,500 acre feet which is 72% of average. The April-July inflow to Lake Powell is forecast to be 6,800,000 acre feet, which is 86% of normal. Snowpack above Lake Powell is 95% of average.
The Arizona Water Banking Authority (AWBA) was created to store Arizona’s unused Colorado River water entitlement in western, central and southern Arizona to develop long-term storage credits to: (i) firm existing water supplies for municipal and industrial users during Colorado River shortages or Central Arizona Project (CAP) service interruptions; (ii) help meet the water management objectives of the Arizona Groundwater Code; and (iii) assist in the settlement of American Indian water rights claims. The ABWA successfully recharged more than 209,000 acre-feet in 2003 allowing for the second year in a row for Arizona to use its full allocation of Colorado River entitlement of 2.8 million acre-feet. This banked water can be used as a hedge against future drought conditions. Further, the first curtailment of CAP deliveries in the event of shortage would occur to non-Indian agricultural users. Such users accounted for a third of CAP deliveries in 2003, creating a buffer for users such as CCWC. Though it is difficult to predict drought conditions with certainty, the activities of AWBA, and the priority for users of CAP, such as CCWC, provides an improved outlook for CCWC supplies.
SCW does not anticipate any constraintsCCWC obtains its water supply from two operating wells and from Colorado River water delivered by the CAP. The majority of CCWC’s water supply is obtained from its CAP allocation and well water is used for peaking capacity in excess of treatment plant capability, during treatment plant shutdown, and to keep the well system in optimal operating condition.
CCWC has an Assured Water Supply designation, by decision and order of the Arizona Department of Water Resources (ADWR), providing in part that, subject to its requirements, CCWC has a sufficient supply of ground water and CAP water which is physically, continuously and legally available to satisfy current and committed demands of its customers, plus at least two years of predicted demands, for 100 years.
CCWC has, however, received a letter from the ADWR stating that the current and committed demand for water in CCWC’s service area has exceeded CCWC’s supply of water in its proven assured water supply account by 400 acre-feet per year. ADWR’s letter requires CCWC to make up this accounting deficit by securing additional water supplies and/or providing information to ADWR that would allow ADWR to issue a new decision that CCWC’s current and committed demands are within the proven available supplies in CCWC’s assured water supply account.
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Note 11 - Business Risks and Commitments (Continued)
The ADWR letter is part of a routine administrative review of all water providers. ADWR’s review will have no impact on CCWC’s ability to deliver water to its existing customers. CCWC has submitted an application to the ADWR to modify its designation of assured supply on February 11, 2004. If there are no objections to the application to modify CCWC’s designation of assured supply by ADWR, they may proceed to modify CCWC’s designation, subject to CCWC obtaining membership in the Central Arizona Groundwater Replenishment District.
Notwithstanding an assured water supply designation, CCWC’s water supply may be subject to interruption or reduction, in particular owing to interruption or reduction of CAP water. In the event of interruption or reduction of CAP water, CCWC can currently rely on its
importedwell water supplies for short-term periods. However, in2000. NOTE 8 - CONTINGENCIES In 1998, ASUS was formedany event, the quantity of water CCWC supplies topursue non-regulated opportunities such as long-term leases,some or all of its customers may be interrupted or curtailed, pursuant to the provisions of its tariffs. CCWC has the physical capability to deliver water in excess of that which is currently accounted for in CCWC’s assured water supply account.MCO Properties, Inc. (MCO), a real estate developer and
operationformer owners of CCWC, has filed a complaint against AWR andmaintenance contractsCCWC in the Superior Court ofgovernmentally-owned waterMaricopa County on June 6, 2003 alleging breach of contract, breach of implied covenant of good faith andwastewater systems. In 1999, Registrant terminated its Golden State Water Company joint venture. Registrant expensed approximately $336,000 against future lossesfair dealing, interference with prospective economic advantage, negligence andcapital account adjustments in 1998. There was no significant financial impact in 1999 associatednegligent misrepresentation and seeking a declaratory judgment. The complaint arises out of allegations by MCO that AWR has failed to comply with thetermination.terms of the Stock Purchase Agreement between AWR and MCO pursuant to which AWR acquired CCWC from MCO and has thereby interfered with MCO’s ability to develop its real property in the Town of Fountain Hills. A revised complaint was filed on December 12, 2003 further alleging that CCWC did not maintain its designation of assured water supply as required in the Stock Purchase Agreement. Similar allegations have been filed by MCO against CCWC with the Arizona Corporation Commission. There have been settlement discussions seeking to resolve these issues (Note 12).In addition, to the actions described above with respect to CCWC’s assured water supply designation, ADWR and CCWC have agreed that the Town of Fountain Hills may approve and record final parcel plats for subdivisions for which CCWC has entered into written commitments to provide water service, conditional on (i) ADWR sending a notification to the Town that ADWR has approved a modification to CCWC’s designation or otherwise has determined that CCWC has enough water for current and committed demands including the subdivision, and (ii) MCO not submitting a request to the State Real Estate Commissioner for a public report for the subdivision in advance of ADWR’s issuance of the notification to the Town.
Bear Valley Electric
All electric energy sold by SCW to customers in its Bear Valley Electric customer service area is purchased from others. In March 2001, SCW entered into a five-year nine-month, block forward purchase contract with Mirant Marketing to supply its Bear Valley Electric customer service area with 15 MWs of electric energy at a price of $95 per MWh beginning April 1, 2001 through December 31, 2006. SCW has filed a complaint with the FERC seeking to reduce the rates in the Mirant Marketing contract to a just and reasonable price. On
April 22, 1999,December 19, 2002 the FERC issued an initial decision denying SCW’s complaint. SCW has appealed the initial decision but anticipates that it is unlikely that FERC will grant its request to reduce these charges. In June 2003, the FERC issued a final order denying SCW’s complaint. On November 10, 2003, the FERC denied SCW’s rehearing request. SCW is currently reviewing its options with respect to the FERC’s latest order denying rehearing and is determining if it will appeal the decision in Federal Court. In June 2001, SCW also executed a three-year, block forward purchase agreement with PWCC for an additional 8 MWs of electric energy to meet Bear Valley Electric’s peak winter demands at a price of $75 per MWh for the first year, $48 per MWh for the second year and $36 per MWh for the third year.Effective November 2002, SCW entered into a series of purchase power contracts with PWCC. Under the agreements, SCW will exchange 15 MWs of electric energy with PWCC at $74.65 per MWh that results in an upfront payment of $20.35 per MWh for 15 MWs over the period beginning November 1, 2002 through December 31, 2006. This upfront payment is being recorded as a reduction of purchased power costs which are included in the supply cost balancing account. In addition, 8 MWs of electric energy are also being sold to PWCC at the prices set forth in the June 2001 energy purchase agreement with PWCC, and 8 MWs are being purchased at $74.65 per MWh beginning on November 1, 2002 through March 31, 2003 and each succeeding November 1 through March 31 through March 31, 2008 and for the period November 1, 2008 through December 31, 2008. Total commitmentsunder these agreements amount to $71.9 million with $12 million due each year through December 31, 2008.
80
Note 11 - Business Risks and Commitments (Continued)
The average minimum load at SCW’s Bear Valley Electric customer service area has been approximately 14 MWs. The average winter load has been 18 MWs with a winter peak of 39 MWs when the snowmaking machines at the ski resorts are operating.
On July 17, 2002, the CPUC
issued an order denying SCW's application seeking approvalapproved a settlement agreement reached among SCW, all intervening parties and the Office ofits recoveryRatepayer Advocates, which permits SCW to recover $77 per MWh of purchased power costs through rates, effective immediately thereafter. SCW will only be allowed to include up to a weighted annual energy purchase cost ofcosts associated with$77 per MWh each year through August 2011,in itsparticipationbalancing account. To the extent SCW’s actual average annual weighted cost for purchased power is less than $77 per MWh, the differential will recover amounts included in theCoastal Aqueduct Extensionelectric supply balancing account. Conversely, to the extent that actual average annual weighted costs for power purchased exceed the $77 per MWh amount, SCW will not be able to include these amounts in its balancing account and such amounts will be expensed. In 2003 and 2002, approximately $0.2 million and $0.7 million, respectively, was expensed. As a result of theState Water Project (SWP). SCW's participationsettlement, SCW is also permitted to collect a surcharge of 2.2¢ per kilowatt hour from its customers for up to ten years commencing August 2001 to allow SCW an opportunity to collect amounts remaining in its electric cost balancing account, with interest, incurred by SCW during the energy crisis in 2000-2001.Demand for energy in SCW’s Bear Valley Electric customer service area generally has been increasing. However, the ability of SCW to deliver purchased power to these customers is limited by the ability of the transmission facilities owned by Southern California Edison Company to transmit this power. As a means of meeting these increasing demands for energy, SCW is constructing a natural gas-fueled 8.4 MW generation facility to be owned by SCW. A Certificate of Public Convenience and Necessity filed with the CPUC seeking authorization for construction of the generation facility was approved on July 10, 2003. It is expected that the generator will be on line during the second quarter of 2004, and should assist SCW in controlling its spot purchase prices.
