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Home My WebLink About2002Annual Report.pdfTHIS FILING IS (CHECK ONE BOX FOR EACH ITEM) Item 1: (!J An Initial (Original) Submission OR Resubmission No. Form Approved OMB No. 1902-0021 (Expires 3/31/2005) Item 2: 0 An Original Signed Form OR Conformed Copy ;", r-.:o ....,,-, ;;:J C-I..:' ::!1:rrl-it::,J:;:--c:J f"\'"\::~(f)t., fT1 () -, Oc''7':tF(/)0 (/)(...) FERC Form No. ANNUAL REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHERS This report is mandatory under the Federal Power Act, Sections 3 4(a), 304 and 309 and 18 CFR 141.1. Failure to report may result ,in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider this report to be of a confidential nature. c::: ~~, r,1~, CJ) ( o-~ , c: r--.) u.) :r:. ...... 1 :;':"0 .".- IT'!I~;n -' (Il ,-' .::: f'T1 :tP (""J Cf! C1' ,,- Exact Legal Name of Respondent (Company) PacifiCorp Year of Report Dec. 31,2002 FERC FORM No.1 (REV. 12-98) Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31 2002 FOOTNOTE DATA Schedule Page: 278 Line No.Column: b 440. 442. 442.2 442. 444. Schedule Pa e: 278 Line No.Column: b 449. 449. 449. IFERC FORM NO.(ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31,2002 FOOTNOTE DATA Line No.Column: b Revenue 617 361 869 52.384.624 672 557,493 Column: d MWH 17,402 646 338.059 740,705 Column: f Customers 12,056 22.680 736 IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dee 31 2002 FOOTNOTE DATA Column: bISchedule Page: 310 Line No. Prior Period Adjustment ISchedule Page: 310 Line No. Prior Period Adjustment Column: j ISchedule Page: 310 Line No.12 Column: j Accrual Adjustment ISchedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. firm transactions. ISchedule Page: 310.Line No.10 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. ISchedule Page: 310.Line No.12 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. !schedule Page: 310. Operating Reserves ISchedule Page: 310. Liquidated Damages Line No.Column: j Line No.Column: j !schedule Page: 310.Line No.Column: b econdary, Economy and/or non-firm sales, including some hourly firm transactions. !Schedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. Schedule Page: 310.Line No.Column: b Prior Period Adjustment Schedule Page: 310.Line No.Column: j Prior Period Adjustment ISchedule Page: 310.Line No.Column: b Black Hills Power & Light Company - FERC 236 - Contract termination date: December 31 2023 March 31 , 2002 IFERC FORM NO.1 (ED. 12-87)Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee31.2oo2 FOOTNOTE DATA ISchedule Page: 310.Line No.12 Column: b econdary, Economy and/or non-firm sales, including some hourly firm transactions. !Schedule Page: 310.Line No.13 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. 'Schedule Page: 310.2 Lin~ No.14 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. !Schedule Page: 310.Line No.Column: b Blanding City - FERC T -12 - Contract termination date: March 1 , 2007. !Schedule Page: 310.Line No.Column: b Prior Period Adjustment 'Schedule Page: 310.Line No.Column: Prior Period Adjustment ISchedule Page: 310.Line No.Column: b Bonneville Power Administration - FERC 543 - Contract termination date:September 30, 2006 \Schedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. Schedule Page: 310.Line No.Column: b Prior Period Adjustment Schedule Page: 310.Line No.Column: j Prior Period Adjustment Schedule Page: 310.Line No.Column: b Prior Period Adjustment Schedule Page: 310.Line No.Column: j Prior Period Adjustment ISchedule Page: 310.Line No.13 Column: b Clark County PUD #1 - FERC T-12 - Contract Termination date: December 12, 2007 ISchedule Page: 310.Line No.13 Column: Curtailments 'Schedule Page: 310.Line No.14 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. \Schedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. 'Schedule Page: 310.Line No. Prior Period Adjustment Column: b IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/3012003 Dee 31,2002 FOOTNOTE DATA ISchedule Page: 310.Line No.Column: Prior Period Ad"ustment Schedule Pa e: 310.Line No.Column: b Cowlitz County PUD - FERC T-12 - Contract Termination date: April 30, 2002 ISchedule Page: 310.Line No. rior Period Adjustment !schedule Page: 310.Line No. Prior Period Adjustment Column: b Column: j ISchedule Page: 310.Line No.10 Column: b eseret Generation & Transmission Cooperative - FERC 462 - Contract Termination July 25, 2003 !Schedule Page: 310.Line No.11 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. 'Schedule Page: 310.Line No. Prior Period Adjustment Column: b ISchedule Page: 310.Line No.12 Column: rior Period Adjustment !schedule Page: 310.Line No.13 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. Schedule Page: 310.Line No.Column: b Prior Period Adjustment Schedule Page: 310.Line No.Column: j Prior Period Adjustment 'Schedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. Schedule Page: 310.Line No.Column: j Operating Reserves chedule Page: 310.Line No.Column: b Prior Period Adjustment chedule Page: 310.Line No.Column: j Prior Period Adjustment 'Schedule Page: 310.Line No.Column: b Flathead Electric Cooperative, Inc./Energy Northwest Inc. - FERC T-12 - Contract Termination date: September 30 2006 'Schedule Page: 310.Line No. Prior Period Adjustment Column: b IFERC FORM NO.1 (ED. 12-87)Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/3012003 Dee 31,2002 FOOTNOTE DATA 'Schedule Page: 310.Line No. Prior Period Adjustment ISchedule Page: 310.Line No.12 Column: b Green Mountain Energy Resources, LLC - FERC T-3 - Contract termination date: December 31 2003 ISchedule Page: 310.Line No.13 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. Column: j !Schedule Page: 310.Line No. Prior Period Adjustment ISchedule Page: 310.Line No. Prior Period Adjustment Column: b Column: j ISchedule Page: 310.Line No.Column: b urricane, City of - FERC T-12 - Contract Termination date: August 31 2007 !Schedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. ISchedule Page: 310. Liquidated Damages ISchedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. Line No.Column: j !schedule Page: 310.Line No.11 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. ISchedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. 'Schedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. ISchedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. !Schedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions, chedule Page: 310.Line No.Column: j Operating Reserves chedule Page: 310.Line No.Column: j Trade Sales ISchedule Page: 310.Line No.12 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions, IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31 2002 FOOTNOTE DATA ISchedule Page: 310. Operating Reserves 'Schedule Page: 310.Line No.14 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. Line No.Column: j !Schedule Page: 310. Operating Reserves 'Schedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. Line No.Column: j !schedule Page: 310.Line No.Column: b Public Service Company of Colorado - FERC 320 - Contract termination date: October 31 , 2022 'Schedule Page: 310. Liquidated Damages !Schedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. Line No.Column:j ISchedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. !Schedule Page: 310. perating Reserves !Schedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions, Line No.Column: j Schedule Page: 310.Line No.Column: j Operating Reserves Schedule Page: 310.Line No.Column: j Liquidated Damages 'Schedule Page: 310.Line No.11 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. ISchedule Page: 310. Operating Reserves 'Schedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. Line No.Column: j ISchedule Page: 310. Pond Sale Line No.Column: j 'Schedule Page: 310.Line No.Column: b Puget Sound Power & Light Company - FERC 254 - Contract termination date: October 31 , 2003 IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1)~An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31 2002 FOOTNOTE DATA 'Schedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions, ISchedule Page: 310.Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions, Schedule Page: 310.Line No.Column: j Operating Reserves Schedule Page: 310.Line No.Column: b Prior Period Adjustment Schedule Page: 310.Line No.Column: j Prior Period Adjustment 'Schedule Page: 310.Line No.10 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. Schedule Page: 310.Line No.Column: b Prior Period Adjustment Schedule Page: 310.Line No.Column: j Prior Period Adjustment !Schedule Page: 310.Line No.13 Column: b Sacramento Municipal Utility District - FERC 250 - Contract termination date: December 31 , 2014 !Schedule Page: 310.Line No.14 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. ISchedule Page: 310.10 Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. Schedule Page: 310.Line No.Column: b Prior Period Adjustment Schedule Page: 310.Line No.Column: j Prior Period Adjustment ISchedule Page: 310.10 Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. 'Schedule Page: 310. Operating Reserves ISchedule Page: 310.10 Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. Line No.Column: j ISchedule Page: 310.Line No.Column: b IFERC FORM NO.1 (ED. 12-87)Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31,2002 FOOTNOTE DATA Prior Period Adjustment ISchedule Page: 310. Prior Period Adjustment ISchedule Page: 310. Prior Period Adjustment ISchedule Page: 310. Prior Period Adjustment Line No.Column: j Line No.Column: b Line No.Column: j ISchedule Page: 310.10 Line No.13 Column: b Sierra Pacific Power Company - FERC 258 - Contract termination date: February 28, 2009 !Schedule Page: 310.10 Line No.14 Column: b Sierra Pacific Power Company - FERC 267 - Contract termination date: April 30, 2021 !Schedule Page: 310.11 Line No.Column: b econdary, Economy and/or non-firm sales, including some hourly firm transactions. !schedule Page: 310.11 Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions, !Schedule Page: 310. perating Reserves \Schedule Page: 310.11 Line No.Column: b Southern California Edison Company - FERC 248 - Contract termination date: September 30, 2006 Line No.Column: j !schedule Page: 310.11 Line No.Column: b Springfield Utility Board - FERC 423 - Contract termination date: July 31 , 2015 Schedule Page: 310.Line No.Column: b Prior Period Adjustment chedule Page: 310.Line No.Column: j Prior Period Adjustment ISchedule Page: 310.11 Line No.10 Column: b State of California - FERC 311 - Contract termination date: December 31 , 2004 'Schedule Page: 310.11 Line No.13 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. Schedule Page: 310.Line No.Column: b Prior Period Adjustment Schedule Page: 310.Line No.Column: j Prior Period Adjustment IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dee 31 , 2002 FOOTNOTE DATA ISchedule Page: 310.12 Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions, 'Schedule Page: 310. Operating Reserves ISchedule Page: 310.12 Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. Line No.Column: j 'Schedule Page: 310.12 Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. ISchedule Page: 310.12 Line No.Column: b Utah Municipal Power Agency - FERC 433 - Contract termination date: July 1 , 2005 'Schedule Page: 310.12 Line No.10 Column: b Utah Municipal Power Agency - FERC 433 - Contract termination date: June 30, 2017 ISchedule Page: 310.12 Line No.11 Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. !schedule Page: 310.12 Line No.13 Column: b WaferTech - FERC T-12 - Contract Termination date: November 30 2002 'Schedule Page: 310.12 Line No.14 Column: b Western Area Power Administration - FERC 313 - Contract termination date: December 31 2004 !schedule Page: 310.13 Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. ISchedule Page: 310.13 Line No.Column: b Secondary, Economy and/or non-firm sales, including some hourly firm transactions. !Schedule Page: 310. Accrual Adjustment Line No.Column: j IFERC FORM NO.1 (ED. 12-87)Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmisslon 04/30/2003 Dee 31 , 2002 FOOTNOTE DATA ISchedule Page: 326 Option premium. ISchedule Page: 326 Line No.Column: b Secondary, economy and/or non-firm purchases. Line No.Column: I !Schedule Page: 326 Line No.Column: b Aquila Power Corp. - Contract Termination Date: September 30,2006. ISchedule Page: 326 ption premium. !Schedule Page: 326 Line No. Gas hedge for tolling agreement. Line No.Column: I Column: I ISchedule Page: 326 Line No. Prior period adjustment. ISchedule Page: 326 Line No. Prior period adjustment. Column: b Column: I ISchedule Page: 326 Line No.10 Column: b Secondary, economy and/or non-firm purchases. ISchedule Page: 326 Line No.11 Column: b Arizona Public Service - Contract Termination Date: October 31 , 2020. ISchedule Page: 326 Line No. Prior period adjustment. ISchedule Page: 326 Line No.12 Column: b Secondary, economy and/or non-firm purchases. Column: I 'Schedule Page: 326 Load curtailment. Line No.Column: I !schedule Page: 326 Line No.13 Column: b Avista Corp. - Contract Termination Date: September 15, 2003. 'Schedule Page: 326 Line No.14 Column: b Secondary, economy and/or non-firm purchases. ISchedule Page: 326 Line No.14 Column: I Operating reservation, Operating expense, bond interest, amortization and taxes. !Schedule Page: 326.Line No.Column: b Secondary, economy and/or non-firm purchases, IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31 , 2002 FOOTNOTE DATA ISchedule Page: 326. Operating reservation. ISchedule Page: 326.Line No.Column: b Under Electric Service Agreement subject to termination upon timely notification. Line No.Column: I !Schedule Page: 326.Line No. Prior period adjustment. 'Schedule Page: 326.Line No. Non-generation agreement. Column: I Column: I ISchedule Page: 326.Line No. Prior period adjustment. ISchedule Page: 326.Line No. Prior period adjustment. Column: b Column: I !schedule Page: 326.Line No.10 Column: b econdary, economy and/or non-firm purchases. !Schedule Page: 326.Line No.12 Column: I Operation and maintenance expense associated with the combustion turbine located in Rapid City, South Dakota. !schedule Page: 326.Line No.Column: b Bonneville Power Administration - Contract Termination Date: 30 days written notice. 'Schedule Page: 326. perating reservation, !schedule Page: 326.Line No.Column: b Secondary, economy and/or non-firm purchases. Line No.Column: I Schedule Page: 326.Line No.Column: I Operating reservation. Schedule Page: 326.Line No.Column: b Prior period adjustment. Schedule Page: 326.Line No.Column: I Operating reservation. 'Schedule Page: 326.Line No. Non-generation agreement. Column: I IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmisslon 04/30/2003 Dee 31 2002 FOOTNOTE DATA chedule Page: 326.Line No.Column: b Prior period adjustment. Schedule Page: 326.Line No.Column: I Prior period adjustment. Schedule Page: 326.Line No.Column: b Prior period adjustment. Schedule Page: 326.Line No.Column: I Prior p'eriod adjustment. 'Schedule Page: 326.Line No.11 Column: I Prior Period Adjustment !Schedule Page: 326.Line No.12 Column: b Prior period adjustment. ISchedule Page: 326.Line No. Prior period adjustment. 'Schedule Page: 326.Line No.14 Column: b Secondary, economy and/or non-firm purchases. Column: I !schedule Page: 326.Line No.Column: b Secondary, economy and/or non-firm purchases. ISchedule Page: 326. Load curtailment. Line No.Column: I ISchedule Page: 326.Line No.Column: I Operating expense, bond interest, amortization and taxes. ISchedule Page: 326.Line No. Prior period adjustment. ISchedule Page: 326.Line No.Column: b Secondary, economy and/or non-firm purchases. Column: I ISchedule Page: 326.Line No.Column: I Operating expense, bond interest, amortization and taxes. 'Schedule Page: 326.Line No.12 Column: b Columbia Storage Power Exchange - Contract Termination Date: March 31 2003. !Schedule Page: 326.Line No. Prior period adjustment. ISchedule Page: 326.Line No. Prior period adjustment. Column: b Column: I I FERC FORM NO.1 (ED. 12-87)Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31,2002 FOOTNOTE DATA ISChedule Page: 326.Line No.Column: b Secondary, economy and/or non-firm purchases. ISchedule Page: 326.Line No. Temperature hedge payout. Column: I SChedule Page: 326.Line No.Column: I Option premium. Schedule Page: 326.Line No.Column: b Prior period adjustment. Schedule Page: 326.Line No.Column: I Prior period adjustment. ISchedule Page: 326.Line No.11 Column: b Deseret Generation & Transmission Coop. - Contract Termination Date: July 25, 2003. 'Schedule Page: 326.Line No. Prior period adjustment. ISchedule Page: 326.Line No. Prior period adjustment. Column: b Column: I ISchedule Page: 326.Line No.Column: I Operating expense, bond interest, amortization and taxes. 'Schedule Page: 326.Line No.Column: b Secondary, economy and/or non-firm purchases. ISchedule Page: 326.Line No. Prior period adjustment. 'Schedule Page: 326.Line No. Prior period adjustment. Column: b Column: I ISchedule Page: 326.Line No.Column: b Secondary, economy and/or non-firm purchases, Schedule Page: 326.Line No.Column: I Prior period adjustment. Schedule Page: 326.Line No.Column: b Prior period adjustment. Schedule Page: 326.Line No.Column: I Prior period adjustment. ISchedule Page: 326.Line No.10 Column: b Secondary, economy and/or non-firm purchases, IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dee 31 , 2002 FOOTNOTE DATA !Schedule Page: 326.Line No.12 Column: b Secondary, economy and/or non-firm purchases. Schedule Page: 326.Line No.Column: b Prior period adjustment. Schedule Page: 326.Line No.Column: I Prior period adjustment. chedule Page: 326.Line No.Column: I Option premium. Schedule Page: 326.Line No.Column: b Prior period adjustment. !schedule Page: 326.Line No.Column: b Secondary, economy and/or non-firm purchases. ISchedule Page: 326.Line No. Prior period adjustment. ISchedule Page: 326.Line No. Prior period adjustment. Column: b Column: I !Schedule Page: 326.Line No.10 Column: b nder Electric Service Agreement subject to termination upon timely notification. \Schedule Page: 326.Line No.14 Column: b Secondary, economy and/or non-firm purchases, Schedule Page: 326.Line No.Column: b Prior period adjustment. Schedule Page: 326.Line No.Column: I Prior period adjustment. Schedule Page: 326.Line No.Column: b Prior period adjustment. Schedule Page: 326.Line No.Column: I Prior period adjustment. ISchedule Page: 326.Line No.Column: b Under Electric Service Agreement subject to termination upon timely notification. ISchedule Page: 326.Line No.Column: b Grant County PUD No, 2 - Contract Termination Date: 2 years written notice. ISchedule Page: 326.Line No.Column: I IFERC FORM NO.1 (ED. 12-87) Page 450, Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31 , 2002 FOOTNOTE DATA ISchedule Page: 326.Line No. Prior period adjustment. ISchedule Page: 326.Line No.Column: I Operating expense, bond interest, amortization and taxes, Column: I 'Schedule Page: 326.Line No. Prior period adjustment. ISchedule Page: 326.Line No. Prior period adjustment. Column: b Column: I ISchedule Page: 326.Line No.10 Column: I Operating expense, bond interest, amortization and taxes, ISchedule Page: 326.Line No.11 Column: b Secondary, economy and/or non-firm purchases. Schedule Page: 326.Line No.Column: I Operating reservation. Schedule Page: 326.Line No.Column: I Prior period adjustment. SchedUle Page: 326.Line No.Column: I Prior period adjustment. 'Schedule Page: 326.Line No.Column: b Under Electric Service Agreement subject to termination upon timely notification. !Schedule Page: 326.Line No. Prior period adjustment. ISchedule Page: 326.Line No. Prior period adjustment. Column: b Column: I !Schedule Page: 326.Line No.Column: I On peak incentive, supplemental dispatch efficiency expense, start-up charges, committee settlements and prior period adjustment. ISchedule Page: 326.Line No. Charge for hourly load shaping, 'Schedule Page: 326.Line No.Column: b Hurricane, City of - Contract Termination Date: August 31 2007, Column: I IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31 , 2002 FOOTNOTE DATA ISchedule Page: 326.Line No.Column: I Labor, equipment and administration fees associated with hydro project in Idaho Falls, Idaho. !Schedule Page: 326. Liquidated damages, ISchedule Page: 326.Line No.11 Column: b Secondary, economy and/or non-firm purchases. Line No.Column: I \Schedule Page: 326. Operating reservation. ISchedule Page: 326.Line No. Gas hedge for tolling agreement. Line No.Column: I Column: I !Schedule Page: 326. Load curtailment. Line No.Column: I !Schedule Page: 326.Line No. Compensation for self-generation, ISchedulePage: 326.Line No. Prior period adjustment. Column: I Column: b !Schedule Page: 326.Line No. rior period adjustment. !schedule Page: 326.Line No.Column: b Secondary, economy and/or non-firm purchases. Column: I 'Schedule Page: 326. Load curtailment. Line No.Column: I !Schedule Page: 326. Option premium. Liquidated damages. Line No.Column: I Schedule Page: 326.Line No.Column: b Prior period adjustment. Schedule Page: 326.Line No.Column: I Prior period adjustment. Schedule Page: 326.Line No.Column: I Prior period adjustment. IFERC FORM NO.1 (ED. 12-87)Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31 2002 FOOTNOTE DATA Schedule Page: 326.Line No.Column: b Prior period adjustment. Schedule Page: 326.Line No.Column: I Prior period adjustment. chedule Page: 326.Line No.Column: I Operating reservation. ISchedule Page: 326.10 Line No.Column: b nder Electric Service Agreement subject to termination upon timely notification. !schedule Page: 326.10 Line No.10 Column: b Secondary, economy and/or non-firm purchases, 'Schedule Page: 326.10 Line No.13 Column: b Under Electric Service Agreement subject to termination upon timely notification. ISchedule Page: 326.10 Line No.14 Column: b Under Electric Service Agreement subject to termination upon timely notification. !Schedule Page: 326.11 Line No.Column: b Secondary, economy and/or non-firm purchases. ISchedule Page: 326.11 Line No.Column: b Secondary, economy and/or non-firm purchases, chedule Page: 326.Line No.Column: I Load curtailment. chedule Page: 326.Line No.Column: I Prior period adjustment. Schedule Page: 326.Line No.Column: I Operating reservation, Schedule Page: 326.Line No.Column: I Prior period adjustment. !schedule Page: 326.11 Line No.14 Column: b Under Electric Service Agreement subject to termination upon timely notification. ISchedule Page: 326. Prior period adjustment. 'Schedule Page: 326.12 Line No.Column: b Secondary, economy and/or non-firm purchases. Line No.Column: I !schedule Page: 326.Line No.Column: b IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmisslon 04/30/2003 Dee 31 2002 FOOTNOTE DATA Secondary, economy and/or non-firm purchases. 'Schedule Page: 326. Operating reservation. 'Schedule Page: 326.12 Line No.Column: b Portland General Electric Company - Contract Termination Date: Round Butte project no longer operating for power production purposes. Line No.Column: I ISchedule Page: 326.12 Line No.Column: I Operation expense plus amortization of unrecovered costs of Cove Project. !Schedule Page: 326.12 Line No.Column: b Secondary, economy and/or non-firm purchases. ISchedule Page: 326. Prior period adjustment. !Schedule Page: 326.12 Line No.Column: b Secondary, economy and/or non-firm purchases. Line No.Column: I !schedule Page: 326.12 Line No.11 Column: b Secondary, economy and/or non-firm purchases. Schedule Page: 326.Line No.Column: I Load curtailment. Schedule Page: 326.Line No.Column: b Prior period adjustment. Schedule Page: 326.Line No.Column: I Prior period adjustment. 'Schedule Page: 326.13 Line No.Column: b nder Electric Service Agreement subject to termination upon timely notification, !Schedule Page: 326.13 Line No.Column: b Secondary, economy and/or non-firm purchases, ISchedule Page: 326. Option premium, ISchedule Page: 326.13 Line No.Column: b Secondary, economy and/or non-firm purchases, Line No.Column: I ISchedule Page: 326.13 Line No.Column: b Secondary, economy and/or non-firm purchases. 'Schedule Page: 326. Operating reservation. Line No.Column: I IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31 2002 FOOTNOTE DATA Operating expense, bond interest, amortization and taxes. Column: b \Schedule Page: 326.13 Line No.11 Column: b Secondary, economy and/or non-firm purchases. 'Schedule Page: 326.13 Line No.13 Column: b Secondary, economy and/or non-firm purchases. ISchedule Page: 326.14 Line No.Column: b Secondary, economy and/or non-firm purchases. 1Schedule Page: 326.14 Line No.Column: b Sacramento Municipal Utility District - Contract Termination Date: December 31 2014. ISchedule Page: 326.14 Line No.Column: b Secondary, economy and/or non-firm purchases, \Schedule Page: 326.14 Line No.12 Column: b Secondary, economy and/or non-firm purchases. ISchedule Page: 326. Operating reservation. Line No.Column: I !schedule Page: 326.14 Line No.14 Column: I Liquidated damages. ISchedule Page: 326.15 Line No.Column: b Secondary, economy and/or non-firm purchases, !Schedule Page: 326. Prior period adjustment. ISchedule Page: 326. Prior period adjustment. Line No.Column: b Line No.Column: I ISchedule Page: 326.15 Line No.Column: b Secondary, economy and/or non-firm purchases. 'Schedule Page: 326.15 Line No.Column: b Sierra Pacific Power Company - Contract Termination Date: April 30, 2021. 'Schedule Page: 326.15 Line No.Column: I Delivery of energy in lieu of financial settlement for losses. ISchedule Page: 326.Line No.Column: I IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2) A Resubmission 04/30/2003 Dee 31 2002 FOOTNOTE DATA Prior period adjustment. ISchedule Page: 326.15 Line No.10 Column: b Southern California Edison Co, - Contract Termination Date: March 15 2003. ISchedule Page: 326. Prior period adjustment. 'Schedule Page: 326.15 Line No.11 Column: b Secondary, economy and/or non-firm purchases, Line No.Column: I ISchedule Page: 326.15 Line No.12 Column: b Under Electric Service Agreement subject to termination upon timely notification. ISchedule Page: 326.15 Line No.14 Column: b Under Electric Service Agreement subject to termination upon timely notification. ISchedule Page: 326. Prior period adjustment. !Schedule Page: 326. Prior period adjustment. Line No.Column: b Line No.Column: I 'Schedule Page: 326.16 Line No.Column: b Under Electric Service Agreement subject to termination upon timely notification. Schedule Page: 326.Line No.Column: I Option premium. Schedule Page: 326.Line No.Column: b Prior period adjustment. Schedule Page: 326.Line No.Column: I Prior period adjustment. 'Schedule Page: 326.16 Line No.Column: b ransalta Energy Marketing Corp. - Contract Termination Date: June 30, 2007. !schedule Page: 326.16 Line No.10 Column: b Secondary, economy and/or non-firm purchases. !schedule Page: 326.16 Line No.12 Column: b Tri-State Generation & Transmission - Contract Termination Date: December 31 2020. ISchedule Page: 326.16 Line No.14 Column: b Secondary, economy and/or non-firm purchases. ISchedule Page: 326. Prior period adjustment. Line No.Column: I IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31 , 2002 FOOTNOTE DATA ISchedule Page: 326.17 Line No.Column: b Secondary, economy and/or non-firm purchases. ISchedule Page: 326.17 Line No.Column: b Secondary, economy and/or non-firm purchases. !Schedule Page: 326.17 Line No.Column: b Secondary, economy and/or non-firm purchases. Schedule Page: 326.Line No.Column: I Load curtailment. Schedule Page: 326.Line No.Column: b Prior period adjustment. Schedule Page: 326.Line No.Column: I Prior period adjustment. ISchedUle Page: 326.17 Line No.10 Column: b Under Electric Service Agreement subject to termination upon timely notification. 'Schedule Page: 326.17 Line No.12 Column: b Secondary, economy and/or non-firm purchases, 'Schedule Page: 326. Operating reservation. 'Schedule Page: 326.18 Line No.Column: b Secondary, economy and/or non-firm purchases !Schedule Page: 326.18 Line No.Column: I Adjustment to financial settlement on energy balance at termination of Electric Service Agreement. Line No.Column: I !Schedule Page: 326.18 Line No.Column: b Secondary, economy and/or non-firm purchases, Schedule Page: 326.Line No.Column: b Prior period adjustment. Schedule Page: 326.Line No.Column: I Prior period adjustment. Schedule Page: 326.Line No.Column: I Option premium, ISchedule Page: 326.18 Line No. Temperature hedge payout. ISchedule Page: 326.18 Line No.10 Column: b Secondary, economy and/or non-firm purchases. Column: I IFERC FORM NO.1 (ED. 12-87)Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2) A Resubmission 04/30/2003 Dee 31 , 2002 FOOTNOTE DATA !schedule Page: 326.18 Line No.10 Column: I Pre-commercial test energy from Gadsby peakers. ISchedule Page: 326.18 Line No.11 Column: I Recognition and reporting of gains and losses on energy trading contracts under EITF Issue No. 98-10. 'Schedule Page: 326.18 Line No.12 Column: I Accounting accrual and excess net power cost deferrals. ISchedule Page: 326.19 Line No. Exchange energy expense. ISchedule Page: 326.19 Line No. Load factoring and storage charges. Column: I Column: I ISchedule Page: 326.19 Line No. Exchange energy expense. Column: I 'Schedule Page: 326. balance energy. !schedule Page: 326.19 Line No. Exchange energy expense. Line No.Column: I Column: I !schedule Page: 326.19 Line No. xchange energy expense. !Schedule Page: 326.19 Line No. Exchange energy expense. Column: I Column: I ISchedule Page: 326.19 Line No. oad factoring and storage expense. !Schedule Page: 326.19 Line No.13 Column: Pacific Northwest Electric Power Planning and Conservation Act, FERC Electric Tariff, Original Volume No, 1. Column: I 'Schedule Page: 326.19 Line No.13 Column: h hese megawatt hours represent book entry only, No actual energy transfer took place. \Schedule Page: 326.19 Line No.13 Column: i These megawatt hours represent book entry only, No actual energy transfer took place, ISchedule Page: 326.19 Line No.13 Column: I !schedule Page: 326.19 Line No. Load factoring and storage expense. ISchedule Page: 326.20 Line No. Exchange energy expense. Column: I Column: I ISchedule Page: 326. Imbalance energy. Line No.Column: I IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee31,2002 FOOTNOTE DATA 'Schedule Page: 326.20 Line No. Load factoring and storage expense. !Schedule Page: 326.20 Line No. Load factoring and storage charges. Column: I Column: I ISchedule Page: 326.20 Line No. Load factoring and storage charges. Column: I !Schedule Page: 326. mbalance energy. !Schedule Page: 326.20 Line No. Exchange energy expense. Line No.Column: I Column: I Schedule Page: 326.Line No.Column: I Imbalance energy. Schedule Page: 326.Line No.Column: I Imbalance energy. chedule Page: 326.Line No.Column: I Imbalance energy. !Schedule Page: 326.21 Line No. Exchange energy expense, ISchedule Page: 326.21 Line No. Exchange energy expense. Column: I Column: I !Schedule Page: 326.21 Line No. Exchange energy expense. !Schedule Page: 326.21 Line No. Load factoring and storage charges. Column: I Column: I ISchedule Page: 326.21 Line No. Exchange energy expense. Column: I Schedule Page: 326.Line No.Column: I Imbalance energy. Schedule Page: 326.Line No.Column: I Imbalance energy. Schedule Page: 326.Line No.Column: I Imbalance energy. Schedule Page: 326.Line No.Column: I IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp I (2) A Resubmission 04/3012003 Dee 31,2002 FOOTNOTE DATA balance energy. !schedule Page: 326.22 Line No.Column: b Not applicable: adjustment for inadvertent interchange. IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1)~An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31,2002 FOOTNOTE DATA !Schedule Page: 328 Line No.Column: b Various si natories to the Ori inal Volume 11 Point-to-Point Transmission Tariff. chedule Pa e: 328 Line No.Column: Various si natories to the Ori inal Volume 11 Point-to-Point Transmission Tariff. chedule Pa e: 328 Line No.Column: Transmission Loss 'Schedule Page: 328 Line No.Column: b arious signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 1schedule Page: 328 Line No.Column: Various si natories to the Ori inal Volume 11 Point-to-Point Transmission Tariff. Schedule Pa e: 328 Line No.Column: d Non-Firm Transmission Service under the 0 en Access Transmission Tariff between various Schedule Pa e: 328 Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff, 'Schedule Page: 328 Line No.Column: arious signatories to the Original Volume 11 Point-to-Point Transmission Tariff. !schedule Page: 328 Line No.Column: ransmission Loss !schedule Page: 328 Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328 Line No.Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328 Line No.Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. 'Schedule Page: 328 Line No.Column: d Evergreen Network Transmission Service under the Open Access Transmission Tariff (SA 228). 'Schedule Page: 328 Line No.Column: ransmission Loss !schedule Page: 328 Line No.Column: d Evergreen Network Transmission Service under the Open Access Transmission Tariff (SA 233). ISchedulePage: 328 Line No.Column: Transmission Loss ISchedule Page: 328 Line No.Column: d vergreen Network Transmission Service under the Open Access Transmission Tariff (SA 233). \Schedule Page: 328 Line No.Column: Network Integration transmission service. 'Schedule Page: 328 Line No.Column: d Dave Johnston Substation operation and maintenance. 'Schedule Page: 328 Line No.Column: Operation and maintenance charges. ISchedule Page: 328 Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328 Line No.Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff, ISchedule Page: 328 Line No.Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31 2002 FOOTNOTE DATA 'Schedule Page: 328 Line No.10 Column: b PacifiCor Merchant is an affiliate to the res ondent. Schedule Pa e: 328 Line No.10 Column: d Network Transmission Service under the Open Access Transmission Tariff (SA 67) terminating on December 31 , 2006. 'Schedule Page: 328 Line No.11 Column: b PacifiCor Merchant is an affiliate to the res ondent. Schedule Pa e: 328 Line No.11 Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 67) terminating on December 31 2023. ISchedule Page: 328 Line No.12 Column: d yodak Substation use of facilities. !schedule Page: 328 Line No.12 Column: Sole use of facilities charge. ISchedule Page: 328 Line No.13 Column: d General Transfer A reement for network service in PACW. Ever reen Schedule Pa e: 328 Line No.13 Column: Sole use of facilities charge. ISchedule Page: 328 Line No.14 Column: d Network Transmission Service terminating on October 31 , 2008. !Schedule Page: 328 Line No.14 Column: Demand dollars plus a fixed cost calculated using plant investment values at various U,S. government facilities. !Schedule Page: 328 Line No.15 Column: d General Transfer Agreement for network service in PACE. Evergreen ISchedule Page: 328 Line No.15 Column: harges for monitoring, scheduling, load following and spinning reserve. !Schedule Page: 328 Line No.16 Column: d General transfer Service Agreement for network service in PACE-Evergreen. 'Schedule Page: 328 Line No.17 Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 179) terminating on September 30 2005. ISchedule Page: 328 Line No.17 Column: harges for monitoring, scheduling, load following and spinning reserve. \Schedule Page: 328.Line No.Column: d Network Transmission Service and Distribution Delivery Service under the Open Access Transmission Tariff (SA 229) terminating on September 30, 2006. 'Schedule Page: 328.Line No.Column: Network Integration transmission service. ISchedule Page: 328.Line No.Column: d Blacksfork Substation 0 eration and maintenance. Schedule Pa e: 328.Line No.Column: Operation and maintenance charges. ISchedule Page: 328.Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff, 'Schedule Page: 328.Line No.Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31, 2002 FOOTNOTE DATA ISchedule Page: 328.Line No.Column: Transmission Loss !Schedule Page: 328.Line No.Column: b arious signatories to the Original Volume 11 Point-to-Point Transmission Tariff. \Schedule Page: 328.Line No.Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.Column: d on-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. \Schedule Page: 328.Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.Column: d Transmission Service and Operating Agreement for network service in PACE, Termination Date April 18, 2021 ISchedule Page: 328.Line No.Column: Charges for monitoring, scheduling, load following and spinning reserve. ISchedule Page: 328.Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.Column: arious signatories to the Original Volume 11 Point-to-Point Transmission Tariff. !schedule Page: 328.Line No.Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. 'Schedule Page: 328.Line No.Column: Transmission Loss ISchedule Page: 328.Line No.Column: d Agreement providing for operation of Open Access Same Time Information System, ISchedule Page: 328.Line No.Column: Sole use of facilities charge. ISchedule Page: 328.Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff, ISchedule Page: 328.Line No.Column: arious signatories to the Original Volume 11 Point-to-Point Transmission Tariff, !Schedule Page: 328.Line No.Column: Prior period adjustment. ISchedule Page: 328.Line No.Column: d Point-to-Point Transmission Service terminating on July 31 , 2028, Schedule Page: 328.Line No.10 Column: d Evergreen Network Transmission Service and Distribution Delivery Service under the Open Access Transmission Tariff (SA 227), 'Schedule Page: 328.Line No.10 Column: Network Integration transmission service. ISchedule Page: 328.Line No.11 Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.11 Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.12 Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.12 Column: IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31 2002 FOOTNOTE DATA Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.12 Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. ISchedule Page: 328.Line No.13 Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.13 Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. !Schedule Page: 328.Line No.13 Column: ransmission Loss !Schedule Page: 328.Line No.14 Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 202) terminating on April 30, 2003. Split of IdaCorp Energy & Idaho Power ISchedule Page: 328.Line No.15 Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 211) terminating on May 1 , 2003, Split of IdaCorp Energy & Idaho Power 'Schedule Page: 328.Line No.16 Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 212) terminating on May 31 , 2003. Split of IdaCorp Energy & Idaho Power ISchedule Page: 328.Line No.17 Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 173) terminating on September 30 2002. S lit of Idaho Power & IdaCor Ener Schedule Pa e: 328.Line No.Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 174) terminating on September 30, 2002, S lit of Idaho Power & IdaCor Ener Schedule Pa e: 328.Line No.Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 193) terminating on December 31 2002. S lit of Idaho Power & IdaCor Ener chedule Pa e: 328.Line No.Column: Transmission Loss ISchedule Page: 328.Line No.Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 213) terminating on June 30, 2002. Split of Idaho Power & IdaCorp Energy 'Schedule Page: 328.Line No.Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 173) terminating on September 30, 2002, ISchedule Page: 328.Line No.Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 174) terminating on September 30, 2002. 'Schedule Page: 328.Line No.Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 193) terminating on December 31 2002. ISchedule Page: 328.Line No.Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 202) terminating on April 30, 2003, 'Schedule Page: 328.Line No.Column: d Point-to-Point Transmission Service under the 0 en Access Transmission Tariff SA 211 terminatin on Ma 1 , 2003. Schedule Pa e: 328.Line No.Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 212) terminating on May 31 , 2003. ISchedule Page: 328.Line No.10 Column: d IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dee 31,2002 FOOTNOTE DATA Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 213) terminating on June 30, 2002. 'Schedule Page: 328.Line No.11 Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 214) terminating on August 31 2002, ISchedule Page: 328.Line No.11 Column: Transmission Loss 'Schedule Page: 328.Line No.12 Column: Transmission Loss ISchedule Page: 328.Line No.13 Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.13 Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.13 Column: d on-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. !schedule Page: 328.Line No.14 Column: d Antelope Substation use of facilities. ISchedule Page: 328.Line No.14 Column: Sole use of facilities charge. ISchedule Page: 328.Line No.15 Column: d Jim Bridger Pump use of facilities. 'Schedule Page: 328.Line No.15 Column: Sole use of facilities charge, ISchedule Page: 328.Line No.16 Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.16 Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.16 Column: Transmission Loss ISchedule Page: 328.Line No.17 Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff, 'Schedule Page: 328.Line No.17 Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff, ISchedule Page: 328.Line No.17 Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. 'Schedule Page: 328.Line No.Column: d Transmission Service and Interconnection Agreement for network service in PACE. Subject to termination upon 3 year written notice. 'Schedule Page: 328.Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.Column: Transmission Loss ISchedule Page: 328.Line No.Column: b arious signatories to the Original Volume 11 Point-to-Point Transmission Tariff. \Schedule Page: 328.Line No.Column: IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31 2002 FOOTNOTE DATA Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points, ISchedule Page: 328.Line No.Column: d Malin to Indian Springs use of facilities. 'Schedule Page: 328.Line No.Column: Sole use of facilities charge, ISchedule Page: 328.Line No.Column: d Pinto Phase Shifer use of facilities, operation and maintenance. 'SChedule Page: 328.Line No.Column: Sole use of facilities charge, 'Schedule Page: 328.Line No.Column: d into Phase Shifer use of facilities, operation and maintenance. !schedule Page: 328.Line No.Column: peration and maintenance charges. !schedule Page: 328.Line No.Column: PacifiCor Power Marketin is an affiliate of the res ondent. Schedule Pa e: 328.Line No.Column: b Point to Point Transmission Service under the Open Access Transmission Tariff Terminating 11/30/2002. 7/31/2002, 7/31/2002. 7/31/2002. IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/3012003 Dee31 2002 FOOTNOTE DATA 'Schedule Page: 328.Line No.13 Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.13 Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.13 Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points, 'Schedule Page: 328.Line No.13 Column: Transmission Loss ISchedule Page: 328.Line No.14 Column: d Dalreed Substation use of facilities, operation and maintenance, 'Schedule Page: 328.Line No.14 Column: Sole use of facilities charge, 'Schedule Page: 328.Line No.15 Column: d Dalreed Substation use of facilities, 0 eration and maintenance. Schedule Pa e: 328.Line No.15 Column: eration and maintenance char es. Schedule Pa e: 328.Line No.16 Column: d Harrison Substation use of facilities, 'Schedule Page: 328.Line No.16 Column: Sole use of facilities charge. ISchedule Page: 328.Line No.17 Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 169) terminating on October 31 2003. ISchedule Page: 328.Line No.17 Column: Transmission Loss ISchedule Page: 328.4 Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff, ISchedule Page: 328.Line No.Column: d on-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. !schedule Page: 328.Line No.Column: ransmission Loss !schedule Page: 328.Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.4 Line No.Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. ISchedule Page: 328.4 Line No.Column: Transmission Loss ISchedule Page: 328.Line No.Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 178) terminating on December 31 2002. ISchedule Page: 328.Line No.Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 182) terminating on December 31 2002. IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31 , 2002 FOOTNOTE DATA 'Schedule Page: 328.Line No.Column: b arious signatories to the Original Volume 11 Point-to-Point Transmission Tariff. !Schedule Page: 328.Line No.Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.Column: ransmission Loss \Schedule Page: 328.Line No.Column: b arious signatories to the Original Volume 11 Point-to-Point Transmission Tariff. !schedule Page: 328.Line No.Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. jSchedule Page: 328.Line No.Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. ISchedule Page: 328.Line No.Column: Transmission loss and prior period adjustment. ISchedule Page: 328.Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff, 'Schedule Page: 328.Line No.Column: arious signatories to the Original Volume 11 Point-to-Point Transmission Tariff. !schedule Page: 328.Line No.Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points, ISchedule Page: 328.Line No.Column: Transmission Loss ISchedule Page: 328.Line No.Column: d Malin to Indian Springs use of facilities, !Schedule Page: 328.Line No.Column: Sole use of facilities charge. Schedule Page: 328.Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff, Schedule Page: 328.Line No.Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.Column: d Transmission Service and Use of facilities Agreement terminating July 31 , 2014. 'Schedule Page: 328.Line No.Column: Sole use of facilities charge. 'Schedule Page: 328.Line No.10 Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.10 Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.10 Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. ISchedule Page: 328.Line No.10 Column: Transmission Loss Schedule Page: 328.Line No.11 Column: d Buffalo Substation distribution delivery service, Schedule Page: 328.Line No.11 Column: Sole use of facilities charge. IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31 , 2002 FOOTNOTE DATA ISchedule Page: 328.Line No.12 Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff, ISchedule Page: 328.Line No.12 Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff, ISchedule Page: 328.Line No.12 Column: Transmission Loss ISchedule Page: 328.Line No.13 Column: b arious signatories to the Original Volume 11 Point-to-Point Transmission Tariff. \Schedule Page: 328.Line No.13 Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.13 Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. ISchedule Page: 328.Line No.13 Column: Transmission Loss ISchedule Page: 328.Line No.14 Column: d Malin to Indian Springs use of facilities. ISchedule Page: 328.Line No.14 Column: Sole use of facilities charge, !Schedule Page: 328.Line No.15 Column: d into Phase Shifer use of facilities, operation and maintenance. !schedule Page: 328.Line No.15 Column: Sole use of facilities charge. ISchedule Page: 328.Line No.16 Column: d Pinto Phase Shifer use of facilities, operation and maintenance. 'Schedule Page: 328.Line No.16 Column: eration and maintenance char es. Schedule Pa e: 328.Line No.17 Column: d oint-to-Point Transmission Service under the Open Access Transmission Tariff (SA 170) terminating on May 31 , 2003. !Schedule Page: 328.Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff, 'Schedule Page: 328.Line No.Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. !Schedule Page: 328.Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. 'Schedule Page: 328.Line No.Column: Transmission Loss ISchedule Page: 328.Line No.Column: b arious signatories to the Original Volume 11 Point-to-Point Transmission Tariff. !schedule Page: 328.Line No.Column: d Transmission Service and Interconnection Agreement for network service in PACEW, Termination Date October 1 2014. ISchedule Page: 328.Line No.Column: Prior period adjustment. I FERC FORM NO.1 (ED. 12-87)Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmisslon 04/30/2003 Dee 31,2002 FOOTNOTE DATA ISchedule Page: 328.Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. ISchedule Page: 328.Line No.Column: Transmission Loss ISchedule Page: 328.Line No.Column: d peration and maintenance at Difficulty Sub, Riverton Sub, Thermopolis Sub and Platte Sub. \Schedule Page: 328.Line No.Column: Operation and maintenance charges. 'Schedule Page: 328.Line No.Column: d Operation and maintenance at Difficulty Sub, Riverton Sub, Thermopolis Sub and Platte Sub. ISChedule Page: 328.Line No.Column: peration and maintenance charges. !schedule Page: 328.Line No.Column: d peration and maintenance at Difficulty Sub , Riverton Sub, Thermopolis Sub and Platte Sub. !schedule Page: 328.Line No.Column: Operation and maintenance charges. 'Schedule Page: 328.Line No.Column: d Operation and maintenance at Difficulty Sub, Riverton Sub, Thermopolis Sub and Platte Sub, !Schedule Page: 328.Line No.Column: Operation and maintenance charges. Prior period adjustment. ISchedule Page: 328.Line No.Column: d Transmission Service Agreement for network service in PACW. Under transfer agreement subject to termination when easement from United States for transmission line between Redmond , Oregon and Prineville, Oregon is removed. ISchedule Page: 328.Line No.10 Column: d Transmission Service Agreement for network service in PACW. ISchedule Page: 328.Line No.10 Column: Sole use of facilities charge, ISchedule Page: 328.Line No.11 Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.11 Column: d Transmission Service and 0 eratin A reement for network service in PACE. Termination Date December 31 , 2003. chedule Pa e: 328.Line No.11 Column: Charges for monitoring, scheduling, load following and spinning reserve, ISchedule Page: 328.Line No.12 Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff, 'Schedule Page: 328.Line No.12 Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.12 Column: d IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee31 2002 FOOTNOTE DATA Transmission service and operating agreement for network service in PACE. Evergreen 'Schedule Page: 328.Line No.12 Column: Imbalance energy, ISchedule Page: 328.Line No.13 Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.13 Column: arious signatories to the Original Volume 11 Point-to-Point Transmission Tariff. !schedule Page: 328.Line No.13 Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. ISchedule Page: 328.Line No.14 Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.14 Column: d Transmission Service and Operating Agreement for network service in PACE. Subject to termination upon 3 year written notice. ISchedule Page: 328.Line No.14 Column: Charges for monitoring, scheduling, load following and spinning reserve. ISchedule Page: 328.Line No.15 Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. !Schedule Page: 328.Line No.15 Column: arious signatories to the Original Volume 11 Point-to-Point Transmission Tariff, !schedule Page: 328.Line No.16 Column: d Transmission Service and Interconnection Agreement for network service in PACE. Subject to termination upon 3 year written notice. 'Schedule Page: 328.Line No.16 Column: rior period adjustment. !Schedule Page: 328.Line No.17 Column: d Transmission Service and Interconnection Agreement for network service in PACE. Subject to termination upon 3 year written notice. ISchedule Page: 328.Line No.Column: d Transmission Service and Interconnection Agreement for network service in PACE. Subject to termination upon 3 year written notice. ISchedule Page: 328.Line No.Column: d Point-to-Point Transmission Service under the Open Access Transmission Tariff (SA 164) terminating on May 31 2003, ISchedule Page: 328.Line No.Column: d vergreen Network Transmission Service under the Open Access Transmission Tariff (SA 175). \Schedule Page: 328.Line No.Column: d Evergreen Network Transmission Service under the Open Access Transmission Tariff (SA 175). ISchedule Page: 328.Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff, 'Schedule Page: 328.Line No.Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points, 'Schedule Page: 328.Line No.Column: rior period adjustment. \Schedule Page: 328.Line No.Column: d Casper Substation operation and maintenance. IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31 2002 FOOTNOTE DATA ISchedule Page: 328.Line No.Column: Operation and maintenance charges. ISchedule Page: 328.Line No.Column: d Thermopolis Substation operation and maintenance. ISchedule Page: 328.Line No.Column: Operation and maintenance charges. !Schedule Page: 328.Line No.Column: b Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. 'Schedule Page: 328.Line No.Column: Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff. ISchedule Page: 328.Line No.Column: d Non-Firm Transmission Service under the Open Access Transmission Tariff between various parties and points. IFERC FORM NO.1 (ED. 12-87)Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmisslon 04/30/2003 Dee 31 2002 FOOTNOTE DATA ISchedule Page: 332 Line No.Column: f Prior period adjustment and use of facilities, Ancillary services. 'Schedule Page: 332 Line No.Column: Prior period adjustment and use of facilities. 'Schedule Page: 332 Line No. Ancillary services, Prior period adjustment. Contract exit fee. ISchedule Page: 332 Line No. Prior period adjustment. ISchedule Page: 332 Line No. Prior period adjustment. Column: f Column: f Column: f 'Schedule Page: 332 Use of Facilities, Line No.Column: f \Schedule Page: 332 Line No.Column: Prior period adjustment and use of facilities. Respondent's portion of specified costs of certain facilities. 'Schedule Page: 332 Ancillary services. ISchedule Page: 332 Line No.11 Column: Transmission service charges and administration fees. Line No.Column: f !Schedule Page: 332 Line No.12 Column: Prior period adjustment. Respondent's portion of specified costs of certain facilities, 'Schedule Page: 332 Line No. Prior period adjustment. Column: f ISchedule Page: 332 Use of Facilities. Line No.Column: ISchedule Page: 332 Line No.15 Column: f Ancillary services. Respondent's portion of specified costs of certain facilities. 'Schedule Page: 332 Line No.16 Column: f Use of Facilities, Respondent's portion of specified costs of certain facilities. ISchedule Page: 332.Line No.Column: f IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31, 2002 FOOTNOTE DATA Ancillary services. ISChedule Page: 332.Line No. Ancillary services. Prior period adjustment. Column: f !Schedule Page: 332. Use of Facilities. Line No.Column: f !Schedule Page: 332.Line No. Prior period adjustment. !Schedule Page: 332.Line No.Column: f Prior period adjustment and use of facilities. Ancillary services. Column: f ISchedule Page: 332. Accrual adjustment. Line No.Column: IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dee 31 2002 FOOTNOTE DATA \Schedule Page: 402 Line No.Column: Cholla Plant is operated by Arizona Public Service Company. Respondent owns Unit No.4 plus 37.65% of related common facilities. Data re orted on lines 5 throu h 43 re resents res ondent's share. Schedule Pa e: 402 Line No.Column: d Colstrip Plant is operated by PPL Montana, LLC and is jointly owned. Data reported on lines 5 through 43 represents res ndent's 10% share of Colstri Plant Units No.3 and No. Schedule Pa e: 402 Line No.Column: Craig Plant is operated by Tri-State Generation and Transmission Association and is jointly owned. Data reported on lines 5 through 43 represents respondent's 19.28% share of Craig Plant Units No, 1 and No, 2, and 12.86% of common facilities, 'Schedule Page: 402.Line No.Column: b Hayden Plant is operated by Public Service Company of Colorado and is jointly owned, Data reported on lines 5 through 43 represents respondent's 24.5% (45 MW) share of Hayden Unit No, 1 , 12.6% (33 MW) share of Hayden Unit No., and 17.5% of common facilities. 'Schedule Page: 402.Line No.Column: Hunter Plant Unit No, 1 is owned by respondent and Provo City Corporation with undivided interest of 93.75% and 6.25% res ectivel . Data re orted in column c re resents res ondent's share, chedule Pa e: 402.Line No.Column: d Hunter Plant Unit No.2 is owned by respondent, Deseret Power Electric Cooperative, and Utah Associated Municipal Power Systems, each with undivided interest of 60.31 %, 25.108%, and 14.582% respectively, Data reported in column (d) re resents res ondent's share. Schedule Pa e: 402.Line No.Column: This represents the respondent's share. Hunter Unit No, 1 is owned by respondent and Provo City Corporation with undivided interest of 93.75% and 6.25% respectively, Hunter Unit No, 2 is owned by respondent, Deserete Power Electric Cooperative, and Utah Associated Municipal Power Systems, each with undivided interest of 60,31 %, 25.108%, and 14.582% res ectivel , Schedule Pa e: 402.Line No.Column: Jim Bridger Plant is operated by PacifiCorp and column (c) represents the respondent's share. Ownership of the plant is as follows: PacifiCor 66 2/3%, Idaho Power Com an 331/3%. Schedule Pa e: 402.Line No.Column: Wyodak Plant is operated by PacifiCorp and column (e) represents the respondent's share. Ownership of the plants is follows: PacifiCo 80%, Black Hills Cor oration 20%. chedule Pa e: 402.Line No.Column: Hermiston Plant is operated by Hermiston Generating Company loP and is jointly owned. Data reported on lines 5 through 43 re resents res ondent's 50.0% share of Hermiston Plant. Schedule Pa e: 402.Line No.Column: PacifiCorp owns the steam turbine generator and associated systems directly related to the operation of this unit at the James River Corporation s Camas, Washington paper mill. Modifications and upgrades to the existing Camas paper mill were necesary to supply steam to the turbine and to ensure continued operation of the unit in the event of mill closure. James River retained ownership of these modifications. James River supplies the fuel and delivers the steam to PacifiCorp s turbine. None of the facilities are jointly owned, Each asset is wholly owned, either by PacifiCorp or James River Cor oration. Schedule Pa e: 402.Line No.Column: f The West Valley Plant is leased from PPM Energy Inc, an affiliate to the respondent. The lease agreement began July 1 2002 and shall expire on December 31 , 2017, subject to other provisions of the agreement. IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04130/2003 Dee 31 , 2002 FOOTNOTE DATA Column: d Line No.Column: Line No.Column: b Line No.Column: d Line No.Column: b IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp I (2) A Resubmission 04/30/2003 Dee31,2002 FOOTNOTE DATA ISchedule Page: 410 Line No.Column: Licensed Pro ect No. 2381 a licable to both Ashton and St. Anthon lants. Schedule Pa e: 410 Line No.10 Column: Licensed Project No. 2401 applicable to both Cove and Grace Plants (See page 406 for Grace plant). \schedule Page: 410 Line No.29 Column: Licensed Pro ect No. 2381 a licable to both Ashton and St. Anthon lants. Schedule Pa e: 410 Line No.35 Column: Used in regulating the release of water from Klamath Lake and in maintaining proper water surface level in the Klamath River between Klamath Falls and Keno, Ore on. Schedule Pa e: 410 Line No.36 Column: Storage reservoir for six plants on the Klamath River (Copco No., Copco No., East Side, West Side, John C. Boyle and Iron Gate), ISchedule Page: 410 Line No.37 Column: Common plant in North Umpqua Project. All common roads, employee houses, control equipment, etc, are in this account. IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee 31,2002 FOOTNOTE DATA Schedule Page: 422 Line No.Column: j Included Above chedule Pa e: 422 Line No.Column: k Included Above Schedule Pa e: 422 Line No.Column: I Included Above Schedule Pa e: 422.Line No.Column: Included Below Schedule Pa e: 422.Line No.Column: k Included Below Schedule Pa e: 422.Line No.Column: I Included Below chedule Pa e: 422.Line No.Column: Included Above Schedule Pa e: 422.Line No.Column: k Included Above Schedule Pa e: 422.Line No.Column: I Included Above Schedule Pa e: 422.Line No.Column: Included Below Schedule Page: 422.Line No.Column: k Included Below Schedule Pa e: 422.Line No.Column: I Included Below IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PaeifiCorp (2)A Resubmission 04/30/2003 Dee31 2002 FOOTNOTE DATA ISchedule Page: 424 138/46 Line No.Column: IFERC FORM NO.(ED. 12-87) Page 450 INDEX Schedule Paae No. Accrued and prepaid taxes " .................. 262-263 Accumulated Deferred Income Taxes ....................................................................234 272-277 Accumulated provisions for depreciation of common utility plant " ....................... 356 utility plant " .............................. 219 utility plant (summary) " ................ 200-201 Advances from associated companies " .............. 256-257 Allowances ........................................,..............................................228-229 Amortization miscellaneous " .............................. 340 of nuclear fuel " ........................ 202-203 Appropriations of Retained Earnings " ........ 118-119 Associated Companies advances from " .......................... 256-257 corporations controlled by respondent " ...... 103 control over respondent " .................... 102 interest on debt to " .................... 256-257 Attestation ......................................................"" i Balance sheet comparative ...................................,..............................................110-113 notes to " ............................... 122-123 Bonds ..............................." ........................................................... 256-257 Capital Stock " ....,............................. 251 expense ....................................,.....................................................254 premiums " ................................... 252 reacquired " ...........................,..... 251 subscribed ..........................................................................,............252 Cash flows, Changes important Construction statement of " ................... 120-121 during year " .............................,.................. 108-109 work in progress work in progress work in progress Control - common utility plant ..... ........... .. .... .... """" .... ...... ... ....... .... 356 - electric " ................ 216 - other utility departments " '" 200-201 corporations controlled by respondent " ...... 103 over respondent " ..........................,. 102 Corporation controlled by " .............................. 103 incorporated .....................................................................................101 CPA, background information on " ................. 101 CPA Certification, this report form "........... i-ii FERC FORM NO.(ED. 12-93)Index INDEX (continued) Schedule Deferred PaQe No, credits, other ...................................................................................269 debits, miscellaneous ............................................................................233 income taxes accumulated - accelerated amortization property ........................................................................272-273 income taxes accumulated - other property .................................................... 274-275 income taxes accumulated - other .............................................................276-277 income taxes accumulated - pollution control facilities .......................................... 234 Definitions, this report form ........................................................................ iii Depreciation and amortization of common utility plant ..........................................................................356 of electric plant ................................................................................219 336-337 Directors ............................................................................................105 Discount - premium on long-term debt .............................................................256-257 Distribution of salaries and wages ...............................................................354-355 Dividend appropriations ..........................................................................118-119 Earnings, Retained ...............................................................................118-119 Electric energy account ..............................................................................401 Expenses electric operation and maintenance ...........................................................320-323 electric operation and maintenance, summary ...................................................... 323 unamortized debt ......................,..........................................................256 Extraordinary property losses ........................................................................230 Filing requirements, this report form General information ..................................................................................101 Instructions for filing the FERC Form 1 ............................................................. i- Generating plant statistics hydroelectric (large) ........................................................................406-407 pumped storage (large) ............." ...,.................................................... 408-409 small plants .................................................................................410-411 steam-electric (large) .............................,.........................................402-403 Hydro-electric generating plant statistics . ...................................................... 406-407 Identification .......................................................................................101 Important changes during year ....................................................................108-109 Income statement of, by departments .................................................................114-117 statement of, for the year (see also revenues) ............................................... 114-117 deductions, miscellaneous amortization ....,...,..................................................340 deductions, other income deduction ...............................................................340 deductions, other interest charges ..,......,.....................................................340 Incorporation information ............................................................................101 FERC FORM NO.(ED. 12-95)Index INDEX (continued) Schedule Paae No. Interest charges, paid on long-term debt, advances, etc ............................................... 256-257 Investments nonutility property ..............................................................................221 subsidiary companies .........................................................................224-225 Investment tax credits, accumulated deferred ..................................................... 266-267 Law, excerpts applicable to this report form .......................................................... iv List of schedules, this report form ..................................................................2-4 Long-term debt ...................................................................................256-257 Losses-Extraordinary property ........................................................................230 Materials and supplies ...............................................................................227 Miscellaneous general expenses .......................................................................335 Notes to balance sheet .............................................................................122-123 to statement of changes in financial position ................................................ 122-123 to statement of income ..............,........................................................122-123 to statement of retained earnings ............................................................122-123 Nonutility property ..................................................................................221 Nuclear fuel materials ...........................................................................202-203 Nuclear generating plant, statistics .............................................................402-403 Officers and officers ' salaries ......................................................................104 Operating expenses-electric expenses-electric Other ...........,................................................................ 320-323 (summary) ......................................................................323 paid-in capital .........................................................,........................253 donations received from stockholders .............................................................253 gains on resale or cancellation of reacquired capital stock ....................................................................................253 miscellaneous paid-in capital ....................................................................253 reduction in par or stated value of capital stock ................................................ 253 regulatory assets ................................................................................232 regulatory liabilities ........................,..................................................278 Peaks, monthly, and output ...........................................................................401 Plant, Common utility accumulated provision for depreciation ...........................................................356 acquisition adjustments ................................................,..........,..............356 allocated to utility departments .................................................................356 completed construction not classified ...........................,................................356 construction work in progress ....................................................................356 expenses .................,.......................................................................356 held for future use ............................................................,.................356 in service .......................................................................................356 leased to others ,.............................................................,..................356 Plant data ...................................................................................336-337 401-429 FERC FORM NO.(ED. 12-95)Index INDEX (continued) Schedule Plant - electric PaQe No. accumulated provision for depreciation ...........................................................219 construction work in progress ....................................................................216 held for future use ..............................................................................214 in service ...................................................................................204-207 leased to others .................................................................................213 Plant - utility and accumulated provisions for depreciation amortization and depletion (summary) .............................................................201 Pollution control facilities, accumulated deferred income taxes .....................................................................................234 Power Exchanges ..................................................................................326-327 Premium and discount on long-term debt ...........................,...................................256 Premium on capital stock .............................................................................251 Prepaid taxes ....................................................................................262-263 Property - losses, extraordinary .....................................................................230 Pumped storage generating plant statistics ....................................................... 408-409 Purchased power (including power exchanges) ...................................................... 326-327 Reacquired capital stock .............................................................................250 Reacquired long-term debt ........................................................................256-257 Receivers ' certificates ......................................,...................................256-257 Reconciliation of reported net income with taxable income from Federal income taxes ......................................................................261 Regulatory commission expenses deferred ..............................................................233 Regulatory commission expenses for year .....,..................,.................................350-351 Research, development and demonstration activities ............................................... 352-353 Retained Earnings amortization reserve Federal .....................................................................119 appropriated .................................................................................118-119 statement of, for the year ....................,..............................................118-119 unappropriated ......................,........................................................118-119 Revenues - electric operating .............................................,......................300-301 Salaries and wages directors fees ...............................................................................,...105 distribution of ..............................................................................354-355 officers ' ........................................................................................ 104 Sales of electricity by rate schedules ....................,..........................................304 Sales - for resale ...................................................................,...........310-311 Salvage - nuclear fuel .....................................................,.....................202-203 Schedules, this report form .......................................................................... Securi ties exchange registration ................,.......................................................250-251 Statement of Cash Flows ..............................................,..........,................120-121 Statement of income for the year ,............................,...................................114-117 Statement of retained earnings for the year ...................................................... 118-119 Steam-electric generating plant statistics .................,..................................... 402-403 Substations ..........................................................................................426 Supplies - materials and ...................................,.........................................227 FERC FORM NO.1 (ED. 12-90)Index INDEX (continued) Schedule PaQe No, Taxes accrued and prepaid charged during year on income, deferred ......................................................................... 