SCW has been, in conjunction with Edison, planning to upgrade transmission facilities to 115kv (the 115kv Project) in order to meet increased energy and demand requirements for SCW’s Bear Valley Electric Service area. On December 27, 2000, SCW filed a lawsuit against Edison for declaratory relief and seeking damages for breach of contract as a result of delays in the
SWP commits it115kv Project, violations of good faith and fair dealing, negligent misrepresentation, intentional misrepresentation and unjust enrichment. Subsequently Edison filed a cross-complaint against SCW for breach of contract, anticipatory breach, and quantum meruit. SCW has also sought declaratory relief from Edison’s claims. To date, SCW has spent approximately $3.4 million in this matter, all of which has been expensed. A settlement has been reached between SCW and Edison, in which (i) SCW is to pay Edison $5.0 million as the cost of abandoning and terminating the 115kv Project, (ii) Edison shall make a filing the FERC to include the cost into a FERC rate schedule under the Transmission Service Agreement between SCW and Edison, and (iii) Edison is to sell the Goldhill substation and associated transmission line to SCW at its book value. Management believes that the FERC’s approval on Edison’s filing is probable and this cost is within the meaning of the CPUC’s Code of “Abandonment Fee” which is recoverable through the supply cost balancing account. As a result, the $5.0 million obligation to Edison arising from this settlement was recorded as a liability with a corresponding amount to a40-year entitlementregulatory asset in the fourth quarter of 2003. A final settlement agreement was reached on March 17, 2004.Operating Leases
Registrant leases equipment and facilities primarily for its Regional and District offices under non-cancelable operating leases with
a 4245 valuevarying terms, provisions, and expiration dates. During 2003, 2002 and 2001, Registrant’s consolidated rent expense was $2,187,008, $1,992,889 and $1,893,337, respectively. Registrant’s future minimum payments under long-term non-cancelable operating leases at December 31, 2003 are as follows:
2004 $ 2,013,136 2005 1,772,953 2006 1,236,079 2007 731,300 2008 404,461 Thereafter 4,020
Total: $ 6,161,949
There is no material difference between the consolidated operations of
approximately $9.5 million. SCW's investmentAWR and the operations of SCW inSWP is currently included in Other Property and Investments. The remaining balance ofregards to therelated liability of approximately $7 million is recorded as otherfuture minimum payments under long-termdebt. SCW intends to recover its investment in SWP through contributions from developers on a per-lot or other basis, and, failing that, sale of its 500 acre-foot entitlement in SWP. SCW believes that its full investment and on-going costs associated with its ownership will be fully recovered.non-cancelable operating leases.81
Note 12 - Contingencies
Water Quality-Related Litigation:
SCW has been named as a defendant in
eleventwenty-two lawsuitswhichthat allege that SCW and other water utilities, deliveredcontaminatedunsafe water toitstheir customers. Plaintiffs in these actions seek damages, including general, special, and punitive damages, according to proofofat trial, as well asattorney'sattorney’s fees on certain causes of action, costs of suit, and other unspecified relief.NineNineteen of the lawsuits involve customer service areas located in Los AngelescountyCounty in the southern portion of California;twothree of the lawsuits involve a customer service area located in SacramentocountyCounty in northern California. On September 1, 1999, the Court of Appeal in San Francisco held that the CPUC had preemptive jurisdiction over regulated public utilities and ordered dismissal of a series oflawsuits pertaining to water quality filed against water utilities, including SCW. Seven out of eleven lawsuits against SCW had been ordered for dismissal by the state Court of Appeals.these lawsuits. On October 11, 1999, one group of plaintiffs appealed the decision to the California Supreme Court.On February 4, 2002, the California Supreme Court
which has acceptedconcluded that (i) thecase. Management is unable to predictCPUC had preemptive jurisdiction over claims seeking injunctive relief and claims based on theoutcometheory that a public utility regulated by the CPUC provided unsafe drinking water even though it had complied with federal and state drinking water standards, but (ii) the CPUC did not have preemptive jurisdiction over damage claims alleging violations ofthis proceeding but, in any event, does not anticipatefederal and state drinking water standards by public utilities regulated by the CPUC. As adecision prior to 2001.result, damage claims based on allegations of violations of federal and state drinking water standards may proceed while the other claims must be dismissed. In light of the breadth ofplaintiff'splaintiffs’ claims, the lack of factual information regardingplaintiff'splaintiffs’ claims and injuries, if any, the impact of the California Supreme Court decision on plaintiffs’ claims and the fact that no discovery has yet been completed, SCW is unableto determineat this time to determine what, if any, potential liability it may have with respect to claims based on allegations of violation of federal and state drinking water standards. Based upon the information currently available to it, Registrant believes that theseclaims. SCWclaims are without merit and intends to vigorously defenditselfagainst theseallegations. Management can not predictclaims.SCW is subject to self-insured retention provisions in its applicable insurance policies and has either expensed the
outcomeself-insured amounts or has reserved against payment of theseproceedings and ifamounts as appropriate. SCW’s various insurance carriers have, to date, provided reimbursement for costs incurred above the self-insured amounts for defense against these lawsuits, subject to a reservation of rights. In addition, on March 16, 2004, the CPUC issued a decision which authorizes SCWis found liable,to establish a memorandum account to accumulate costs to comply with certain contamination remediation requirements for future recovery. Based on the decision, SCWwould pursue recovery through its insurance coverage providers.reversed $1.0 million of water quality related reserves into income during the fourth quarter of 2003.Order Instituting Investigation (OII):
In
response to those lawsuits and similar actions, inMarch 1998, the CPUC issued anOrder Instituting Investigation (OII) directedOII toall Class A and Bregulated water utilities in the state of California, includingSCW, intoSCW. The purpose of the OII was to determine whether existing standards and policies regarding drinking water quality adequately protect the public health and whether those standards and policiesarewere being uniformly complied with by those water utilities.The OII notes the constitutional and statutory jurisdiction ofOn November 2, 2000, a final decision from the CPUCand the DOHS to establish and enforce adherence to water quality standards for water delivered by utilities to their customers and, in the case ofconcluded that the CPUC has the jurisdiction toestablish rates which permit water utilities to furnish water that meetsregulate theestablished water quality standards at prices which are both affordable and that allow the utility to earn a reasonable return on its investment. SCW has made its filing in this proceeding on a seriesservice ofquestions dealing with the current drinking water standards, compliance bywater utilities withsuch standards, appropriate remedies for failurerespect tocomply with drinking standardsthe health andwhether stricter or additionalsafety of that service; that the California Department of Health Services requirements governing drinking waterstandards are required. The Water Division ofquality adequately protect theCPUC has issued its reportpublic health and safety; and that, based onthese filings by the utilities. A final decision in the OII is anticipated in 2000. The OII leaves open the possibilityan extensive review ofevidentiary hearings and further action by the CPUC. The Administrative Law Judge assigned to the OII has issued a draft decision finding that25 years of water quality records, regulated water utilities, including SCW, have satisfactorily complied withDOHS regulationpast andrequirements.present drinking water quality requirements, except for one small unrelated water utility in Northern California.The CPUC had previously authorized establishment of memorandum accounts to capture expenses related to the OII. Under the memorandum account procedure, SCW may recover litigation costs from ratepayers to the extent authorized by the CPUC. As of December 31, 2003 and 2002, SCW had incurred a net cost of $890,000 related to the OII for which it had established a reserve in prior years due to uncertainty of recoverability. In a decision issued by the CPUC on March 16, 2004 on SCW’s filing for its Region III and general office functions, SCW is now allowed to recover these cost through a special condition surcharge over a twelve-month period. Based on the decision, SCW reversed the $890,000 OII reserve into income during the fourth quarter of 2003.
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Note 12 – Contingencies (Continued)
Other Water Quality Litigation:
On October 25, 1999, SCW filed a lawsuit against the State of California and its State Water Resources Control Board, Central Valley Regional Water Quality Control Board, and Department of Toxic Substances Control (collectively, the “State”) alleging that the State had substantially participated in a project to inject chemical pollution into portions of the Sacramento County groundwater basin and that pollution is progressively destroying the groundwater supply in SCW’s Rancho Cordova water system. SCW and the State have entered into a comprehensive $2,475,000 settlement for all of SCW’s claims against the State, contingent upon the court’s approval of the good faith of the settlement, which SCW received in full during the third quarter of 2003.
In a separate case, also filed on October 25, 1999, SCW sued Aerojet-General Corporation (Aerojet) for causing the contamination of eastern portions of the Sacramento County groundwater basin. A cross complaint filed by Aerojet against SCW for negligence and constituting a public nuisance was voluntarily dismissed by Aerojet in October 2002. On October 10, 2003, Registrant entered into a confidential Memorandum of Understanding (“MOU”) with the Aerojet-General subsidiary of GenCorp, Inc. for the settlement of legal actions brought by SCW. The MOU sets forth the present financial terms and the structure of a settlement to cover, over time, capital and litigation related costs incurred by SCW resulting from the contamination. The MOU and the settlement embodied therein was found to be binding by the Sacramento Superior Court on January 18, 2004. Further documentation incorporating the terms of the MOU is presently underway. However, documentation is not complete and management is presently unable to predict when a comprehensive set of settlement documents will be completed.
Based on the financial terms in the MOU, SCW established a receivable from Aerojet in an amount of $16.7 million at the end of 2003, of which $8.7 million has been received in early 2004 and is included in current “Other Accounts Receivable” on the balance sheets. The remainder of the costs is subject to further settlement documentation. Reimbursements received from Aerojet have been applied directly to reduce SCW’s costs of utility plant and purchased water. Prior to the MOU, Aerojet had reimbursed SCW $4.3 million in capital costs and $171,000 for additional water supply.
In an action related to the draft settlement agreement, Registrant and Aerojet have signed three separate agreements requiring Aerojet to pay for certain infrastructure and upgrades to the Coloma Treatment Plant as a contingency plan should additional wells be impacted prior to the high summer demand period of 2004. The value of the three agreements approximates $6.8 million in capital improvements. In addition, SCW is in negotiations with the County of Sacramento regarding a replacement of water supply.
The CPUC has previously authorized memorandum accounts to allow for recovery, from customers, of costs incurred by SCW in prosecuting the suits filed against the State and Aerojet, less any recovery from the defendants or others. As of December 31, 2003, approximately $16.2 million in legal and consulting related costs has been recorded as deferred charges and included in “Regulatory Assets” on the balance sheets. The CPUC has authorized SCW to increase rates, effective April 28, 2001, for recovery over a six-year period of approximately $1.8 million, in expenses that were incurred on or before August 31, 2000, in the Aerojet matter recorded as a regulatory asset (Note 2). As part of an abbreviated application for SCW’s Region I, SCW requested a long-term amortization of the balance of costs included in the Aerojet litigation memorandum account, net of any reimbursement amount. The draft agreement also addresses the possible recovery of SCW’s deferred charges through revenues in new development areas. Management believes these costs are recoverable either through rates or the settlement agreement with Aerojet. It is management’s intention to offset any settlement that may occur from these actions against the balance in the memorandum accounts at the time of settlement.
83
Note 12 – Contingencies (Continued)
The compound MTBE has been detected in a well serving SCW’s Los Osos water system. For some time, SCW has been working with the Regional Water Quality Control Board as well as the owner of a service station. Although the owner of the service station has attempted remediation with funds provided through the California Underground Storage Tank Fund (“CUSTF”), it appears there will be insufficient funds from the CUSTF to complete remediation sufficient to return the well to service. In order to prevent the running of the statute of limitations, on August 12, 2002 SCW filed suit in the Superior Court of the State of California for the County of San Luis Obispo against the operators and owners of the service station facility, and Chevron USA Products, Inc., the supplier. A settlement with Chevron has been reached and a filing has been made for dismissal by the Court. The impacted well may need to be removed permanently from service and the settlement with Chevron is expected to afford SCW sufficient funds to commence site development and construction of a replacement well.
Perchlorate and/or Volatile Organic Compounds (VOC) have been detected in five wells servicing SCW’s San Gabriel System. SCW filed suit, along with two other affected water purveyors and the San Gabriel Basin Water Quality Authority (WQA), in the federal court against some of those responsible for the contamination. Some of the other potential defendants settled with SCW, other water purveyors and the WQA on VOC related issues prior to the filing of the lawsuit. In response to the filing of the Federal lawsuit, the Potentially Responsible Party (PRP) defendants filed motions to dismiss the suit or strike certain portions of the suit. The judge issued a ruling on April 1, 2003 granting in part and denying in part the defendant’s motions. A key ruling of the court was that the water purveyors, including the Registrant, by virtue of their ownership of wells contaminated with hazardous chemicals are themselves PRPs under the Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA). Registrant has, pursuant to permission of the court, amended its suit to claim certain affirmative defenses as an “innocent” party under CERCLA. Registrant is presently unable to predict the outcome of this ruling on its ability to fully recover from the PRPs future costs associated with the treatment of these wells.
On August 29, 2003, the US Environmental Protection Agency issued Unilateral Administrative Orders (“UAO”) against 41 parties deemed responsible for polluting the groundwater in that portion of the San Gabriel Valley from which SCW’s two impacted wells draw water. SCW was not named as a party to the UAO. The UAO requires that these parties remediate the contamination. As a result of the issuance of the UAO, these parties have begun settlement discussions regarding the Federal lawsuits with SCW, the other two affected water purveyors and WQA. Registrant is presently unable to predict the ultimate outcome of these settlement discussions.
As discussed previously, MCO has filed a complaint against AWR and CCWC in the Superior Court of Maricopa County (CV 2003-011184) on June 6, 2003 alleging breach of contract, breach of the implied covenant of good faith and fair dealing, interference with prospective economic advantage, negligence and negligent misrepresentation and seeking a declaratory judgment. The complaint arises out of allegations by MCO that AWR has failed to comply with the terms of the Stock Purchase Agreement between MCO and AWR pursuant to which AWR acquired CCWC from MCO and has thereby interfered with MCO’s ability to develop its real property in the Town of Fountain Hills. A revised complaint was filed on December 12, 2003 further alleging that CCWC has not maintained its designation of assured supply as required in the Stock Purchase Agreement. Similar allegations have been filed by MCO against CCWC with the Arizona Corporation Commission (Docket No. W-02113A-3-0383). There have been settlement discussions seeking to resolve these issues. In addition, CCWC has undertaken actions that it believes will enable it to continue to maintain its assured water supply designation in a manner that will enable CCWC to provide water service to new real estate developments in the Town of Fountain Hills, including properties owned by MCO. AWR and Arizona Department of Water Resources (“ADWR”) have also agreed that the Town of Fountain Hills may approve and record final parcel plats for subdivisions for which CCWC has entered into written commitments to provide water service, conditional on (i) ADWR sending a notification to the Town that ADWR has approved a modification to CCWC’s designation or otherwise has determined that CCWC has enough water for current and committed demands including the subdivision, and (ii) MCO not submitting a request to the State Real Estate Commissioner for a public report for the subdivision in advance of ADWR’s issuance of the notification to the Town.
84
Note 12 - Contingencies (Continued)
Condemnation of Properties:
The laws of the State of California provide for the acquisition of public utility property by governmental agencies through their power of eminent domain, also known as condemnation, where doing so is in the public interest. In addition, however, the laws of the State of California also provide: (1) that the owner of the utility property may contest whether the
draft decision will be approvedcondemnation is actually inpart orthe public interest; and (2) that the owner is entitled to receive the fair market value of its property if the property is ultimately taken. Although the City of Claremont, California located inits entiretySCW’s Region III has not initiated the formal condemnation process pursuant to California law, the City hired a consultant to perform an appraisal of the value of Registrant’s water system serving that city. SCW intends to vigorously defend itself against any condemnation action initiated by theCPUC.City.Other Litigation:
Registrant is also subject to ordinary routine litigation incidental to its business. Other than those disclosed above, no other legal proceedings are pending, which are believed to be material. Management believes that rate recovery, proper insurance coverage and reserves are in place to insure against
anticipatedproperty, general liability andworkers'workers’ compensationclaims. 4346 NOTE 9claims incurred in the ordinary course of business.Note 13 -
CONSTRUCTION PROGRAM SCW's 2000 construction budget providesConstruction ProgramConstruction Program
SCW maintains an ongoing water distribution main replacement program throughout its customer service areas based on the priority of leaks detected, fire protection enhancement and a reflection of the underlying replacement schedule. In addition, SCW upgrades its electric and water supply facilities in accordance with industry standards, local requirements and CPUC requirements. SCW’s Board of Directors has approved anticipated net capital expenditures for
gross expenditures2004 principally reflecting water supply related projects such as drilling and equipping of new wells, building a new reservoir, and distribution and street improvement projects. As of December 31, 2003, SCW has unconditional purchase obligations for capital projects of approximately$59 million, $3.6 million$12.5 million.CCWC’s Board of
which is anticipated to be obtained from developersDirectors has approved a net capital budget for 2004 primarily reflecting a new treatment center building andothers. Neitherdistribution improvement on its Golden Eagle Plant.AWR
norand ASUS have no material capitalcommitments; however,commitments. However, ASUS actively seeks opportunities to own, lease or operatemunicipalwater and wastewater systems for governmental entities, which may involve significant capital commitments.NOTE 10Registrant does not have any material capital expenditures for specific environmental control facilities or measures.