262-263 ......................................................................... 262-263 and accumulated .............................................................234 272-277 reconciliation of net income with taxable income for ............................................ 261 Transformers, line - electric .......................................................................429 Transmission lines added during year .....................................................................424-425 lines statistics ............................................................................422-423 of electricity for others ...................................................................328-330 of electricity by others ........................................................................332 Unamortized debt discount ...............................................................................256-257 debt expense .'.'..'..'...'.." '.'.....'....'.'....'.'...'.'................................. 256-257 premium on debt .............................................................................256-257 Unrecovered Plant and Regulatory Study Costs ...................................................... 230 FERC FORM NO.1 (ED. 12-90)Index '-:; Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. . Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) 327 125 150 371 FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) CAMAS Distribution - Unat 69.12. CANYON CREEK Distribution - Unat 69.24. CHESTERFIELD Distribution - Unat 46.12. CLIFTON Distribution - Unat 46.12. DOWNEY Distribution - Unat 46.12. DUBOIS Distribution - Unat 69.12. EASTMONT Distribution - Unat 69.12. EGIN Distribution - Unat 69.12. GEORGETOWN Distribution - Unat 69.12. GRACE CITY Distribution - Unat 46.12. HAMER Distribution - Unat 69.12. HAYES Distribution - Unat 69.12. HENRY Distribution - Unat 46.12. HOLBROOK Distribution - Unat 69.12. HOOPES Distribution - Unat 69.12. IDAHO FALLS Distribution - Unat 46.12. INDIAN CREEK Distribution - Unat 69.12. JEFFCO Distribution - Unat 69.24. KETTLE Distribution - Unat 69.24. LIFTON PUMPING STATION Distribution - Unat 69. LUND Distribution - Unat 46.12. MCCAMMON Distribution - Unat 46.12. MENAN Distribution - Unat 69.12. MERRILL Distribution - Unat 69.12. MILLER Distribution - Unat 69.12.47 MONTPELIER Distribution - Unat 46.12. MOODY Distribution - Unat 69.12.47 NEWDALE Distribution - Unat 69.12. OSGOOD Distribution - Unat 69.12. PRESTON Distribution - Unat 46.12. RAYMOND Distribution - Unat 69.12. RENO Distribution - Unat 69.12. REXBURG Distribution - Unat 69.12. RIGBY Distribution - Unat 69.12. RIRIE Distribution - Unat 69.12. ROBERTS Distribution - Unat 69.12. RUBY Distribution - Unat 69.12. SAND CREEK Distribution - Unat 69.12. SANDUNE Distribution - Unat 69.24. SHELLEY Distribution - Unat 46.12. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) 25 . FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) SMITH Distribution - Unat 69.12. SOUTH FORK Distribution - Unat 69.12. SUGAR CITY Distribution - Unat 69.12.47 TANNER Distribution - Unat 46.12. TARGHEE Distribution - Unat 46.12. THORNTON AREA Distribution - Unat 69.12. UCON Distribution - Unat 69.12. WATKINS Distribution - Unat 69.12. WEBSTER Distribution - Unat 69.12. WESTON Distribution - Unat 46.12. TOTAL 3723.775. NUMBER OF SUBSTATIONS DISTRIBUTION - 60 GOSHEN (IDAHO)Transmission - Atte 345.161.69. GRACE HE PLANT Transmission - Atte 46.161. AMPS Transmission - Unat 230.69. ANTELOPE Transmission - Unat 230.138.161. BONNEVILLE Transmission - Unat 161.69. CARIBOU Transmission - Unat 138.46. CONDA Transmission - Unat 138.46. FISH CREEK Transmission - Unat 161.46. FRANKLIN Transmission - Unat 138.46. JEFFERSON Transmission - Unat 161.69. MALAD Transmission - Unat 138.69.12. SCOVILLE Transmission - Unat 138.69. SUGAR MILL Transmission - Unat 161.69.46. TREASURETON Transmission - Unat 230.138. TOTAL 2375.1081.449. NUMBER OF SUBSTATIONS TRANSMISSION - 14 MONTANA BIGFORK HE PLANT Transmission - Unat 34. TOTAL 34. NUMBER OF SUBSTATIONS TRANSMISSION - 1 OREGON BEND HE PLANT Distribution - Atte CHINA HAT Distribution - Atte 115.12. VINE STREET HE PLANT Distribution - Atte 20. WEST SIDE Distribution - Atte 69.12. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. ,. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by eason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) 177 691 415 133 168 467 2269 FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~./ Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) 26TH STREET Distribution - Unat 20. 35TH STREET Distribution - Unat 20. ARLINGTON Distribution - Unat 69.12. BANDON Distribution - Unat 20.12. BEACON Distribution - Unat 69.12. BEATTY Distribution - Unat 69.12. BLALOCK Distribution - Unat 69.12. BLANDENA Distribution - Unat 57. BLY Distribution - Unat 69.12. BOISE CASCADE Distribution - Unat 69. BONANZA Distribution - Unat 69.12. BROWNSVILLE Distribution - Unat 69.20. CANNON BEACH Distribution - Unat 115.12. CASEBEER Distribution - Unat 69.20. CHILOQUIN MARKET Distribution - Unat 69.12. CLEARWATER # 2 Distribution - Unat 11. CLEARWATER #1 Distribution - Unat 115.12. COLLISEUM Distribution - Unat 20. COLUMBIA Distribution - Unat 115.12. CROOKED RIVER RANCH Distribution - Unat 69.20. CUTLER CITY Distribution - Unat 20. DOUGLAS-VENEER Distribution - Unat 69.12. ELK CREEK DAM CON ST. Distribution - Unat 69.12. FALL CREEK HE PLANT Distribution - Unat 20. FIELDER CREEK Distribution - Unat 115.20. FOOTHILLS Distribution - Unat 69.12. FRALEY Distribution - Unat 69.12. GARDEN VALLEY Distribution - Unat 69.20. GAZLEY Distribution - Unat 69.12. GEARHART Distribution - Unat 12. GLENEDEN Distribution - Unat 20. GLIDE Distribution - Unat 115.12. GORDON HOLLOW Distribution - Unat 69.20. GRASS VALLEY Distribution - Unat 20. GROVE Distribution - Unat 12. HAMAKER Distribution - Unat 69.12. HAZELWOOD Distribution - Unat 12.20. HENLEY Distribution - Unat 69.12. HENRY STREET Distribution - Unat 20. HILL STREET Distribution - Unat 12. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~rt Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) nA Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by . reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i) (j) (k) FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2) n A Resubmission 04130/2003 SUBSTATIONS 1. Report below the information called for conceming substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) 1 HINKLE Distribution - Unat 69.12. HOOD RIVER Distribution - Unat 69.12. JORDAN POINT Distribution - Unat 115.12. JOSEPH Distribution - Unat 20.12. K STREET Distribution - Unat 66.12. KENWOOD Distribution - Unat 69.12. 7 KINGSLEY FIELD Distribution - Unat 69. 8 KNAPPA SVENSEN Distribution - Unat 115.12.47 9 LAKEVIEW Distribution - Unat 69.12. LANCASTER Distribution - Unat 69.20. MAPLE STREET Distribution - Unat 20. MEDCO Distribution - Unat 115.12. MINAM Distribution - Unat 69.12. MODOC Distribution - Unat 69.12. MORO Distribution - Unat 20.2.40 MYRTLE POINT Distribution - Unat 115.20. NELSCOTT Distribution - Unat 20. OAKLAND Distribution - Unat 115.12. ORCHARD STREET Distribution - Unat 12. PACIFIC PLYWOOD Distribution - Unat 69. PROVOL T Distribution - Unat 69.12. RED BLANKET Distribution - Unat 69. RICH MFG.Distribution - Unat 57.11. RIDDLE-VENEER Distribution - Unat 69.12. ROGUE RIVER Distribution - Unat 69.20.12. ROSS AVENUE Distribution - Unat 69.12. RUCH Distribution - Unat 69.12. SANTIAM LBR CO Distribution - Unat 20. SELMA Distribution - Unat 69.12. SHASTA WAY Distribution - Unat 12. SIMTAG BOOSTER PUMP Distribution - Unat 34. SOUTH DUNES Distribution - Unat 115.12. SPRAGUE RIVER Distribution - Unat 69.12. STAYTON CITY Distribution - Unat 20. STEAMBOAT STATION Distribution - Unat 115. SUTHERLIN Distribution - Unat 115.12. TEXUM Distribution - Unat 69.12. TILLER Distribution - Unat 115.12. TOLO Distribution - Unat 69.12. TOM CREEK Distribution - Unat 69.2.40 FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002(2) n A Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease , give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) 13 . FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) TONGUE POINT Distribution - Unat 22. TURKEY HILL Distribution - Unat 69.12. PL YWOOD Distribution - Unat 20. UMAPINE Distribution - Unat 69.12. WARRENTON Distribution - Unat 115.12. WASCO Distribution - Unat 20. WECOMA BEACH Distribution - Unat 20. WHISKEY RUN WIND GEN Distribution - Unat 14. WINSTON Distribution - Unat 69.12. YOUNGS BAY Distribution - Unat 115.22.12. TOTAL 5561.1117.50. NUMBER OF SUBSTATIONS DISTRIBUTION - 94 ALBINA TID - Attended 115.69.11. BLOSS TID - Attended 115.12. CLEVELAND AVE.TID - Attended 69.12. FERNHILL TID - Attended 115.12. GREEN TlD - Attended 69.20. STEVENS ROAD TID - Attended 115.20. VILAS ROAD TID - Attended 115.12. AGNESS AVENUE TID - Unattended 115.12. ALDERWOOD TID - Unattended 115.12. AMERICAN CAN TID - Unattended 69.12. APPLEGATE TID - Unattended 115.69.13. ASHLAND TID - Unattended 115.69.12. ATHENA TID - Unattended 69.12. BELKNAP TID - Unattended 69.12. BROOKHURST TID - Unattended 69.12. BRYANT TID - Unattended 69.12. BUCHANAN TID - Unattended 115.20. BUCKAROO TID - Unattended 69.12. CAMPBELL TID - Unattended 115.12. CARNES TID - Unattended 69.12. CAVE JUNCTION TID - Unattended 115.69.12. CAVEMAN TID - Unattended 115.12. CHERRY LANE TID - Unattended 69.12. CHILOQUIN TID - Unattended 230.115.69. CIRCLE BOULEVARD TID - Unattended 115.20. CLOAKE TID - Unattended 69.20. COBURG TlD - Unattended 69.20. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da. Yr)Dec. 31 2002 (2)A Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. ). Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line Transformers Spare (In Service) (In MVa)In Service Transformers Type of Equipment Number of Units Total Capacity No. (In MVa) (f) (g) (h)(i)(k) 800 110 174 26 : 30 ' 119 38 . FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) nA Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation , designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) COLUMBIA TID - Unattended 57.11. COOS RIVER TID - Unattended 115.20. COQUILLE TID - Unattended 115.20. CROWFOOT TID - Unattended 115.20. CULLY TID - Unattended 115.12. CULVER TID - Unattended 69.12. DAIRY TID - Unattended 69.12. DALLAS TID - Unattended 115.20. DESCHUTES TID - Unattended 69.12. DEVILS LAKE TID - Unattended 115.20. DIXON TID - Unattended 115. DODGE BRIDGE TID - Unattended 69.20. EASY VALLEY TID - Unattended 115.12. EMPIRE NEW TID - Unattended 115.20. ENTERPRISE TID - Unattended 69.20.12.50 . FREEWA TER TID - Unattended 69. GLENDALE TID - Unattended 230.12. GOLD HILL TID - Unattended 69.12. GOSHEN (OREGON)TID - Unattended 115.20. GRANT TID - Unattended 115.20. GRIFFIN CREEK TID - Unattended 115.12. HARRISBURG TID - Unattended 69.20. HERMISTON TID - Unattended 69.12. HILLVIEW TID - Unattended 115.20. HOLLADAY TID - Unattended 115.11. HOLLYWOOD TID - Unattended 115.12. HORNET TID - Unattended 69.12. INDEPENDENCE TID - Unattended 69.20. JACKSONVILLE TID - Unattended 115.69.12. JEFFERSON TID - Unattended 69.20. JEROME PRAIRIE TID - Unattended 115.12. JUNCTION CITY TID - Unattended 69.20. KILLINGSWORTH TID - Unattended 69.12. KNOTT TID - Unattended 115.57.12. LAKEPORT TID - Unattended 69.12. LEBANON TID - Unattended 115.20. LEMOLO # 1 TID - Unattended 11.115.12. LINCOLN TID - Unattended 115.12. LOCKHART TID - Unattended 115.20. LYONS (NEW)TID - Unattended 69.12. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) 177 105 FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002(2) riA Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation , designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) MADRAS TID - Unattended 69.12.50 MALLORY TID - Unattended 115.12.47 MARYS RIVER TID - Unattended 115.20. MEDFORD TID - Unattended 115.69.12. MERLIN TID - Unattended 115.12. MERRILL TID - Unattended 69.12. MILE-TID - Unattended 115.69.12. MURDER CREEK TID - Unattended 115.20.12. MYRTLE CREEK TID - Unattended 69.12. NORTH BEND PLANT TID - Unattended 115.12. OAK KNOLL TID - Unattended 115.12. BRIEN (NEW)TID - Unattended 115.12. OCHOCO LUMBER CO TID - Unattended 12. OREMET TID - Unattended 115.20.12. OVERPASS TID - Unattended 69.12. PALLETTE TID - Unattended 40.20. PARK STREET TID - Unattended 115.12. PARKROSE TID - Unattended 57.12. PENDLETON TID - Unattended 69.12. PILOT ROCK TID - Unattended 69.12. POWELL BUTTE TID - Unattended 115.12. PRINEVILLE TID - Unattended 115.12. PROSPECT 1 HE PLANT TID - Unattended 69. PROSPECT 2 HE PLANT TID - Unattended 69. PROSPECT 3 HE PLANT TID - Unattended 69. QUEEN AVE TID - Unattended 69.20. RIDDLE TID - Unattended 69.12. ROSEBURG TID - Unattended 69.20. RUSSELLVILLE TID - Unattended 115.12. SAGE RD TID - Unattended 115.12. SCENIC TID - Unattended 115.69.12. SCIO TID - Unattended 69.12. SEASIDE TID - Unattended 115.12. SODA SPRINGS TID - Unattended 115. SOUTH GATE TID - Unattended 69.20. STATE STREET TID - Unattended 115.20. STAYTON TID - Unattended 69.20. SWEET HOME TID - Unattended 115.20. TAKELMA TID - Unattended 115.20. TALENT TID - Unattended 69.12. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) 100 FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) riA Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for conceming substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) TUCKER TID - Unattended 115.69.12. UMATILLA TID - Unattended 69.12. VERNON TID - Unattended 69.12. VILLAGE GREEN TID - Unattended 115.20. VINE STREET TID - Unattended 20.69. WALLOWA TID - Unattended 69.12. WARM SPRINGS TID - Unattended 20.69. WESTERN KRAFT TID - Unattended 115.12. 9 WESTON NEW TID - Unattended 69.12. WEYERHAEUSER TID - Unattended 69.12. WHITE CITY TID - Unattended 115.12. WILLOW COVE TID - Unattended 34. WINCHESTER TID - Unattended 115.69.12. TOTAL 10798.2959.277.69 NUMBER OF SUBSTATIONS TID 120 BEND Transmission - Atte 69.12. CLEARWATER #2 HE PL T Transmission - Atte 11.115. DIXONVILLE 230KV Transmission - Atte 230.115.69. DIXONVILLE 500KV Transmission - Atte 500.230. JC BOYLE Transmission - Atte 69.2.40 JOHN C BOYLE HE PL T Transmission - Atte 11.230. KLAMATH FALLS Transmission - Atte 230.69. LEMOLO #1 HE PLANT Transmission - Atte 11.115.12. LEMOLO #2 HE PLANT Transmission - Atte 11.115. LONE PINE (NEW)Transmission - Atte 230.115. LONE PINE (OLD)Transmission - Atte 115.69. MALIN Transmission - Atte 500.230.69. POWERDALE HE PLANT Transmission - Atte 69. PROSPECT CENTRAL Transmission - Atte 69.115. TOKETEE Transmission - Atte 115. TOKETEE HE PLANT Transmission - Atte 115. WALLOWA FALLS HE PL T Transmission - Atte 20. WEST SIDE HE PLANT Transmission - Atte 69.12. BROOKS-SCANLON LBR Transmission - Unat 12.69. CALAPOOYA Transmission - Unat 230.69. CLEARWATER 1 HE PLT Transmission - Unat 115. CLINE FALLS HYDRO Transmission - Unat 12. COLD SPRINGS Transmission - Unat 230.69. COVE Transmission - Unat 230.69. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) 100 4364 214 344 650 250 625 108 342 127 FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002(2) riA Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (1). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) CRATER LAKE Transmission - Unat 20. DALREED Transmission - Unat 230.34. DAYS CREEK Transmission - Unat 115.69. DIAMOND HILL Transmission - Unat 230.69. EAGLE POINT HE PLANT Transmission - Unat 115. EAST SIDE HE PLANT Transmission - Unat 69. FISH CREEK Transmission - Unat 115. FISH CREEK HE PLANT Transmission - Unat 115. 9 FISHHOLE Transmission - Unat 115.69. FRY Transmission - Unat 230.115. GRANTS PASS Transmission - Unat 230.115.69. GREEN SPRINGS PLANT Transmission - Unat 125.71. HAZELWOOD Transmission - Unat 115.69. HURRICANE Transmission - Unat 230.69. ISTHMUS Transmission - Unat 230.115. KENNEDY Transmission - Unat 69.57. MERIDIAN 500 KV Transmission - Unat 500.230. MONPAC Transmission - Unat 115.69. OPAL SPRINGS HE PL T Transmission - Unat 69. PILOT BUTTE Transmission - Unat 230.69.12. PINE PRODUCTS Transmission - Unat 24.115. PONDEROSA Transmission - Unat 230.115.12. REDMOND Transmission - Unat 12.115.69. ROBERTS CREEK Transmission - Unat 115.69. ROUNDUP Transmission - Unat 230.69. SLIDE CREEK Transmission - Unat 115. SLIDE CREEK HE PLANT Transmission - Unat 115. STAYTON HE PLANT Transmission - Unat TROUTDALE Transmission - Unat 230.115.69. WILLOW CREEK Transmission - Unat 69.34. TOTAL 6451.4868.509. NUMBER OF SUBSTATIONS TRANSMISSIONS - 54 UTAH EAST MILL CREEK Distribution 43.12. MCCORNICK IRRIGATION Distribution 46.12. MYTON Distribution 69.12. ALTAVIEW Distribution - Unat 46.12. AMALGA Distribution - Unat 46.12. AMERICAN FORK Distribution - Unat 43.12. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31, 2002(2) n A Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for Increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) 560 458 250 650 400 250 500 6479 FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page , summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) ARAGONITE Distribution - Unat 138.12.47 AURORA Distribution - Unat 42.12. BEAR RIVER Distribution - Unat 43.12.47 BENJAMIN Distribution - Unat 44.12. BINGHAM Distribution - Unat 43.12. BLUE CREEK Distribution - Unat 46.12. BLUFF Distribution - Unat 69.12. BLUFFDALE Distribution - Unat 43.12.47 BOTHWELL Distribution - Unat 42.12. BOX ELDER Distribution - Unat 42.12. BRIAN HEAD Distribution - Unat 34.12. BRICKYARD Distribution - Unat 43.12. BRIGHTON Distribution - Unat 43.24.14. BROOKLAWN CREAMERY Distribution - Unat 46.12. BRUNSWICK Distribution - Unat 43.12. BUSH Distribution - Unat 43.12. BUTLERVILLE Distribution - Unat 43.12.47 CAMERON Distribution - Unat 138.46. CAMP WILLIAMS Distribution - Unat 138.12. CANNON Distribution - Unat 43.12. CANYONLANDS Distribution - Unat 69.12. CAPITOL Distribution - Unat 43.12. CARBIDE Distribution - Unat 67.12. CARBONVILLE Distribution - Unat 43.12. CASTO Distribution - Unat 43.12.47 CEDAR NORTH Distribution - Unat 34. CENTENNIAL Distribution - Unat 138.12. CENTERVILLE Distribution - Unat 43.12. CENTRAL Distribution - Unat 42.12.47 CHAPARRAL Distribution - Unat 46. CHERRYWOOD Distribution - Unat 132.12. CIRCLEVILLE Distribution - Unat 67.12. CLEAR CREEK Distribution - Unat 43.12.47 CLEAR LAKE Distribution - Unat 44.12. CLEARFIELD Distribution - Unat 43.12.47 CLINTON Distribution - Unat 132.12. CLIVE Distribution - Unat 42.12. COALVILLE Distribution - Unat 43.24.12. COLLEGE Distribution - Unat 42.24. COLTON WELL Distribution - Unat 46.12. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) riA Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i) (j) (k) FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002(2) riA Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) COLUMBIA Distribution - Unat 138.45. CORINNE Distribution - Unat 42.12. COVE FORT Distribution - Unat 43.12. CRESCENT JUNCTION Distribution - Unat 46.12. CUDAHY Distribution - Unat 132.12. DAIRY FORK Distribution - Unat 46.12. DAMMERON VALLEY Distribution - Unat 67.12. DECKER LAKE Distribution - Unat 138.12. 9 DELLE Distribution - Unat 43.12. DELTA Distribution - Unat 43.12. DESERET Distribution - Unat 42. DEWEYVILLE Distribution - Unat 42.12. DIMPLE DELL Distribution - Unat 138.12. DIXIE DEER Distribution - Unat 34.12. DOG VALLEY Distribution - Unat 46.12. DRAGERTON Distribution - Unat 43.12. DRAPER Distribution - Unat 43.12. DUMAS Distribution - Unat 138.12.47 EAST BENCH Distribution - Unat 43. EAST HYRUM Distribution - Unat 43.12. EAST PROVO Distribution - Unat 46.12. EDEN Distribution - Unat 43.12. EL MONTE Distribution - Unat 132.45. ELBERTA Distribution - Unat 46.12. ELK MEADOWS Distribution - Unat 42.12. ELSINORE Distribution - Unat 44.12.47 EMERY CITY Distribution - Unat 69.12.47 EMIGRATION Distribution - Unat 43.12. EMMA PARK Distribution - Unat 132.12.47 ENTERPRISE VALLEY Distribution - Unat EUREKA Distribution - Unat 46.12. FARMINGTON Distribution - Unat 43.12. FAYETTE Distribution - Unat 43.12. FERRON Distribution - Unat 69.12. FIDDLER'S CANYON Distribution - Unat 34.12. FIELDING Distribution - Unat 44.12.47 FIFTH WEST Distribution - Unat 132.12. FLUX Distribution - Unat 42.12. FOOL CREEK Distribution - Unat 42.12. FOUNTAIN GREEN Distribution - Unat FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 0413012003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for Increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i) (j) (k) FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) riA Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale , may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) FREEDOM Distribution - Unat 45.12.47 FRUIT HEIGHTS Distribution - Unat 43.12. GARDEN CITY Distribution - Unat 67.12. GARKANE INTERTIE Distribution - Unat 68.46.2.40 GATEWAY Distribution - Unat 69.34.12. GENEVA Distribution - Unat 132.13. GOSHEN (UTAH)Distribution - Unat 46.12.47 GRANTSVILLE Distribution - Unat 43.12. GRAVEL PIT Distribution - Unat 46.12. GREEN CANYON Distribution - Unat 132.45. GREEN RIVER Distribution - Unat 46.12. GRINDING Distribution - Unat 138.13. GROW Distribution - Unat 132.46.12. GUNNISON Distribution - Unat 45.50. HALE Distribution - Unat 43.12.47 HAMILTON FORT Distribution - Unat 34.12. HAMMER Distribution - Unat 138.12.47 HATCH Distribution - Unat 138.69. HAVASU Distribution - Unat 69.24.12.47 HELPER Distribution - Unat 120.45. HELPER CITY Distribution - Unat 45. HENEFER Distribution - Unat 43.12. HIAWATHA Distribution - Unat 44.24. HINKLEY Distribution - Unat 43.12. HOGGARD Distribution - Unat 132.12. HOGLE Distribution - Unat 43.12. HONEYVILLE Distribution - Unat 132.46. HURRICANE BENCH Distribution - Unat 69.12. HURRICANE FIELDS Distribution - Unat 34.12. IRONTON Distribution - Unat 46.12. IVINS Distribution - Unat 34.12. JUAB Distribution - Unat 43.12. JUNCTION Distribution - Unat 69.12. KAIBAB Distribution - Unat 67.12. KAMAS Distribution - Unat 43.12. KANARAVILLE Distribution - Unat 34.12.47 KEARNS Distribution - Unat 43.12.47 KENSINGTON Distribution - Unat 43. KYUNE Distribution - Unat 46. LAKE POINT Distribution - Unat 42.12. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondenfs books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) nA Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) LAKEPARK Distribution - Unat 132.12. LAMPO Distribution - Unat 138.46. LARK Distribution - Unat 42.12. LASAL Distribution - Unat 67.12.7200. LAYTON Distribution - Unat 43.12. LA-BOY Distribution - Unat 43.12. LE GRANDE Distribution - Unat 43.12. LEWISTON Distribution - Unat 43.12. LINDON Distribution - Unat 46.12. LISBON Distribution - Unat 67.12. LOAFER Distribution - Unat 46.12. LOGAN CANYON Distribution - Unat 46. LONETREE Distribution - Unat 34.19.12. LOST CREEK Distribution - Unat 46. LOWER BEAVER Distribution - Unat 44.12. L YNNDYL Distribution - Unat 43.12. MAESER Distribution - Unat 67.12. MANTUA Distribution - Unat 45.24.12. MAPLETON Distribution - Unat 46.12. MARRIOTT Distribution - Unat 46.12. MARYSVALE Distribution - Unat 43. MATHIS Distribution - Unat 43.12. MCKAY Distribution - Unat 43.12.47 MEADOWBROOK Distribution - Unat 46.12. MEDICAL Distribution - Unat 46.12. MELLING Distribution - Unat 34. MIDVALE Distribution - Unat 43.12. MIDWAY Distribution - Unat 132.45. MILFORD Distribution - Unat 42.12.47 MILFORD Distribution - Unat 46. MILLS Distribution - Unat 44. MILLVILLE Distribution - Unat 43.12. MINERAL PRODUCTS Distribution - Unat 69.46. MINERSVILLE Distribution - Unat 44.12. MOAB CITY Distribution - Unat 67.12. MONTEZUMA Distribution - Unat 69.12. MOORE Distribution - Unat 69.12. MORGAN Distribution - Unat 42.12.47 MORONI Distribution - Unat 43.12.47 MOSS JUNCTION Distribution - Unat 42.12. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002(2) DA Resubmission 04130/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name. of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2) 0 A Resubmission 0413012003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) MOUNTAIN DELL Distribution - Unat 43.12.40 MOUNTAIN GREEN Distribution - Unat 43.12.47 NEBO Distribution - Unat 138.46. NEW HARMONY Distribution - Unat 69.12. NEW LAVERKIN Distribution - Unat 69.12.47 NEWGATE Distribution - Unat 43.12. NEWTON Distribution - Unat 43.12.47 NIBLEY Distribution - Unat 43.12.47 NORTH BENCH Distribution - Unat 43.12.25. NORTH FIELDS Distribution - Unat 42.12. NORTH HOLDEN IRRIGATION Distribution - Unat 46.12. NORTH LOGAN Distribution - Unat 43.12. NORTH OGDEN Distribution - Unat 43.12.47 NORTH SALT LAKE Distribution - Unat 43.12.47 NORTHEAST Distribution - Unat 41.12.47 NORTHRIDGE Distribution - Unat 46.12. OAK SPRINGS Distribution - Unat 46. OAKLAND AVENUE Distribution - Unat 43.12. OAKLEY Distribution - Unat 42.12. OCKEY Distribution - Unat 46. OL YMPUS Distribution - Unat 43.12.47 OPHIR Distribution - Unat 42.12. ORANGE Distribution - Unat 43.12. ORANGEVILLE Distribution - Unat 69.12. OREM Distribution - Unat 43.12.47 PANGUITCH Distribution - Unat 67.12.47 PARlETTE Distribution - Unat 43.25.14.40 PARK CITY Distribution - Unat 43.12.47 PARKWAY Distribution - Unat 132.12.47 PARLEYS Distribution - Unat 43.12. PARRISH Distribution - Unat 138.46.13. PARRY Distribution - Unat 44. PELICAN POINT Distribution - Unat 46.12. PINE CREEK Distribution - Unat 43.12. PINNACLE Distribution - Unat 46.12. PLEASANT GROVE Distribution - Unat 43.12.47 PLEASANT VIEW Distribution - Unat 43.12. PRICE Distribution - Unat 43.72.46. PROLER Distribution - Unat 46. PROMONTORY Distribution - Unat 44.12.47 FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line Name and Location of Substation VOLTAGE (In MVa) No.Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) QUAIL CREEK Distribution - Unat 34.12. QUARRY Distribution - Unat 46.12. QUITCHAPA Distribution - Unat 34.12. RAINS#2 Distribution - Unat 45. RANDOLPH Distribution - Unat 44.12. RASMUSSON Distribution - Unat 44.12.47 RATTLESNAKE Distribution - Unat 67.24. RED BUTTE Distribution - Unat 69.12. RED NARROWS Distribution - Unat 46.12. RED ROCK Distribution - Unat 69. RESEARCH PARK Distribution - Unat 43.12. RICH Distribution - Unat 67.12. RICHFIELD Distribution - Unat 43.12. RICHMOND Distribution - Unat 43.12. RIDGELAND Distribution - Unat 138.12. RIDING RECEIVING Distribution - Unat 138.46.13. RITER Distribution - Unat 43.12. ROSE PARK Distribution - Unat 43.12. ROUND VALLEY Distribution - Unat 46. ROWLEY Distribution - Unat 132.13. ROYAL Distribution - Unat 46.12. SALINA Distribution - Unat 43.12.47 SANDY Distribution - Unat 43.12. SANPITCH Distribution - Unat 45. SANTAQUIN Distribution - Unat 46.12. SARATOGA Distribution - Unat 43.12. SCIPIO Distribution - Unat 42.12. SCOFIELD Distribution - Unat 46.12. SCOFIELD RESERVOIR Distribution - Unat 46.12. SECOND STREET Distribution - Unat 43.12. SEVENMILE Distribution - Unat 69.12.47 SEVIER Distribution - Unat 132. SHARON Distribution - Unat 43.12. SILVER CREEK Distribution - Unat 134.46.13. SINK Distribution - Unat 44. SKULL VALLEY Distribution - Unat 41.12. SMITHFIELD Distribution - Unat 132.45. SNARR Distribution - Unat 43.12. SNYDERVILLE Distribution - Unat 43.12. SOLDIER SUMMIT Distribution - Unat 46.12. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) riA Resubmission 04/3012003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 3. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No. In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) SOUTH GRANGER Distribution - Unat 43.12. SOUTH MILFORD IRRIGATION Distribution - Unat 43.12. SOUTH MOUNTAIN Distribution - Unat 138.12. SOUTH OGDEN Distribution - Unat 43.12. SOUTH YARD Distribution - Unat 46. SOUTHEAST Distribution - Unat 46.12. SOUTH PARK Distribution - Unat 43.12. SOUTHWEST Distribution - Unat 43.12. SPANISH VALLEY Distribution - Unat 69.12. SPRINGDALE Distribution - Unat 34.12. ST. JOHN Distribution - Unat 42.12. STANSBURY Distribution - Unat 43.12.47 SUMMIT PARK Distribution - Unat 43.12. SUNSTONE Distribution - Unat 43. SUPERIOR Distribution - Unat 67.12. SUTHERLAND Distribution - Unat 43.24.14. SWISS Distribution - Unat 44.12. TABIONA Distribution - Unat 66.11. TAYLOR Distribution - Unat 43.12. THIEF CREEK Distribution - Unat 132.25.14.40 THIRD WEST Distribution - Unat 43.12. THIRTEENTH SOUTH Distribution - Unat 41.12. THISTLE Distribution - Unat 46.12.47 THOMPSON Distribution - Unat 45. TIMP Distribution - Unat 130.46. TWENTY THIRD STREET OGDEN Distribution - Unat 43. UINTAH Distribution - Unat 43.12. UNION Distribution - Unat 43.12. UNIVERSITY Distribution - Unat 43.12. UPALCO Distribution - Unat 138.69.12. UTE Distribution - Unat 69. VALLEY CENTER Distribution - Unat 43.12. VERMILLION Distribution - Unat 46.12.47 VERNAL Distribution - Unat 67.12.47 VICKERS Distribution - Unat 44.12. VINEYARD Distribution - Unat 46.12. WALLSBURG Distribution - Unat 132.12.47 WARREN Distribution - Unat 132.12.47 WASATCH Distribution - Unat 41.12. WASHAKIE Distribution - Unat 132. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) OA Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. ). Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No. In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002(2) riA Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) Name and Location of Substation Character of SubstationNo.Primary Secondary Tertiary (a)(b)(c)(d)(e) WELBY Distribution - Unat 43.12. WELFARE Distribution - Unat 46.12. WELLINGTON Distribution - Unat 46.12. WEST COMMERCIAL Distribution - Unat 43.12. WEST JORDAN Distribution - Unat 138.12. WEST OGDEN Distribution - Unat 132.12. WEST ROY Distribution - Unat 43.12. WEST TEMPLE Distribution - Unat 43. WHITE MESA Distribution - Unat 67.12.47 WINKLEMAN Distribution - Unat 45. WOLF CREEK Distribution - Unat 69.12. WOODRUFF Distribution - Unat 44.12. WOODS CROSS Distribution - Unat 43.12. WOODSIDE Distribution - Unat 46.12. WYUTA Distribution - Unat 43.12.47 TOTAL 17974.4443.8899. NUMBER OF SUBSTATIONS DISTRIBUTION - 301 HOLLADAY TID - Unattended 43.12. LINCOLN TID - Unattended 43.12. REDWOOD TID - Unattended 43.12.47 TOTAL 131.40 37.21. NUMBER OF SUBSTATIONS TID - 3 HUNTER Transmission 345.138.43. PAVANT Transmission 230.46.13. SIGURD Transmission 345.230.138. SPANISH FORK Transmission 345.138.46. WEST CEDAR Transmission 230.138.34. ABAJO Transmission - Atte 138.69. ANGEL Transmission - Atte 138.46.12. ASHLEY Transmission - Atte 135.69. BARNEY Transmission - Atte 138.44. BEN LOMOND Transmission - Atte 345.230.138. BLACKHAWK Transmission - Atte 67.45. BOOK CLIFFS Transmission - Atte 69.44. COLEMAN Transmission - Atte 138.69.34. COTTONWOOD Transmission - Atte 132.46.12.47. HIGHLAND Transmission - Atte 138.46.12. HORSESHOE Transmission - Atte 132.43.12. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i) (j) (k) 137 389 134 112 1734 FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for conceming substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) HUNTINGTON CITY Transmission - Atte 67.43.12. JORDAN Transmission - Atte 138.46.12. LAVERKIN Transmission - Atte 138.69.34. MCFADDEN Transmission - Atte 138.69.13. MIDDLETON Transmission - Atte 138.69.34. MOAB Transmission - Atte 132.69.12. NINETY SOUTH Transmission - Atte 345.138.46. OQUIRRH Transmission - Atte 138.46.13. PAROWAN VALLEY Transmission - Atte 230.138.34. PINTO Transmission - Atte 345.138.69. RIVERDALE Transmission - Atte 132.45.12. SIXTH SOUTH Transmission - Atte 138.43.12. SNOWVILLE Transmission - Atte 69.43.12.47 SPHINX Transmission - Atte 115.45.12. SYRACUSE Transmission - Atte 138.46.12.47 i TAYLORSVILLE Transmission - Atte 138.46.13. TERMINAL Transmission - Atte 345.230.138. TOOELE Transmission - Atte 132.45. WES1WA TER Transmission - Atte 67.43.12. WINCHESTER HILLS Transmission - Atte 34.34.12. FILLMORE Transmission - Unat 46.46. FOUNTAIN GREEN HE PLANT Transmission - Unat 46. JERUSALEM Transmission - Unat 138.46. JERUSALEM Transmission - Unat 132.45. LITTLE MOUNTAIN PLANT Transmission - Unat 230.34. MCCLELLAND Transmission - Unat 132.12. MID-VALLEY Transmission - Unat 345.138. PONDEROSA Transmission - Unat 44. WILLOW CREEK Transmission - Unat 44.12. TOTAL 7299.3276.1043. NUMBER OF SUBSTATIONS TRANSMISSION - 45 WASHINGTON UNION GAP TID - Attended 230.115.12. VOELKER TID - Attended 115.12. ATTALIA TID - Unattended 69.12. BOWMAN STREET TID - Unattended 69.12. CASCADE KRAFT TID - Unattended 69.12. CLINTON TID - Unattended 115.13. DAYTON TID - Unattended 69. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) 257 320 500 3405 348 118 FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002(2) riA Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individl!al stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) 1 DODD RD TID - Unattended 69.20. GRANDVIEW TID - Unattended 115.12. 3 HOPLAND TID - Unattended 115.12. MILL CREEK TID - Unattended 69.12. 5 NOB HILL TID - Unattended 115.12. 6 NORTH PARK TID - Unattended 115.12. 7 ORCHARD TID - Unattended 115.12. 8 PACIFIC TID - Unattended 115.12. 9 PASCO TID - Unattended 115.69. POMEROY TID - Unattended 69.12. PROSPECT POINT TID - Unattended 69.12. PUNKIN CENTER TID - Unattended 115.12. RIVER ROAD TID - Unattended 115.12. SELAH TID - Unattended 115.12. SULPHER CREEK TID - Unattended 115.12. SUNNYSIDE TID - Unattended 115.12. TIETON TID - Unattended 115.34.12. TOPPENISH TID - Unattended 115.12. TOUCHET TID - Unattended 69.12. WAITSBURG TID - Unattended 69. WAPATO TID - Unattended 115.12. WENAS TID - Unattended 115.12. WHITE SWAN TID - Unattended 69.12. WILEY TID - Unattended 115.12. TOTAL 3174.566.36. NUMBER OF SUBSTATIONS TID - 31 CONDIT PLANT Transmission - Atte 69. MERWIN HE PLANT Transmission - Atte 13.115. NACHES HE PLANT Transmission - Atte 12.115. WALLA WALLA Transmission - Atte 230.69. YALE HE PLANT Transmission - Atte 13.115.12. CENTRAL Transmission - Unat 69.12. JAMES RIVER COGENERATION Transmission - Unat 13.69. NACHES DROP HE PLANT Transmission - Unat 12. OUTLOOK Transmission - Unat 230.115. POMONA HEIGHTS Transmission - Unat 230.115. SWIFT #1 HE PLANT Transmission - Unat 13.230. WALLULA Transmission - Unat 230.69. TOTAL 1050.1002.134. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) riA Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) 1336 179 300 144 125 261 120 1319 FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~rt Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) NUMBER OF SUBSTATIONS TRANSMISSION - 12 WYOMING DRY FORK Distribution - Atte 69. EMIGRANT Distribution - Atte 115.12. FORT CASPER Distribution - Atte 69.12. HANNA Distribution - Atte 34.13. LA BONTE Distribution - Atte 13. STANDARD OIL Distribution - Atte 69. VETERANS Distribution - Atte 34.13. AIR BASE Distribution - Unat 12. ALKALI ANTICLINE Distribution - Unat 34. ANTELOPE MINE Distribution - Unat 230.34. BAILEY DOME Distribution - Unat 34.13.2.40 BAIROIL Distribution - Unat 115.57.34. BAR X Distribution - Unat 230.34. BELLAMY NO.Distribution - Unat 115.34. BIG MUDDY Distribution - Unat 69.12. BLACKS FORK Distribution - Unat 230.34. BLUFF # 1 Distribution - Unat 34. BRYAN Distribution - Unat 115.12. BUFFALO-TOWN Distribution - Unat 20. BYRON Distribution - Unat 34. CASSA Distribution - Unat 57.20.12. CENTER STREET Distribution - Unat 115. CHATHAM Distribution - Unat 34. CHUKAR Distribution - Unat 12. COLTER Distribution - Unat 34. COLUMBIA-GENEVA STL Distribution - Unat 230.13. COLUMBINE Distribution - Unat 20. COMMUNITY PARK Distribution - Unat 69.12. COWLEY-DEAVER (DEAVER TOWN)Distribution - Unat 34. CROOKS GAP Distribution - Unat 34.13. DEER CREEK Distribution - Unat 69.12. DOUGLAS Distribution - Unat 57. EVANS Distribution - Unat 69.13. FAIRGROUNDS Distribution - Unat 69.12. FARMERS UNION Distribution - Unat 34. FETTERMAN Distribution - Unat 13. FORT SANDERS Distribution - Unat 115.13. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) riA Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease , give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line Transformers Spare (In Service) (In MVa)In Service Transformers Type of Equipment Number of Units Total Capacity No. (In MVa) (f) (g) (h)(i)(k) 150 28 . FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31, 2002(2) n A Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (1). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) FRONT STREET Distribution - Unat 13. GALLUP Distribution - Unat 34. GLENDO Distribution - Unat 57. GLENROCK Distribution - Unat 69. GREAT DIVIDE Distribution - Unat 115.34. GREEN RIVER Distribution - Unat 34. GREYBULL Distribution - Unat 34. JACKALOPE Distribution - Unat 115.12. JIM BRIDGER 34.5KV Distribution - Unat 69. LANDER Distribution - Unat 34.12. LARAMIE Distribution - Unat 115.13. LARAMIE PLANT Distribution - Unat 13. LINCH Distribution - Unat 69.13. LOVELL (LOVELL TOWN)Distribution - Unat 34. MANDERSON Distribution - Unat 34. MEDICINE WHEEL Distribution - Unat 34. MILL IRON Distribution - Una~34.13. MILLS Distribution - Unat 12. MOXA Distribution - Unat 69. MURPHY DOME Distribution - Unat 34.12. ORIN Distribution - Unat 57. ORPHA Distribution - Unat 57. PAC.FRUIT EXPRESS Distribution - Unat 13. PARCO Distribution - Unat 34.13. PARK STREET Distribution - Unat 34. PITCHFORK Distribution - Unat 69.24. PLATTE PIPE NATURAL Distribution - Unat 57. PLATTE RIVER DJ Distribution - Unat 69. POISON SPIDER Distribution - Unat 69. POPLAR STEET Distribution - Unat 12. RAINBOW Distribution - Unat 230.34.13. RED BUTTE Distribution - Unat 69.12. REFINERY Distribution - Unat 115.12. RELIANCE Distribution - Unat 34. RESERVOIR Distribution - Unat 12. RIVER DOME Distribution - Unat 34. SAGE HILL Distribution - Unat 34.13. SERVICE PIPE - MIDWEST HrS Distribution - Unat 69. SERVICE PIPE IND STA Distribution - Unat 34.2.40 SHOSHONI Distribution - Unat 34. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04130/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f)(a)(h)(i) (j) (k) FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) riA Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) SINCLAIR Distribution - Unat 34. SOUTH CODY Distribution - Unat 69.25. SOUTH ELK BASIN Distribution - Unat 34. SPRING CREEK Distribution - Unat 115.13. SVILAR Distribution - Unat 34. TEAPOT Distribution - Unat 69.12. TEN MILE Distribution - Unat 69.34. THERMOPOLIS TOWN Distribution - Unat 34. WAMSUTTER Distribution - Unat 34. WARM SPRINGS SPL.Distribution - Unat 115. WELCH Distribution - Unat 57. WERTZ-SINCLAIR Distribution - Unat 57.13. WEST ADAMS Distribution - Unat 34. WORLAND Distribution - Unat 115.34. WORLAND TOWN Distribution - Unat 34. TOTAL 5825.942.70. NUMBER OF SUBSTATIONS DISTRIBUTION - 92 ASTLE TID - Unattended 34.13. BRIDGER PUMP TID - Unattended 230.34.13. MANSFACE TID - Unattended 230.34. MIDWEST TID - Unattended 230.69.34. MINERS TID - Unattended 230.115.34. ROCK SPRINGS PLANT TID - Unattended 34.13. TOTAL 989.280.84. NUMBER OF SUBSTATIONS TID - 6 DAVE JOHNSON PLANT Transmission - Atte 13.115.230. ELK BASIN Transmission - Atte 34. HILLTOP Transmission - Atte 115.34.20. JIM BRIDGER PLANT Transmission - Atte 22.345. WYODAK PLANT Transmission - Atte 22.69.230. BUFFALO Transmission - Unat 230.20. CASPER Transmission - Unat 230.115.69. D. J. COAL MINE Transmission - Unat 69.34. FIREHOLE Transmission - Unat 230.34. FRANNIE Transmission - Unat 230.34. GARLAND Transmission - Unat 230.34. GLENDO-AUTO Transmission - Unat 69.57. GRASS CREEK Transmission - Unat 230.34. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) riA Resubmission 0413012003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) 804 262 485 FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) LITTLE MOUNTAIN Transmission - Unat 230.34. MUSTANG Transmission - Unat 230.115. OREGON BASIN Transmission - Unat 230.34. PLATTE Transmission - Unat 230.115.34. POINT OF ROCKS Transmission - Unat 230.34. RIVERTON Transmission - Unat 230.34.12. ROCK SPRINGS Transmission - Unat 230.34. SALT CREEK PAN AM Transmission - Unat 69.34. SOUTH TRONA Transmission - Unat 230.34. WESTVACO Transmission - Unat 230.34. WYOPO Transmission - Unat 230.34. YELLOWCAKE Transmission - Unat 230.34. TOTAL 4296.1538.596. NUMBER OF SUBSTATIONS TRANSMISSION - 25 CALIFORNIA DISTRIBUTION - 31 T/D- TRANSMISSION - 11 IDAHO DISTRIBUTION - 60 TID - 0 TRANSMISSION - MONTANA DISTRIBUTION - 0 TID - 0 TRANSMISSION - 1 OREGON DISTRIBUTION - 94 TID - 120 TRANSMISSION - 54 UTAH DISTRIBUTION - 301 TID - 3 TRANSMISSION - 45 FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2) n A Resubmission 0413012003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. s. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondenfs books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No. In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) 200 240 150 1686 158 327 371 177 2269 800 110 4364 214 6479 137 389 3405 FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) OA Resubmission 04130/2003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) WASHINGTON DISTRIBUTION - 0 TID - 31 TRANSMISSION - 12 WYOMING DISTRIBUTION - 92 TID - 6 TRANSMISSION - 25 FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) riA Resubmission 04/3012003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for Increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No. In Service Transformers Number of Units (In MVa) (f) (g) (h)(i)(k) 1336 1319 804 262 1686 FERC FORM NO.1 (ED. 12-96)Page 427. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec31,2002 FOOTNOTE DATA ISchedule Page: 103 Line No.Column: On May 5, 2000, the assets of Centralia Mining Company were sold to TransAlta. 'Schedule Page: 103 Une No.Column: Idaho Power holds a 33.33% ownershi interest in Brid er Coal Com an . Schedule Pa e: 103 Line No.Column: CH2MHili holds a 10% ownershi interest in PacifiCor Environmental Remediation Com an Schedule Pa e: 103 Une No.Column: PacifiCorp Future Generations, Inc. owns interests in Canopy Botanicals, SRL, relating to Rain Forest Carbon Emissions Credits. ISchedule Page: 103 Line No.10 Column: PacifiCorp Group Holding Company transferred to PacifiCorp Holdings, Inc. a fully owned subsidiary of Scottish Power, onFebruary 4, 2002. IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dee 31 2002 FOOTNOTE DATA ISchedule Page: 104 Line No.Column: The Respondent sets forth the salary information for its five most highly compensated officers for the year ended December 31 , 2002, consistent with Item 402 of Regulation S-K as promulgated by the Securities and Exchange Commission. Salary information for other officers will be provided to the Commission upon request, but the Company considers such information rsonal and confidential to such officers. See 18 CFR 388.107 d , chedule Pa e: 104 Line No.Column: The Respondent sets forth the salary information for its five most highly compensated officers for the year ended December 31 , 2002, consistent with Item 402 of Regulation S-K as promulgated by the Securities and Exchange Commission. Salary information for other officers will be provided to the Commission upon request, but the Company considers such information ersonal and confidential to such officers. See 18 CFR 388.107 d , Schedule Pa e: 104 Line No.Column: The Respondent sets forth the salary information for its five most highly compensated officers for the year ended December 31 , 2002 , consistent with Item 402 of Regulation S-K as promulgated by the Securities and Exchange Commission. Salary information for other officers will be provided to the Commission upon request, but the Company considers such information ersonal and confidential to such officers. See 18 CFR 388.107 d , chedule Pa e: 104 Line No.Column: The Respondent sets forth the salary information for its five most highly compensated officers for the year ended December 31 , 2002, consistent with Item 402 of Regulation S-K as prornulgated by the Securities and Exchange Commission. Salary information for other officers will be provided to the Commission upon request, but the Company considers such information ersonal and confidential to such officers. See 18 CFR 388.107 d , Schedule Pa e: 104 Line No.11 Column: The Respondent sets forth the salary information for its five most highly compensated officers for the year ended December 31 , 2002, consistent with Item 402 of Regulation S-K as promulgated by the Securities and Exchange Commission. Salary information for other officers will be provided to the Commission upon request, but the Company considers such information ersonal and confidential to such officers. See 18 CFR 388.107 d , Schedule Pa e: 104 Line No.15 Column: b Elected Executive Vice President Janua 1 , 2002 Schedule Pa e: 104 Line No.17 Column: b Elected Senior Vice President Februa 11 , 2002 Schedule Pa e: 104 Line No.23 Column: b Elected Senior Vice President Februa 11 , 2002 chedule Pa e: 104 Line No.25 Column: b Elected Vice President Au ust 22, 2002 Schedule Pa e: 104 Line No.35 Column: b Resigned August 12, 2002 IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec 31 2002 FOOTNOTE DATA ISchedule Page: 105 Une No. Elected Janua 1 , 2002 Schedule Pa e: 105 Line No. Elected Director A ril18, 2002 Schedule Pa e: 105 Line No. Retired March 31 , 2002 Column: Column: Column: IFERC FORM NO.(ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec31 2002 FOOTNOTE DATA ISchedule Page: 114 Line No.13 Column: Reconciliation to Page 262-263 Taxes Accrued, Prepaid , and Charged During The Year. Page 263, Line 41Total Taxes Charged to Accounts 408.1 & 409.235 671 210 Statement of Income For The Year, Page 114, Line 13 Statement of Income For The Year, Page 114, Line 14 tatement of Income For The Year, Page 114, Line 15 !schedule Page: 114 Line No.14 Column: See Footnote on Line 13 Column C ISchedulePage: 114 Line No.15 Column: See Footnote on Line 13 Column C ISchedule Page: 114 Une No.48 Column: d See footnotes for page 262 - 263 column L other for account 409. 123,964 333 93,566,061 18.140.816 235,671 210 !schedule Page: 114 Une No.49 Column: d 848 page 272-277 28.712 page 234 part of the balance on line 17. 39,560 'Schedule Page: 114 Line No.50 Column: d 882 564 page 272 - 277 account 411. 29,052 page 234 part of the balance on line 17. 169,778 page 272 - 277 account 411. 081 394 IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec 31 2002 FOOTNOTE DATA ISchedule Page: 120 Line No.Column: b Amortization of Organization Costs Amortization of Software Development Amortization of Other Intangible Assets Amortization of Electric Plant Acq. Adj. Amortization of Regulatory Assets - Debits Amortization of Unrecovered Plant - Trojan Amortization of Regulatory Liabilities - Credits Amortization of Regulatory Assets - Credit 'Schedule Page: 120 Line No.18 Column: b Cum. Effect of Change in Acctg. Princ. FAS 133 F AS 133 Derivative Adjustrnents Coal Depreciation & Depletion Incl. in Fuel PMI Equity Earnings Incl. in Cost of Fuel (Gain)/Loss on Sale of Property Establish Trail Mt. Mine Reg. Asset WY & ID Reg. Orders-Def. Net Power Costs ID Orders Def. Net Power Costs Amort. Accumulated Provision for Pension & Benefits Accurn. Provision for Reorg. & Restructuring Mining Accruals & Other Deferred Credits Other Operating Activities 758 797 404 976 812 404 053,787 404 507 086 406. 847 407. 901 678 407. -689 183 407. 873,869 407.4 478,693 856,502 602 331 218 646 057 927 895,376 614 107 -62 569,420 030 340 389 039 069,591 996 764 992.794 -43 088,333 439 182.3/216/242/253/283 151 151 254/411.6/411. 182. 182. 182. 228. 228. 228/253 ISchedule Page: 120 Line No. Customer Advances for Construction Other Investment/Special Funds Column: b 621 503 357.326 978 829 252 124/128 ISchedule Page: 120 Line No.67 Column: b Inter-Company Borrowing (Note Agreements)169 000 233 IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A ResubmisSlon 04/30/2003 Dec 31, 2002 FOOTNOTE DATA 'Schedule Page: 122(a)(b) Line No.Column: b These are common stock investments related to SERP trust funds, so all changes are due to fair value changes; none were due to settled contracts/investments. chedule Page: 122(a)(b) Line No.Column: No change in fair value. These marks were frozen May 15, 2001 when the Company ceased designated contracts as Cash Flow Hedges. All frozen mark contracts were settled by December 31 2002 IFERC FORM NO.1 (ED. 12-87)Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dee 31, 2002 FOOTNOTE DATA ISchedule Page: 204 Line No.Column: g Balance at Balance at Beginning End ofLineAccount Description of Year Additions Retirements Transfers YearNo.(a)(b)(c)(d)(e)(f) (g) 1 39921 LAND OWNED IN FEE 634 916 634,916 2 39922 LAND RIGHTS 30,361,367 361 367 3 39930 STRUCTURES 46,984 248 997 361)986,888 439941 SURFACE - PLANT EQUIPMENT 779,650 779 650) 5 39942 SURFACE - DRAGLINE 7,433 469 433 469 6 39943 SURFACE - RAILROAD EQUIPMENT 1,464 867 (800 051)664 816 7 39944 SURFACE - ELECTRIC POWER FACILITIES 210 167 210 167 8 39945 UNDERGROUND - COAL MINE EQUIPMENT 108 054 888 246,860 (11 988,544)(164,497)100,148 707 9 39951 VEHICLES 183 536 091 (180,366)(91 235)946 026 10 39952 HEAVY CONSTRUCTION EQUIPMENT 181 082 197 272 (866 851)(448 314)23,063 189 11 39960 MISCELLANEOUS GENERAL EQUIPMENT 963 642 205 158 (475,407)693 393 12 39961 COMPUTERS - MAINFRAME 248 799 521 706 015)613,305 13 39970 MINE DEVELOPMENT AND ROAD EXTENSTION 419,059 22,419,059 TOTAL PLANT USED IN MINING OPERATIONS 257,919,691 753,902 (22,794,245)(704,046)240,175,302 IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmlssion 04/30/2003 Dec 31,2002 FOOTNOTE DATA ISchedule Page: 214 Une No.Column: Needed to access to future coal ortals & federal coal reserves when East Mountain is mined out. Schedule Pa e: 214 Line No.Column: To be converted to 138 kV, scheduled in service date is 2005. ISchedule Page: 214 Line No.Column: Various dates and lans. Schedule Pa e: 214 Line No.23 Column: For additional transmission ca aci ,scheduled in service date is 2005. Schedule Pa e: 214 Line No.25 Column: Various dates and plans. IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec31 2002 FOOTNOTE DATA 'Schedule Page: 219 Line No.Column: A reduction of 3,608 210 for the depreciation of the regulatory liability "1996 Depreciation Study" in account 254, is also char ed to account 403 for the ear. chedule Pa e: 219 Line No.Column: b Account 503.1 Blundell Depletion 1 120 137 Account 421 Depreciation for Future Use 231Total Other Accounts 1 123,368 'Schedule Page: 219 Une No.15 Column: Transfer of reserves related to electric plant, collection from others and miscellaneous adjustments. IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec 31,2002 FOOTNOTE DATA ISchedule Page: 227 Mining M&S General Plant M&S Line No.10 Column: $4,591 679 194.831 $4,786 510 IFERC FORM NO.(ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec 31 2002 FOOTNOTE DATA \Schedule Page: 232. 151. 407. 557 Line No.Column: ISchedule Page: 232. 151. 407. 557 Line No.Column: IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubrnission 04/30/2003 Dec 31 2002 FOOTNOTE DATA 'Schedule Page: 233 456. 456. 456. 456.266 456.177 456. 456. Line No.Column: d IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec 31 2002 FOOTNOTE DATA ISchedule Page: 234 Line 7 - Other. Line No.Column: Column: Balance at Beg. of Year 821 871 166 923 142 666 841 550) Supplemental Executive Retirement Plan (SERP) Sales of Emission Allowances Federal Income Tax Interest Sick Leave, Vacation & PT Injuries & Damages Trojan Decommissioning Other M-1 Line 4 & 5 Differences NW Power Act Noncash Pension, Bonus & Severance Utiltiy Asset Writedowns Property Tax Litigation Accrual Bonus Liability Glenrock 263A Exchange Tulana Farms Sec 174 R & E Expenditures PMI Deferred Tax Adjustments Centralia Mining Company Monsanto Contract Redding Contract Glenrock Overburden Amort Utah Rate Case Refund CAIMT Asset Writeoff University of WY Contract Total ISchedule Page: 234 Line 17 - Other: Line No. Malin Line 30 South Substation Site Writedown Nonutility Asset Writedown Centralia Mining Reclamation - NOB' Yakima Hydro Licensing Fee Trail Mountain Closing Costs Total Balance at Beg. of Year 10,064,439 (123,489) 698 524 283,210 300 132 163 673) (119 661 535) (186 983) (302 049) 755,998 122 848 249,435 999 362 295,695 283 621 203 578 643 875 922 147 447 242) 59,047 141 (110 621 ) 333 891 208 305 289 910 Balance at End of Year 10,410,415 (123,489) 784 221 728 892,303 709,926) (62 928 639) 2,414,448 (25 828 752) 272 331 (560,457) 686 183,815) 295 695 682 386 14,402 162 184 864) 713,419 447 242) 618 440 (110 621) (956 232) (10 015 239) Balance at End of Year 809 859 166 923 142 666 726 577) 101 661) 169,402) 121 808 I FERC FORM NO.1 (ED. 12-87)Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmisslon 04/30/2003 Dec 31 , 2002 FOOTNOTE DATA Oregon Public Utility Commission, Docket No. UF-4193, Order No. 02-769, dated October 30,2002. Washington Utilities and Transportation Commission, Docket No. UE-021259, dated October 23 2002. Idaho Public Utilities Comrnission, Docket No. PAC-02-4, Order No. 29144, dated October 30, 2002. IFERC FORM NO.(ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmisslon 04/30/2003 Dec 31,2002 FOOTNOTE DATA 'Schedule Page: 256.Line No.32 Column: Pollution Control Obligations Secured by Pledged First Mortgage Bonds: Issue Var. Rate Series 1994 Var. Rate Series 1994 Var. Rate Series 1994 Var. Rate Series 1994 Var. Rate Series 1994 Var. Rate Series 1994 5/8 Series Due Nov. 2021 65% Series Due Nov. 2023 5/8 Series Due Nov. 2023 Amount 655,000 260,000 190,000 121 940 000 365,000 060,000 300 000 500 000 16,400 000 Pledgee Moffat County, CO Sweetwater County, WY Converse County, WY Emery County, UT Carbon County, UT Lincoln County, WY Lincoln County, WY Emery County, UT Emery County, UT Pollution Control Obligations were issued to either finance or refinance the cost of certain pollution control facilities at steam electric plants located within the boundaries of the respective pledgees. ISchedule Page: 256.Line No.13 Column: The reconciliation of net changes to Account 223 is as follows: Beginning Advances Repayments Balance PC I 223 712 000 PC II 139 176 000 Total 362 888 000 Interest Added Ending Balance 223,712 000 139 176 000 362 888 000 ISchedule Page: 256.Line No.17 Column: Account 427 Interest on long-terrn Debt Account 430 Interest on Debt to Associated Companies Less: short-term Intercompany Interest 223 270 934 572 506 399 714 252,443 726 ISchedule Page: 256.Line No.23 Column: Long-term debt authorized but not yet issued as of December 31 , 2002 is as follows: Authorization for the issuance of $1 600,000 000 of long-term debt of which $800,000 000 remains available as of December 31, 2002 is as follows: Oregon Public Utility Commission, Docket No. UF-4167, Order No. 99-786, dated December 23 1999; amended November 13, 2001 , Order No. 01-965. Washington Utilities and Transportation Commission, Docket No. UE-991745, dated December 8, 1999. Idaho Public Utilities Commission, Docket No. PAC-01-, Order No. 28806, dated August 7 2001. Authorization for the issuance of pollution control revenue bonds ($125,000,000 authorized; $79 225,000 available as of December 31 , 2002) is as follows: IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec 31,2002 FOOTNOTE DATA Oregon Public Utility Commission, Docket No. UF-4128, Order No. 95-518, dated May 25 1995. Washington Utilities and Transportation Commission, Docket No. UE-950490, dated May 24 1995. Idaho Public Utilities Commission, Docket No. PAC-95-, Order No. 26039 dated June 13,1995. IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec 31,2002 FOOTNOTE DATA ISchedule Page: 261 Line No.10 Column: Particulars (Details) Federal Income Tax Bad Debts Allowance Utility Asset Writedown Weatherization Sick Leave, Vacation & Personal Leave Accrual Injuries & Damages Reserve NW Power Act Inventory Adjustment Trojan Decommissioning Costs Other Misc. Accruals and Debits Regulated Items Deferred For Books But Not For Return Total Deductions Recorded on Books Not Deducted for Return: Amount 566 061 929 607 630 653 734 819 13,013 223 830 490 854 891 918 585 195,644 014 249 041 225 248 729 447 'Schedule Page: 261 Line No.20 Column: Particulars (Details) Trail Mountain Closing Costs Prepaid Taxes Pension/Retirement Severance Bonus Liability Glenrock 263A Final Reclamation/Environmental Cleanup Redding Contract Total Deductions on Return Not Charged Against Book Income: 'Schedule Page: 261 Line No.28 Column: b Federal Income Tax at 35.00% 2001/2002 Federal Accrual to Return Adjustments Total Amount 716,474 312,456 982 253 996 800 035 012 022 864 031 048 550 008 114 646 915 130,624,499 (37 058,438) 93,566 061 Reconciliation: Account 570001 Federal Income Tax Exp-Utility Account 570002 Federallncorne Tax Exp-Non-Utility Total 93,566 061 93,566 061 IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec 31 , 2002 FOOTNOTE DATA 'Schedule Page: 262 Line No.Column: Fuel Tax Credit Reclass to State Other FAS 133 Taxes on Cum. Eft. of Chan e in Accl Princ. Schedule Pa e: 262 Line No.Column: I Fuel Stock, Account 151 'Schedule Page: 262 Line No.14 Column: I Other Income & Deductions, Accounts 408.2 & 409. Rents Distribution , Account 589 ISchedule Page: 262 Line No.17 Column: Reflects sales tax charged to accounts to which taxed material was charged. 'Schedule Page: 262 Line No.17 Column: I Clearing Accounts, 184 ISchedule Page: 262 Line No.18 Column: Prior eriod ad'ustment not reflected in be innin balance. Schedule Pa e: 262 Line No.22 Column: I Other Income and Deductions, Accounts 408.2 & 409. ISchedule Page: 262 Line No.27 Column: I Other Income and Deductions, Accounts 408.2 & 409. ISchedule Page: 262 Line No.31 Column: I ration & Maintenance Ex nse Schedule Pa e: 262 Line No.32 Column: Reflects sales tax char ed to accounts to which taxed material was char ed. Schedule Pa e: 262 Line No.32 Column: I Clearin Account 184 Schedule Pa e: 262 Line No.36 Column: I Other Income and Deductions Accounts 408.2 & 409. 'Schedule Page: 262 Line No.37 Column: I Amount char ed to miscellaneous taxes. Schedule Pa e: 262.Line No.Column: I Other Income and Deductions, Accounts 408.2 & 409. Distribution Rents, Account 589 ISchedule Page: 262.Line No.Column: I Operations & Maintenance Accounts ISchedule Page: 262.Line No.13 Column: Reclass 'Schedule Page: 262.Line No.15 Column: Amount is from Franchise Tax Assoc with Unbilled Revenues in error. (169 291) (10 116 684) (301 017) 135,492 796 15,279 675 (61 704) 'Schedule Page: 262.Line No.19 Column: I Other Income and Deductions, Accounts 408.2 & 409. Fuel Stock, Account 151 ISchedule Page: 262.Line No.22 Column: I Operations and Maintenance Accounts ISchedule Page: 262.Line No.23 Column: Reflects sales tax charged to accounts to which taxed material was charged. 14,400 220 562 IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec 31 2002 FOOTNOTE DATA 'Schedule Page: 262.Line No.23 Column: I Clearin Account 184 Schedule Pa e: 262.Line No.28 Column: I Other Income and Deductions Accounts, 408.2 & 409. Distribution Rents, Account 589 Schedule Pa e: 262.Line No.30 Column: I Amount charged to government charges & levies. ISchedule Page: 262.Line No.31 Column: Prior period adjustment not reflected in beginning balance. Column: I Column: I Column: I Line No.Column: I IFERC FORM NO.1 (ED. 12-87) Page 450. Name of Respondent This Report is:Date of Report Year of Report (1)~An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec 31 , 2002 FOOTNOTE DATA 'Schedule Page: 269.Line No.24 Column: Per FERC Order 627 this was reclassified to account 244 on December 6, 2002 IFERC FORM NO.1 (ED. 12-87) Page 450 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec 31 2002 FOOTNOTE DATA Schedule Page: 276 Line No.Column: a . CHANGES DURING YEAR CHANGES DURING YEAR Amounts Amounts Amounts Amounts Debited to Cred~ed to Debited to Credited to Account Account 410.Account 411.Account 410.Account 411.2 Line 8 - Other. Purchase Power Agreement Settlement 864 001)483 397 190 136 250) 211 148 Other M-1 Differences 563 182)074 722 868 960 190 (4,357 420) Henniston Breakage Fee 612,080 612 080 Special Assessment 949 652 10,994 190 102 607 FAS 106 244606)524 745 190 (13 769 351) Regulatory Assel 317 192)190 317 192) Coalpile Inventory Adjustment 554 397 142 316 125 904 190 570809 APS Abandonment 190 Weatherization/Customer Service 318 484 627 864 190 690620 Idaho Customer Balancing Account 190 Prepaid Taxes 113,789 450236 844 159 190 719 866 Trust Income & Expense (617 064)323 933 (940,997) Agnew Advance Royalty Payment 190 Hazardous Waste 361 863)530 570 655,026 190 486 319) Extraction Tax (340 892)262 549 347 (144690) Garfield Advance Royalties 83 -88 IRS Settlement 542,936)190 542 936) Glenrock Inventroy Adj Mine Road Relocation 190 Section 453 Installment Interest Amort of Pollution Control Liebility 552 366 125,433 190 426 933 R & E - Solar II Project 190 Software Write-off 382,335 547,480 190 (24 664 886) 519 741) PMI DefBlTed Tax Adjustments 967 793 967 793 CMC Inventory Adj 866 603 866,603 190 GCC DefBITed Tax Adjustments (164 336)561 962 190 726 298) Electric Mutual Insurance Receivable 190 FAS133 Derivatives (17 018 193)14,434 018 211 584 175) Flowthrough Partnership Income 058 884 056 884 (12 480 545)572,430 632 807 (28 540 922) IFERC FORM NO.1 (ED. 12-87) Page 450 Year of Report Dec. 31 2002 This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr)(2) n A Resubmission 04130/2003 t-YK ~ ! ncl'\;:'~J' ccount 456)(l;ontlnued) (Including transactions reffered to as 'wheeling as - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all nonfirm service regardless of the length of the contract and service from , designated units of less than one year. Describe the nature of the service in a footnote tor each adjustment. AD - for out-ot-period adjustment. Use this code tor any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote tor each adjustment. 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations tor all single contract path , " point to point" transmission service. In column (t), report the designation tor the substation , or other appropriate identification tor where energy was received as specified in the contract. In column (g) report the designation tor the substation , or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts ot billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. Name of Respondent PacifiCorp FERC Rate Schedule of Tariff Number (e) OV- OV- OV- OV- OV- OV- OV- OV- OV- OV- OV- 298 298 OV- Point of Receipt (Subsatation or Other Designation) (f) Point of Delivery (Substation or Other Designation) (g) Billing Demand (MW) (h) TRANSFER OF ENERGY MegaWatt Hours MegaWatt HoursReceived Delivered(i) Line No. 712 14,479 71;. 14,475 Mona Sub Mona Sub Red Butte Hot Springs 958 038 96,155 596 958 031 151 59E Malin Sub Foote Creek Sub Indian Springs Buffalo Sub 840 880,772 84C 880 77. Malin Sub Pinto Sub Pinto Sub Yellowtail Sub Indian Springs Wyodak Sub 827 183,345 183,34! FERC FORM NO.1 (ED. 12-90)Page 329. Blank Page (Next Page is: 330. ccoun(Includin transactions reffered to as 'wheeling 8. Report in column (i) and (j) the total megawatthours received and delivered. 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount ot energy transterred. In column (m), provide the total revenues trom all other charges on bills or vouchers rendered, including out ot period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11011) in column (n). Provide a tootnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. Provide total amounts in column (i) through (n) as the last Line. Enter 'TOTAL" in column (a) as the Last Line. The total amounts in columns (i) and (j) must be reported as Transmission Received and Delivered on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. Name of Respondent PacifiCorp This ~ort Is:(1) ~An Original(2) 0 A Resubmission Date of Report (Mo, Da, Yr) 04/30/2003 Demand Charges ($) (k) REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERSEnergy Charges (Other Charges) ($) ($) (I) (m) 787,823 537 607 500 542 700 313,875 107 728 26,841 541 296 526 214 800 763,546 200 45,145,047 14,873,749 296,064 FERC FORM NO.1 (ED. 12-90)Page 330. Year of Report Dec. 31 2002 Total Revenues ($) (k+l+m) (n) Ine No. 958 505 90,682 607,500 542,700 458,197 514 640 31,269 33,250 701 079 604 281 099,797 764,579 204 250 459 866 17,410 97,200 314,860 ccoun(Includin transactions referred to as 'wheeling 1. Report all transmission ot electricity, i. e., wheeling, provided for other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers. 2. Use a separate line of data tor each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column(d) enter a Statistical Classification code based on the original contractual terms and conditions ot the service as follows: LF - for Long-term firm transmission service. "Long-term" means one year or longer and "firm" means that service cannot be interrupted tor economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as , provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. SF - tor short-term firm transmission service. Use this category for all firm services, where the duration of each period of commitment for service is less than one year. Year of Report Dec. 31 2002Name of Respondent PacifiCorp Line No. Payment By (Company of Public Authority) (Footnote Affiliation) (a) Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) Statistical Classifi- cation (d) 1 Texas Utilities 2 TransAlta Energy Marketing Inc. 3 Tri-State Generation & Transmiss. Tri-State Generation & Transmiss. 5 Tri-State Generation & Transmiss. 6 Tri-State Generation & Transmiss. 7 Tri-State Generation & Transmiss. 8 Tri-State Generation & Transmiss. Bonneville Power Administration Crooked River Irrigation District United States Bureau of Reclam. Utah Associated Municip. Power 9 United States Bureau of Reclam. 10 United States Bureau of Reclam. 11 Utah Associated Municipal Power 12 Utah Municipal Power Agency 13 Utah Municipal Power Agency 14 Utah Municipal Power Agency 15 Warm Springs Power Enterprises 16 Western Area Power Administration 17 Westem Area Power Administration TOTAL FERC FORM NO.1 (ED. 12-90)Page 328. Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2) 0 A Resubmission 04/30/2003l..!!" . :::'" -: ! ' .-. "'"' Y'- ccou':lt 4~)ll;ontmued)(Including transactions reffered to as 'wheeling as - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all nonfirm service regardless ot the length of the contract and service from, designated units of less than one year. Describe the nature of the service in a tootnote tor each adjustment. AD - tor out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a tootnote for each adjustment. 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations tor all single contract path , " point to point" transmission service. In column (t), report the designation tor the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation tor the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract.Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. FERC Rate Point of Receipt Point of Delivery Billing TRANSFER OF ENERGY LineSchedule of (Subsatation or Other (Substation or Other Demand Megawatt Hours Megawatt Hours No.Tariff Number Designation)Designation)(MW)Received Delivered (e)(f) (g) (h)(i) OV-799 795 OV-919 915 OV-Various Various 654 OV-050 05C 123 Difficulty Sub 123 Riverton Sub 123 Thermopolis Sub 123 Platte Sub Franklin Sub Various 000 000 Redmond Sub Various 297 Various Various 257 692 334 692 334 Various Various OV-319 279 Various Various 412 137 412 OV- 262 Various Various 327 968,469 1 ,968 46~ 263 Utah Low Voltage Utah Low Voltage 827 183,345 183 345 FERC FORM NO.1 (ED. 12-90)Page 329. Blank Page (Next Page is: 330. Date of Report(Mo, Da, Yr) 04/3012003 ccount(Including transactions reffered to as 'wheeling 8. Report in column (i) and (j) the total megawatthours received and delivered. 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transterred. In column (m), provide the total revenues trom all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a tootnote all components ot the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). It no monetary settlement was made, enter zero (11011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. Provide total amounts in column (i) through (n) as the last Line. Enter 'TOTAL" in column (a) as the Last Line. The total amounts in columns (i) and (j) must be reported as Transmission Received and Delivered on Page 401 , Lines 16 and 17. respectively. 11. Footnote entries and provide explanations tollowing all required data. Name of Respondent PacifiCorp Demand Charges ($) (k) REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERSEnergy Charges (Other Charges) ($) ($) (I) (m) 50,873 276 446 353 256 119 700 752 061 310 45,145 047 14,873,749 296,064 FERC FORM NO.1 (ED. 12-90)Page 330. Year of Report Dec. 31 2002 Total Revenues ($) (k+l+m) (n) No. 16,352 101 218 098 64,000 904 164 328 -6,860 000 3,495 882 962 18,012 131 1,460 596 119,700 764 207 53,310 314 860 Name of Respondent PacifiCorp This ~ort Is:(1) ~An Original (2) A Resubmission Year of Report Dec. 31 2002 ccoun (Including transactions referred to as 'wheeling 1. Report all transmission of electricity, i. e., wheeling, provided for other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers. 2. Use a separate line ot data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received trom and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column(d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as tollows: LF - for Long-term firm transmission service. "Long-term" means one year or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as , provide in a tootnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out ot the contract. SF - for short-term firm transmission service. Use this category for all firm services, where the duration of each period of commitment for service is less than one year. Line No. Payment By (Company of Public Authority) (Footnote Affiliation) (a) 1 Western Area Power Administration Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) Statistical Classifi- cation (d) 2 Westem Area Power Administration 3 Westem Area Power Administration 4 Westem Area Power Administration Westem Area Power Admin. Westem Area Power Admin. Westem Area Power Admin. Western Area Power Admin. 5 Westem Area Power Administration 6 Western Area Power Administration 7 Westem Area Power Administration 8 Williams Energy Market & Trad. Co. TOTAL FERC FORM NO.1 (ED. 12-90)Page 328. Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002(2) n A Resubmission 04130/2003. 1=1 t-YK "1 ~. ,~, ~~J' ccount 456)(Continued) (Including transactions reffered to as 'wheeling as - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all nonfirm service regardless of the length of the contract and service trom , designated units of less than one year. Describe the nature of . the service in a footnote tor each adjustment. AD - tor out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" tor service provided in prior reporting years. Provide an explanation in a tootnote for each adjustment. 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations tor all single contract path , " point to point" transmission service. In column (t), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation , or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number ot megawatts ot billing demand that is specified in the firm transmission service contract.Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. FERC Rate Point of Receipt Point of Delivery Billing TRANSFER OF ENERGY Line Schedule of (Subsatation or Other (Substation or Other Demand MegaWatt Hours MegaWatt Hours No. Tariff Number Designation)Designation)(MW)Received Delivered (e)(f)(9)(h)(i) 286 Various Various 31,452 45. OV-Yellowtail Sub Dave Johnston Sub OV-Various Various OV-Wyoming Distribut.Wyoming Distribut.42,872 87. OV-Various Various 980 98( 331 Casper Sub 330 Thermopolis Sub OV-Various Various 260 26C 827 183,345 183,34! FERC FORM NO.1 (ED. 12-90)Page 329. Blank Page (Next Page is: 330. Name of Respondent PacifiCorp This ~ort Is:(1) ~An Original (2) A Resubmission Year of Report Dec. 31 2002 Date of Report (Mo, Da, Yr) 04/30/2003 ccount(Includin transactions reffered to as 'wheeling 8. Report in column (i) and (j) the total megawatthours received and delivered. 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components ot the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). It no monetary settlement was made, enter zero (11011) in column (n). Provide a tootnote explaining the nature ot the non-monetary settlement, including the amount and type of energy or service rendered. 10. Provide total amounts in column (i) through (n) as the last Line. Enter TOTAL" in column (a) as the Last Line. The total amounts in columns (i) and (j) must be reported as Transmission Received and Delivered on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. Demand Charges ($) (k) REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERSEnergy Charges (Other Charges) ($) ($) (I) (m) 452 45,145,047 873 749 296,064 Total Revenues ($)Ine (k+l+m)No. (n) 452 215,000 646 33,413 628 164 1,460 67,314 860 215 50,646 638 1 ,460 FERC FORM NO.1 (ED. 12-90)Page 330. Name of Respondent PacifiCorp This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/30/2003 TRANS ISSION OF ELECTRICITY BY OTHE S (Account 565) (Including transactions referred to as "wheeling 1. Report all transmission, Le., wheeling ot electricity provided to respondent by other electric utilities, cooperatives, municipalities, orother public authorities during the year. 2. In column (a) report each company or public authority that provide transmission service. Provide the full name of the company; abbreviate it necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. 3. Provide in column (a) subheadings and classify transmission service purchased form other utilities as: "Delivered Power to Wheeler" or "Received Power trom Wheeler. 4. Report in columns (b) and (c) the total Megawatthours received and delivered by the provider of the transmission service. 5. In columns (d) through (g), report expenses as shown on bills or vouchers rendered to the respondent. In column (d), provide demand charges. In column (e), provide energy charges related to the amount ot energy transferred. In column (t), provide the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (t). Report in column (9) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero \,0") column (g). Provide a footnote explaining the nature ot the non-monetary settlement, including the amount and type ot energy or service rendered. 6. Enter "TOTAL" in column (a) as the last Line. Provide a total amount in columns (b) through (g) as the last Line. Energy provided by the respondent for the wheeler's transmission tosses should be reported on the Electric Energy Account, Page 401. If the respondent received power from the wheeler, energy provided to account for Losses should be reported on Line 19. Transmission By Others Losses, on Page 401. Otherwise, Losses should be reported on line 27, Total Energy Losses, Page 401. 7. Footnote entries and provide explanations following all required data. Line Name of Company or Public No. Authority (Footnote Affiliations) (a) 1 Arizona Public Service Avista Corporation Big Horn Rurl Elec Coop Blanding City Bonneville Power Admin California ISO Flowell Electric Assoc. Hermiston Gen Co, loP. Idaho Power Company 10 Los Angeles Dept of W&P 11 Mid Area Cont. Pwr Pool 12 Montana Power Company 13 Moon Lake Elec. Assoc. 