85
Note 14 -
ALLOWANCE FOR DOUBTFUL ACCOUNTS The table below presents SCW's provision for doubtful accounts charged to expense and accounts written off, net of recoveries for the lastBusiness SegmentsAWR has three
years.
December 31, --------------------------------- 1999 1998 1997 ----- ----- ----- (dollars in thousands)Balance at beginning of year $ 403 $ 466 $ 387 Provision charged to expense 852 631 707 Accounts written off, net of recoveries (768) (694) (628) ----- ----- ----- Balance at end of year $ 487 $ 403 $ 466 ----- ----- -----Neither AWR nor ASUS have established any provision for doubtful accounts. NOTE 11 - BUSINESS SEGMENTS Registrant has twoprincipal business units:awater and electric distributionunit,units, through its SCW subsidiary, a water-service utility operation conducted through its CCWC unit, and anon-regulatednonregulated activity unit through the ASUS subsidiary. All activities of SCW currently are geographically located withinCalifornia, except for one contract providing customer service and billing services to a utilityCalifornia. All activities of CCWC are located in the state of Arizona. All activities of ASUS are conducted in California and Arizona. Both SCWis aand CCWC are regulatedutility which operates both water and electric systems. AWR has no material operations other than its SCW subsidiary.utilities. On astand alonestand-alone basis, AWR has no material assets other than its investments in its subsidiaries. The tables below set forth information relating toSCW'sSCW’s operatingsegments. SCW manages its operations on a regional basis using the five categories below as broad-level measures of profitability. Region I incorporates service areas in northernsegments, CCWC andcentral California; Region II contains service areas throughout Los Angeles; Region III encompasses water operations in eastern Los Angles County, Orange County, San Bernardino County and Imperial County. SCW also provides electric service to the City of Big Bear Lake and surrounding areas.nonregulated businesses. Included in the amounts set forth, certain assets, revenues and expenses have been allocated. The identifiable assets are net of respective accumulated provisions for depreciation.
YEAR ENDED DECEMBER 31, 1999 ----------------------------------------------------------------------- WATER ---------------------------------------- REGION I REGION II REGION III ELECTRIC TOTAL -------- --------- ---------- -------- -------- (dollars in thousands)Operating revenues $ 27,221 $ 70,770 $ 61,692 $13,348 $173,031 Operating income before income taxes 6,567 15,841 16,022 3,821 42,251 Identifiable assets 108,675 140,175 177,457 25,725 452,032 Depreciation expense 2,736 4,041 5,395 1,344 13,516 Capital additions $ 12,966 $ 21,926 $ 14,513 $ 2,173 $ 51,578 -------- -------- -------- ------- --------4447
Year Ended December 31, 1998 ----------------------------------------------------------------------- Water ----------------------------------------- Region I Region II Region III Electric Total -------- --------- ---------- -------- -------- (dollars in thousands)Operating revenues $24,927 $ 57,273 $ 52,584 $13,211 $147,995 Operating income before income taxes 6,799 11,732 13,144 3,847 35,522 Identifiable assets 97,463 123,044 169,264 24,981 414,752 Depreciation expense 2,551 3,378 4,701 1,640 12,270 Capital additions $13,302 $ 14,452 $ 15,795 $ 1,720 $ 45,239 ------- -------- -------- ------- --------
Year Ended December 31, 1997 ----------------------------------------------------------------------- Water ----------------------------------------- Region I Region II Region III Electric Total -------- --------- ---------- -------- -------- (dollars in thousands)Operating revenues $24,340 61,085 55,551 $12,779 $153,755 Operating income before income taxes 5,897 9,593 13,709 4,089 33,288 Identifiable assets 87,039 112,556 158,934 25,095 383,624 Depreciation expense 2,306 3,042 4,603 1,001 10,952 Capital additions $10,007 15,431 11,671 $ 2,116 $ 39,225 ------- -------- -------- ------- --------NOTE 12Capital additions reflect capital expenditures paid in cash and exclude property installed by developers and conveyed to the Company.
As Of And For The Year Ended December 31, 2003 SCW CCWC Non- Consolidated (dollars in thousands) Water Electric Water Regulated* Eliminations AWR Operating revenues $ 181,025 $ 24,492 $ 6,221 $ 1,014 ($83 ) $ 212,669 Operating income (loss) before income taxes 45,996 (717 ) 1,409 (3,916 ) 42,772 Interest expense, net 15,664 1,396 475 535 18,070 Identifiable assets 533,837 36,883 31,481 97 602,298 Depreciation and amortization expense 17,298 1,566 921 7 19,792 Capital additions 41,627 11,987 3,558 39 57,211
As Of And For The Year Ended December 31, 2002 SCW CCWC Consolidated (dollars in thousands) Water Electric Water Nonregulated* AWR Operating revenues $ 180,904 $ 21,298 $ 6,157 $ 846 $ 209,205 Operating income (loss) before income taxes 46,974 4,169 1,749 (2,295 ) 50,597 Interest expense, net 15,275 1,361 482 581 17,699 Identifiable assets 507,802 26,591 28,851 67 563,311 Depreciation and amortization expense 15,914 1,470 918 — 18,302 Capital additions $ 38,581 $ 907 $ 1,100 $ 67 $ 40,655
As Of And For The Year Ended December 31, 2001 SCW CCWC Consolidated (dollars in thousands) Water Electric Water Nonregulated* AWR Operating revenues $ 175,204 $ 15,251 $ 6,270 $ 789 $ 197,514 Operating income (loss) before income taxes 54,037 (3,941 ) 1,915 60 52,071 Interest expense, net 13,385 1,192 527 631 15,735 Identifiable assets 484,002 27,182 28,658 — 539,842 Depreciation and amortization expense 15,264 1,446 1,241 — 17,951 Capital additions $ 44,773 $ 2,256 $ 541 — $ 47,570 *Includes amounts from ASUS and AWR.
86
Note 15 -
SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED)Allowance for Doubtful AccountsThe table below presents Registrant’s provision for doubtful accounts charged to expense and accounts written off, net of recoveries. Provisions included in 2003, 2002 and 2001 for AWR and SCW are as follows:
AWR December 31, (dollars in thousands) 2003 2002 2001 Balance at beginning of year $ 769 $ 972 $ 510 Provision charged to expense 518 324 1,033 Accounts written off, net of recoveries (456 ) (527 ) (571 )
Balance at end of year $ 831 $ 769 $ 972
SCW December 31, (dollars in thousands) 2003 2002 2001 Balance at beginning of year $ 729 $ 951 $ 498 Provision charged to expense 512 290 998 Accounts written off, net of recoveries (444 ) (512 ) (545 )
Balance at end of year $ 797 $ 729 $ 951
Neither AWR nor ASUS have established any provision for doubtful accounts.
Note 16 – Supplemental Cash Flow Information
The following table sets forth non-cash financing and investing activities and other cash flow information (in thousands).
AWR SCW December 31, December 31, 2003 2002 2001 2003 2002 2001 Income taxes paid $ 2,134 $ 11,297 $ 7,089 $ 4,190 $ 11,624 $ 6,602 Interest paid $ 18,247 $ 18,150 $ 15,634 $ 17,370 $ 17,101 $ 14,461 Property installed by developers and conveyed $ 3,414 $ 2,247 $ 1,919 $ 3,414 $ 2,247 $ 1,919 Intangible asset – SFAS 87 minimum liability $ 1,624 — — $ 1,624 — — Liability assumed from Edison Settlement that is expected to receive regulatory treatment $ 5,000 — — $ 5,000 — — Receivable recorded for amounts to be reimbursed by Aerojet for capital projects $ 12,706 — — $ 12,706 — — Adoption of new accounting standard for ARO: Regulatory Asset $ 2,495 — — $ 2,479 — — Utility Plant, net 223 — — 221 — — Asset Retirement Obligations (2,718 ) — — (2,700 ) — — 87
Note 17 - Selected Quarterly Financial Data (Unaudited)
The quarterly financial information presented below is unaudited. The business of Registrant is of a seasonal nature and it is
management'smanagement’s opinion that comparisons of basic earnings for thequarterquarterly periods do not reflect overall trends and changes inRegistrant'sRegistrant’s operations.
AWR For The Year Ended December 31, 2003 Operating Operating Basic Earnings (in thousands, except per share amounts) Revenues Income Net Income Per Share First Quarter $ 46,676 $ 7,555 $ 2,990 $ 0.20 Second Quarter 51,817 7,419 2,911 0.19 Third Quarter 63,725 12,179 7,796 0.51 50,451 6,452 (1,805 ) (0.12 )
Year $ 212,669 $ 33,605 $ 11,892 $ 0.78
SCW For The Year Ended December 31, 2003 Operating Operating (in thousands) Revenues Income Net Income First Quarter $ 45,173 $ 7,417 $ 3,124 Second Quarter 50,043 8,012 3,761 Third Quarter 61,683 12,416 8,256 48,618 6,760 (1,256 )
Year $ 205,517 $ 34,605 $ 13,885
Operating Revenues Operating Income Net Income Earnings per Share ------------------------ ---------------------- ---------------------- ------------------ 1999(1) Fourth quarter of 2003 reflects the following:
• a $3.5 million pre-tax charge to earnings to reflect a Proposed Decision issued by the CPUC (Note 2). As required by the Proposed Decision issued by the CPUC on December 19, 2003, SCW will be required to refund to customers approximately $3.5 million in net proceeds received from potentially responsible parties since 1998 1999 1998 1999 1998 1999 1998 -------- -------- ------- ------- ------- ------- ----- ----- (in thousands, except per share amounts)First Quarter $ 36,132 $ 29,955 $ 5,854 $ 4,382 $ 2,977 $ 1,843 $0.33 $0.20 Second Quarter 42,116 35,001 7,251 5,586 4,406 2,767 0.49 0.31 Third Quarter 51,597 47,002 10,266 9,432 6,690 6,374 0.74 0.71for the contamination of the Company’s groundwater supply.• a $6.2 million pre-tax charge to earning to reflect decision issued by the CPUC on March 16, 2004. The decision ordered SCW to refund 70 percent of the total amount of lease revenues received by the City of Folsom since 1994, plus interest, to customers (Note 2). 88
Note 17 - Selected Quarterly Financial Data (Unaudited) (Continued)
AWR For The Year Ended December 31, 2002 Operating Operating Basic Earnings (in thousands, except per share amounts) Revenues Income Net Income Per Share First Quarter $ 44,485 $ 7,918 $ 3,807 $ 0.25 Second Quarter 52,802 9,886 5,435 0.36 Third Quarter 61,612 11,864 7,639 0.50 50,306 7,980 3,458 0.23
Year $ 209,205 $ 37,648 $ 20,339 $ 1.34
SCW For The Year Ended December 31, 2002 Operating Operating (in thousands) Revenues Income Net Income First Quarter $ 42,940 $ 7,851 $ 4,014 Second Quarter 50,907 9,791 5,596 Third Quarter 59,581 11,716 7,730 48,774 8,180 3,880
Year $ 202,202 $ 37,538 $ 21,220
(2) Fourth Quarter 43,576 36,102 5,143 5,661 2,028 3,639 0.23 0.40 -------- -------- ------- ------- ------- ------- ----- ----- Year $173,421 $148,060 $28,514 $25,061 $16,101 $14,623 $1.79 $1.62 -------- -------- ------- ------- ------- ------- ----- -----quarter of 2002 reflects the reversal of $6.5 million reserve for potential non-recovery of electric power costs incurred to serve customers at SCW’s Bear Valley Electric customer service area, and $2.5 million unrealized loss on purchased power contracts pursuant to SFAS No. 133.NOTE 13 - YEAR 2000 READINESS UPDATE Registrant has no Y2K incidents, business disruptions, failures or legal proceedings to report. There were no effects or changes to Registrant's operating trends or revenue patterns as a result89
Report of
the millennium turnover. SCW formally announced its 100% Y2K Ready status when it filed its Compliance Report with the CPUC on November 1, 1999. SCW will be submitting the last CPUC report on this issue by March 1, 2000. Registrant's general process for addressing the Y2K issue was (i) to inventory all systems that may have a potential Y2K impact, (ii) to determine the materiality of these non-Y2K ready systems, (iii) to replace and test, correct and test, or prepare for the failure of material items that have been determined to be non-Y2K ready, and (iv) to prepare contingency plans. Registrant is significantly dependent on third party suppliers, such as energy and telecommunication companies and wholesale water suppliers. In order to conduct its business, Registrant initiated due diligence with certain of its major service providers to address their Y2K readiness. In the event that such suppliers might be adversely affected by Y2K, Registrant prepared its contingency plan which included, among other things, increased staffing during critical periods, manual back-up for 4548 automated systems and the use of portable generators capable of providing power during a black-out. Several "dry runs" were exercised in 1999, which simulated Y2K situations that implemented Registrant's contingency plan. The dry runs proved to be effective exercises that identified areas of strength and weakness, and provided real-life experience from which to make informed decisions about Y2K preparation and contingency plan. Not all Y2K problems were necessarily expected to surface in early 2000. Registrant does not have, and may never fully have, sufficient information about the Y2K exposure of these third parties to adequately predict the risks posed by them to Registrant. If the third parties later discover any Y2K problems that are not remedied, resulting problems could include loss of utility services and disruption of water supplies. On September 2, 1999, the CPUC issued an order denying regulated water utilities the authority to create memorandum accounts for Y2K expenses. The order, however, provides that, after January 1, 2000, regulated water utilities may file for recovery of capital investment, not otherwise included in current rates, associated with Y2K mitigation efforts. Y2K final expenditures have been estimated at approximately $7.5 million. Registrant has spent $4.8 million at January, 2000, $4.0 million of which is in capital investments. On March 1, 2000, Registrant filed an advice letter with the CPUC for recovery of Y2K related costs. Registrant believes that these capital expenditures as well as the remaining Y2K-related investments will be recovered through rates, but can give no assurance that the CPUC will authorize recovery of all or some of these costs. NOTE 14 - SUBSEQUENT EVENT On March 10, 2000, Registrant entered into an agreement to acquire the common stock of Chaparral City Water Company, a privately operated water company serving approximately 10,000 customers in the town of Fountain Hills, Arizona and portions of Scottsdale, Arizona for an aggregate value of $31.2 million, including assumption of approximately $12 million in debt. Chaparral City Water Company was purchased from MCO Properties Inc., a wholly-owned subsidiary of MAXXAM Inc. This marks the first acquisition outside of California for Registrant. The sale of Chaparral City Water Company requires notification to the Arizona Corporation Commission and other conditions customary in transactions of this type. The approval of Registrant's shareholders is not required. It is anticipated that the transaction will close within one year. 4649 REPORT OF MANAGEMENTManagementThe consolidated financial statements contained in the annual report were prepared by the management of American States Water Company, which is responsible for their integrity and objectivity. The consolidated financial statements were prepared in accordance with generally accepted accounting principles and include, where necessary, amounts based upon
management'smanagement’s best estimates and judgments. All other financial information in the annual report is consistent with the consolidated financial statements and is also the responsibility of management.Registrant maintains systems of internal control, which are designed to help safeguard, the assets of Registrant and provide reasonable assurance that accounting and financial records can be relied upon to generate accurate financial statements. These systems include the hiring and training of qualified personnel, appropriate segregation of duties, delegation of authority and an internal audit function, which has reporting responsibility to the Audit Committee of the board of directors.
The Audit Committee, composed of three outside directors, exercises oversight of
management'smanagement’s discharge of its responsibilities regarding the systems of internal control and financial reporting. The committee periodically meets with management, the internal auditor and the independent accountants to review the work and findings of each. The committee also reviews the qualifications of, and recommends to the board of directors, a firm of independent accountants.The independent accountants,
Arthur AndersenPricewaterhouseCoopers LLP, have performed an audit of the consolidated financial statements in accordance with generally accepted auditing standards. Their audit gave consideration toRegistrant'sRegistrant’s system of internal accounting control as a basis for establishing the nature, timing and scope of their work. The result of their work is expressed in their Report of IndependentPublic Accountants. /s/ Floyd E. Wicks /s/ McClellan Harris III - ----------------------------------- ----------------------------------- President, Chief Executive Officer Chief Financial Officer, Vice President - Finance, Treasurer and Corporate Secretary February 10, 2000 4750 REPORT OF INDEPENDENT PUBLIC ACCOUNTANTSAuditors.