14 Navajo Tribal Utility 15 Nevada Power Company 16 Portland General Elec. TOTAL FERC FORM NO.1 (ED. 12-90) EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERSeman nergy Total Cost of~?eS Chri?es TranshWssion(d) (e) 19~ 072 000 988 275 3,183 742 247 752 171 896 419,648 36,195 12,312 46,541 932 901 710 300 144,458 Yearof Report Dec. 31, 2002 052 052 440,962 3,469,954 420,722 420,722 208 208 609,087 678,652 449,779 449 779 83,193 88,752 730 505 312 637 779 702 811 200 76,376 167,477 167,477 558,985 560,192 026,387 160 58,920,073 12,357 669 671 711 Page 332 105,257 895,241 18,917 035 169 75,422 473 397 144 143 453 949.453 Name of Respondent PacifiCorp Year of Report Dec. 31 2002 This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/30/2003 TRANS ISSION OF ELECTRICITY BY OTHE S (Account 565) (Including transactions referred to as "wheeling 1. Report all transmission, Le., wheeling ot electricity provided to respondent by other electric utilities, cooperatives, municipalities, or other public authorities during the year. 2. In column (a) report each company or public authority that provide transmission service. Provide the full name of the company; abbreviate it necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. 3. Provide in column (a) subheadings and classify transmission service purchased form other utilities as: "Delivered Power to Wheeler" or "Received Power trom Wheeler. 4. Report in columns (b) and (c) the total Megawatthours received and delivered by the provider of the transmission service. 5. In columns (d) through (g), report expenses as shown on bills or vouchers rendered to the respondent. In column (d), provide demand charges. In column (e), provide energy charges related to the amount of energy transterred. In column (f), provide the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components ot the amount shown in column (t). Report in column (9) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero column (g). Provide a footnote explaining the nature ot the non-monetary settlement including the amount and type ot energy or service rendered. 6. Enter "TOTAL" in column (a) as the last Line. Provide a total amount in columns (b) through (g) as the last Line. Energy provided by the respondent for the wheeler's transmission tosses should be reported on the Electric Energy Account , Page 401. If the respondent received power from the wheeler, energy provided to account for Losses should be reported on Line 19. Transmission By Others Losses, on Page 401. Otherwise, Losses should be reported on line 27 , Total Energy Losses, Page 401. 7. Footnote entries and provide explanations following all required data. EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERSnergy er Total Cost of rSres ChrSres Trans;;rission00 769 730 350 336,651 16,017 Line Name of Company or Public No. Authority (Footnote Affiliations) (a) Public Ser.Co.Colorado 769,730 Seattle City Light Sierra Pacific Power Co 16,350 269,360 16,017 310,400 328 304 829,210 728 549 596 804 43,173 2884 Snohomish PUD 5 S. California Edison Co 48,321 Springfield Utility Surprise Valley Elec. 8 Tri State G&T 9 Westem Area Power 351 090 285 363,465 285 10 Accrual Adjustment TOTAL 12,357,669 671 711026,387 160 920 073 FERC FORM NO.1 (ED. 12-90)Page 332. 769 002 328 304 762 876 613 017 836 103,185 76,949 453 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr) Dec. 31 2002(2) Fi A Resubmission 04/30/2003 MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC) Line Descri ftion AmountNo.(b) Industry Association Dues 092 346 . Nuclear Power Research Expenses Other Experimental and General Research Expenses Pub & Dist Info to Stkhldrs...expn servicing outstanding Securities 470,101 Oth Expn ~=5,000 show purpose, recipient, amount. Group if ..:: $5,000 Bank Charges & Fees Bank of New York 25,972 Bank One 952 US Bank 510,413 Wachovia Bank 220,885 Wells Fargo Bank 95,612 Other 137 Community & Economic Development CCD Business Development Corp.000 Eastem Idaho Economic Development Council 000 Oregon Economic Association 000 Rural Development Initiatives Inc.000 State of Utah Challenge Grant 10,000 Wayne Brown Institute 000 Utah Center for Rural Life 500 Other 190 Corporate Memberships & Subscriptions American Legislative Exchange 000 Arlington Club 180 Association of Edison Illuminating Co.954 Business for Social Responsibility 10,000 Casper Area Development Alliance 000 Davis Chamber of Commerce 000 DSTAR 000 Economic Development for Central Oregon 000 Laramie Economic Development Corp.000 North American Energy 000 Northwest Power Quality Service 10,000 OgdenlWeber Chamber of Commerce 000 Portland Ambassadors 000 Portland Oregon Sports 000 Redmond Economic Development 000 Salt Lake Area Chamber of Commerce 691 UMA 2002 Dues 928 United Telecom Council 580 USWAG 2001 Dues 919 Utah Foundation 22,500 TOTAL 52,410,216 FERC FORM NO.1 (ED. 12-94)Page 335 Name of Respondent I This ~ort Is:Date of Rep'ort Year of Report PacifiCorp (1) An Original (Mo, Da, Yr) Dec. 31 2002(2) Fi A Resubmission 04/30/2003 MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC) Line DeSCri)tion Amount No.(b) Corporate Memberships & Subscriptions - Continued Utah Hispanic Chamber of Commerce 5,000 Utah Manufactures Association 18,578 Utah Taxpayers Association 20,000 Westem Power Trading Forum 000 Wyoming Taxpayers Association 121 Yakima County Development 000 Other 146,696 Directors Fees 324 638 General 1997 Software Write Off - Utah 514 363 1999 Software Write Off - Utah 367 023 BSIP/SAP Re-Engineering 1998 205,197 BSIP/SAP Re-Engineering 1999 056,144 BSIP/SAP Re-Engineering 2000 573 Computer Mainframe Writedown UT Amortization 843,274 Early Retirement UT Amortization 683 020 ENTRIX Inc.317 Glenrock Mine Reclamation UT Amortization 300 787 Glenrock Mine UT 1998 Case (Excl. Reclamation)152,774 Glenrock Mine UT Stipulation (Excl. Reclamation)149,625 McCune Mansion 837 Nature Conservancy 121 501 Transition Plan Reg. Asset Amortization 25,256,460 Transition Team Costs - UT 485,905 UT Amortization - Deferred Pension Reg. Asset 159 014 Write Off Yakama Hydro Licensing Costs 726 751 Y2K Expense UT Amortization 735 Y2K Expense OR Amortization 268,659 Service Management V1 Write Off 738 974 David Eccles School of Business 000 PD - Crew & Resource Management (CRM) Reclass 236 452 Other 337 062 TOTAL 52,410 216 FERC FORM NO.1 (ED. 12-94)Page 335. Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04/30/2003 DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Account 403 404 405) (Except amortization of aquisition adjustments) 1. Report in Section A for the year the amounts for: (a) Depreciation Expense (Account 403); (b) Amortization of Limited-Term Electric Plant (Account 404); and (c) Amortization ot Other Electric Plant (Account 405). 2. Report in Section 8 the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year. 3. Report all available intormation called for in Section C every fifth year beginning with report year 1971 , reporting annually only changes to columns (c) through (g) from the complete report of the preceding year. Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type ot plant included in any sub-account used. In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances state the method of averaging used. For columns (c), (d), and (e) report available intormation tor each plant subaccount, account or tunctional classification Listed in column (a). It plant mortality studies are prepared to assist in estimating average service Lives, show in column (t) the type mortality curve selected as most appropriate for the account and in column (g), it available, the weighted average remaining life of surviving plant. It composite depreciation accounting is used, report available information called for in Columns (b) through (g) on this basIs. 4. It provisions tor depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom ot section C the amounts and nature of the provisions and the plant items to which related. A. Summary of Depreciation and Amortization Charges ILlne Functional Classification ~reCiation . f-mOl1lZation Q!mOI1lZ'll.tIOn or TotalNo.xpense Limited Term Elec-Other Electric(Account 403)tric Plant (Acc 404)Plant (Acc 405)(a)(b)(c)(d)(e) 1 Intangible Plant 44,071 040 758 797 829 837 2 Steam Production Plant 120 512 919 120,512 919 Nuclear Production Plant Hydraulic Production Plant-Conventional 875 034 259 12,903,293 Hydraulic Production Plant-Pumped Storage Other Production Plant 976,662 976 662 7 Transmission Plant 459,259 45,459,259 Distribution Plant 141 769 652 141 769 652 General Plant 864 397 931 301 795,698 Common Plant-Electric TOTAL 368,457 923 46,030,600 758,797 416,247 320 B. Basis for Amortization Charges The amortization of limited-Term Electric Plant is based on straight-line amortization over the life of the asset. The amortization of Other Electric Plant consists of costs associated with the merger of PacifiCorp and Utah Power & Light Company. Amortization is straight-line over a 15 year period. FERC FORM NO.1 (ED. 12-88)Page 336 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) riA Resubmission 04/30/2003 DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued) C. Factors Used in Estimating Depreciation Charges Line uepreCiacle I::stlmateo Net Appflecr lIIIOffality Average No.Account No.Plant Base Avg. Service Salvage Depr. rates Curve Remaining (In Th~~~andS) 7~~ (per~nt)(PeJ~nt)r~e Life (a)(0) FERC FORM NO.1 (ED. 12-95)Page 337 Name of Respondent This ~rt Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) FiA Resubmission 04130/2003 REGULATORY COMMISSION EXPEN ES 1. Report particulars (details) ot regulatory commission expenses incurred during the current year (or incurred in previous years, if being amortized) relating to format cases before a regulatory body, or cases in which such a body was a party. 2. Report in columns (b) and (c), only the current year's expenses that are not deferred and the current year's amortization ot amounts deferred in previous years. Line Description Assessed by Expenses Total . u~ferred No.(Fumish name of regulatory commission or body the Regulatory Expense for In Account Commission Current Year 18;2.docket or case number and a description of the case)Utility (b) + (c)Beginning 0 Year (a)(b)(c)(d)(e) Before the Public Service Commission of Utah: Annual Fee 883,951 883,951 Other State Regulatory Expenses 151 670 151 670 Before the Idaho Public Utilities Commission: Annual Fee 222 774 222 774 Other State Regulatory Expenses 40,703 703 Before the Public Service Commission of Wyoming: Annual Fee 440,024 440,024 Other State Regulatory Expenses 352 194 352,194 Before the Public Utilities Commission of California: Annual Fee 49,819 819 Other State Regulatory Expenses 23,981 981 Before the Public Utility Commission of Oregon: Annual Fee 243,875 243 875 Other State Regulatory Expenses 404 109 404 109 Before the Washington Utilities and Transportation Commission: Annual Fee 260,227 260 227 Other State Regulatory Expenses 383 383 Before the Federal Energy Regulatory Commission: Annual Fee 815 648 815,648 Other State Regulatory Expenses, Montana 850 850 TOTAL 916,318 008,890 925,208 FERC FORM NO.1 (ED. 12-96)Page 350 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 REGULATORY COMMISSION EXPENSES (Continued) 3. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization. 4. List in column (f), (g), and (h) expenses incurred during year which were charged currently to income, plant, or other accounts. 5. Minor items (less than $25 000) may be grouped. EXPENSES INCURRED DURING YEAR AMORTIZED DURING YEAR CURRENTLY CHARGED TO Deferred to Contra Amount Deferred in LineDepartmentCWoumAmountAccount 182.Account Account 182.No.End of Year (f) (g) (h)(i)(k)(I) Electric 928 883 951 Electric 928 151 670 Electric 928 222 774 Electric 928 40,703 Electric 928 440 024 Electric 928 352,194 Electric 928 49,819 Electric 928 981 Electric 928 243 875 Electric 928 404 109 Electric 928 260 227 Electric 928 33,383 Electric 928 815,648 Electric 928 850 925,208 FERC FORM NO.1 (ED. 12-96)Page 351 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31,2002 (2) Ei A Resubmission 04/30/2003 RESEARCH, DEVELOPMENT, AND DEMONS RATION ACTIVITIES 1. Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D & D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(ldentify recipient regardless of affiliation.) For any R, D & D work carried with others, show separately the respondent's cost for the year and cost chargeable to others (See definition of research, development, and demonstration in Uniform System of Accounts). 2. Indicate in column (a) the applicable classification, as shown below: Classifications: A. Electric R, D & D Performed Intemally:(3) Transmission (1) Generation a. Overhead a. hydroelectric b. Underground i. Recreation fish and wildlife (4) Distribution ii Other hydroelectric (5) Environment (other than equipment) b. Fossil-fuel steam (6) Other (Classify and include items in excess of $5,000. c. Intemal combustion or gas turbine (7) Total Cost Incurred d. Nuclear B. Electric, R, D & D Performed Extemally: e. Unconventional generation (1) Research Support to the electrical Research Councilor the Electric f. Siting and heat rejection Power Research Institute Line Classification Description No.(a)(b) A. Electric R, D & D performed internally (1) Generation b. Fossil-fuel steam Hunter Farm - Evapotranspiration Study Hunter Farm - Soil Conservation Study Huntington Farm - Evapotranspiration Study Huntington Farm - Soil Conservation Study (7) Total Cost Incurred B. Electric R, D & D performed extemally NONE FERC FORM NO.1 (ED. 12-87)Page 352 Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04130/2003 RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES (Continued) (2) Research Support to Edison Electric Institute (3) Research Support to Nuclear Power Groups (4) Research Support to Others (Classify) (5) Total Cost Incurred 3. Include in column (c) all R, D & D items performed intemally and in column (d) those items performed outside the company costing $5,000 or more, briefly describing the specific area of R, D & D (such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc. Group items under $5 000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D & D activity. 4. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e) 5. Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research Development, and Demonstration Expenditures, Outstanding at the end of the year. 6. If costs have not been segregated for R, D &D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by Est." 7. Report separately research and related testing facilities operated by the respondent. Costs Incurred Internally Costs Incurred Externally AMOUNTS CHARGED IN CURRENT YEAR Unamortized LineCurre fc~ Year Current Year Account Amount Accumulation No. (d)(e)(f) (g) 558 506 16,558 16,245 506 16,245 32,141 506 32,141 533 506 31,533 477 96,477 FERC FORM NO.1 (ED. 12-87)Page 353 Name of Respondent PacifiCorp Year of Report Dec. 31, 2002 This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/30/2003 DISTRIBUTION OF SALARIES AND WAGES Report below the distribution ot total salaries and wage~ tor the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used. (a) Direct Payroll Distribution (b) TotalLine No. Classification Electric Operation Production Transmission Distribution Customer Accounts 7 Customer Service and Informational Sales Administrative and General 10 TOTAL Operation (Enter Total of lines 3 thru 9) 11 Maintenance 12 Production 13 Transmission 14 Distribution 15 Administrative and General 16 TOTAL Maint. (Total oflines 12 thru 15) 17 Total Operation and Maintenance 18 Production (Enter Total oflines 3 and 12) 19 Transmission (Enter Total of lines 4 and 13) 20 Distribution (Enter Total of lines 5 and 14) 21 Customer Accounts (Transcribe from line 6) 22 Customer Service and Informational (Transcribe from line 7) 23 Sales (Transcribe from line 8) 24 Administrative and General (Enter Total of lines 9 and 15) 25 TOTAL Oper. and Maint. (Total of lines 18 thru 24) 26 Gas 27 Operation 28 Production-Manufactured Gas 29 Production-Nat. Gas (Including Expl. and Dev. 30 Other Gas Supply 31 Storage, LNG Terminaling and Processing 32 Transmission 33 Distribution 34 Customer Accounts 35 Customer Service and Informational 36 Sales 37 Administrative and General 38 TOTAL Operation (Enter Total of lines 28 thru 37) 39 Maintenance 40 Production-Manufactured Gas 41 Production-Natural Gas 42 Other Gas Supply 43 Storage, LNG Terminaling and Processing 44 Transmission 45 Distribution 46 Administrative and General 47 TOTAL Maint. (Enter Total of lines 40 thru 46) 299,199 106,644 960 732 603 724 041 403 138,372 79,091 156 212 241 230 113,412 705 10,196 421 193,119 603,724 041,403 138,372 729 430 303 315 174 FERC FORM NO.1 (ED. 12-88)Page 354 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04/30/2003 DIST~IBUTION OF SALARIES AND WAGES (Continued) Line Classification Direct Payroll . Allpcatlon of TotalDistributionPayroll charged for No.Clearin~ Accounts (a)(b)(d) Total Operation and Maintenance Production-Manufactured Gas (Enter Total of lines 28 and 40) Production-Natural Gas (Including Expl. and Dev.) (Total lines 29, Other Gas Supply (Enter Total of lines 30 and 42) Storage, LNG Terminaling and Processing (Total of lines 31 thru Transmission (Lines 32 and 44) Distribution (Lines 33 and 45) Customer Accounts (Line 34) Customer Service and Informational (Line 35) Sales (Line 36) Administrative and General (Lines 37 and 46) TOTAL Operation and Maint. (Total of lines 49 thru 58) Other Utility Departments Operation and Maintenance TOTAL All Utility Dept. (Total of lines 25, 59, and 61)303,315 174 303,315 174 Utility Plant Construction (By Utility Departments) Electric Plant 117,925 959 117,925,959 Gas Plant Other (provide details in footnote): TOTAL Construction (Total of lines 65 thru 67)117 925,959 117 925,959 Plant Removal (By Utility Departments) Electric Plant Gas Plant Other (provide details in footnote): TOTAL Plant Removal (Total of lines 70 thru 72) Other Accounts (Specify, provide details in footnote): Fuel Stock 505,180 26,505 180 Misc. Income Deduction 961 053 961 053 Misc. Nonoperating/Nonutility 629,271 629 271 TOTAL Other Accounts 095,504 29,095 504 TOTAL SALARIES AND WAGES 450,336 637 450,336,637 FERC FORM NO.1 (ED. 12-88)Page 355 Name of Respondent PacifiCorp This ~ort Is:(1) ~An Original (2) A Resubmission ELECTRIC ENERGY ACCOU Date of Report (Mo, Da, Yr) 04130/2003 Year of Report Dec. 31 2002 Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year. Line No. Item (a) 1 SOURCES OF ENERGY 2 Generation (Excluding Station Use): 3 Steam 4 Nuclear 5 Hydro-Conventional 6 Hydro-Pumped Storage 7 Other 8 Less Energy for Pumping 9 Net Generation (Enter Total of lines 3 through 8) 10 Purchases 11 Power Exchanges: 12 Received 13 Delivered 14 Net Exchanges (Line 12 minus line 13) 15 Transmission For Other (Wheeling) 16 Received 17 Delivered 18 Net Transmission for Other (Line 16 minus line 17) 19 Transmission By Others Losses 20 TOTAL (Enter Total of lines 9 10, and 19) FERC FORM NO.1 (ED. 12-90) MegaWatt Hours (b) Page 401a Line No. Item (a) 21 DISPOSITION OF ENERGY 22 Sales to Ultimate Consumers (Including Interdepartmental Sales) 23 Requirements Sales for Resale (See instruction 4, page 311. 24 Non-Requirements Sales for Resale (See instruction 4, page 311. 25 Energy Fumished Without Charge 26 Energy Used by the Company (Electric Dept Only, Excluding Station Use) 27 Total Energy Losses 28 TOTAL (Enter Total of Lines 22 Through 27) (MUST EQUAL LINE 20) MegaWatt Hours (b) 029,924 198 901 30,334,565 102 901 275,859 81,942,150 Name of Respondent PacifiCorp This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr)(2) 0 A Resubmission 04/30/2003 MONTHLY PEAKS AND OUTPUT 1. If the respondent has two or more power systems which are not physically integrated, fumish the required information for each non-integrated system. 2. Report in column (b) the system s energy output for each month such that the total on Line 41 matches the total on Line 20. 3. Report in column (c) a monthly breakdown of the Non-Requirements Sales For Resale reported on Line 24. include in the monthly amounts any energy losses associated with the sales so that the total on Line 41 exceeds the amount on Line 24 by the amount of losses incurred (or estimated) in making the Non-Requirements Sales for Resale. 4. Report in column (d) the system s monthly maximum megawatt Load (60-minute integration) associated with the net energy for the system defined as the difference between columns (b) and (c) 5. Report in columns (e) and (f) the specified information for each monthly peak load reported in column (d). Year of Report Dec. 31 2002 NAME OF SYSTEM:PacifiCorp line Monthly Non-Requirments MONTHLY PEAKSales for Resale &No.Month Total Monthly Energy Associated Losses Megawatts (See Instr. 4)Day of Month Hour (a)(b)(c)(d)(e)(f) 29 January 678,584 038,188 7,459 0800 PST 30 February 983 058 885,698 396 0800 PST 31 March 059,284 785,139 134 0800 PST 32 April 8,405,537 521,426 6,494 0900 PST 33 May 218,851 199.496 203 1600 PDT 34 June 490,671 212 375 035 1500 PDT 35 July 559,908 716,481 549 1600 PDT 36 August 002 639 425,648 967 1600 PDT 37 September 357 084 318,061 362 1600 PDT 38 October 309,088 208 895 295 0800 PST 39 November 201 162 945,601 227 0800 PST 40 December 676 284 077,557 613 1800 PST TOTAL 942 150 30,334 565 FERC FORM NO.1 (ED. 12-90)Page 401b Name of Respondent This ~rt Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2)0 A Resubmission 04/3012003 Dec. 31 STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants) 1. Report data for plant in Service only.2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and intemal combustion plants of 10,000 Kw or more, and nuclear plants.3. Indicate by a footnote any plant leased or operated as a joint facility.4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel bumed converted to Mct.7. Quantities of fuel burned (Line 37) and average cost per unit offuel burned (line 40) must be consistent with charges to expense accounts 501 and 547 (Line 41) as show on Line 19.8. If more than one fuel is bumed in a plant fumish only the composite heat rate for all fuels bumed. Line Item Plant No.Name: Carbon Name: (a)(b) Kind of Plant (Intemal Comb, Gas Turb, Nuclear Steam Steam Type of Constr (Conventional , Outdoor, Boiler, etc)Outdoor Boiler Full Outdoor Year Originally Constructed 1954 1981 Year Last Unit was Installed 1957 1981 Total Installed Cap (Max Gen Name Plate Ratings-MW)188.414. Net Peak Demand on Plant - MW (60 minutes)177 382 Plant Hours Connected to Load 8653 7887 Net Continuous Plant Capability (Megawatts) When Not Limited by Condenser Water 175 380 When Limited by Condenser Water Average Number of Employees Net Generation, Exclusive of Plant Use - KWh 1323395000 2533121000 Cost of Plant: Land and Land Rights 956546 1178241 Structures and Improvements 10867218 45215540 Equipment Costs 66860399 312724395 Total Cost 78684163 359118176 , 17 Cost per KW of Installed Capacity (line 5)417.2013 867.4352 Production Expenses: Oper, Supv, & Engr 139579 1199395 Fuel 11200680 33804544 Coolants and Water (Nuclear Plants Only) Steam Expenses 706274 2312670 Steam From Other Sources Steam Transferred (Cr) Electric Expenses 1332017 851123 Misc Steam (or Nuclear) Power Expenses 4058652 1840294 Rents 13057 202364 Allowances Maintenance Supervision and Engineering 2107244 Maintenance of Structures 142478 537925 Maintenance of Boiler (or reactor) Plant 2592516 4092974 Maintenance of Electric Plant 871343 362359 Maintenance of Misc Steam (or Nuclear) Plant 408147 1493069 Total Production Expenses 21464743 48399233 Expenses per Net KWh 0162 0191 Fuel: Kind (Coal, Gas , Oil, or Nuclear)Coal Oil Coal Oil Unit (Coa I-ton s/Oi I-ba rrel/Gas-mcf/N uclear -indicate)Tons Barrel Tons Barrel Quantity (units) of Fuel Burned 606830 2688 1372197 7211 Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)12264 140000 9757 140131 Avg Cost of Fuel/unit, as Delvd f.b. during year 18.087 35.472 000 23.217 33.734 000 Average Cost of Fuel per Unit Bumed 18.301 35.472 000 24.459 33.734 000 Average Cost of Fuel Burned per Million BTU 746 033 000 253 686 0.000 Average Cost of Fuel Burned per KWh Net Gen 008 000 000 013 000 000 Average BTU per KWh Net Generation 11259,053 000 000 10587.530 000 000 FERC FORM NO.1 (ED. 12-95)Page 402 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2)0 A Resubmission 04/30/2003 Dec. 31 STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)(Continued) 9. Items under Cost of Plant are based on U. S. of A. Accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.10. For IC and GT plants, report Operating Expenses, Account Nos. ;47 and 549 on Line 24 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 31, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, intemal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data conceming plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant.~p~m LineName: Name: Name:Dave Johnston No. (f) Steam Steam Steam Conventional Outdoor Boiler Semi-Outdoor 1984 1979 1959 1986 1980 1972 155.172.816. 158 165 762 8622 8758 8760 144 165 762 208 283 219 984315000 1366706000 5759784000 1291268 137086 10417291 55203726 35132156 47257355 147470917 116284469 329026863 203965911 151553711 386701509 1310.7507 880.4608 473.4927 37419 227799 183357 6504548 13311369 42488522 279842 863016 229613 34629 388468 3318 1682778 1777662 11872454 30680 4812 11192 113116 349336 200632 407814 1654314 1380297 1571534 8319726 383750 405912 2474524 181187 348873 1017498 10828878 19656595 68254518 0110 0144 0119 Coal Oil Coal Oil Coal Oil Coal Barrels Coal Barrels Coal Barrels 614942 3575 694806 659 3845637 9577 8513 141000 10094 122360 8299 140000 10.290 33.734 000 18.337 32.884 000 10.508 32.884 000 10.381 33.734 000 19.126 32.884 000 10.967 32.884 000 610 696 000 947 731 000 661 593 000 007 000 000 010 000 000 007 000 000 10658.349 000 000 10265.151 000 000 11092.224 000 000 FERC FORM NO.1 (ED. 12-88)Page 403 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2)0 A Resubmission 04130/2003 Dec. 31 STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued) 1. Report data for plant in Service only.2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants.3. Indicate by a footnote any plant leased or operated as a joint facility.4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.6. If gas is used and purchased on a thenn basis report the Btu content or the gas and the quantity of fuel bumed converted to Mct.7. Quantities of fuel bumed (Line 37) and average cost per unit of fuel burned (Line 40) must be consistent with charges to expense accounts 501 and 547 (Line 41) as show on Line 19.8. If more than one fuel is bumed in a plant furnish only the composite heat rate for all fuels bumed. Line Item Plant Plant "~,,v.'"'~F No.Name:Name' f:J_~' '" . ,"' . ",'N.". ;$M' . , ''" (a) ,...- ' (c . ,. Kind of Plant (Intemal Comb, Gas Turb, Nuclear Steam Steam Type of Constr (Conventional, Outdoor, Boiler, etc)Outdoor Boiler Outdoor Boiler Year Originally Constructed 1965 1978 Year Last Unit was Installed 1976 1978 Total Installed Cap (Max Gen Name Plate Ratings-MW)81.472. Net Peak Demand on Plant - MW (60 minutes)405 Plant Hours Connected to Load 8760 8031 Net Continuous Plant Capability (Megawatts) When Not Limited by Condenser Water 430 When Limited by Condenser Water Average Number of Employees 105 Net Generation, Exclusive of Plant Use - KWh 645723000 3027001000 Cost of Plant: Land and Land Rights 167098 9646568 Structures and Improvements 5185907 60088408 Equipment Costs 59557158 211074253 Total Cost 64910163 280809229 Cost per tQN of Installed Capacity (line 5)798.8943 594.3052 Production Expenses: Oper, Supv, & Engr 263544 43515 Fuel 7515454 24156475 Coolants and Water (Nuclear Plants Only) Steam Expenses 532742 2629979 Steam From Other Sources Steam Transferred (Cr) Electric Expenses 164358 128836 Misc Steam (or Nuclear) Power Expenses 794399 2682630 Rents 39846 Allowances Maintenance Supervision and Engineering 225464 Maintenance of Structures 146545 1642851 Maintenance of Boiler (or reactor) Plant 327312 3352108 Maintenance of Electric Plant 4971 504409 Maintenance of Misc Steam (or Nuclear) Plant 143255 204698 Total Production Expenses 10118044 35385347 Expenses per Net KWh 0157 0117 Fuel: Kind (Coal, Gas, Oil, or Nuclear)Coal Oil Coal Oil Unit (Coal-tons/Oil-barrel/Gas-mcf/Nuclear-indicate)Tons Barrels Tons Barrels Quantity (units) of Fuel Burned 321612 517 1372925 4797 Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)10348 132599 11521 140000 Avg Cost of Fuel/unit, as Delvd f.b. during year 22.286 31.197 000 16.360 34.656 000 Average Cost of Fuel per Unit Burned 23.318 31.197 000 17.471 34.656 000 Average Cost of Fuel Burned per Million BTU 127 601 000 758 024 000 Average Cost of Fuel Burned per tQNh Net Gen 012 000 000 008 000 000 Average BTU per tQNh Net Generation 10312.410 000 000 10460.238 000 000 FERC FORM NO.1 (ED. 12-95)Page 402. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2)0 A Resubmission 04/30/2003 Dec. 31, STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)(Continued) 9. Items under Cost of Plant are based on U. S. of A. Accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 24 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 31 , " Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, intemal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data conceming plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant. Plant Plant Plant Line)y1l1lllfl8"-~'t" "'" Hunter Unit No.~ti1~SMName: fI&~ . " ~.&i', ~v ., i)J!j,9: Name:Name: ~8W.~ik.0 ~:"-' ::' 0". ::tt No.(e) Steam Steam Steam Outdoor Boiler Outdoor Boiler Outdoor Boiler 1980 1983 1978 1980 1983 1983 472.495.1440. 265 461 1311 6782 8099 8760 430 460 1320 231 1670598000 3418272000 8115871000 9646568 10253198 29546333 49284908 88364297 197737614 146286297 373875813 731236363 205217773 472493308 958520310 434.3233 953.5687 665.4081 43515 43515 130544 12434824 26072894 62664192 1710565 2909275 7249819 131012 131012 390860 2620553 2693949 2756026 38877 50855 129577 1844648 1619656 5107155 7091977 4790420 15234505 1946806 731845 3183060 110003 143488 458189 22731674 39186909 97303927 0136 0115 0120 Coal Oil Coal Oil Coal Oil Tons Barrel Tons Barrel Tons Barrels 745564 2139 1593913 9019 3712402 15956 11504 140000 11490 140000 11505 140000 16.360 34.656 000 16.360 34.656 0.000 16.360 34.656 000 16.583 34.656 000 16.162 34.656 0.000 16.731 34.656 000 721 640 000 703 885 000 727 894 000 007 000 000 008 000 000 008 000 000 10275.668 000 000 10730.908 000 000 10536.529 000 000 FERC FORM NO.1 (ED. 12-88)Page 403. Name of Respondent This (!Jort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2) 0 A Resubmission 04130/2003 Dec. 31 STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued) 1. Report data for plant in Service only.2. Large plants are steam plants with installed capacity (name plate rating) of 25 000 Kw or more. Report in this page gas-turbine and intemal combustion plants of 10,000 Kw or more, and nuclear plants.3. Indicate by a footnote any plant leased or operated as a joint facility.4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel bumed converted to Mct.7. Quantities of fuel bumed (Line 37) and average cost per unit of fuel burned (Line 40) must be consistent with charges to expense accounts 501 and 547 (Line 41) as show on Line 19.8. If more than one fuel is bumed in a plant fumish only the composite heat rate for all fuels burned. Line Item Plant Plant No.Name: Huntington Name: .~..- (a)(b) "',"~ JM.b" " ~rf. ~ ." ". . I.' 1 Kind of Plant (Internal Comb, Gas Turb, Nuclear Steam Steam Type of Constr (Conventional, Outdoor, Boiler, etc)Outdoor Boiler Semi-Outdoor Year Originally Constructed 1974 1974 Year Last Unit was Installed 1977 1979 Total Installed Cap (Max Gen Name Plate Ratings-MW)996.2311. Net Peak Demand on Plant - MW (60 minutes)896 1404 Plant Hours Connected to Load 8510 8760 8 Net Continuous Plant Capability (Megawatts) 9 When Not limited by Condenser Water 895 2120 When Limited by Condenser Water Average Number of Employees 162 359 Net Generation, Exclusive of Plant Use - KWh 5977919000 9630099000 Cost of Plant: Land and Land Rights 2405337 1146361 Structures and Improvements 94498627 132803837 Equipment Costs 324856385 672352890 Total Cost 421760349 806303088 Cost per KIN of Installed Capacity (line 5)423.4542 348.8677 Production Expenses: Oper, Supv, & Engr 13527 3993621 Fuel 49079025 115998979 Coolants and Water (Nuclear Plants Only) Steam Expenses 5411594 2017319 Steam From Other Sources Steam Transferred (Cr) Electric Expenses 104440 Misc Steam (or Nuclear) Power Expenses 7054560 3976614 Rents 493704 219744 Allowances Maintenance Supervision and Engineering 1017097 274333 Maintenance of Structures 1496827 7468228 Maintenance of Boiler (or reactor) Plant 10358518 19192990 Maintenance of Electric Plant 4425884 6719392 Maintenance of Misc Steam (or Nuclear) Plant 1079620 1626374 Total Production Expenses 80430356 157557396 Expenses per Net KWh 0135 0164 Fuel: Kind (Coal, Gas, Oil, or Nuclear)Coal Oil Coal Oil Unit (Coal-tons/Oil-barrel/Gas-mcf/Nuclear-indicate)Tons Bareis Tons Barrels Quantity (units) of Fuel Burned 2696708 22832 5495620 26972 Avg Heat Cont - Fuel Bumed (btu/indicate if nuclear)11321 140000 9116 140000 Avg Cost of Fuel/unit, as Delvd f.b. during year 17.533 32.614 000 20.674 33.716 000 Average Cost of Fuel per Unit Burned 17.923 32.614 000 20.938 33.716 000 Average Cost of Fuel Burned per Million BTU 792 547 000 149 734 000 Average Cost of Fuel Bumed per KWh Net Gen 008 000 000 012 000 000 Average BTU per KWh Net Generation 10236.322 000 000 10420.474 000 000 FERC FORM NO.1 (ED. 12-95)Page 402. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2) 0 A Resubmission 04/3012003 Dec. 31 STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)(Continued) 9. Items under Cost of Plant are based on U. S. of A. Accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 24 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 31 , " Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.11. For a plant equipped with combinations ot fossil fuel steam, nuclear steam, hydro, intemal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data conceming plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant. Plant Plant Plant Line Name: Naughton Name:Name:Gadsby No. (d)(f) Steam Steam Steam Outdoor Boiler Conventional Outdoor 1963 1978 1951 1971 1978 1955 707.362.251. 719 280 218 8760 8570 6285 700 335 235 153 5019304000 2289062000 495453000 458248 210526 1020271 55589785 48028460 13415332 268469813 248617252 54710346 324517846 296856238 69145949 458.8770 820.0449 274.8249 415967 1659328 160342 54128384 16445405 30585119 4807154 8889 6699143 1932783 3972995 14081 1938 4651 1362522 3518 1323801 309894 169481 11660823 3483601 1320594 4262794 470290 1487804 1102615 576420 219331 85786173 24883177 37599633 0171 0109 0759 Coal Gas Coal Oil Gas Tons MCF Tons Barrels MCF 2639187 241663 1695517 3735 5839878 10024 1054 8110 151224 1058 20.179 000 000 624 40.716 000 000 000 000 20.150 931 000 610 40.716 000 584 000 000 023 730 000 593 411 000 320 000 000 011 000 000 007 000 000 062 000 000 10592.167 000 000 12024.575 000 000 12508.882 000 000 FERC FORM NO.1 (ED. 12-88)Page 403. Name of Respondent This ~rt Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2) DA Resubmission 04/30/2003 Dec. 31 STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued) 1. Report data for plant in Service only.2. Large plants are steam plants with installed capacity (name plate rating) of 25 000 Kw or more. Report in this page gas-turbine and intemal combustion plants of 10 000 Kw or more, and nuclear plants.3. Indicate by a footnote any plant leased or operated as a joint facility.4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mct.7. Quantities of fuel bumed (Line 37) and average cost per unit of fuel burned (Line 40) must be consistent with charges to expense accounts 501 and 547 (Line 41) as show on Line 19.8. If more than one fuel is bumed in a plant fumish only the composite heat rate for all fuels bumed. Line Item Plant Plant ~1~BII~~1IINo.Name: Uttle Mountain Name: (a)(b) Kind of Plant (Internal Comb, Gas Turb, Nuclear Gas Turbine Steam Type of Constr (Conventional, Outdoor, Boiler, etc)Outdoor Boiler Gas Turbine Year Originally Constructed 1972 1996 Year Last Unit was Installed 1972 1996 Total Installed Cap (Max Gen Name Plate Ratings-MW)16.237. Net Peak Demand on Plant - (60 minutes)247 Plant Hours Connected to Load 6127 7135 Net Continuous Plant Capability (Megawatts) When Not Limited by Condenser Water 236 When Limited by Condenser Water Average Number of Employees Net Generation, Exclusive of Plant Use - KWh 80803000 1477254000 Cost of Plant: Land and Land Rights 635 842245 Structures and Improvements 204044 12474621 Equipment Costs 4067990 144642185 Total Cost 4272669 157959051 Cost per KW of Installed Capacity (line 5)267.0418 666.4939 Production Expenses: Oper, Supv, & Engr 1401 Fuel 5033056 36890160 Coolants and Water (Nuclear Plants Only) Steam Expenses Steam From Other Sources Steam Transferred (Cr) Electric Expenses 961132 6622594 Misc Steam (or Nuclear) Power Expenses Rents 345 Allowances Maintenance Supervision and Engineering Maintenance of Structures Maintenance of Boiler (or reactor) Plant Maintenance of Electric Plant Maintenance of Misc Steam (or Nuclear) Plant 1704 Total Production Expenses 5997638 43512754 Expenses per Net KWh 0742 0295 Fuel: Kind (Coal, Gas, Oil, or Nuclear)Gas Gas Unit (Coal-tons/Oil-barreUGas-mcf/Nuclear-indicate)MCF MCF Quantity (units) of Fuel Bumed 1377981 10480463 Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)1053 1067 Avg Cost of Fuel/unit, as Delvd f.b. during year 000 000 000 000 000 000 Average Cost of Fuel per Unit Bumed 652 000 000 520 000 000 Average Cost of Fuel Bumed per Million BTU 3.469 000 000 456 000 000 Average Cost of Fuel Bumed per KWh Net Gen 062 000 000 025 000 000 Average BTU per KWh Net Generation 17952.403 000 000 7210.637 000 000 FERC FORM NO.1 (ED. 12-95)Page 402. Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2) 0 A Resubmission 04/30/2003 Dec. 31 STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)(Continued) 9. Items under Cost of Plant are based on U. S. of A. Accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 24 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 31 , " Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data conceming plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant. Plant Name: Blundell Name: Name: No. (d) Steam - Geothermal Steam Gas Turbine Indoor Outdoor Boiler Outdoor 1984 1996 2002 1984 1996 2002 26.52.217. 218 8599 8637 2493 185 184449000 239497000 373926000 31026429 6150130 5733734 33073388 28682437 70249947 34416171 2701.9210 659.1873 0000 1062 15181956 27807 3800080 18610 7256900 1483244 3128 559804 39520 66629 78990 16027 5513359 21738 22998660 0299 0001 0615 Gas MCF 3697709 1034 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 106 000 000 000 000 000 000 000 000 007 000 000 000 0000 0.000 0.000 000 000 041 000 000 000 000 000 000 000 000 10132.609 000 000 FERC FORM NO.1 (ED. 12-88)Page 403. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2)0 A Resubmission 04/30/2003 Dec. 31 STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued) 1. Report data for plant in Service only.2. Large plants are steam plants with installed capacity (name plate rating) of 25 000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10 000 Kw or more, and nuclear plants.3. Indicate by a footnote any plant leased or operated as a joint facility.4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel bumed converted to Mct.7. Quantities of fuel bumed (Line 37) and average cost per unit of fuel bumed (Line 40) must be consistent with charges to expense accounts 501 and 547 (Line 41) as show on Line 19.8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels bumed. Line Item Plant Plant No.Name: Gadsby Gas Peakers Name: (a)(b)(c) Kind of Plant (lntemal Comb, Gas Turb, Nuclear Gas Turbine Type of Constr (Conventional, Outdoor, Boiler, etc)Outdoor Year Originally Constructed 2002 Year Last Unit was Installed 2002 Total Installed Cap (Max Gen Name Plate Ratings-MW)141. Net Peak Demand on Plant - MW (60 minutes)133 Plant Hours Connected to Load 3651 Net Continuous Plant Capability (Megawatts) 9 When Not Limited by Condenser Water 131 When Limited by Condenser Water Average Number of Employees Net Generation, Exclusive of Plant Use - KWh 162366000 Cost of Plant: Land and Land Rights Structures and Improvements Equipment Costs 70276509 Total Cost 70276509 Cost per KW of Installed Capacity (line 5)498.4150 0000 Production Expenses: Oper, Supv, & Engr Fuel 3461312 Coolants and Water (Nuclear Plants Only) Steam Expenses Steam From Other Sources Stearn Transferred (Cr) Electric Expenses Misc Steam (or Nuclear) Power Expenses Rents Allowances Maintenance Supervision and Engineering Maintenance of Structures Maintenance of Boiler (or reactor) Plant Maintenance of Electric Plant Maintenance of Misc Steam (or Nuclear) Plant Total Production Expenses 3461312 Expenses per Net KWh 0213 0000 Fuel: Kind (Coal, Gas, Oil, or Nuclear)Gas Unit (Coal-tons/Oil-barrel/Gas-mcf/Nuclear-indicate)MCF Quantity (units) of Fuel Bumed 1728306 Avg Heat Cont - Fuel Bumed (btulindicate if nuclear)1058 Avg Cost of Fuel/unit, as Delvd f.b. during year 000 000 000 000 000 000 Average Cost of Fuel per Unit Bumed 209 000 000 000 000 000 Average Cost of Fuel Bumed per Million BTU 026 000 000 000 000 000 Average Cost of Fuel Burned per KWh Net Gen 021 000 000 000 000 000 Average BTU per KWh Net Generation 11127.385 000 000 000 000 000 FERC FORM NO.1 (ED. 12-95)Page 402. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2)0 A Resubmission 04130/2003 Dec. 31 STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)(Continued) 9. Items under Cost of Plant are based on U. S. of A. Accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.10. For IC and GT plants, report Operating Expenses, Account Nos. )47 and 549 on Line 24 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 31 , " Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, intemal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data conceming plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant. Plant Plant Plant Line Name:Name:Name:No. (d)(e)(f) 0000 0000 0000 0000 0000 0000 000 000 000 000 000 000 000 000 000 000 000 000 000 0.000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 0.000 000 000 FERC FORM NO.1 (ED. 12-88)Page 403. Name of Respondent This (!Jort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2) DA Resubmission 04/30/2003 Dec. 31 HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants) 1. Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings) 2. If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number. 3. If net peak demand for 60 minutes is not available, give that which is available specifying period. 4. If a group of employees attends more than one generating plan, report on line 11 the approximate average number of employees assignable to each plant. Line Item FERC Licensed Project No.2082 FERC Licensed Project No.2082 No.Plant Name: Copco No.Plant Name: Copco No. (a)(b)(c) Kind of Plant (Run-of-River or Storage) \~' ~~J1Iep Plant Construction type (Conventional or Outdoor)Conventional Conventional Year Originally Constructed 1918 1925 Year Last Unit was Installed 1922 1925 Total installed cap (Gen name plate Rating in MW)20.27. Net Peak Demand on Plant-Megawatts (60 minutes) Plant Hours Connect to Load 772 684 Net Plant Capability (in megawatts) (a) Under Most Favorable Oper Conditions (b) Under the Most Adverse Oper Conditions Average Number of Employees Net Generation, Exclusive of Plant Use - Kwh 822 000 112,000 Cost of Plant Land and Land Rights 180,375 914 Structures and Improvements 166 705 560 289 Reservoirs, Dams, and Waterways 440 053 819,603 Equipment Costs 761 572 352,832 Roads, Railroads, and Bridges 105,442 240,200 TOTAL cost (Total of 14 thru 18)654 147 993,838 Cost per I(JN of Installed Capacity (line 5)432.7074 333.1051 Production Expenses Operation Supervision and Engineering -45,160 -60,966 Water for Power 733 739 Hydraulic Expenses 270 314 Electric Expenses Misc Hydraulic Power Generation Expenses 293 961 374 868 Rents 396 125 Maintenance Supervision and Engineering Maintenance of Structures 135 110 137 723 Maintenance of Reservoirs, Dams, and Waterways 788 60,531 Maintenance of Electric Plant 219 823 162 344 Maintenance of Misc Hydraulic Plant 102 701 136,162 Total Production Expenses (total 22 thru 32)828,622 897 840 Expenses per net I(JNh 0108 0092 FERC FORM NO.1 (ED. 12-88)Page 406 Name of Respondent PacifiCorp This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr)(2) DA Resubmission 04/30/2003 HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued) 5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses. 6. Report as a separate plant any plant equipped with combinations of steam, hydro, intemal combustion engine, or gas turbine equipment. Year of Report Dec. 31 2002 FERC Licensed Project No. 1927 Plant Name: Clearwater No. (d) FERC Licensed Project No. 1927 Plant Name: Clearwater No. (e) FERC Licensed Project No. Plant Name: Cutler 2420 Line No. Outdoor 1953 1953 15. 741 Outdoor 1953 1953 26. 053 Storage Conventional 1927 1927 30. 072 559 122 344 156 952 480 855,758 323.7172 754,944 930,549 150,572 219,901 055,966 425.2295 512 464 659 112 023,945 668,962 566,413 15,430 896 514.3632 100 062 190 370,867 253 079 283 10,433 10,714 308,325 0063 173,440 128 063 598 729 288 561 62,545 135 969 537 402 0115 143,508 148 742 456 302 1 ,438 13,146 52,912 396 102 095 834,737 0222 FERC FORM NO.1 (ED. 12-88)Page 407 Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2) DA Resubmission 04/30/2003 Dec. 31, HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants) 1. Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings) 2. If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number. 3. If net peak demand for 60 minutes is not available, give that which is available specifying period. 4. If a group of employees attends more than one generating plan, report on line 11 the approximate average number of employees assignable to each plant. Line Item FERC Licensed Project No.1927 FERC Licensed Project No.2401 No.Plant Name: Fish Creek Plant Name: Grace (a)(b)(c) Kind of Plant (Run-of-River or Storage)Storage Plant Construction type (Conventional or Outdoor)Outdoor Conventional Year Originally Constructed 1952 1908 Year Last Unit was Installed 1952 1923 Total installed cap (Gen name plate Rating in MW)11.33. Net Peak Demand on Plant-Megawatts (60 minutes) Plant Hours Connect to Load 027 760 Net Plant Capability (in megawatts) (a) Under Most Favorable Oper Conditions (b) Under the Most Adverse Oper Conditions Average Number of Employees Net Generation , Exclusive of Plant Use - Kwh 571 000 584 000 Cost of Plant Land and Land Rights 50,393 Structures and Improvements 557 744 156,015 Reservoirs, Dams, and Waterways 759 697 554 308 Equipment Costs 664,512 180,032 Roads, Railroads, and Bridges 409,412 134 TOTAL cost (Total of 14 thru 18)391,365 11,983,882 Cost per 'rWI of Installed Capacity (line 5)671.9423 363.1479 Production Expenses Operation Supervision and Engineering 378 970 Water for Power 162 Hydraulic Expenses 873 016 Electric Expenses Misc Hydraulic Power Generation Expenses 303 783 028 845 Rents 340 506 Maintenance Supervision and Engineering 581 Maintenance of Structures 10,526 965 Maintenance of Reservoirs, Dams, and Waterways 583 188 109 Maintenance of Electric Plant 133,896 637 Maintenance of Misc Hydraulic Plant 037 367 183 Total Production Expenses (total 22 thru 32)407 716 733,974 Expenses per net 'rWIh 0081 0232 FERC FORM NO.1 (ED. 12-88)Page 406. Name of Respondent PacifiCorp Year of Report Dec. 31 2002 This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) 0 A Resubmission 04/30/2003 HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued) 5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses. 6. Report as a separate plant any plant equipped with combinations of steam, hydro, internal combustion engine, or gas turbine equipment. FERC Licensed Project No. 2082 Plant Name: Iron Gate (d) FERC Licensed Project No. 2082 Plant Name: JC Boyle (e) FERC Licensed Project No. Plant Name: Lemolo No. 1927 Line No. Outdoor 1962 1962 18. 447 Outdoor 1958 1958 80. 063 Outdoor 1955 1955 29. 026 341 706 686,688 447 812 362,657 638,679 14,477 542 804.3079 984 162 818 10,405 743 720 632 604 730 19,948 907 249.3613 709,103 509 496 105,030 407 171 730,800 404.5103 -40,644 160 543 266 024 883 65,718 50,066 102 543 90,238 591 531 0062 180 640 931 229 079 -65 373 924 241 980 212 891 138,431 398 258 001,481 0052 193,452 143 300 730,492 661 578 40,170 786 009 650 687 0057 FERC FORM NO.1 (ED. 12-88)Page 407. Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2) DA Resubmission 04/30/2003 Dec. 31 HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants) 1. Large plants are hydro plants of 10 000 Kw or more of installed capacity (name plate ratings) 2. If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number. 3. If net peak demand for 60 minutes is not available, give that which is available specifying period. 4. If a group of employees attends more than one generating plan, report on line 11 the approximate average number of employees assignable to each plant. Line Item FERC Licensed Project No.1927 FERC Licensed Project No.935 No.Plant Name' IiiiJfpm~IIIWY~":Plant Name: Merwin . ',. ..' ",. ':-'IJJir~'J, (a) ""'."&~ ..~ ~*" """,, " ~",.!-. (c) Kind of Plant (Run-of-River or Storage)Run-of River Storage Plant Construction type (Conventional or Outdoor)Outdoor Conventional Year Originally Constructed 1956 1931 Year Last Unit was Installed 1956 1958 Total installed cap (Gen name plate Rating in MW)33.136. Net Peak Demand on Plant-Megawatts (60 minutes)147 Plant Hours Connect to Load 669 758 Net Plant Capability (in megawatts) (a) Under Most Favorable Oper Conditions 144 (b) Under the Most Adverse Oper Conditions 141 Average Number of Employees Net Generation, Exclusive of Plant Use - Kwh 140,818,000 486,481 000 Cost of Plant Land and Land Rights 991 404 Structures and Improvements 688,448 925 756 Reservoirs, Dams, and Waterways 868,868 304,223 Equipment Costs 964 898 381 005 Roads, Railroads, and Bridges 993 032 729,940 TOTAL cost (Total of 14 thru 18)515,246 332 328 Cost per KW of Installed Capacity (line 5)561.0681 370.0906 Production Expenses Operation Supervision and Engineering 220,135 279 921 Water for Power 162 669 Hydraulic Expenses 720 798,173 Electric Expenses Misc Hydraulic Power Generation Expenses 752 888 214 035 Rents 016 Maintenance Supervision and Engineering Maintenance of Structures 688 682,408 Maintenance of Reservoirs, Dams, and Waterways 365 209 329 Maintenance of Electric Plant 324 226 287 Maintenance of Misc Hydraulic Plant 35,555 581 053 Total Production Expenses (total 22 thru 32)723,553 590,821 Expenses per net KWh 0051 0053 FERC FORM NO.1 (ED. 12-88)Page 406. Name of Respondent PacifiCorp Year of Report Dec. 31, 2002 This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr)(2) 0 A Resubmission 04/30/2003 HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued) 5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses. 3. Report as a separate plant any plant equipped with combinations of steam, hydro, intemal combustion engine, or gas turbine equipment. FERC Licensed Project No. Plant Name: Toketee (d) 1927 FERC Licensed Project No. Plant Name: Oneida (e) 472 FERC Licensed Project No. 2630 Plant Name: Prospect No. Line No. Outdoor 1950 1950 42. 670 Storage Conventional 1915 1920 30. 758 Conventional 1928 1928 32. 073 1,429 228 271 942 625 065 111 245 437,480 245.5878 36,698 188,094 537 738 048,460 381,105 192 095 306.4032 105,168 019,734 940 405 721,260 191,385 977 952 311.8110 283 508 209 371 941 278 566 983 151 338 30,650 849,906 0041 104,374 148 742 450 293 288 1 ,438 7,432 851 316 113,428 720 734 0258 255,305 157 538 948 104 918 733 129 380 263 684 23,161 190,370 0066 FERC FORM NO.1 (ED. 12-88)Page 407. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2) DA Resubmission 04/30/2003 Dec. 31 HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants) 1. Large plants are hydro plants of 10 000 Kw or more of installed capacity (name plate ratings) 2. If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number. 3. If net peak demand for 60 minutes is not available, give that which is available specifying period. 4. If a group of employees attends more than one generating plan, report on line 11 the approximate average number of employees assignable to each plant. Line Item FERC Licensed Project No.1927 FERC Licensed Project No. No.Plant Name: Slide Creek Plant Name: Soda (a)(b)(c) Kind of Plant (Run-of-River or Storage)Run-of-River Storage Plant Construction type (Conventional or Outdoor)Outdoor Conventional Year Originally Constructed 1951 1924 Year Last Unit was Installed 1951 1924 Total installed cap (Gen name plate Rating in MW)18.14. Net Peak Demand on Plant-Megawatts (60 minutes) Plant Hours Connect to Load 721 136 Net Plant Capability (in megawatts) (a) Under Most Favorable Oper Conditions (b) Under the Most Adverse Oper Conditions Average Number of Employees Net Generation, Exclusive of Plant Use - Kwh 80,879,000 590 000 Cost of Plant Land and Land Rights 504,056 Structures and Improvements 607 138 572 786 Reservoirs, Dams, and Waterways 753,383 996,525 Equipment Costs 160,042 072,224 Roads, Railroads, and Bridges 778 TOTAL cost (Total of 14 thru 18)537 341 145 591 Cost per f(W of Installed Capacity (line 5)307.6301 581.8279 Production Expenses Operation Supervision and Engineering 120,074 740 Water for Power Hydraulic Expenses 428 Electric Expenses Misc Hydraulic Power Generation Expenses 418 233 125 923 Rents 153 Maintenance Supervision and Engineering Maintenance of Structures 344 253 Maintenance of Reservoirs, Dams, and Waterways 550 595 Maintenance of Electric Plant 049 855 Maintenance of Misc Hydraulic Plant 13,118 3,405 Total Production Expenses (total 22 thru 32)364,584 154 838 Expenses per net f(Wh 0045 0123 FERC FORM NO.1 (ED. 12-88)Page 406. Name of Respondent PacifiCorp Year of Report Dec. 31 2002 This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) 0 A Resubmission 04/30/2003 HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued) 5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses. 5. Report as a separate plant any plant equipped with combinations of steam, hydro, intemal combustion engine, or gas turbine equipment. FERC Licensed Project No. Plant Name: Soda Springs (d) 1927 FERC Licensed Project No. 2111 Plant Name: Swift No. (e) FERC Licensed Project No. Plant Name: Yale 2071 Line No. Run-of-River Outdoor 1952 1952 11. 282 Storage Conventional 1958 1958 240. 260 834 Storage Conventional 1953 1953 134. 169 645 817 681 3,467,419 092,874 25,845 403,819 491.2563 813,808 735,975 37,455,102 256,495 395 145 656,525 265.2355 777 170 862,192 068,666 358 192 154 925 221,145 374.7847 73,378 873 275 778 105 657 265 684 544 382 372 0066 272,403 180 290,646 371 988 111 109 990 110 212 143,974 286,918 042 394 0047 704,417 659 128 074 189 801 98,939 189 161 174 329 963 684 0055 FERC FORM NO.1 (ED. 12-88)Page 407. Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002(2) n A Resubmission 04/30/2003 G NERATING PLANT STATISTICS (Small Plants) 1. Small generating plants are steam plants of, less than 25 000 Kw; intemal combustion and gas turbine-plants, conventional hydro plants and pumped storage plants of less than 10,000 Kw installed capacity (name plate rating).2. Designate any plant leased from others, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, and give a concise statement of the facts in a footnote. If licensed project, give project number in footnote. Line Year Iinstall~d cawClty lI!et Peak Net Generation Name of Plant Orig.Name Plate atin Demand Excluding Cost of Plant No.Const.(In MW)(6~B1n.Plant Use (a)(b)(c)(e)(f) 1 Hydro Plants:Licensed Proj. No. 2 American Fork 696 1907 5,403 936,920 1917 368 761 386 4 Beaver - Upper 814 1907 263 507 548 5 Bend 2643 1913 440 846 190 6 Skookumchuck 1990 109 657 150 7 Big Fork 2652 1910 19,523 595,522 8 Cline Falls 1913 972 291,595 9 Condit 2342 1913 15.961 814 974 1917 197 790,699 Drop Plant (Naches)1914 585 416,855 Eagle Point 1957 065 705,068 East Side 2082 1924 10,844 809,650 Fall Creek 2082 1903 11,628 966,284 Fountain Green 1922 523 440 817 Granite 1896 056 474 861 Gunlock 1917 372 481 400 Last Chance 4580 1983 1.4 547 497 842 Naches 1909 844 784 361 Paris 703 1910 314 309 081 Pioneer 2722 1897 10,000 710,057 Powerdale 2659 1923 754 645,249 Prospect #1 2630 1912 398 539,021 Prospect #3 2337 1932 34,963 800 182 Prospect #4 2630 1944 394 184 246 Sand Cove 1926 318 842,890 Snake Creek 1910 014 888 199 Stairs 597 1895 902 166 236r-- --.......'. 1915 963 319 082r--Veyo 1920 217 719,316 Viva Naughton 1986 122 154 968 Wallowa Falls 308 1921 882 749,618 Weber 1744 1911 118 447,705 West Side 2082 1908 930 347 350 7,468 183 684 534 629,524 Pumping Plant Lifton 1917 10,520,918 FERC FORM NO.1 (ED. 12-87)Page 410 Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr) Dec. 31, 2002(2) 0 A Resubmission 04/30/2003 GENERATING PLANT STATISTICS (Small Plants) (Continued) 3. List plants appropriately under subheadings for steam, hydro, nuclear, intemal combustion and gas turbine plants. For nuclear, see instruction 11, Page 403.4. If net peak demand for 60 minutes is not available, give the which is available, specifying period.5. If any plant is equipped with combinations of steam, hydro intemal combustion or gas turbine equipment, report each as a separate plant. However, if the exhaust heat from the gas :urbine is utilized in a steam turbine regenerative feed water cycle, or for preheated combustion air in a boiler, report as one plant. Plant Cost Per MW Operation Production Expenses Fuel Costs (in cents LineInst Capacity Exc l. Fuel Fuel Maintenance Kind of Fuel (per Million Btu) (g) (h)(i)(k)(I)No. 041,022 820 952 288,439 280 421 034 003,019 129 911 104 151 825,371 124 028 787 122 650 146 983,483 157 732 173,390 266,366 13,263 087 706,016 223 574 79,090 371 753 199 681 225 324 272,269 605,677 80,212 112,231 569 604 54,147 127 538 460 838 77,356 39,461 4,408 167 786 281 233 390 192 183 687 714 68,251 27,238 651 260 59,157 58,808 551,439 178,156 683 441 545 21,665 064 913 992 195 108 112,515 264 578 201,462 46,307 145 681 394 80,314 944 360 193 301 209 184 246 38,362 30,870 053 613 784 16,356 886 912 165 883 156 616 650 819 640 562 218 358 713 438 632 58,666 11,347 924 946 250 766 2,492 830 22,685 39,277 644 254 139,212 901 535 874 60,903 17,651 100 140 732 183,935 112 322 FERC FORM NO.1 (ED. 12-87)Page 411 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 0413012003 TRANSMISSION LINE STATIST 1. Report information concerning transmission lines, cost of Ii,:,es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts.Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121 , Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. VO!.,TAGEJ~LENGJ.H ~ole WileS)Line Type of(Indicate wtiere ~lrI t e s cf /) Number No.other than u dergroun lines 60 cycle 3 chase)Supporting report circuit miles) From Operating Designed fUn""""&fnJCfure I U':1,~tr p1h~res CircuitsStructureof Lin of 1."0 erDesi rca ed(a)(b)(c)(d)(e) (g) (h) 1 Malin, Oregon Indian Springs., CA 5O0.500.Steel Tower 47. 2 Midpoint, Idaho Malin, Oregon 500.500.Steel Tower 446. 3 Malin, Oregon Medford, Oregon 500.500.Steel Tower 83. 4 Alvey Sub, Oregon Dixonville Sub, Oregon 500.500.Steel Tower 58. 5 Malin , Oregon Captain Jack, OR 500-:G(500.Steel Tower 6 Dixonville, Oregon Meridian, OR 5OO.500.Steel Tower 74. 7 Ben Lomond Sub., Utah Borah Substation, Idaho 345lK 345.Steel- H 134. 8 Ben Lomond Sub., Utah Terminal Substation, UT 345.345.Steel- D 47. 9 Spanish Fork Sub., Utah Camp Williams Sub., Utah 345.345.Steel- SP 35. Huntington Plant, Utah Sigurd Substation, Utah 345.345.Steel-86. Huntington PIt. Sub., UT Spanish Fork Sub., Utah 345.345.Steel - H 78. Terminal Substation, UT Ninety South Sub., Utah 345.345.Steel- SP 15. Emery Substation , Utah Sigurd Substation, Utah 345.345.Steel - H 68. Sigurd Substation , Utah Camp Williams Sub., Utah 345.345.Steel - H-P 116. Camp Williams Sub., Utah Ninety South Sub., Utah 345.345.Steel - SP Terminal Substation, UT Camp Williams Sub., Utah 345.345.Steel- D 25. Emery Substation, Utah Camp Williams Sub., Utah 345.345.Steel- H 86. Newcastle, Utah Utah - Nevada Border 345.345.Steel- D 54. Sigurd Substation, Utah Newcastle, Utah 345.345.Steel - D 137. Goshen Substation, Idaho Kinport Substation, ID 345.345.Steel - H 41. Huntington Plant, Utah Four Comers Sub., NM 345.345.Wood - U 55. Camp Williams Sub., Utah Huntington Plant, Utah 345.345.Wood - U 152. Huntington Plant, Utah Pinto Substation, Utah 345.345.Wood - U 156. Camp Williams Sub., Utah Sigurd Substation, Utah 345.345.Wood - U 111. Jim Bridger Plant #3, WY Borah Substation , Idaho 345.345.Steel Tower 240. Jim Bridger Plant #2, WY Kinport Substation, ID 345.345.Steel Tower 234. Fairview, Oregon Isthmus, Oregon 230.230.H Frame Wood 12. Antelope Sub., Idaho Lost River 230kV Line, ID 230.230.Wood - H 20. Walla Walla, Washington Hells Canyon, ID 230.230.H Frame Wood 72. Bethel, Oregon Fry, Oregon 230.230.H Frame Wood 26. Fry, Oregon Dixonville, Oregon 230.230.H Frame Wood 44. Alvey, Oregon Dixonville, Oregon 230.230.H Frame Wood 59. Troutdale, Oregon linneman, Oregon 230:-01 230.Steel Tower Troutdale, Oregon Gresham, Oregon 230.230.Steel Tower McNary, Washington Walla Walla, Washington 230.230.H Frame Wood 56. TOTAL 14,876.100.191 FERC FORM NO.1 (ED. 12-87)Page 422 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 RANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. R:eport Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the . 10le miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses bome by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for in columns (j) to (I) on the book cost at end of year. COST OF LINE (Include In Column (j) Land EXPENSES, EXCEPT DEPRECIATION AND TAXES Size of Land rights, and clearing right-of-way) Conductor and Material Land Construction and Total Cost Operation Maintenance Rents Total Line Other Costs Expenses Expenses (0)ExpE)nses No.(i) (j) (k)(I)(m)(n) (p) 1852 134,35E 4,416,172 550,528 1272.109,681 150,616,208 153,725,896 1272.907,17!949,834 40,857,009 1272.1,425,18(19,733,578 158,758 1272.23!1,460,186 1,469,416 1272.0 912,26,247,891 31,160,135 54.229,35,010,252 40,239,905 272.0 886,21,814,448 700,69E 1272.069,158,595 16,228,424 ~54.318,831 20,042,861 20,361 692 ~54.791,811 670,321 18,462,132 1272.614 871 7,457,557 10,072,435 ~54.281,83-13,610,468 13,892,302 ~54.510,19,757,045 20,267 535 1272.0 486,895,713 382,455 1272.231,002,609 12,233,699 54.926,251 27,916,136 28,842,387 54.320,87;50,649,76e 52,970,637 954.56,05(13,548,519 13,604,569 95.313,47 565,555 879,032 ~54.117,618,232 735,894 95.887 901 18,394,649 282,549 1795. (~'!\ 1795.84,95~918,176 003,135 1272.0 128,26,192,950 321,172 272.099,79E 997,165 096,961 54.285,566,041 851 363 95.12,92(195,831 208,760 1272.64,277 140 341 534 1272.351 168,966 520,948 1272.0 485,89!284,258 770,154 ~54.1,428,13,342,361 770,608 ~54.413,491 413,491 ~54 .368,841 574 074 942,920 1272.220,697,802 918,769 79,299,189 362,198,423 441,497 612 FERC FORM NO.1 (ED. 12-87)Page 423 Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Ei A Resubmission 04/30/2003 TRANSMISSION LINE STATIST CS 1. Report information conceming transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts.Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121 , Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. LENG~H ~ole WileS)Line IUN (Indicate wtiere Type of ~lJt e mro Number No.other than u dergrou lines 60 cycle 3 Dhase)Supporting report circuit miles) From Operating Designed On ~trl,iCture f~'lciJwes CircuitsStructureof Line 1)0 erDesir;ated(a)(b)(c)(d)(e) (g) (h) 1 BPA Heppner, Oregon Dalred Substation, Orego 230.230.H Frame Wood 2 Sigurd Substation, Utah Garfield, Utah 230.230.Wood - U 118. 3 Dixonville, Oregon Reston, Oregon 230.230.H Frame Wood 17. 4 Yamsey, Oregon Klamath Falls, Oregon 230.230.H Frame Wood 56. 5 Yamsey, Oregon Klamath Falls, Oregon 230.230.Steel Tower 6 Dixonville, Oregon Lone Pine, Oregon 230.230.H Frame Wood 7 Klamath Falls, Oregon Medford, Oregon 230.230.H Frame Wood 76. 8 Klamath Falls, Oregon Malin, Oregon 230.230.H Frame Wood 35. 9 Table Rock, SW Station, OR Grants Pass, Oregon 23O.230.H Frame Wood 35. Grants Pass, Oregon Days Creek, Oregon 230.230.H Frame Wood 71.00 Dixonville, Oregon Dixonville, Oregon 230.230.Wood 1.00 Sigurd Substation, Utah Pavant Substation, Utah 230.230.Wood - U 43. Pavant Substation, Utah Nevada - Utah State line 230.230.Wood - U 98. Bannack Pass, Idaho Antelope Sub., Idaho 230.230.Wood - U 76. Brady Substation, Idaho Treasureton Sub., Idaho 230.230.Wood - U 66. Ben Lomond Sub., Utah Naughton PIt. #1 , WY 230.230.Wood - U 88. Sigurd Substation, Utah Arizona - Utah State line 230.230.Wood - U 149. Birch Creek Sub., WY Railroad Substation, WY 230.230.Wood - HSW 12. Birch Creek Sub., WY Railroad Substation, WY 230.230.Wood - HSW Ben Lomond Sub., Utah Naughton PIt. #2, WY 230.230.Wood - U 50. Ben Lomond Sub., Utah Naughton PIt. #2, WY 230.230.Wood - U 29. Chappel Creek, WY Naughton Plant, WY 230.230.Wood Tower 46. Ben Lomond Sub., Utah Terminal Substation, UT 230.230.Steel- D-46. Naughton Plant, Wyoming Treasureton Sub., Idaho 230.230.Wood - U 78. Naughton Plant, Wyoming Treasureton Sub., Idaho 230.230.Wood - U 1.00 Swift Plant #1 , WA Cowlitz Co. Line, WA 230.230.H Frame Wood Swift Plant #2, WA BPA Woodland, WA 230.230.H Frame Wood 23. Union Gap, Washington BPA Midway, WA 230.230.H Frame Wood 39. Walla Walla, Washington Lewiston, ID 230.230.H Frame Wood 45. Walla Walla, Washington Wanapum, Washington 230.230.H Frame Wood 33. Pomona, Washington Wanapum, Washington 23O.230.H Frame Wood 37. Centralia, Washington BPA Tap, Washington 23O.230.H Frame Wood Pomona, Washington Wanapum, Washington 230.230.H Frame Wood Meridian Sub, OR Lone Pine Sub, OR 230.230. Billings, Montana Yellowtail, Montana 230.230.H Frame Wood 39. TOTAL 14,876.100.191 FERC FORM NO.1 (ED. 12-87)Page 422. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 04/30/2003 'RANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage ~nes as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, fumish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for in columns 0) to (I) on the book cost at end of year. (;U::; I ut- LINt: (IncluCle In (;Olumn U) LanCl EXPENSES, EXCEPT DEPRECIATION AND TAXES Size of Land rights, and clearing right-of-way) Conductor and Material Land Construction and Total Cost Operation Maintenance Rents Total LineOther Costs Expenses Expenses (0)Expenses No.(i) (j) (k)(I)(m)(n) (p) 95.108,274 108,274 95.390,620,943 011,821 39,971 942,039 982,010 95. 95.247 3,496,42c 743,513 95.397 880,49f 278,185 95.173,697 244 870,85. 1272.0 115,441 576,699 692 147 1954.191,12'088,533 279 657 ~272.0 379 961 10,720,324 100,285 1272.0 385,576 385,576 1795.41,49~ 4,348,262 389 761 95. ;;:.". ,/;-0))\ 1272.10 2,424 716 2,429,819 95.72,865,316 937,434 95.420,40 746,456 166,865 54.22,64.4,460,228 4,482 871 54.165,277,573 442 627 54.181 1,487 637 668 684 1272.736,757 291 493 321 1272.1,421,791 1,427 954.170,900 151 071,118 1272.0 572,45 758,400 10,330,859 954.56,49 856,821 913,319 954.27,749 28,318 954.174 634 175 927 954.103,53~844,948,375 1272.0 172,451 525,982 698,433 1272.366,022,388,923 ~4.235,518,898 754,430 1780.207,12~640,020 847 143 ~54.33,165,771 199 656 ~56.334,252 334,421 017,742 017 742 1272.32,991 1,457,833 1,490,831 79,299,189 362,198,423 441,497 612 FERC FORM NO.1 (ED. 12-87)Page 423. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31,2002(2) nA Resubmission 04/30/2003 TRANSMISSION LINE STATIST 1. Report information conceming transmission lines, cost of lir:tes, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts.Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121 , Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. \/nl ;Af"'-~J~~Line ,IIUN Type of LENGJti ~ole WileS)(Indicate wliere ~IO t e s cf D Number No.other than u aergroun lines 60 cycle 3 ohase)Supporting report circuit miles) From Operating Designed un ::?trl,lcture u!l.'=!.t~1h~res CircuitsStructureof Line of 'toot er (a)(b)(c)(e)Desi lWated Ine (d) (g) (h) 1 Yellowtail, Montana Muddy Ridge, Wyoming 230.230.H Frame Wood 176. 2 Sheridan, Wyoming Decker, Montana 230.230.H Frame Wood 14. 3 Dave Johnston Plant, WY Casper, Wyoming 230.230.H Frame Wood 31.00 4 Yellowtail, Montana Casper, Wyoming 230-:DI 230.H Frame Wood 169. 5 Rock Springs, Wyoming Kemmerer, Wyoming 230.230.H Frame Wood 71.00 6 Rock Springs, Wyoming Atlantic City, Wyoming 230.230.H Frame Wood 69. 7 Thermopolis, Wyoming Riverton, Wyoming 230.230.H Frame Wood 51. 8 Casper, Wyoming Riverton, Wyoming 230. ()( 230.H Frame Wood 110. 9 Dave Johnston Plant, WY Rock Springs, Wyoming 230.230.H Frame Wood 233. Dave Johnston Plant, WY Spence, Wyoming 230.230.H Frame Wood 31.00 Riverton, Wyoming Atlantic City, Wyoming 230.230.H Frame Wood 50. Rock Springs, Wyoming Flaming Gorge, Utah 230.230.H Frame Wood 48. Palisades, Wyoming Green River, Wyoming 230.230.H Frame Wood Buffalo, Wyoming Gillette, Wyoming 230.230.H Frame Wood 68. Jim Bridger Plant, WY Point of Rocks, Wyoming 230.230.H Frame Wood Jim Bridger Plant, WY Point of Rocks, Wyoming 230.230.H Frame Wood Dave Johnston Plant, WY Yellowcake, Wyoming 230.230.H Frame Wood 69. Wyodak, WY Sub. Tie Line, WY 230.230.H Frame Wood Jim Bridger Plant, WY Point of Rocks Ln 2, WY 230.230.H Frame Wood Blue Rim, Wyoming South Trona, Wyoming 230.230.H Frame Wood 13. Monument, Wyoming Exxon Plant, Wyoming 230.230.H Frame Wood 13. Firehole, Wyoming Mansface, Wyoming 230.230.Steel Pole Firehole, Wyoming Mansface, Wyoming 230.230.H Frame Wood 10. Monuments, Wyoming South Trona, Wyoming 23O.230.H Frame Wood 19. Spence Sub., WY Jim Bridger Plant, WY 230.H Frame Wood Jim Bridger Plant, WY Mustang Sub., Wyoming 230.230.H Frame Wood 73. Spence Sub., Wyoming Mustang Sub., Wyoming 230.230.H Frame Wood 77. Rock Springs, Wyoming Flaming Gorge, Utah 230.230.Steel Tower Line 59, CA Copco II, CA 230.230.H Frame Wood Arizona/Utah State Line Glen Canyon Sub., Arizon 230.230.H Frame Wood 10. Miners Sub, Wyoming Foote creek Sub., Wyoming 230.230. Montana-Idaho State line Grace Plant, Idaho 161.01 161.Wood - H 57.90. Goshen Substation, Idaho Rigby Substation, Idaho 161.161.00 Wood - H 29. Goshen Substation, Idaho Antelope Substation, ID 161.01 161.Wood - H 45. Goshen Substation, Idaho Sugar Mill Substation, ID 161.01 161.Wood - SP 16. TOTAL 876.100.191 FERC FORM NO.1 (ED. 12-87)Page 422. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 RANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. ~eport Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, fumish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses bome by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for in columns G) to (I) on the book cost at end of year. (;U::i I Ut- LINE (Include In Column (j) Land,EXPENSES, EXCEPT DEPRECIATION AND TAXES Size of Land rights, and clearing right-of-way) Conductor and Material Land Construction and Total Cost Operation Maintenance Rents Total LineOther Costs Expenses Expenses (0)Expenses No.(i)(k)(I)(m)(n) (p) 1272.0 120,94!161 210 282 159 1272.0 26,569,722 595,815 1795.14,92S 920,707 935,635 1271.0 130,191 611 899 742,096 1271.52,90E 131,926 184,832 54.85S 773,80"805 661 1272.0 11"765,256 822,368 54.67,365,224 433,081 1272.58,530,612 588,714 1272 33,00!658,898 691,906 1271.0 48,281 889,759 938,040 1272.0 30,76!924 838 955,607 1272.0 627,42;1 627,434 1272.14,42S 195,868 210,296 272.80C 134,061 138,861 1272.130,166 130,166 1272.294 29C 935,129 229 419 1272.15,46.:15,463 1272.439,682 443,649 1272.847 677 847,677 1272.0 160 129 160,129 1272. 1272.661,277 661 277 1272.707 965 707 965 1272.170,295 170,295 1272.760 523 760,523 1272.508,067 508,067 1272.4,48.1 320 874 325,356 33S 820,071 824,410 430,671 430,671 041 284 041,284 ~97.18,97f 083,716 102,694 397.27,52(466,798 494,318 397.197 100 205,957 397.48,810,721 858,948 79,299,189 362 198,423 441,497,61;1 FERC FORM NO.1 (ED. 12-87)Page 423. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) CiA Resubmission 04130/2003 TRANSMISSION LINE STATIST 1. Report information conceming transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts.Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. IIUN (Indicate w ~~~ ~G~H ~ole wiles)Line Type of ~J:lt e NumberNo.other than u aergroun lines 60 cvcle 3 chase)Supporting report circuit miles) From Operating Designed un ~trl,lCture f~~Th~res CircuitsStructure. Line not er (a)(b)(c)(e)Desl r~ated Ine(d) (g) (h) 1 Sugar Mill Sub., Idaho Rigby Substation, Idaho 161.161.Wood - SP 17. 2 Goshen Substation, Idaho Bonneville Sub., Idaho 161.161.00 Wood - SP-23. 3 Billings, Montana Yellowtail, Montana 161.161.00 H Frame Wood 46. 4 Big Grassy Sub., ID Idaho Power line, ID 161.0(161.00 Wood - H 5 Rigby Sub., Idaho Jefferson Roberts, Idaho 161.161.Wood - SP 18. 6 Thermopolis, Wyoming Wapa Tie Line #2, Wyoming 161.161. 7 Naughton Plant, Wyoming Evanston Substation, WY 138.138.Wood - H 56. 8 Evanston Substation, WY Anschutz Substation, WY 138.138.Wood - H 9 Evanston Substation , WY Anschutz Substation, WY 138.138.Wood - H 10. Naughton Plant, Wyoming Carter Creek Sub., WY 138.138.Wood - H 26. Railroad Sub., Wyoming Carter Creek Sub., WY 138.138.Wood - H 26. Painter Substation, WY Natural Gas Sub., WY 138.138.Wood - H Grace Plant, Idaho Terminal Sub.UT(103-104 138.138.Steel- S 42. Grace Point, ID Terminal Sub, UT (103-138.138.Wood - H 110. Grace Plant, Idaho Terminal Sub., UT (105)138.138.Wood - H 138. Grace Plant, Idaho Soda Plant, Idaho 138.138.Wood - H Oneida Plant, Idaho Ovid Substation, Idaho 138.138.Wood - H 23. Antelope Substation, ID Scoville Sub., Idaho 138.138.Wood - H Soda Plant, Idaho Monsanto Sub., Idaho 138.138.Wood - H Caribou Substation , ID Grace Plant, Idaho 138.138.Wood - H 12. Caribou Substation, ID Becker Substation, Idaho 138.138.Wood - H Treasureton Sub., ID Franklin Sub., Idaho 138.138.Wood - H & SP 10. Franklin Substation, ID Smithfield Sub., Utah 138.138.Wood - H 21.00 Midvalley Substation, UT Thirty South Sub., UT 138.138.Wood - H Angel Substation, UT Smith's UT 138.138.Wood - H Terminal Substation, UT Kennecott Sub., Utah 138.138.Steel - S 11.00 Terminal Substation, UT 30 South Switch Rack, UT 138.138.Steel - S Jordan, UT Terminal Substation, UT 138.138.Wood - H Wheelon Substation, Utah American Falls Sub., UT 138.138.Wood - H 82. Cutler Plant, UT Wheelon Substation, UT 138.138.Wood - H Terminal Substation, UT Helper Substation, Utah 138.138.Wood - H 116. Hale Plant, Utah Nebo Substation, Utah 138.138.Wood - H 48. Carbon Plant, Utah Helper Substation, Utah 138.138.Wood - H Terminal Substation, UT Tooele Substation, Utah 138.138.Wood - H 23. Wheelon Substation, Utah Smithfield Sub., Utah 138.138.Wood - H 18. TOTAL 876.100.191 FERC FORM NO.1 (ED. 12-87)Page 422. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31,2002(2) 0 A Resubmission 04/30/2003 RANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. ~eport Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, fumish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent tor year, and how determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for in columns (j) to (I) on the book cost at end of year. I",U;:' I ur LINE (InClUae In (;Olumn U) Lana,EXPENSES, EXCEPT DEPRECIATION AND TAXES Size of Land rights, and clearing right-of-way) Conductor and Material Land Construction and Total Cost Operation Maintenance Rents Total LineOther Costs Expenses Expenses (0)Expenses No.