s/ FLOYD E. WICKS s/ McCLELLAN HARRIS III Floyd E. Wicks McClellan Harris III President, Chief Executive Officer Chief Financial Officer, Sr. Vice President - Finance, Treasurer and Corporate Secretary March 23, 2004
90
Report of Independent Auditors
To
the Shareholders andthe Board of Directors and Shareholders
of American States WaterCompany: We have auditedCompanyIn our opinion, the accompanying consolidated balance sheets and consolidated statements of capitalization and the related consolidated statements of income, of changes in common shareholders’ equity and of cash flows present fairly, in all material respects, the financial position of American States Water Company and its
subsidiary,subsidiaries (the Company) and Southern California Water Company(California corporations), as of(SCW) at December 31,19992003 and19982002, and therelated consolidated statementsresults ofincome, changes in common shareholders' equitytheir operations and their cash flows for the each of the three years in the period ended December 31,1999.2003 in conformity with accounting principles generally accepted in the United States of America. These financial statements are the responsibility of theRegistrant's management. OurCompany’s and SCW’s management; our responsibility is to express an opinion on these financial statements based on our audits. We conducted our audits of these statements in accordance with auditing standards generally accepted in the UnitedStates. Those standardsStates of America, which require that we plan and perform theauditaudits to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financialstatements. An audit also includesstatements, assessing the accounting principles used and significant estimates made by management,as well asand evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.In our opinion,As discussed in Note 1 to the accompanying consolidated financial statements,
referredon January 1, 2003 the Company adopted Statement of Financial Accounting Standards No. 143 and began accruing for asset retirement obligations.As discussed in Note 1 to
above present fairly,the accompanying consolidated financial statements, on January 1, 2002 the Company adopted Statement of Financial Accounting Standards No. 142 and changed its method of accounting for goodwill.PricewaterhouseCoopers LLP
Los Angeles, California
March 17, 200491
Item 9. Changes in
all material respects,and Disagreements with Accountants on Accounting and Financial DisclosureNone
Item 9A. Controls and Procedures
Registrant has established disclosure controls and procedures that are designed to provide reasonable assurance that information required to be disclosed in our periodic reports filed or submitted under the
financial positionSecurities Exchange Act ofAmerican States Water Company1934 is recorded, processed, summarized andits subsidiary, Southern California Water Company,reported within the time periods specified in the Securities and Exchange Commission’s rules and forms. In accordance with Exchange Act Rules 13a-15 and 15d-15, Registrant carried out an evaluation, under the supervision and with the participation of management, including the Chief Executive Officer and Chief Financial Officer, of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the disclosure controls and procedures were effective as of December 31,19992003 to provide reasonable assurance that information required to be disclosed in the reports filed or submitted under the Exchange Act is recorded, processed, summarized and1998,reported within the time periods specified in the Securities and Exchange Commission’s rules and forms.Registrant has been reviewing the procedures and controls for development of its tax accruals and current and deferred tax estimates. In the fourth quarter of 2003, Registrant completed this review of its processes and controls for developing its tax provision and related balances. This culminated in the development of a formal procedure for the development and review of the tax balances and estimates. Registrant hired a new tax manager to carry out the review and to implement and comply with the formal procedures.
In addition, Registrant has formalized procedures in place, covering the bidding of capital projects. These procedures are designed to achieve the lowest bid price from qualified contractors as well as to promote diversity among contractors. The procedures also provide for bypass of a formal bid process for emergency situations. Registrant has recently discovered that a greater than anticipated percentage of contracts in certain areas were being awarded on an emergency basis and to fewer than anticipated contractors. Certain of those contracts are being further scrutinized by Registrant. In addition, two executives involved in awarding such capital contracts have been terminated, in part, for perceived failures to adequately follow Registrant’s procedures. Registrant is evaluating its bidding procedures for capital projects as a part of its review of internal controls in preparation for compliance with Section 404 of the Sarbanes-Oxley Act of 2002 and may, based on the results of
its operationsthis review, modify those procedures in order to ensure that the Company’s objectives are being met in a consistent manner.92
PART III
Item 10. Directors and
its cash flows for eachExecutive Officers of thethree years in the period ended December 31, 1999, in conformity with accounting principles generally accepted in the United States. /s/ Arthur Andersen LLP - ----------------------------------- Arthur Andersen LLP Los Angeles, California February 10, 2000, except for Note 14, as to which the date is March 10, 2000 4851 ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE None. PART III ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANTRegistrantInformation responsive to Part III, Item 10 is included in the Proxy Statement, to be filed by Registrant with the Commission pursuant to Regulation 14A, under the captions therein entitled
"Election“Election ofDirectors"Directors” and"Executive“Executive Officers - Experience, Security Ownership andCompensation"Compensation” and is incorporated herein by reference pursuant to General Instruction G(3).ITEMItem 11.
EXECUTIVE COMPENSATIONExecutive CompensationInformation responsive to Part III, Item 11 is included in the Proxy Statement, to be filed by Registrant with the Commission pursuant to Regulation 14A, under the captions therein entitled
"Election“Election ofDirectors"Directors” and"Executive“Executive Officers - Experience, Security Ownership andCompensation"Compensation” and"Performance Graph"“Performance Graph” and is incorporated herein by reference pursuant to General Instruction G(3).ITEMItem 12.
SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENTSecurity Ownership of Certain Beneficial Owners and Management and Related Stockholder MattersInformation responsive to Part III, Item 12 is included in the Proxy Statement, to be filed by Registrant with the Commission pursuant to Regulation 14A, under the captions therein entitled
"Election“Election ofDirectors"Directors” and"Executive“Executive Officers - Experience, Security Ownership andCompensation"Compensation” and is incorporated herein by reference pursuant to General Instruction G(3).ITEMItem 13.
CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONSCertain Relationships and Related TransactionsInformation responsive to Part III, Item 13 is included in the Proxy Statement, to be filed by Registrant with the Commission pursuant to Regulation 14A, under the captions therein entitled
"Election“Election ofDirectors"Directors” and is incorporated herein by reference pursuant to General Instruction G(3).PART IV ITEMItem 14.
EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K (a) 1. ReferencePrincipal Accounting Fees and ServicesInformation responsive to Part III, Item 14 is
madeincluded in the Proxy Statement, to be filed by Registrant with theFinancial StatementsCommission pursuant to Regulation 14A, under the captions therein entitled “Information on Independent Public Accountants” and is incorporated herein by reference pursuant toPart II,General Instruction G(3).Item
8 hereof. 2. All required schedules may be found in the15. Exhibits, FinancialStatementsStatement Schedules andNotes to Financial Statements incorporated herein by reference to Part II, Item 8 hereof or at the conclusion of this Item. Schedules III, IV, and V are omitted as they are not applicable. (b) Exhibits - 3.1 By-Laws of American States Water Company incorporated herein by reference to Registrant'sReports on Form 8-Kdated November 2, 1998. Commission File No. 333- 47647. 4952
(a) 1. Reference is made to the Financial Statements incorporated herein by reference to Part II, Item 8 hereof. 2. All required schedules may be found in the Financial Statements and Notes to Financial Statements incorporated herein by reference to Part II, Item 8 hereof or at the conclusion of this Item. Schedules II, III, IV, and V are omitted as they are not applicable. (b) No reports on Form 8-K were filed with the SEC during the fourth quarter of 2003. (c) Exhibits -
3.1 By-Laws of American States Water Company incorporated herein by reference to Registrant’s Form 8-K, dated November 2, 1998. 3.2 Amended and Restated By-laws of Southern California Water Company incorporated by reference to Registrant's Form 10-K for the year ended December 31, 1998. Commission File No. 001-14431. 3.3 Amended and Restated Articles of Incorporation of American States Water Company incorporated herein by reference to Registrant's Form 8-K, dated November 2, 1998. Commission File No. 333-47647. 3.3.1 Certificate of Amendment of Amended and Restated Articles of Incorporation, dated August 25, 1998, of American States Water Company incorporated by reference to Registrant's Form 10-K for the year ended December 31, 1998. Commission File No. 001-14431. 3.3.2 Certificate of Amendment of Amended and Restated Articles of Incorporation of American States Water Company, dated August 25, 1999.(1) 3.3 Restated Articles of Incorporation of Southern California Water Company incorporated herein by reference to Registrant's Form 8-K, dated January 20, 1999. Commission File No. 000-01121. 4.1 Amended and Restated Rights Agreement, dated January 25, 1999, by and between American States Water Company and ChaseMellon Shareholder Services, L.L.C., as Rights Agent incorporated by reference to Registrant's Form 10-K for the year ended December 31, 1998. Commission File No. 001-14431. 4.2 Indenture, dated September 1, 1993 between Southern California Water Company and Chemical Trust Company of California incorporated herein by reference to Registrant's Form 8-K. Registration No. 33-62832. 10.1 Agreement of Merger dated as of June 25, 1998 by and among Southern California Water Company, SCW Acquisition Corp. and American States Water Company incorporated herein by reference to Registrant's Form 8-K, dated July 1, 1998. Commission File No. 333-47647. 10.2 Deferred Compensation Plan for Directors and Executives incorporated herein by reference to Registrant's Registration Statement on Form S-2. Registration No. 33-5151.(2) 10.3 Reimbursement Agreement, dated October 3, 1997, between Southern California Water Company and The Bank of Nova Scotia incorporated herein by reference to Registrant's Form 10-K with respect to the year ended December 31, 1997. Commission File No. 000-01121. 10.4 Second Sublease dated October 5, 1984 between Southern California Water Company and Three Valleys Municipal Water District incorporated herein by reference to Registrant's Registration Statement on Form S-2. Registration No. 33-5151. 5053 10.5 Note Agreement dated as of May 15, 1991 between Southern California Water Company and Transamerica Occidental Life Insurance Company incorporated herein by reference to Registrant's Form 10-Q with respect to the quarter ended June 30, 1991. Commission File No. 000-01121. 10.6 Schedule of omitted Note Agreements, dated May 15, 1991, between Southern California Water Company and Transamerica Annuity Life Insurance Company, and Southern California Water Company and First Colony Life Insurance Company incorporated herein by reference to Registrant's Form 10-Q with respect to the quarter ended June 30, 1991. Commission File No. 000-01121. 10.7 Loan Agreement between California Pollution Control Financing Authority and Southern California Water Company, dated as of December 1, 1996 incorporated by reference to Registrant's Form 10-K for the year ended December 31, 1998. Commission File No. 001-14431. 