(i)(k)(I)(m)(n) (p) 97.27,53E 925,353 952,889 54.362,27!807,280 169,559 56.23,361 250,448 273,816 56.26,208 26,208 56.76,301 242,793 319,099 12,306 12,306 95.146,875,641 022,286 95.129,131 473,050 6O2,18C 95.290,803 294,184 95.41,411 588,374 629,785 95.72,62,810 587 883,209 95.12,421 278,836 291,26C 95.765,181 234,821 000,006 95. 1?50.132,96!895 842 028,802 95.28!146 357 149,646 336.410 976 415,793 397.14f 390 538 ~7.55E 109,052 111 607 1795.18,28-'421 186 439,470 ~97.14,42/145,941 160,365 1795.101 509 110 548,211 p97.47,042,458 090,071 193 583 193,583 229 20,229 50.346,819 351,477 00.831 960,134 961 971 666,764,997 2,431 570 50.118,18C 132,238 250,418 50.69,072 69,072 50.458,79~354,433 813 232 97.27,54E 210,878 238,423 54.78E 98,978 99,764 97.801 057 686 062,487 97.188,011 737,230 925,248 79,299,189 362 198,423 441,497 612 FERC FORM NO.1 (ED. 12-87)Page 423. Name of Respondent This '(!prt Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04/30/2003 TRANSMISSION LINE STATIST 1. Report information conceming transmission lines, cost of lir:'es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts.Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121 , Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood , or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. LENG~H ~ole Wiles)Line (Indicate wtier Type of ~~t e SJD Number No.other than ergroun lines 60 ~cle 3 Dhase)Supporting report circuit miles) From Operating Designed On~ure ::;.t~Q1h~res CircuitsStructureof Line of 'tlJot er (a)(b)(c)(e)Desir;ated(d) (g) (h) 1 Helper Substation, Utah Moab Substation, Utah 138.138.Wood - H 115. 2 Ninetieth South Sub, Utah Carbon Plant, Utah 138.138.Wood - H 72.00 3 Terminal Substation, UT Ninetieth South Sub, UT 138.138.Wood - H 16. 4 30 South Switch Rack, UT McClelland Sub., Utah 138.138.Wood - SP 5 Moab Substation, Utah Pinto Substation, Utah 138.138.Wood - H 58. 6 Pinto Substation, Utah Abajo, UT 138.138.Wood - H 44. 7 Carbon Plant, Utah Ashley Substation, Utah 138.138.Wood - H 91.00 8 McClelland Sub., Utah Cottonwood Sub., Utah 138.138.Wood - SP 9 Ashley Substation, Utah Vemal Substation , Utah 138.138.Wood - H 12. Sigurd Substation, Utah West Cedar Substation, U 138.0!138.Wood - H 115. Ben Lomond Sub., Utah EI Monte Substation, UT 138.138.Wood - H 13. Cottonwood Sub., Utah Ninetieth South Sub, Uta 138.138.Wood - SP 11. Terminal Substation, UT Rowley Substation, Utah 138.138.Wood - H 56. Huntington Plant, Utah McFadden Substation, UT 138.138.Wood - H Ben Lomond Sub., Utah EI Monte Substation, UT 138.138.Wood- Cottonwood Sub., Utah Silvercreek Sub., Utah 138.138.Wood - SP 30. Ninetieth South Sub, Utah Taylorsville Sub., Utah 138.138.Wood - SP Gadsby Plant, Utah McClelland Sub., Utah 138.138.Wood - SP Ninetieth South Sub, Utah Oquirrh Substation, Utah 138.138.Wood - SP Nebo, UT Jerusalem, UT 138.138.Wood Tower 24. Ben Lomond Sub., Utah Western Zircon Sub., UT 138.138.Wood - H 14. Tooele Substation, Utah Oquirrh Substation , Utah 138.138.Wood - SP 22. Wheelon Substation, Utah Nucor Steel Sub., Utah 138.138.Wood - H Nebo Substation, Utah Martin-Marietta Sub., UT 138.138.Wood - H 30. West Cedar Sub., Utah Middleton Substation., UT 138.138.Wood - H 80. Gadsby Plant, Utah Terminal Substation , UT 138.138.Wood - H 12. Oquirrh Substation, Utah Kennecott Sub., Utah 138.138.Wood - H Oquirrh Substation, Utah Bamey Substation, Utah 138.138.Wood - HS West Cedar Sub., Utah Pepcon Substation, Utah 138.138.Wood - SP 14. Taylorsville Substation, U Mid-Valley Substation , U 138.138.Steel - SP Warren Substation, Utah Kimberty Clark Sub., UT 138.138.Wood. HP 1.00 Honeyville, Utah Promontory, Utah 138.138.Wood Tower 22. Ninetieth South Sub, Utah Hale Plant, Utah 138.138.Wood Tower 32. Dumas, UT Bimple, UT 138.138.Wood Tower Columbia Sub, Utah Sunnyside Co. Gen., Utah 138.138.Wood Tower TOTAL 876.100.191 FERC FORM NO.1 (ED. 12-87)Page 422. Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) nA Resubmission 04/30/2003 RANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. ~eport Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, fumish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses bome by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for in columns 0) to (I) on the book cost at end of year. COST Of LINt: (InCIUae In (;Olumn 0) Land,EXPENSES, EXCEPT DEPRECIATION AND TAXES Size of Land rights, and clearing right-of-way) Conductor and Material Land Construction and Total Cost Operation Maintenance Rents Total LineOther Costs Expenses Expenses (0)Expenses No.(i)(k)(I)(m)(n) (p) 97.33,961 524 755 558,723 1795.345,83 624 708 970,543 1272.0 429.071 881,715 310,786 1795.181 537 250 599,431 97.40,11!996,661 036,776 97.43,00.927 208 970,210 97.37~665,865 713,239 1795.13,73~239,547 253,280 397.54E 272,179 277,725 97.52,28C 893,139 945,419 95.18,84'704,664 723,509 95.549,06/648,393 197,457 95.222,28!244 295 2,466,581 j97.234,826 235,090 95.901 433,607 458,508 97.177 82~847,104 024,928 95.435,845 441,023 95.56,75!925,859 982,618 95.291 99!1,259,328 551 326 97.253,53!135,086 388,625 1250.96,45 966,828 063,285 t795.252,891 023 817 276,708 95.46,909,120 956,067 97.66,45 772,781 839,233 97.25,141 1,473 512 1,498,660 1272.668,771 810,473 1,479,244 95.201,459 201,459 95.661 440,160 456,828 95.43,59C 085,024 128,614 1272.0 33,46!2,492 894 526,360 97.72.141,422 156,144 97.475,68,874,162 349,844 97.146,42'527,357 673,782 97.136,585 136,585 J97.-41 79,299,189 362,198,423 441,497,612 FERC FORM NO.1 (ED. 12-87)Page 423. Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 TRANSMISSION LINE STATIST CS 1. Report information conceming transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts.Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121 , Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles ot line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. ~~d1~te wher NGJ.~ ~~Ie 6rileS)Line Type of Number No.other than ~~ergroun1rhnes 60 cvcle 3 chase)Supporting report circuit miles) From Operating Designed I un ~tructure qtr~1JWes CircuitsStructureof Lin 0 ~o Desi~a ed Ine (a)(b)(c)(d)(e) (g) (h) 1 Syracuse Sub, Utah Ben Lomond Sub, Utah 138.138.Steel- D- 2 Hale Plant, Utah Midway Sub, Utah 138.138.Wood - H 15. 3 Jordan 138 kv, UT Fifth West 138 kv, UT 138.138.Steel Tower 1.00 4 Gadsby 138 kv, UT Jordan 138 kv, UT 138J)(138.Steel Tower 1.00 5 2-138 kv Riverdale Sub, UT 138 kv Riverdale Sub, UT . 138.138.Steel Tower 6 Panther, UT Willo Creek, UT 138J)(138.Wood Tower 7 Hamer Substaion, UT Butterville Substation, UT 138.138.Wood Tower 8 Midway Substation , UT Silver Creek Sub, UT 138.138.Wood Tower 9 Midway Substation, UT Cottonwood Sub, UT 138.138.Wood Tower Pavant Substaion , UT Delta, UT 138.138.Wood Tower 26. Blundell Substation , UT Milford Substation, UT 138.138.Wood Tower 13. Butlerville Substation, UT Ninety South Sub, Utah 138.138. McFadden Substation, UT Blackhawk Substation , Utah 138.138. All These 115 kV lines 115.115.Wood & Steel 427. All These 69 kV lines 69.69.Wood & Steel 972. All These 57 kV lines 57.57.Wood & Steel 118. All These 46 kV lines 46.46.Wood & Steel 506. Expense Excpt Dep. & Tax TOTAL 14,876.100.191 FERC FORM NO.1 (ED. 12-87)Page 422. Name of Respondent This ~lls:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31,2002 (2) Ei A Resubmission 04/30/2003 RANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. ~eport Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, fumish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for in columns (j) to (I) on the book cost at end of year. \.,;V;) I VI'" LINE (InClUde In Column (j) Land EXPENSES, EXCEPT DEPRECIATION AND TAXES Size of Land rights, and clearing right-of-way) Conductor and Material Land Construction and Total Cost Operation Maintenance Rents Total LineOther Costs Expenses Expenses (0)Expenses No.(i) (j) (k)(I)(m)(n) (p) 1272.353,104 353 104 ~97.246,894,983 141,486 1272.0 078,958 078,974 1272.381,900 382,655 95.76,205 76,205 97.40,890 40,890 188,391 354,585 542,976 755,012 755,012 380,733 380,733 55,43~140,316 195,755 22,50C 771 201 793,701 10,210 10,210 747,470 747,470 510,355 810 031 102,320,386 257 174,068,166 177,325,50E 41,23'379,139 6,420,373 331,71 j 147,296,263 151,627,980 299,189 362,198,423 441,497 612 FERC FORM NO.1 (ED. 12-87)Page 423. Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, 09, Yr)Dec. 31 2002(2) n A Resubmission 0413012003 RANSMISSION LINES ADDED DURING YEAR 1. Report below the intormation called for concerning Transmission lines added or altered during the year.It is not necessary to report minor revisions of lines. 2. Provide separate subheadings tor overhead and under- ground construction and show each transmission line separately. If actual costs of competed construction are not readily available for reporting columns (I) to (0), it is permissible to report in these columns the Line LINE IUN L~~9'th C::I ::; ~IR( Ilrrs PER IIR No.Type A\I~rage Present UltimateFromNumber perMilesMiles (a)(b)(c)(d)(e)(f) (g) Elmonte - UT East Bench - UT Steel ObI. Ck.17. Snow Basin Tap - UT Snow Basin - UT Wood Single Po 17. Terminal - UT West Valley - UT Wood H Frame West Valley - UT Oquirrh - UT Wood H Frame Oregon Basin - WY Pitchfork - WY 24.Wood H Frame Texaco/Huntington Tap - UT TexacolHuntington - UT Wood Single Po 14. 7 Texaco/Orangeville Tap - UT Texaco/Orangeville - UT Wood Single Po 14. TOTAL 48.85. FERC FORM NO.1 (ED. 12-86)Page 424 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04130/2003 TRAN MISSION LINES ADDED DURING YEAR (Continued) costs. Designate, however, it estimated amounts are reported. Include costs of Clearing Land and Rights-of-Way, and Roads and Trails, in column (I) with appropriate footnote, and costs ot Underground Conduit in column (m). 3. It design voltage differs from operating voltage, indicate such tact by tootnote; also where line is other than 60 cycle. 3 phase, indicate such other characteristic. Voltage Line Size Specification conf~uration Land and Poles, Towers Conductors Total No.and pacing (Operating)Land Rights and Fixtures and Devices(h)(i)(k)(I)(m)(n)(0) 1272 MCM ACSR Vertical 10' 000 932,000 400,000 337 000 397.5 MCM ACSR Vertical 6'10,000 252,000 90,000 352,000 1557 MCM ACSRITW Horiz. 10'138 300,000 1,400,000 600,000 300,000 1557 MCM ACSRITW Horiz. 10'138 350,000 874,000 700,000 924 000 397.5 MCM ACSR Horiz. 8'600,000 348,000 800,000 748,000 397.5 MCM ACSR Vertical 000 246,632 50,000 316,632 397.5 MCM ACSR Vertical 30,000 456,193 100,000 586 193 315,OO(508,825 740,000 563,825 FERC FORM NO.1 (ED. 12-86)Page 425 Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002 (2) CiA Resubmission 04/3012003 SUBSTATIONS 1. Report below the information called for concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy tor resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the tunctional character ot each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) CALIFORNIA BIG SPRINGS Distribution - Unat 69.12. CANBY # 2 Distribution - Unat 69. CLEAR LAKE Distribution - Unat 69.12. CRESCENT CITY Distribution - Unat 12. FILKINS Distribution - Unat 12. GASQUET Distribution - Unat 69. GOOSE LAKE Distribution - Unat 69. HAMBURG Distribution - Unat 69. HAPPY CAMP Distribution - Unat 69.12. HORNBROOK Distribution - Unat 69.12. LAKE EARL Distribution - Unat 69.12. LITTLE SHASTA Distribution - Unat 69. LUCERNE Distribution - Unat 69.12. MACDOEL Distribution - Unat 69.20.12. MILLER REDWOOD Distribution - Unat 69.13. MONTAGUE Distribution - Unat 69.12. NUTGLADE Distribution - Unat 69. PATRICKS CREEK Distribution - Unat 69. PEREZ Distribution - Unat 69.12. SCOTT BAR Distribution - Unat 69.12. SEIAD Distribution - Unat 69.12. SHASTINA Distribution - Unat 115.20. SHOTGUN CREEK Distribution - Unat 69.12. SIMONSON Distribution - Unat 69.12. SMITH RIVER Distribution - Unat 69.12. SNOW BRUSH Distribution - Unat 69. SOUTH DUNSMUIR Distribution - Unat 69. TULELAKE Distribution - Unat 69.12. WALKER-BRYAN Distribution - Unat 69.12. YUBA Distribution - Unat 69.12. YUROK Distribution - Unat 69.12. TOTAL 2071.312.16. NUMBER OF SUBSTATIONS DISTRIBUTION - 31 COPCO #2 T/D - Attended 115.69. AL TURAS T/D - Unattended 115.69.12. BELMONT T/D - Unattended 69.12. CASTELLA T/D - Unattended 69. DOG CREEK T/D - Unattended 69. FERC FORM NO.1 (ED. 12-96)Page 426 Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 04/30/2003 SUBSTATIONS (Continued) 5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc.and auxiliary equipment for increasing capacity. 6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name ot lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company. Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line (In Service) (In MVa)Transformers Spare Type of Equipment Total Capacity No.In Service Transformers Number of Units (In MVa) (f) (g) (h)(i) (j) (k) 158 FERC FORM NO.1 (ED. 12-96)Page 427 Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 04130/2003 SUBSTATIONS 1. Report below the intormation called tor concerning substations of the respondent as of the end of the year. 2. Substations which serve only one industrial or street railway customer should not be listed below. 3. Substations with capacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. 4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end ot the page, summarize according to function the capacities reported for the individual stations in column (t). Line VOLTAGE (In MVa) No.Name and Location of Substation Character of Substation Primary Secondary Tertiary (a)(b)(c)(d)(e) DORRIS T/D - Unattended 69.12. FT. JONES TID - Unattended 69.12. GREEN HORN TID - Unattended 69.12. MC CLOUD TID - Unattended 12.69. MT SHASTA T/D - Unattended 69.12. NEWELL T/D - Unattended 69.12. NORTH DUNSMUIR T/D - Unattended 69.12. NORTHCREST T/D - Unattended 69.12. REDWOOD T/D - Unattended 69.12. TUNNEL TID - Unattended 69.12. WEED T/D - Unattended 69.12. YREKA T/D - Unattended 115.69.12. TOTAL 1136.406.173. NUMBER OF SUBSTATIONS TID - 17 COPCO #1 HE PLANT Transmission - Atte 69. FALL CREEK Transmission - Atte 2.40 69. IRON GATE Transmission - Atte 69. AGER Transmission - Unat 115.69. COPCO" 230 KV Transmission - Unat 230.115. COPCO #2 HE PLANT Transmission - Unat 69. CRAG VIEW Transmission - Unat 115.69. DEL NORTE Transmission - Unat 115.69. FALL CREEK HE PLANT Transmission - Unat 69. INTERNATIONAL PAPER Transmission - Unat 69. WEED JUNCTION Transmission - Unat 115.69. TOTAL 779.738. NUMBER OF SUBSTATIONS TRANSMISSION - 11 IDAHO MUD LAKE Distribution 69.12. LAVA Distribution - Atte 46.12. ALEXANDER Distribution - Unat 46.12. AMMON Distribution - Unat 69. ANDERSON Distribution - Unat 69. ARCO Distribution - Unat 69.12. ARIMO Distribution - Unat 43.12. BANCROFT Distribution - Unat 46.12. BELSON Distribution - Unat 69.12. BERENICE Distribution - Unat 69.25. FERC FORM NO.1 (ED. 12-96)Page 426. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2) CiA Resubmission 04/30/2003 SALES FOR RESALE (Account 447) (Continued) OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column 0). Explain in a footnote all components of the amount shown in column 0). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401 , line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401 iine 24. 10. Footnote entries as required and provide explanations following all required data. MegaWatt Hours REVENUE Total ($)Line Sold Demand Charges Energy Charges Other Charges (h+i+j)No. ($)($)($)(g) (h)(i)(k) 214 094 13,000 46,753 217 844 338,492 045 716,840 740 885 14,464 459 641 459 641 80,600 422 216 2,422 216 800 220,900 220,900 169 531 531 893 96,661 661 870 632,000 001,460 633,460 132 446 583,850 102 484 686 334 956 141,718 141 718 23,024 770,374 770,374 80,160 121 000 186 368 307 368 464 280 856 960 856 960 198 901 880,486 172 473 135 213 188 172 30,334 565 114 731 005 956 769 059 106 582 907 964 917 157 30,533 466 117,611,491 960 941,532 106,447,694 972,105,329 FERC FORM NO.1 (ED. 12-90)Page 311. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2) CiA Resubmission 04/3012003 SALES FOR RESALE (Account 447) 1. Report all sales for resale (Le., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Line Name of Company or Public Authority Statistical FERC Rate Avera Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly iIIing Avera Avera cation Tariff Number Demand (MW)Monthly NC Deman Monthly CP mand (a)(b)(e)(d)(e)(f) Western Area Power Administration WSPP Western Area Power Administration WSPP Williams Energy Services Co.WSPP Williams Energy Services Co.WSPP Accrual adjustment Subtotal RQ Subtotal non- Total FERC FORM NO.1 (ED. 12-90)Page 310. Name of Respondent This ~ort Is:Date of Report Year of Report PaeifiCorp (1) X An Original (Mo, Da, Yr)Dee. 31 2002(2) n A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) (Continued) OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401 , line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401 ,iine 24. 10. Footnote entries as required and provide explanations following all required data. MegaWatt Hours REVENUE LineTotal ($) Sold Demand Charges Energy Charges Other Charges (h+i+j)No. ($)($)($)(g) (h)(i)(k) 53,045 514 975 514 975 275 214 730 714 730,714 150 300 300 572,934 13,887 084 13,887 084 19,966 ':' 625,895 198,901 880 486 172,473 135 213 188 172 334,565 114 731 005 956,769,059 106,582,907 964 917 157 30,533,466 117 611 491 960,941,532 106,447 694 972 105,329 FERC FORM NO.1 (ED. 12-90)Page 311. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Ei A Resubmission 04/30/2003 ELECTRIC OPERATION AND MAINTENANCE EXPENSES If the amount for previous year is not derived from previously reported figures, explain in footnote. Line Account IiiIIiiiINo.urrent ear PrevIous ear (a)(b) (e) 1. POWER PRODUCTION EXPENSES A. Steam Power Generation Operation (500) Operation Supervision and Engineering 454 230 790,828 (501) Fuel 416,893,788 458,552,629 (502) Steam Expenses 20,588,036 823,036 (503) Steam from Other Sources 818 690 084,109 (Less) (504) Steam Transferred-Cr. (505) Electric Expenses 278,101 896,069 (506) Miscellaneous Steam Power Expenses 778 525 770,811 (507) Rents 719,202 420 534 (509) Allowances TOTAL Operation (Enter Total of Lines 4 thru 12)501 530 572 572,338,016 Maintenance (510) Maintenance Supervision and Engineering 850,450 300,999 (511) Maintenance of Structures 004 614 599,236 (512) Maintenance of Boiler Plant 79,596,829 70,662,236 (513) Maintenance of Electric Plant 128 131 421 569 (514) Maintenance of Miscellaneous Steam Plant 673,206 295,689 TOTAL Maintenance (Enter Total of Lines 15 thru 19)138,253,230 122 279 729 TOTAL Power Production Expenses-Steam Power (Entr Tot lines 13 & 20)639 783 802 694,617 745 B. Nuclear Power Generation Operation (517) Operation Supervision and Engineering (518) Fuel (519) Coolants and Water (520) Steam Expenses (521) Steam from Other Sources (Less) (522) Steam Transferred-Cr. (523) Electric Expenses (524) Miscellaneous Nuclear Power Expenses (525) Rents TOTAL Operation (Enter Total of lines 24 thru 32) Maintenance (528) Maintenance Supervision and Engineering (529) Maintenance of Structures (530) Maintenance of Reactor Plant Equipment (531) Maintenance of Electric Plant (532) Maintenance of Miscellaneous Nuclear Plant TOTAL Maintenance (Enter Total of lines 35 thru 39) TOTAL Power Production Expenses-Nuc. Power (Entr tot lines 33 & 40) C. Hydraulic Power Generation Operation (535) Operation Supervision and Engineering 353,922 695 974 (536) Water for Power 842 (537) Hydraulic Expenses 720 545 682 757 (538) Electric Expenses (539) Miscellaneous Hydraulic Power Generation Expenses 17,623,450 586 121 (540) Rents 942 155,029 TOTAL Operation (Enter Total of Lines 44 thru 49)055,857 119 881 FERC FORM NO.1 (ED. 12-93)Page 320 Name of Respondent This ~rt Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04/30/2003 ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued) If the amount for previous year is not derived from previously reported figures, explain in footnote. Line Account \10. urrent ear PrevIous ear (a)(b) (e) C. Hydraulic Power Generation (Continued) Maintenance (541) Mainentance Supervision and Engineering 345 98,498 (542) Maintenance of Structures 763,439 644,627 (543) Maintenance of Reservoirs, Dams, and Waterways 2,480,357 777,463 (544) Maintenance of Electrie Plant 228,423 919,984 (545) Maintenance of Miscellaneous Hydraulic Plant 038,194 772 960 TOTAL Maintenance (Enter Total of lines 53 thru 57)517,758 213 532 TOTAL Power Production Expenses-Hydraulic Power (tot of lines 50 & 58)26,573,615 23,333,413 D. Other Power Generation Operation (546) Operation Supervision and Engineering (547) Fuel 60,566,484 45,330 542 (548) Generation Expenses 631,383 769,939 (549) Miscellaneous Other Power Generation Expenses 539,118 302 871 (550) Rents 900,212 348 576 TOTAL Operation (Enter Total of lines 62 thru 66)79,637 197 52,751 928 Maintenance (551) Maintenance Supervision and Engineering 023 (552) Maintenance of Structures (553) Maintenance of Generating and Electric Plant 943 (554) Maintenance of Miscellaneous Other Power Generation Plant 167 TOTAL Maintenance (Enter Total of lines 69 thru 72)43,133 TOTAL Power Production Expenses-Other Power (Enter Tot of 67 & 73)680,330 751 928 E. Other Power Supply Expenses (555) Purehased Power 905 522 159 260 192 525 (556) System Control and Load Dispatching 117,111 465,245 (557) Other Expenses 42,450,052 -67 783 447 TOTAL Other Power Supply Exp (Enter Total of lines 76 thru 78)948,089 322 192,874 323 TOTAL Power Production Expenses (Total of lines 21 74 & 79)694 127 069 963 577,409 2. TRANSMISSION EXPENSES Operation (560) Operation Supervision and Engineering 309,128 384,568 (561) Load Dispatching 279,937 355 000 (562) Station Expenses 104,258 076 839 (563) Overhead Lines Expenses 695 753 937,413 (564) Underground Lines Expenses (565) Transmission of Electricity by Others 76,949,453 94,737 373 (566) Miscellaneous Transmission Expenses 1,492 444 358,298 (567) Rents 690,935 170 546 TOTAL Operation (Enter Total of lines 83 thru 90)89,521,908 106 678,945 Maintenance (568) Maintenance Supervision and Engineering 646 622 (569) Maintenance of Structures 396 422 381 (570) Maintenance of Station Equipment 746,774 935,168 (571) Maintenance of Overhead Lines 076,751 144 298 (572) Maintenance of Underground Lines (573) Maintenance of Miscellaneous Transmission Plant 151 732 TOTAL Maintenance (Enter Total of lines 93 thru 98)896,718 16,534,247 100 TOTAL Transmission Expenses (Enter Total of lines 91 and 99) 101 3. DISTRIBUTION EXPENSES 102 Operation 103 (580) Operation Supervision and Engineering 517 580 22,869 598 FERC FORM NO.1 (ED. 12-93)Page 321 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued) If the amount for previous year is not derived from previously reported figures, explain in footnote. Line Account No.urrent ear PrevIous ear (a)(b) (e) 104 3. DISTRIBUTION Expenses (Continued) 105 (581) Load Dispatehina 125,339 5 946,416 106 (582) Station Expenses 1,435,139 546,586 107 (583) Overhead Line Expenses 365,876 13,882,859 108 (584) Underground Line Expenses 619,960 228,725 109 (585) Street Lighting and Signal System Expenses 110 (586) Meter Expenses 842 846 254,415 111 (587) Customer Installations Expenses 28,592 33,665 112 (588) Miscellaneous Expenses 186,686 894 696 113 (589) Rents 060 893 348,851 114 TOTAL Operation (Enter Total of lines 103 thru 113)23,774,379 54,005,811 115 Maintenance 116 (590) Maintenance Supervision and Engineering 316,692 369,221 117 (591) Maintenance of Structures 118 (592) Maintenance of Station Equipment 463,616 081 114 119 (593) Maintenance of Overhead Lines 770 709 976 551 120 (594) Maintenance of Underground Lines 731,119 15,207 036 121 (595) Maintenance of Line Transformers 122 (596) Maintenance of Street Lighting and Signal Systems 744,375 014 379 123 (597) Maintenance of Meters 2,428 894 844 240 124 (598) Maintenance of Miscellaneous Distribution Plant 861 875 -6,973,510 125 TOTAL Maintenance (Enter Total of lines 116 thru 124)593,530 68,519,031 126 TOTAL Distribution Exp (Enter Total of lines 114 and 125)103 367 909 122 524 842 127 4. CUSTOMER ACCOUNTS EXPENSES 128 Operation 129 (901) Supervision 604,939 666 770 130 (902) Meter Readina Expenses 17,906,601 18,942,399 131 (903) Customer Records and Collection Expenses 316,529 36,499,802 132 (904) Uncollectible Accounts 20,912 788 17,152,475 133 (905) Miscellaneous Customer Accounts Expenses 358,335 507 343 134 TOTAL Customer Accounts Expenses (Total of lines 129 thru 133)099 192 85,768,789 135 5. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES 136 Operation 137 (907) Supervision 138 (908) Customer Assistance Expenses 093 855 837 698 139 (909) Informational and Instructional Expenses 614 392 439 738 140 (910) Miscellaneous Customer Service and Informational Expenses 352 157 674 581 141 TOTAL Cust. Service and Information. Exp. (Total lines 137 thru 140)060,404 952,027 142 6. SALES EXPENSES 143 Operation 144 (911) Supervision 24,677 197 145 (912) Demonstrating and Selling Expenses 146 (913) Advertising Expenses 1 ,439 669 147 (916) Miscellaneous Sales Expenses 536,479 950 749 148 TOTAL Sales Expenses (Enter Total of lines 144 thru 147)513 313 990 615 149 7. ADMINISTRATIVE AND GENERAL EXPENSES 150 Operation 151 (920) Administrative and General Salaries 125,892 586 072 996 152 (921) Office Supplies and Expenses 24,497 102 013,390 153 (Less) (922) Administrative Expenses Transferred-Credit 251,881 31,421,183 FERC FORM NO.1 (ED. 12-93)Page 322 Name of Respondent PacifiCorp Year of Report Dee. 31 2002 This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/30/2003 ELECTRIC OPERATION AND MAINTENANCE PENSES (Continued) If the amount for previous year is not derived from previously reported figures, explain in footnote.Line Account Amount for 154 7. ADMINISTRATIVE AND GENERAL EXPENSES (Continued) 155 (923) Outside Services Employed 156 (924) Property Insurance 157 (925) In uries and Damages 158 (926) Employee Pensions and Benefits 159 (927) Franchise Requirements 160 (928) Regulatory Commission Expenses 161 (929) (Less) Duplicate Charges-Cr. 162 (930.1) General Advertisin Expenses 163 (930.2) Miscellaneous General Expenses 164 (931) Rents 165 TOTAL Operation (Enter Total of lines 151 thru 164) 166 Maintenance 167 (935) Maintenance of General Plant 168 TOTAL Admin & General Expenses (Total of lines 165 thru 167) 169 TOTAL Elec Op and Maint Expn (Tot 80 100 126 134 141 148 168) AmountforPrevious Year (e) 45,778,089 19,899,367 879 772 679 066 532 780,842 12,556,429 334 451 925 208 843,900 970,152 52,410 216 012,396 260,169 786 8,439,902 747 993 021,479 172 211 077 285 177 697,439 17,225,008 277 394 794 270,981 307 931 117 180,628,556 502 655 430 FERC FORM NO.1 (ED. 12-93)Page 323 Name of Respondent This ~ort Is:Date of Report Year of Report PaeifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 PU~CHA~ED POWER JAccount 555)(nclu 109 power ex anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition , the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service , aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman I Monthly CP Demand (a)(b)(c)(d)(e)(f) 1 Power Purehases Allegheny Energy Supply Company, LLC 3 American Electric Power 4 Anaheim, City of 5 Anaheim, City of 6 Aquila Merchant Services, Ine. 7 Aquila Merchant Services, Inc. 8 Arizona Public Service Co. 9 Arizona Public Service Co. Arizona Publie Service Co. Arizona Public Service Co. Associated Food Stores Avista Corp.150 136 107 Avista Corp. Total FERC FORM NO.1 (ED. 12-90)Page 326 Name of Respondent PacifiCorp Date of Report (Mo, Da, Yr) 04/3012003 Year of Report Dee. 31 2002 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines , list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401 , line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. POWER EXCHANGESMegaWatt Hours Purchased MegaWatt Hours MegaWatt HoursReceived Delivered (g) (h) (i) Demand Charges ($) COST/SETTLEMENT OF POWER Energy Charges Other Charges ($) ($) (k) (I) 307 131 257 202 521 109 115 043 000 31,418 353 485 589 198 082 122,932 184 998 562 919 215,972 944 FERC FORM NO.1 (ED. 12-90)Page 327 LineTotal O+k+l) No.of Settlement ($) (m) 932 667 890,446 000 077 755 750 000 34,113 027 615 560 150 975 -48 164 337,421 98,520 905 522 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dee. 31 2002 (2) CiA Resubmission 04/30/2003 PU~CHA~ED POWER JAccount 555)(nclu 109 power ex anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Aetual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman!Monthly CP Demand (a)(b)(e)(d)(e)(f) 1 Avista Corp. 2 Avista Energy, Inc. 3 Avista Energy, Inc.III4 Beaver City Bell Mountain Power 6 Benton County Public Utility District 7 Biomass One, loP.22.23.17. 8 Birch Creek Hydro 9 Black Hills Power & Light Company Black Hills Power & Light Company Blaek Hills Power & Light Company Black Hills Power & Light Company 11. Bogus Creek Boise Cascade Corporation Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) nA Resubmission 04130/2003 ccou ::!::!::!L (l;ontinued)!lnCludlng power exe anges) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff. or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401, line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total G+k+l)No. Received Delivered ($)($) of Settlement ($) (g) (h)(i)(I)(m) 97!790 27C 790 270 115 09!570,24~570,249 100 676 26!534 66,287 48E 115,98-115,984 95,02:055 700 238, '......" 15,241 700 767 636 366 220,74(857 106 108 321 73,74~742 263 57.722 06/722 067 450 000 :;: 2~'Zi 430 677,430 15E 21E 34,216 554 31,418,353 15,485 589 15,198 082 122,932 184 998,562,919 215 972 944 905 522,15! FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002(2) n A Resubmission 04/30/2003 PU~CH~ED POWERchAccou~t 555)(nel Ing power ex anges 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(e)(d)(e)(f) 1 Bonneville Power Administration 925 925 815 Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration 5 Bonneville Power Administration 6 Bonneville Power Administration 7 Boston Power 8 Boston Power Boyd, James Boyd, James BP Energy Company BP Energy Company BP Energy Company Burbank, City of Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dee. 31,2002(2) riA Resubmission 0413012003 ecou H\~g~~~ (Continued)Tlneludlng power exe ange ) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (50-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column (j), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total G+k+l)No. Received Delivered ($)($)($) of Settlement ($) (g) (h)(i)(k)(I)(m) 719 000 719,000 404 404 542 080 690 255 050 553,291 484 205 484 205 261 999 19,42 34,269 181 72..51,66E 668 211 16,722 311 99~;:3;872 10,866 336 769 52~743 82~743,822 800 800 800 31,418,353 15,485,589 15,198 082 122 932 184 998 562 919 215 972 944 905,522 159 FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PaeifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 ~CHA~ED POWER hAccount 555) (nelu Ing power exe anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman ~ Monthly CP Demand (a)(b)(c)(d)(e)(f) Burbank, City of Califomia Independent System Operato Carbon Fiber Teehnology LLC CDM Hydro Central Oregon Irrigation District Chelan County Public Utility District Chelan County Public Utility District 8 Chelan County Public Utility District ~;C:"':" 9 Chelan County Public Utility District City of Buffalo Colorado Springs Utilities Columbia Storage Power Exchange ..'::""" Commercial Energy Management Commercial Energy Management :":. Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2) CiA Resubmission 04130/2003 cco~~~~~i\ (Continued)(lneludlng power ex anges) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges , report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401 , line 10. The total amount in column (h) must be reported as Exchange Received on Page 401, line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purehased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total O+k+l)No. Received Delivered ($)($)($) of Settlement ($) (g) (h)(i)(k)(I)(m) 34~295 28~295 283 091 115 831 115 831 23,06~925 748 322 901 248,655 15,46C 286 804 202 75'1,489,559 341 963 291 324 68,070 0(350 20,350 77,20C 011 500 011,500 1 ,79~20,355 43,05;,63,407 23~96;,962 79,001 1,45;,667 745 74,416 544 31,418,353 15,485 589 15,198,082 122,932 184 998,562 919 215,972 944 905,522,159 FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04130/2003 PU~CHA~ED POWER hAccount 555) (nelu 109 power exe anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. ,Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition , the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman~Monthly CP Demand (a)(b)(c)(d)(e)(f) 1 ConAgra Energy Services, Inc. Conoco Inc.9$':. Conoco Inc. Constellation Power Source, Inc. Constellation Power Source, Ine. Coral Power Curtiss Livestock Davis County Waste Management Davis County Waste Management Deschutes Valley Water District Deseret Generation & Transmission !'*R, ". Deseret Generation & Transmission Desert Power, loP. Douglas County Public Utility District Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dee. 31 2002 (2) CiA Resubmission 04/30/2003 CCOU R\~gg~~ (l;onttnUeo) ~ .-. . Oneludtng power exc ange ) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours , of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m). the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I)include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401 , line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401, line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total G+k+l)No.Received Delivered ($)($)($) of Settlement ($) (g) (h)(i)(k)(I)(m) 80C 767 09C 767 090 80C 60C 24,600 21 ,702. 082 775,86"22,477 444 378,821 543 39€543,398 12~18€186 21€951 35,951 ~'" 310 26,09€354 918 296 48€651 404 251 44(544 55f 544 558 33,981 -483,534 78,38'592 1 O~592 105 077 134,80.134 802 418,353 485 589 198,082 122 932 184 998,562 919 215,972 944 905,522, 15~ FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dee. 31 2002 (2) n A Resubmission 04/30/2003 ~CH~ED POWER hAccount 555)(nelu 109 power exe anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(e)(d)(e)(f) 1 Douglas County Public Utility District 2 Douglas County Public Utility District --:,)~~ 3 DR Johnson Lumber Company 4 DR Johnson Lumber Company ",.. ':/' 5 Dry Creek 6 Duke Energy Trading & Marketing, LLC r\~' ::':;,,::: 'ye; 7 Duke Energy Trading & Marketing, LLC 8 Eagle Point Irrigation District 9 Eagle Point Irrigation District f\QwK"'c'VAA' EI Paso Electric Company ..: EI Paso Electric Company EI Paso Energy Marketing Co. :". :'C' ' :"':' EI Paso Energy Marketing Co. EI Paso Energy Marketing Co. Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/3012003 ccouHt..=:!:!L (l'ontlnuec)(inCludlng power exc anges) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received , enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total G+k+l)No.Received Delivered ($)($)($) of Settlement ($) (g) (h)(i)(k)(I)(m) 266 27'168,088 72C 1 ,300,45~300,454 64,501 783,495 578,08~361 584 :AA(,131 96E 201 975 83,531 285,506 33C 330 550,49c 442 'i,17,433,324 903 581 267 16~304 743 ):, , 780 091 266 22~266 224 26C 260 15C 02~025 :;:;:i:/~'-480 1 ,556 39C 737,41C 370 970 31,418 353 15,485 589 198,082 122 932,184 998 562,919 215 972,944 905,522 159 FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dee. 31,2002(2) riA Resubmission 04/30/2003 PU~Ccr;~ED POWER hAccount 555)(n u 109 power exc anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Publie Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(c)(d)(e)(f) 1 Enron Power Marketing, Inc. Entergy-Koch Trading, loP. Eugene Water & Electric Board Exelon Power Team Exelon Power Team ItJ,:;t;. Falls Creek Falls Creek 7)17, Farmers Irrigation District Fery, Loyd Fillmore City ~/;: Franklin County Public Utilities Dist Galesville Dam Garland Canal General Chemical Corporation Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) riA Resubmission 04/30/2003 ~\~gg~\ (l,;ontlnued)(lneludJng powerexc ange ) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) mustbe in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401 , line 10. The total amount in column (h) must be reported as Exchange Received on Page 401, line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total G+k+l)No. Received Delivered ($)($) of Settlement ($) (g) (h)(i)(I)(m) 2,41. 144 60!O66,94!066,940 81!895 00.895,06~ 60C 231 80!231 800 72~1 OC 100 85f 179,431 169 601 349 032 1 ,44~,,:c. :.. 