10.8 Agreement for Financing Capital Improvement dated as of June 2, 1992 between Southern California Water Company and Three Valleys Municipal Water District incorporated herein by reference to Registrant's Form 10-K with respect to the year ended December 31, 1992. Commission File No. 000-01121. 10.9 Water Supply Agreement dated as of June 1, 1994 between Southern California Water Company and Central Coast Water Authority incorporated herein by reference to Registrant's Form 10-K with respect to the year ended December 31, 1994. Commission File No. 000-01121. 10.10 Amended and Restated Retirement Plan for Non-Employee Directors of American States Water Company, dated as of October 25, 1999.(1)(2) 10.11 Dividend Reinvestment and Common Share Purchase Plan incorporated herein by reference to American States Water Company Rule 424 (b) (3) filing dated October 27, 1999. Commission File No. 333-88979. 10.12 Key Executive Long-Term Incentive Plan incorporated herein by reference to Registrant's 1995 Proxy Statement, Commission File No. 00 0-01121.(2) 10.13 Energy Management Services Agreement between Southern California Water Company and Illinova Energy Partners, Inc.(1) 10.14 Amended and Restated Change in Control Agreements, dated as of October 25, 1999, between American States Water Company, Southern California Water Company and certain executives.(1)(2) 10.15 Amended and Restated Change in Control Agreements, dated as of October 25, 1999, between Southern California Water Company and certain executives.(1)(2) 10.16 Southern California Water Company Pension Restoration Plan.(1)(2) 10.17 American States Water Company Annual Incentive Plan.(1)(2) 13. 1999 Annual Report to Shareholders.(1) 5154 21. Subsidiaries of Registrant incorporated herein by reference to Registrant's Form 10-K with respect to the year ended December 31, 1998. Commission File No. 001-14431. 23. Consent of Independent Public Accountants.(1) 27. Schedule UT.(1) (d) None. --------------------- (1) Filed concurrently herewith (2) Management contract or compensatory arrangement 5255 REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS ON SUPPLEMENTAL SCHEDULE To American States Water Company: We have audited in accordance with auditing standards generally accepted in the United States, the consolidated financial statements included in this Form 10-K, and have issued our report thereon dated February 10, 2000. Our audits of the consolidated financial statements were made for the purpose of forming an opinion on those basic consolidated financial statements taken as a whole. The supplemental schedule listed in Part IV of this Form 10-K, which is the responsibility of American States Water Company's management, is presented for purposes of complying with the Securities and Exchange Commission's rules and regulations, and is not part of the basic consolidated financial statements. This supplemental schedule has been subjected to the auditing procedures applied in the audits of the basic consolidated financial statements and, in our opinion, fairly states in all material respects the financial data required to be set forth therein in relation to the basic consolidated financial statements taken as a whole. /s/ Arthur Andersen LLP - ----------------------------------- Arthur Andersen LLP Los Angeles, California February 10, 2000 5356 AMERICAN STATES WATER COMPANY SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT CONDENSED BALANCE SHEETS
December 31, --------------------------- 1999 1998 --------- --------- (in thousands)ASSETS Cash and equivalents $ 169 $ 96 Other current assets 4,003 139 --------- --------- Total current assets 4,172 235 Investments in subsidiaries 160,370 156,035 Other deferred debits 123 50 ========= ========= Total assets $ 164,665 $ 156,320 ========= ========= LIABILITIES AND CAPITALIZATION Accounts payable $ 4,116 $ 164 Other current liabilities (257) (143) --------- --------- Total current liabilities 3,859 21 Common shareholders' equity 158,846 154,299 Preferred shares 1,960 2,000 --------- --------- Total capitalization 160,806 156,299 Total liabilities and capitalization $ 164,665 $ 156,320 ========= =========5457 CONDENSED STATEMENTS OF INCOME For the Year Ended December 31, 1999, and the Six Months Ended December 31, 1998
1999 1998 -------- -------- (in thousands except per share amount)Operating Revenue And Other Income $ 413 $ (397) Operating Expenses 654 166 -------- -------- Loss Before Equity in Earnings of Subsidiaries (241) (563) Equity in Earnings of Subsidiaries 16,342 15,140 -------- -------- Net Income 16,101 14,577 Dividends on Preferred Shares (88) (44) -------- -------- Earnings Available For Common Shareholders $ 16,013 $ 14,533 -------- -------- Weighted Average Number of Common Shares Outstanding 8,958 8,958 -------- -------- Basic Earnings Per Common Share $ 1.79 $ 1.62 -------- --------5558 CONDENSED STATEMENTS OF CASH FLOWS For the Year Ended December 31, 1999, and the Six Months Ended December 31, 1998
1999 1998 -------- ------- (in thousands)Cash Flows From Operating Activities $ 11,666 $ 5,793 -------- ------- Cash Flows Used in Financing Activities (11,593) (5,697) -------- ------- Increase (Decrease) in Cash and Equivalents 73 96 Cash and Equivalents at Beginning of Period 96 -- -------- ------- Cash and Equivalents at the End of Period $ 169 $ 96 -------- ------- Cash dividends received fromSouthern California Water Company$ 12,040 $ 5,889incorporated by reference to Registrant’s Form 10-K for the year ended December 31, 2002.3.3 Amended and Restated Articles of Incorporation of American States Water Company incorporated by reference to Registrant’s Form 10-K for the year ended December 31, 2002. 3.3.1 Restated Articles of Incorporation of Southern California Water Company incorporated herein by reference to Registrant’s Form 8-K, dated January 20, 1999. 565993
4.1 Amended and Restated Rights Agreement, dated January 25, 1999, by and between American States Water Company and ChaseMellon Shareholder Services, L.L.C., as Rights Agent incorporated by reference to Registrant’s Form 10-K for the year ended December 31, 1998. 4.2 Indenture, dated September 1, 1993 between Southern California Water Company and Chemical Trust Company of California incorporated herein by reference to Registrant’s Form 8-K. 10.1 Agreement of Merger dated as of June 25, 1998 by and among Southern California Water Company, SCW Acquisition Corp. and American States Water Company incorporated herein by reference to Registrant’s Form 8-K, dated July 1, 1998. 10.2 Deferred Compensation Plan for Directors and Executives incorporated herein by reference to Registrant’s Registration Statement on Form S-2, Registration No. 33-5151.(2) 10.3 Second Sublease dated October 5, 1984 between Southern California Water Company and Three Valleys Municipal Water District incorporated herein by reference to Registrant’s Registration Statement on Form S-2, Registration No. 33-5151. 10.4 Note Agreement dated as of May 15, 1991 between Southern California Water Company and Transamerica Occidental Life Insurance Company incorporated herein by reference to Registrant’s Form 10-Q with respect to the quarter ended June 30, 1991. 10.5 Schedule of omitted Note Agreements, dated May 15, 1991, between Southern California Water Company and Transamerica Annuity Life Insurance Company, and Southern California Water Company and First Colony Life Insurance Company incorporated herein by reference to Registrant’s Form 10-Q with respect to the quarter ended June 30, 1991. 10.6 Loan Agreement between California Pollution Control Financing Authority and Southern California Water Company, dated as of December 1, 1996 incorporated by reference to Registrant’s Form 10-K for the year ended December 31, 1998. 10.7 Agreement for Financing Capital Improvement dated as of June 2, 1992 between Southern California Water Company and Three Valleys Municipal Water District incorporated herein by reference to Registrant’s Form 10-K with respect to the year ended December 31, 1992. 10.8 Water Supply Agreement dated as of June 1, 1994 between Southern California Water Company and Central Coast Water Authority incorporated herein by reference to Registrant’s Form 10-K with respect to the year ended December 31, 1994. 10.9 Amended and Restated Retirement Plan for Non-Employee Directors of American States Water Company, dated as of October 25, 1999, incorporated herein by reference to Registrant’s Form 10-K with respect to the year ended December 31, 1999.(2) 10.10 Dividend Reinvestment and Common Share Purchase Plan incorporated herein by reference to American States Water Company Rule 424 (b) (3) filing dated October 27, 1999. 10.11 Amended and Restated Change in Control Agreements, dated as of October 25, 1999, between American States Water Company, Southern California Water Company and certain executives incorporated herein by reference to Registrant’s Form 10-K with respect to the year ended December 31, 1999.(2) 10.12 Amended and Restated Change in Control Agreements, dated as of October 25, 1999, between Southern California Water Company and certain executives incorporated by reference to Registrant’s Form 10-K with respect to the year ended December 31, 1999.(2) 10.13 Southern California Water Company Pension Restoration Plan incorporated herein by reference to Registrant’s Form 10-K with respect to the year ended December 31, 1999.(2) 10.14 American States Water Company Annual Incentive Plan as amended April 29, 2002 incorporated by reference to Registrant’s Form 10-Q for the quarter ended March 31, 2002.(2) 94
10.15 American States Water Company amended 2000 Stock Incentive Plan incorporated herein by reference to Registrant’s Form 10-Q for the quarter ended September 30, 2003. (2) 10.16 Loan and Trust Agreement between The Industrial Development Authority of The County of Maricopa, Chaparral City Water Company and Bank One, Arizona, NA,, dated as of December 1, 1997 incorporated by reference to Registrant’s Form 10-K with respect to the year ended December 31, 2000. 10.17 Delivery Agreement between Central Arizona Water Conservation District and Chaparral City Water Company, dated as of December 6, 1984 incorporated by reference to Registrant’s Form 10-K with respect to the year ended December 31, 2000. 10.18 Repayment Contract between the United States Bureau of Reclamation and Chaparral City Water Company, dated as of December 6, 1984 for construction of a delivery and storage system to transport CAP water incorporated by reference to Registrant’s Form 10-K with respect to the year ended December 31, 2000. 10.19 Energy Transaction Confirmation with Mirant Americas Energy Marketing, LP incorporated by reference to Registrant’s Form 10-Q with respect to the quarter ended March 31, 2001. 10.20 Power Purchase Agreement in June 2001 between Southern California Water Company and Pinnacle West Capital Corporation incorporated by reference to Registrant’s Form 10-Q with respect to the quarter ended June 30, 2001. 10.21 Western Systems Power Pool Agreement incorporated by reference to Registrant’s Form 10-Q with respect to the quarter ended June 30, 2001. 10.22 Automated Power Exchange Master Service and Participation Agreement incorporated by reference to Registrant’s Form 10-K with respect to the year ended December 31, 2001. 10.23 American States Water Company Three-Year Dividend Equivalent Right Certificate incorporated by reference to Registrant’s Form 10-Q for the quarter ended March 31, 2002. (2) 10.24 Power Purchase Agreement dated September 3, 2002 between Southern California Water Company and Pinnacle West Capital Corporation incorporated by reference to Registrant’s Form 10-K for the year ended December 31, 2002. 10.25 Amendment to the Credit Agreement between American States Water Company dated June 6, 2002 with Wells Fargo Bank, N.A., as Administrative Agent incorporated by reference to Registrant’s Form 10-K for the year ended December 31, 2002(1). 21. Subsidiaries of Registrant incorporated herein by reference to Registrant’s Form 10-K with respect to the year ended December 31, 1998. 23. Consent of Independent Public Accountants. (1) 31.1 Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002(1) 31.2 Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (1) 32.1 Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (3) 32.2 Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (3)
(d) None.
(1) Filed concurrently herewith (2) Management contract or compensatory arrangement (3) Furnished concurrently herewith. 95
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
AMERICAN STATES WATER COMPANY and its subsidiary SOUTHERN CALIFORNIA WATER COMPANY By: /s/ McCLELLAN HARRIS III . -------------------------------- McClellan Harris III Vice President - Finance, Treasurer, Chief Financial Officer and Secretary Date: March 15, 2000
AMERICAN STATES WATER COMPANY
and its subsidiary
SOUTHERN CALIFORNIA WATER COMPANYBy: /s/ McCLELLAN HARRIS III Sr. Vice President-Finance, Chief Financial Officer, Treasurer and Secretary Date: March 23, 2004 Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of Registrant and in the capacities and on the dates indicated.
/s/ LLOYD E. ROSS . Date: March 15, 2000 - ----------------------------------- Lloyd E. Ross
Date: /s/ LLOYD E. ROSS
Lloyd E. Ross
Chairman of the Board and DirectorMarch 23, 2004 /s/ FLOYD E. WICKS
Floyd E. Wicks
Principal Executive Officer, President,
CEO and DirectorMarch 23, 2004 /s/ McCLELLAN HARRIS III
McClellan Harris III
Principal Financial and Accounting Officer,
Sr. VP-Finance, CFO, Treasurer and
SecretaryMarch 23, 2004 /s/ JAMES L. ANDERSON
James L. Anderson
DirectorMarch 23, 2004 /s/ JEAN E. AUER
Jean E. Auer
DirectorMarch 23, 2004 /s/ N.P. DODGE, JR.
N.P. Dodge, Jr.
DirectorMarch 23, 2004 /s/ ANNE M. HOLLOWAY
Anne M. Holloway
DirectorMarch 23, 2004 /s/ ROBERT F. KATHOL
Robert F. Kathol
DirectorMarch 23, 2004 96
Report of Independent Auditors on
Financial Statement SchedulesTo the Board of Directors
of American States Water CompanyOur audits of the
Board and Director /s/ FLOYD E. WICKS .consolidated financial statements referred to in our report dated March15, 2000 - ----------------------------------- Floyd E. Wicks Principal Executive Officer; President, CEO and Director /s/ McCLELLAN HARRIS III . March 15, 2000 - ----------------------------------- Clellan Harris III Principal Financial and Accounting Officer; CFO, VP - Finance, Treasurer and Secretary /s/ LINDA J. MATLICK . March 15, 2000 - ----------------------------------- Linda J. Matlick Controller - Southern California17, 2004 appearing in the 2003 Annual Report to Shareholders of American States Water Company/s/ JAMES L. ANDERSON .(which report and consolidated financial statements are included in this Annual Report on Form 10-K) also included an audit of the financial statement schedules listed in Item 15(a)(2) of this Form 10-K. In our opinion, these financial statement schedules present fairly, in all material respects, the information set forth therein when read in conjunction with the related consolidated financial statements.PricewaterhouseCoopers LLP
Los Angeles, California
March15, 2000 - ----------------------------------- James L. Anderson, Director 5760 /s/ JEAN E. AUER . March 15, 2000 - ----------------------------------- Jean E. Auer, Director /s/ N. P. DODGE, JR. . March 15, 2000 - ----------------------------------- N. P. Dodge, Jr., Director /s/ ANNE M. HOLLOWAY . March 15, 2000 - ----------------------------------- Anne M. Holloway, Director /s/ ROBERT F. KATHOL . March 15, 2000 - ----------------------------------- Robert F. Kathol, Director 5817, 200497
AMERICAN STATES WATER COMPANY
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENTCONDENSED BALANCE SHEET
December 31, (in thousands) 2003 2002 Cash and equivalents $ 2,141 $ 2,297 Inter-company receivables 37,111 12,597 Other current assets 351 1,335
Total current assets 39,603 16,229
Investments in subsidiaries 228,680 231,737 Other deferred debits 284 401
Total assets $ 268,567 $ 248,367
Notes payable to banks $ 56,000 $ 35,000 Accounts payable 1 59 Other liabilities 79 29
Total liabilities 56,080 35,088
Common shareholders’ equity 212,487 213,279
Total capitalization 212,487 213,279
Total liabilities and capitalization $ 268,567 $ 248,367
98
AMERICAN STATES WATER COMPANY
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENTCONDENSED STATEMENTS OF INCOME
December 31, (In thousands, except per share amounts) 2003 2002 2001 Operating Revenues and Other Income $ — $ — $ — Operating Expenses 454 651 403
Loss Before Equity in Earnings of Subsidiaries (454 ) (651 ) (403 ) Equity in Earnings of Subsidiaries 12,346 20,990 21,859
Net Income 11,892 20,339 21,456 Dividends on Preferred Shares — (29 ) (84 )
Earnings Available For Common Shareholders $ 11,892 $ 20,310 $ 21,372
Weighted Average Number of Common Shares Outstanding 15,200 15,144 15,120
Basic Earnings Per Common Share $ 0.78 $ 1.34 $ 1.41
Weighted Average Number of Diluted Common Shares Outstanding 15,227 15,157 15,122
Fully Diluted Earnings per Common Share $ 0.78 $ 1.34 $ 1.41
99
AMERICAN STATES WATER COMPANY
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENTCONDENSED STATEMENTS OF CASH FLOWS
December 31, (in thousands) 2003 2002 2001 Cash Flows (Used in) From Operating Activities ($ 2,120 ) $ 1,247 $ 3,884
Cash Flows Used in Investing Activities — — (25,000 )
Cash Flows From Financing Activities: Net change in notes payable to banks 21,000 15,000 20,000 Net change in inter-company borrowings (21,000 ) (14,000 ) — Redemption of preferred shares — (1,880 ) — Dividends paid (13,436 ) (13,223 ) (13,188 ) Dividends received from subsidiaries 15,400 14,630 14,533
Net cash provided from financing activities 1,964 527 21,345
Increase (Decrease) in Cash and Equivalents (156 ) 1,774 229 Cash and Equivalents at Beginning of Period 2,297 523 294
Cash and Equivalents at the End of Period $ 2,141 $ 2,297 $ 523
Cash dividends received from Southern California Water Company and Chaparral City Water Company $ 15,400 $ 14,630 $ 14,533
100