131 996 70.330 539 934 2Df 264 744 281 44'445 16C 19,68C 19,680 2,4H 48,48,443 38~192 332,191 367,383 191 111 446 293,28~404 731 68C 03.25,032 31,418,353 15,485,589 15,198,082 122 932 184 998,562 919 215,972 944 905,522, 15~ FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PaeifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 ~CHAd1ED POWER hAccou~t 555)(nCiu Ing power exc anges 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(c)(d)(e)(f) 1 General Chemical Corporation Geneva Steel Corporation Geneva Steel Corporation Georgetown Power 5 Grand Valley Power I Lr':; 6 Grant County Public Utility District ::17 Grant County Public Utility District 8 Grant County Public Utility District 9 Grant County Public Utility District Grant County Public Utility District Grant County Public Utility District We;''if: Grant County Public Utility District Grays Harbor Public Utility District Great Salt Lake Minerals Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent PacifiCorp Date of Report (Mo, Da, Yr) 04/30/2003 Year of Report Dee. 31 2002 This ~ort Is:(1) l!SJAn Original(2) A Resubmission ccount Ineludmg po er exchange) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. POWER EXCHANGESMegaWatt Hours Purchased MegaWatt Hours MegaWatt HoursReceived Delivered (g) (h) (i) COST/SETTLEMENT OF POWER Energy Charges Other Charges ($) ($) (k) (I) Demand Charges ($)(j) 234 155 092 31,418,353 15,485,589 198 082 122 932 184 998,562 919 215,972 944 FERC FORM NO.1 (ED. 12-90)Page 327. LineTotal (j+k+l) No.of Settlement ($) (m) 190 445 80,529 364 966,784 189,492 229,062 249 066 285,472 670 202 802 276 380 333 905 522, Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002 (2) Fi A Resubmission 04/30/2003 ~CHA~ED POWER hAccount 555) (nelu 109 power exc anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman ' Monthly CP Demand (a)(b)(e)(d)(e)(f) Green Mountain Energy Company Heber Light & Power Company Hermiston Generating Company, loP. Hermiston Generating Company, loP.242 242 181 Hinson Power Company, LLC Hurricane, City of IdaCorp Energy 8 Idaho Falls, City of 9 Idaho Falls, City of Idaho Power Company Idaho Power Company IGI Resouces, Inc. Ingram Warm Springs Raneh Intermountain Power Project Total FERC FORM NO.1 (ED. 12-90)Page 326. This ~ort Is: (1) I!JAn Original (2) A Resubmission ccountneludlng power exChanges) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. Name of Respondent PacifiCorp Date of Report (Mo, Da, Yr) 04130/2003 Year of Report Dec. 31 2002 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total O+k+l)No. Received Delivered ($)($)($) of Settlement ($) (g) (h)(i)(k)(I)(m) 86,739 258 075 94,047 861 379 648 292 242 239 717 236 236 977 445 752 399,379 34,080,088 118,411 341 350 878 122,301 403,536 31,418,353 15,485,589 15,198 082 122 932 184 998,562 919 215,972,944 905,522, FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PaeifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2) CiA Resubmission 04/30/2003 PU~CHA~ED POWER hAccount 555) (nelu Ing power exc anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Publie Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman I Monthly CP Demand (a)(b)(c)(d)(e)(f) Kennecott Kennecott Lacomb Irrigation Lacomb Irrigation '" .,,;, Lake Siskiyou La-Boy Manufacturing Los Angeles Dept. of Water & Power Los Angeles Dept. of Water & Power ;;), h;/(, Luckey, Paul Magnesium Corporation of America Marsh Valley Hydro & Electric Company Marsh Valley Hydro & Electric Company ,4r;). Metropolitan Water District Middlefork Irrigation District Total FERC FORM NO.1 (ED. 12-90)Page 326. This ~ort Is:(1) ~An Original (2) A Resubmission ccoun In udlng power exehanges) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. Date of Report (Mo, Da, Yr) 0413012003 Year of Report Dec. 31 2002 Name of Respondent PacifiCorp 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401 , line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total fj+k+l)No. Received Delivered ($)($) of Settlement ($) (g) (h)(i)fj)(I)(m) 517 997 126 685 115,115,913 854 284,800 931 555 139 36,180,43 732 569 463 542 528 341 341 920,45 920,455 135 284 46,182,060 200 178,225 117,485 418 353 15,485,589 198,082 122 932 184 998,562 919 215 972 944 905 522, FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2) CiA Resubmission 04130/2003 PU~CHA~ED POWER hAccount 555) (nclu Ing power exc anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Sehedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(e)(d)(e)(f) MIECO, Inc. Mink Creek Hydro Mink Creek Hydro Mirant Americas Energy Marketing, loP Modesto Irrigation District Monsanto Morgan City Morgan Stanley Capital Group, Inc. Morgan Stanley Capital Group, Ine.100 Morgan Stanley Capital Group, Inc. Mountain Energy Municipal Energy Agency of Nebraska Murray City Nephi City Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent This ~ort Is:Date of Report Year of Report PaeifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002 (2) CiA Resubmission 04/30/2003 .-. ccou~~~~~L. (Continued)(iriCludlng power exc anges) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401 , line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total O+k+l)No.Received Delivered ($)($)($) of Settlement ($) (g) (h)(i)(k)(I)(m) 124 57,093,45 093,452 67~252 882 93,51"346 394 ~""" -456 537 981 492 73f 492,738 13C 64,40C 64,400 h\:091,747 340 340 1,736 070 60,413,138 60,413 138 000 740 000 440 000 180 000 814 814 333 333 46"33,905 33,905 040 040 683 683 31,418 353 15,485 589 198,082 122 932 184 998 562 919 215,972,944 905,522 15~ FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 04/30/2003 6ru~ED POWER hAccount 555)n u Ing power exc anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(c)(d)(e)(f) 1 Nevada Power Company 2 Nevada Power Company 3 Newspaper Agency Corp. 4 Nicholson Sunnybar Ranch 5 North Fork Sprague 6 Northem California Power Agency 7 Nucor Corporation 8 O.J. Power Company 9 Odell Creek Oregon Metallurgical Corporation Ormsby, Leslie Pacific Northwest Generating Cooperat Pancheri, Inc. Payson City Corporation Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dee. 31 2002(2) nA Resubmission 04/30/2003 ccou ~~~L (t,;ontlnUed)71neludmg power exc anges) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses , or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401 , line 10. The total amount in column (h) must be reported as Exchange Received on Page 401, line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401, line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total O+k+l)No.Received Delivered ($)($)($) of Settlement ($) (g) (h)(i)(k)(I)(m) 798 867 134 867 134 137 875 317 82'i 317,825 ,d." "';","", 1 ,579 598 85,002 1 ,79E 814 163,41~189 227 20C 60C 600 1;~;Oqo 239 000 31~132 4,408 13,540 27~314 975 25,289 47€550,O4~549 199 451 451 06€29E 75,296 275 54'818 1,46 """;:"'\:' ;ii/!~1 ,631 31,418,353 15,485,589 15,198,082 122 932 184 998 562 919 215 972 944 905 522 15~ FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dee. 31 2002(2) n A Resubmission 04/30/2003 PU~CHA~ED POWER hAccount 555)(nclu mg power exe anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(c)(d)(e)(f) Pinnacle West Capital Corporation 2 Pinnacle West Capital Corporation 3 Portland General Electric Portland General Electric (;)Sj~ i, 5 Portland General Electric Powerex I""-~ , '/":' C', Powerex PPL Energy Plus, LLC PPL Montana, LLC PPL Montana, LLC Praxair Preston City Hydro Prineville Energy, LLC Prineville Energy, LLC Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 ccou ~~~L (Continued)(Ineludmg power exe anges) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total fj+k+l)No. Received Delivered ($)($)($) of Settlement ($) (g) (h)(i)(k)(I)(m) 1,470 59'39,593 1 OE 39,593 106 89,63f 253,253 077 780,731,79f 19,731 795 625 0Qi:183.003F\,'" 4OE 119, ':, i,Y'119 525i;' 762 91€997 52E 20,997 526 24~897 52~82,78C 780 625 828,20E 828 206 "if"597 61E 121 36,62E 128,747 12~51C 510 ;::: 1 0 096 31,418,353 485,589 15,198,082 122,932 184 998 562,919 215,972 944 905,522 159 FERC FORM NO.1 (ED. 12-90)Page 327. This ~rt Is: (1) l!JAn Original (2) A Resubmission PURCHASED POWER (Account 555)(Including power exchanges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: Name of Respondent PacifiCorp Date of Report (Mo, Da, Yr) 04/30/2003 Year of Report Dec. 31, 2002 RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. os - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line No. Name of Company or Publie Authority (Footnote Affiliations) (a) Statistical Classifi- cation (b) 1 Provo City 2 Public Service Company of Colorado 3 Publie Service Company of Colorado 4 Public Service Company of New Mexico 5 Publie Service Company of New Mexico 6 Puget Sound Energy 7 Puget Sound Energy 8 Ralphs Ranch, Inc. 9 Redding, City 10 Redding, City of 11 Reliant Energy Services, Inc. 12 Reliant Energy Services, Inc. 13 Riverside, City of 14 Riverside, City of Total FERC FORM NO.1 (ED. 12-90) FERC Rate Sehedule or Tariff Number (e) Actual Demand (MW)verage Average Monthly NCP Deman Monthly CP Demand(e) . (f) Average Monthly Billing Demand (MW) (d) Page 326. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2) CiA Resubmission 04130/2003PI CCO gRt ~~~L (Continued) ,~, ' (ineludfng power ex anges) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be In megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401 , line 10. The total amount in column (h) must be reported as Exchange Received on Page 401, line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401, line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purehased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total O+k+l)No. Received Delivered ($)($)($) of Settlement ($) (g) (h)(i)(k)(I)(m) 17~85C 850 70~13~135 139 601 583 93~"P'"32,600 055 85f 202 78~202 782 268,45f 702 18'702 185 150 55r ,;::!U3;~p(J 150;'i 525 061 976,976,667 32€23,23,387 19C :, ", -:- 1:,iF: ' ';', ,:, ,';:':"":" 977 1 ~ 775 775 980 33,189,244 189 244 146 25,621 621 35r 128,294 128,294 31,418 353 15,485 589 198 082 122,932 184 998 562,919 215 972,944 905,522 159 FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PaeifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002 (2) Fi A Resubmission 04/30/2003 ~CHA~ED POWER hAccount 555)(nclu Ing power exe anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy. capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(e)(d)(e)(f) 1 Rocky Mountain Generation Cooperative 2 Rocky Mountain Generation Cooperative 3 Roush, Neil 4 Sacramento Municipal Utility District 5 Sacramento Municipal Utility District .;i, 6 Salt River Project ,.,.,.", ' 7 Salt River Project 8 San Diego Gas & Electric 9 Santa Clara, City of Santiam Water Control District Seattle City Light Seattle City Light I~, /:' Seawest Sempra Energy Resources 100 100 Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31, 2002(2) n A Resubmission 04/30/2003 CCOU H\~g~~, (0 ntlnued)(InCluding power exc ange AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis , enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401 , line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purehased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($) of Settlement ($) (g) (h)(i) (j) (k)(I)(m) 55C 407,611 407 617 97'15,721 15,721 28.16,431 16,437 12,473,431 473,431 85,71C 965,95.965 952 771 454,981 454 981 263,14!213,641 213 648 20!105 15!105,150 130 327 76!327 760 581 632 116,7O:i 130,334 102 66C 917 917 964 50C 061 805,34E 805,346 103 300 000 142, -;';"",,,, 340 716 31,418 353 15,485,589 198 082 122,932 184 998,562 915 215,972,944 905,522 155 FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PaeifiCorp (1) X An Original (Mo, Da, Yr)Dee. 31,2002 (2)0 A Resubmission 04/30/2003 PU~C~~ED POWER ~ccount 555)( nc u Ing power exe anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(c)(d)(e)(f) Sempra Energy Trading Corp.~t. Sempra Energy Trading Corp. 3 SF Phosphates Limited Company 4 SF Phosphates Limited Company ~?i; 5 Sierra Pacific Power Company ~f1. .~:'- 6 Sierra Pacific Power Company 7 Sierra Pacific Power Company 8 Slate Creek 9 Snohomish Public Utility District No. Southem California Edison Company """ Southern California Edison Company CIS;. Spanish Fork City ~i. Springfield Utility Board Springville City Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent This ~ort Is:Date of Report Year of Report PaeifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 ccou ~~~L (Continued)Tlnaudlng power exe anges) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total O+k+l)No. Received Delivered ($)($) of Settlement ($) (g) (h)(i)(I)(m) 193 3,49E 496 845 551 26,574 27E 26,574 276 542 708,59"708 592 256 818,640 284 843,18S 843 188 455,144 079,36S 079,368 28C 084 12~163,429 1 ,032,831 52,91.:823,021 823 021 513,158 105 14C 140 357 72,000 353,20C 353,200 617 31,418 353 15,485 589 198,082 122 932 184 998,562 919 215,972 944 905,522,155 FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PaeifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2) D A Resubmission 04130/2003 PU~C~A~ED POWER hAccount 555)( nc u 109 power exc anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of reqUIrement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Publie Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Sehedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(e)(d)(e)(f) Strawberry Electric Service District IIIStrawberry Electric Service District Sunnyside Cogeneration Associates 52.51.44. Tacoma, City of Thayn Ranch Hydro Tractebel Energy Marketing, Inc. 7 TransAlta Energy Marketing Ine. 8 TransAlta Energy Marketing Inc. l1li:9 TransAlta Energy Marketing Inc. Tri-State Generation & Transmission Tri-State Generation & Transmission Tri-State Generation & Transmission Tucson Electric Power Tucson Electric Power Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 ccou ~gi~\ (t,;ontlnueCl)(Ineludlng power exc ange AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401 , line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No. Received Delivered ($)($) of Settlement ($) (g) (h)(i) (j) (I)(m) 13~1M 26 126 31~313 393 21'194 301 705 341 18,899 642 65,19~381,28E 381 286 2,490 307 797 60C 151 540 151,540 1 , 119 63~30,912,312,548 92C c;,29,015 060 149 451,40S 94,451,409 70(896 65€896 656 10,43E 262 32S 262,329 271 774 000 363,14S 137 148 87"847,26€847 266 777 25~777 252 31,418,353 485 589 198 082 122 932 184 998,562,919 215 972 944 905 522 159 FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This F ~j/ Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2) D A Resubmission 04130/2003 PU~CHA~ED POWER hAccount 555)(nelu Ing power exc anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(e)(d)(e)(f) 1 UBS Warburg Energy LLC 2 United States Bureau of Reclamation 3 Utah Associated Municipal Power Syste 0:' 4 Utah Associated Municipal Power Syste 5 Utah Municipal Power Agency I"'",' "c " 6 Utah Municipal Power Agency 7 Varian Corp. 8 Walla Walla, City of 9 Walla Walla, City of Washington City Western Area Power Administration Western Area Power Administration Whitmore Oxygen Co. Whitney, A. C. Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dee. 31 2002(2) n A Resubmission 04130/2003 ccou ~~~L (Continued)Oneludlng power exc anges) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401 , line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total O+k+l)No. Received Delivered ($)($) of Settlement ($) (g) (h)(i)(I)(m) 46,00C 510 50C 510,500 86f 30,591 235 57E 23,578 90(900 59C 590 824 146,146 419 99/136,942 296,870 1,433,812 32,497 729 729 96~388 352 388,352 59,385 271 801 275 956 31,418,353 15,485,589 15,198,082 122 932 184 998 562,919 215 972,944 905,522 159 FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PaeifiCorp (1) X An Original (Mo, Da, Yr)Dee. 31,2002(2) riA Resubmission 04/30/2003 ~CHA~ED POWER hAccount 555)(nclu mg power exe anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(c)(d)(e)(f) 1 Wiggins, Duane 2 Willamette Industries 3 Willamette Industries 4 Williams Energy Market & Trading Co. 5 Williams Energy Market & Trading Co. 6 Williams Energy Market & Trading Co. 7 XL Trading Partners 8 XL Trading Partners 9 Yakima Tieton PacifiCorp ... 'i:;~fl: PacifiCorp PacifiCorp Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent PacifiCorp Year of Report Dec. 31 2002 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (50-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges. report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401 , line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column 0) must be reported as Exchange Delivered on Page 401, line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total O+k+l)No. Received Delivered ($)($)($) of Settlement ($) (g) (h)(i)(k)(I)(m) 557 922 973 200 383 193 -440 100 000 099 000 208 769 798 317 929 108 017 311 -44 794,449 31,418 353 15,485,589 198 082 122 932 184 998 562 919 215,972,944 905 522 FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 PU~CHA~ED POWER hAccount 555) (nclu Ing power exc anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(c)(d)(e)(f) 1 Power Exchanges Anaheim, City of WSPP 3 Arizona Public Service Co.306 Ashland, City of 353 5 Avista Corp.366 6 Avista Corp.554 7 Basin Electric Power Cooperative 8 Black Hills Power & Light Company 246 9 Bonneville Power Administration 554 Bonneville Power Administration 368 Bonneville Power Administration 237 Bonneville Power Administration 256 Bonneville Power Administration 14; Bonneville Power Administration Total FERC FORM NO.1 (ED. 12-90)Page 326. This ~ort Is:(1) ~An Original (2) D A Resubmission ccountIncluding po er exehanges) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. Date of Report(Mo, Da, Yr) 04/30/2003 Year of Report Dec. 31 2002 Name of Respondent PaeifiCorp 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) . must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received , enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401 , line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column 0) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purehased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total U+k+l)No. Received Delivered ($)($)($) of Settlement ($) (g) (h)(i)(k)(I)(m) 123,800 123 800 571,417 571,429 566 231 995 176 166 600 875 219 975 219 423 657 269 584 574 999 865 125 000 83,493 263 309,533 2,462 2,462 696 115,826,527 109 676 113 626 043 31,418,353 485,589 15,198,082 122 932 184 998 562,919 215,972 944 905 522 FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PaeifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 PU~CHA~ED POWERchAccount 555)(nelu Ing power ex anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(c)(d)(e)(f) Bonneville Power Administration 347 Bonneville Power Administration 3 California Independent System Operato Chelan County Publie Utility District 554 5 Clark County Publie Utility District 417 6 Colockum Transmission Company 343 7 Cowlitz County Public Utility Distric 554 8 Douglas County Publie Utility Distric 554 9 Emerald Peoples Utility District 351 Enron Power Marketing, Inc. Eugene Water & Electric Board Flathead Electrie Cooperative Georgia Pacific Grant County Publie Utility District 554 Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent PacifiCorp Year of Report Dec. 31 2002 This ~ort Is:(1) ~An Original (2) A Resubmission ccounneludmg po er exehanges) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (50-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401 , line 10. The total amount in column (h) must be reported as Exchange Received on Page 401, line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total O+k+l)No. Received Delivered ($)($)($) of Settlement ($) (g) (h)(i)(k)(I)(m) 654 239 660 742 122 000 989 738 930 705 262 262 13,800 271 747 250 449 203 198 529 -40,141 141 231 104,473 988 241 165 545 895 136 17,517 10,648 240 371 052 813 197 214 56,926 31,418 353 15,485,589 198,082 122,932 184 998 562 919 905,522 FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) riA Resubmission 0413012003 PU~CHA~ED POWER J,Account 555)(nelu Ing power ex anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition , the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(c)(d)(e)(f) 1 Idaho Power Company 380 Los Angeles Deptof Water & Power WSPP 3 Montana Power Company 554 Pope & Talbot 5 Portland General Electrie 554 6 Public Service Company of Colorado WSPP 7 Publie Service Company of Colorado 8 Public Service Company of Colorado 319 9 Redding, City 364 Seattle City Light 554 Seawest 554 Sierra Pacific Power Company WSPP Southern Califomia Edison 248 Tri-State Generation & Transmission 319 Total FERC FORM NO.1 (ED. 12-90)Page 326. This ~ort Is: Date of Report(1) l.!.IAn Original (Mo, Da, Yr)(2) nA Resubmission 04/30/2003 ccount ~~~~\ (continued) (lneludlng power exchanges) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups. for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. Name of Respondent PacifiCorp Year of Report Dec. 31 2002 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours Purehased (g) POWER EXCHANGES MegaWatt Hours MegaWatt HoursReceived Delivered(h) (i) 330,851 202,424000 37 958 5,450 238 161,959 Demand Charges ($) COST/SETTLEMENT OF POWER Energy Charges Other Charges ($) ($) (k) (I) LineTotal G+k+l) No.of Settlement ($) (m) 78,363 015 113 899 304 071 342 320 725 164 571 817 160 748 840 947 18,938 .,' ,I'257 968 318 514 334 092 733,514 211 897 100,627 257,414 153 393 ;.:Pt,';595 418,353 15,485,589 198 082 122 932 184 998,562 919 215 972 944 905,522, 15~ FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2)DA Resubmission 04/3012003 PU~CHA~ED POWER hAccount 555)(nclu Ing power exc anges) 1. Report all power purchases made during the year. Also report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service.The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service.Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Line Name of Company or Publie Authority Statistical FERC Rate Average Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Average Average cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand (a)(b)(e)(d)(e)(f) 1 Utah Associated Municipal Power Syste Utah Municipal Power Agency 3 Warm Springs Power Enterprises Western Area Power Administration 6 System Deviation !~;,;;),,:'(' Total FERC FORM NO.1 (ED. 12-90)Page 326. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/3012003 ccou~gg~~ (Contlnuea)(Including power exc ange AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401 line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401, line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWER Line Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total O+k+l)No. Received Delivered ($)($) of Settlement ($) (g) (h)(i)(k (m) 228,997 323,839 -468,452 438 303 422 831 358,355 874 711 532 714 951 109,990 34E 31,418 353 15,485 589 198 082 122,932 184 998,562 919 215 972,944 905 522,159 FERC FORM NO.1 (ED. 12-90)Page 327. Name of Respondent PaeifiCorp This ~ort Is:(1) ~An Original (2) A Resubmission Year of Report Dee. 31 2002 ccoun (lneluding transactions referred to as 'wheeling 1. Report all transmission of electricity, L e., wheeling, provided for other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column(d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: LF - for Long-term firm transmission service. "Long-term" means one year or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as , provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. SF - for short-term firm transmission service. Use this category for all firm services, where the duration of each period of commitment for service is less than one year. Payment By (Company of Public Authority) (Footnote Affiliation) (a) 1 Aquila Power Corporation 2 Aquila Power Corporation 3 Arizona Public Service Co. 4 Arizona Public Service Co. 5 Basin Electric Power Cooperative 6 Basin Electric Power Cooperative 7 Basin Electric Power Cooperative 8 Basin Electric Power Cooperative 9 Black Hills Power & Light Co. 10 Black Hills Power & Light Co. 11 Black Hills Power & Light Co. 12 Black Hills Power & Light Co. 13 Bonneville Power Administration 14 Bonneville Power Administration 15 Bonneville Power Administration 16 Bonneville Power Administration 17 Bonneville Power Administration Line No. TOTAL FERC FORM NO.1 (ED. 12-90) Energy Received From (Company of Publie Authority) (Footnote Affiliation) (b) Energy Delivered To (Company of Publie Authority) (Footnote Affiliation) (e) Statistical Classifi- cation (d) Black Hills Power & Light Co. Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration Page 328 Name of Respondent This ~rt Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 ~L~\'" I ~!\--II T t-YK \..! I ccount 456)(Continued)(Including transactions reffered to as 'wtieeliriiii OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories. such as all nonfirm service regardless of the length of the contract and service from, designated units of less than one year. Describe the nature of the service in a footnote for each adjustment. AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path , " point to point" transmission service. In column (t), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract.Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. FERC Rate Point of Receipt Point of Delivery Billing TRANSFER OF ENERGY Line Schedule of (Subsatation or Other (Substation or Other Demand MegaWatt Hours Megawatt Hours No. Tariff Number Designation)Designation)(MW)Received Delivered (e)(f) (g) (h)(i) OV-672 67. OV-200 20C OV-43,120 43,12C OV-600 600 OV-Yellowtail Sub Sheridan Sub OV-Yellowtail Sub Sheridan Sub OV-Yellowtail Sub Sheridan Sub 136 Dave Johnston Sub OV-91,283 91 ,28~ OV-Various Sheridan Sub OV-Various Wyodak Sub 226 Wyodak Sub 237 Various Various 277 324 Lost Creek Hydro PI Various 237 136 237 136 299 Various Various 200 159 177 159 177 256 Various Various 362 OV-Green Springs Hyd Alvey Sub 827 183,345 183,34~ FERC FORM NO.1 (ED. 12-90)Page 329 Blank Page (Next Page is: 330) Name of Respondent PacifiCorp Date of Report (Mo, Da, Yr) 04/30/2003 Year of Report Dec. 31 2002 ccoun (Including transactions reffered to as 'wlieeling 8. Report in column (i) and (j) the total megawatthours received and delivered. 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or servicere~e~. 10. Provide total amounts in column (i) through (n) as the last Line. Enter "TOTAL" in column (a) as the Last Line. The total amounts in columns (i) and (j) must be reported as Transmission Received and Delivered on Page 401 , Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. Demand Charges ($) (k) REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERSEnergy Charges (Other Charges) ($) ($) (I) (m) 309 106 163,858 760,848 656 100 814 607 819 384 556 246 496 607 45,145,047 FERC FORM NO.1 (ED. 12-90) 873,749 296,064 Page 330 Total Revenues ($) (k+l+m) (n) No. 152 056 730 159 944 6,400 354,313 174 436 11,964 400 239 010 760 848 656 100 43,458 888,731 312 276 034 988 556,246 511 732 314 860 Name of Respondent PaeifiCorp This~ort Is:(1) ~An Original (2) A Resubmission Year of Report Dec. 31 2002 Date of Report (Me, Da, Yr) 04/3012003 ccount(Includin transactions referred to as 'wheeling 1. Report all transmission of electricity, L e., wheeling, provided for other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column(d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: LF - for Long-term firm transmission service. "Long-term" means one year or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. SF - for short-term firm transmission service. Use this category for all firm services, where the duration of each period of commitment for service is less than one year. Line Payment By Energy Received From Energy Delivered To Statistical No.(Company of Public Authority)(Company of Public Authority)(Company of Public Authority)Classifi- (Footnote Affiliation)(Footnote Affiliation)(Footnote Affiliation)cation (a)(b)(e)(d) Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration Bridger Valley Rural Elee. Assoc. Cargill-Alliant, LLC Cheyenne Light, Fuel & Power Deseret Generation & Transmiss. Deseret Generation & Transmiss. Deseret Generation & Transmiss. Dynegy Power Marketing, Inc. Fall River Rural Electric Coop. Flathead Electric Coop. Inc. Georgia Paeifie IdaCorp Energy IdaCorp Energy IdaCorp Energy Nevada Power Company IdaCorp Energy Deseret Generation & Transm.Nevada Power Company IdaCorp Energy Deseret Generation & Transm.Idaho Power Company Ida Corp Energy CA Independent Sys. Op.IdaCorp Energy TOTAL FERC FORM NO.1 (ED. 12-90)Page 328. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002(2) DA Resubmission 04/30/2003 ~!'" t:!-t:l; I r;~~11 Y FgR U I Ht:K.~!... ccour:1t 4~)(l;ontlnued) (Including transactions reffered to as 'wlieeling OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all nonfirm service regardless of the length of the contract and service from, designated units of less than one year. Describe the nature of the service in a footnote for each adjustment. AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path , " point to point" transmission service. In column (t), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation , or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract.Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. FERC Rate Point of Receipt Point of Delivery Billing TRANSFER OF ENERGY Line Schedule of (Subsatation or Other (Substation or Other Demand MegaWatt Hours MegaWatt Hours No. Tariff Number Designation)Designation)(MW)Received Delivered (e)(f) (g) (h)(i) OV-Various Gazely Sub 213 Blacksfork Sub OV-66,369 66,36E OV-720 72C 280 Various Various 167 167 OV-120 12C 462 OV- 322 Targhee Sub Goshen Sub OV-Yellowtail Sub Various OV-135 263 135, OV-101 101 OV-142,720 142 72C OV-Mid-Red Butte OV-Mona Sub Red Butte OV-Mona Sub Jim Bridger Sub OV-Crag View Sub Enterprise Sub 827 183,345 183,34E FERC FORM NO.1 (ED. 12-90)Page 329. Blank Page (Next Page is: 330. Name of Respondent PacifiCorp This ~ort Is: (1) l!JAn Original (2) A Resubmission Date of Report (Mo, Da, Yr) 04/30/2003 Year of Report Dec. 31 2002 ccoun(Includin transactions reffered to as 'wheeling 8. Report in column (i) and 0) the total megawatthours received and delivered. 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. Provide total amounts in column (i) through (n) as the last Line. Enter "TOTAL" in column (a) as the Last Line. The total amounts in columns (i) and (j) must be reported as Transmission Received and Delivered on Page 401 , Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. Demand Charges ($) (k) REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERSEnergy Charges (Other Charges) ($) ($) (I) (m) 179 140 102 302 151 308 523 326 025 305,856 625 250 455 625 243,000 145 047 14,873,749 296,064 FERC FORM NO.1 (ED. 12-90)Page 330. Total Revenues ($) (k+l+m)No. (n) 216 357 964 248,201 160 371 287 269 18,510 151 308 91,181 326,025 335,181 625 20,250 455,625 243,000 314,860 Name of Respondent PacifiCorp Date of Report (Mo, Da, Yr) 04130/2003 Year of Report Dec. 31, 2002 ccoun (Including transactions referred to as 'wheeling 1. Report all transmission of electricity, L e., wheeling, provided for other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column(d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: LF - for Long-term firm transmission service. "Long-term" means one year or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as , provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. SF - for short-term firm transmission service. Use this category for all firm services, where the duration of each period of commitment for service is less than one year. Line No. Payment By (Company of Public Authority) (Footnote Affiliation) (a) Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (e) Statistical Classifi- cation (d) Energy Received From (Company of Publie Authority) (Footnote Affiliation) (b) LA. Dept of Water & Power Nevada Power Company LA Dept of Water & Power Mid-Columbia 1 IdaCorp Energy 2 IdaCorp Energy 3 Idaho Power Company 4 Idaho Power Company 5 Idaho Power Company 6 Idaho Power Company 7 Idaho Power Company 8 Idaho Power Company 9 Idaho Power Company 10 Idaho Power Company 11 Idaho Power Company 12 Idaho Power Company 13 Idaho Power Company 14 Idaho Power Company 15 Idaho Power Company 16 Mirant Americas Energy Marketing 17 Mirant Americas Energy Marketing IdaCorp Energy IdaCorp Energy Idaho Power Company Nevada Power Company Nevada Power Company Idaho Power Company Idaho Power Company Idaho Power Company Idaho Power Company Idaho Power Company Western Area Power Admin. Deseret Generation & Transm. Deseret Generation & Transm. CA Independent Sys. Op. LA. Dept of Water & Power Nevada Power Company LA. Dept of Water & Power Idaho Power Company TOTAL FERC FORM NO.1 (ED. 12-90)Page 328. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31, 2002 (2) 0 A Resubmission 04/30/2003 ~!'" FgR ~! ,. ccount 4~ti)(l;ontlnued) (Including transactions reffered to as 'heeling os - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all nonfirm service regardless of the length of the contract and service from , designated units of less than one year. Describe the nature of the service in a footnote for each adjustment. AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path , " point to point" transmission service. In column (t), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract.Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. FERC Rate Point of Receipt Point of Delivery Billing TRANSFER OF ENERGY Line Schedule of (Subsatation or Other (Substation or Other Demand MegaWatt Hours MegaWatt Hours No. Tariff Number Designation)Designation)(MW)Received Delivered (e)(f) (g) (h)(i) (j) OV-Mona Sub Borah/Brady 100 OV-Red Butte Borah/Brady OV-Mona Sub Jim Bridger Sub OV-Mid-Red Butte OV-Mona Sub Red Butte OV-Mona Sub Jim Bridger Sub OV-Crag View Sub Enterprise Sub OV-Mona Sub BorahlBrady 100 OV-Red Butte BorahlBrady OV-Mona Sub Jim Bridger Sub OV-Jim Bridger Sub Flaming Gorge OV-33,899 33,899 OV-33,264 33,26~ 257 Antelope Sub 203 Jim Bridger Sub OV-73,150 73,15C OV-046 78,04E 827 183,345 183,34! FERC FORM NO.1 (ED. 12-90)Page 329. Blank Page (Next Page is: 330. Name of Respondent PacifiCorp Year of Report Dee. 31 2002 Date of Report (Mo, Da, Yr) 04130/2003 ccount (Including transactions reffered to as 'wheeling 8. Report in column (i) and 0) the total megawatthours received and delivered. 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. Provide total amounts in column (i) through (n) as the last Line. Enter "TOTAL" in column (a) as the Last Line. The total amounts in columns (i) and 0) must be reported as Transmission Received and Delivered on Page 401 , Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. Demand Charges ($) (k) REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERSEnergy Charges (Other Charges) ($) ($) (I) (m) Total Revenues ($) (k+l+m) (n) No. 579 200 151 875 182,250 405,000 162 000 215 000 486, 868,800 455,625 182,250 486,000 579,200 309,626 182 250 405 000 162,000 215,000 486 000 868 800 455,625 182 250 604 454 187,064 156,388 73,824 284 256 601 19,476 202 500 19,476 145,047 873,749 296,064 67,314 860 FERC FORM NO.1 (ED. 12-90)Page 330. Name of Respondent PaeifiCorp Date of Report (Mo, Da, Yr) 04/3012003 ccount(Including transactions referred to as 'wheeling 1. Report all transmission of electricity, L e., wheeling, provided for other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column(d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: LF - for Long-term firm transmission service. "Long-term" means one year or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. SF - for short-term firm transmission service. Use this category for all firm services, where the duration of each period of commitment for service is less than one year. Year of Report Dec. 31 2002 Line No. Payment By (Company of Public Authority) (Footnote Affiliation) (a) 1 Moon Lake Electric Assoeiation 2 Morgan Stanley Capital Group Ine. 3 Morgan Stanley Capital Group Inc. Pacific Gas & Electric Pacific Gas & Electrie Pacific Gas & Electric 17 Powerex Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) Statistical Classifi- cation (d) Pope & Talbot Portland General Electrie Portland General Electric Portland General Electric Portland General Electrie Bonneville Power Administration CAISO TOTAL FERC FORM NO.1 (ED. 12-90)Page 328. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/3012003 i OF ELEC1 KIl,;l I T F9R lJ I M~K (1. ccount 456)(Contmued) !Including transactions reffered to as 'wlieeling OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all nonfirm service regardless of the length of the contract and service from, designated units of less than one year. Describe the nature of . the service in a footnote for each adjustment. AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path , " point to point" transmission service. In column (t), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation , or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract.Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. FERC Rate Point of Receipt Point of Delivery Billing TRANSFER OF ENERGY LineSehedule of (Subsatation or Other (Substation or Other Demand lIIregawaffHou rs Megawatt Hours No.Tariff Number Designation)Designation)(MW)Received Delivered (e)(f) (g) (h)(i) 302 Duchesne Duchesne OV-040 68,O4C OV-479,716 479 71E Malin Sub Indian Springs 298 Pinto Sub 298 Pinto Sub OV-Wallula Sub Mid-155 OV-West Valley Project Red Butte OV-West Valley Project Borah/Brady OV-West Valley Project Gonder OV-380 380 OV-113 014 113 014 OV-296 29E 137 Dalreed Sub 137 Dalreed Sub 372 Harrison Sub OV-Bonneville Pwr Adm Weed Jct. Sub 827 183,345 183,34! FERC FORM NO.1 (ED. 12-90)Page 329. Blank Page (Next Page is: 330. Name of Respondent PacifiCorp Year of Report Dec. 31, 2002 Date of Report(Mo, Da, Yr) 04/30/2003 ccount(Including transactions reffered to as 'wheeling 8. Report in column (i) and (j) the total megawatthours received and delivered. 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. Provide total amounts in column (i) through (n) as the last Line. Enter "TOTAL" in column (a) as the Last Line. The total amounts in columns (i) and (j) must be reported as Transmission Received and Delivered on Page 401 , lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. Demand Charges ($) (k) REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERSEnergy Charges (Other Charges) ($) ($) (I) (m) Total Revenues ($) (k+l+m) (n) No. 219 311 850 710 20,892 536,327 027 677 237 500 459,866 410 558 625 313 875 202,500 349 891 219 311 850 837 314 985 31,260 133,197 20,892 245 043 027,677 558 625 313 875 202,500 349 000 944 000 45,145,047 873,749 296,064 67,314 860 FERC FORM NO.1 (ED. 12-90)Page 330. ccoun(IncJudin transactions referred to as 'wheelin ' 1. Report all transmission of electricity, L e., wheeling, provided for other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column(d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: LF - for Long-term firm transmission service. "Long-term" means one year or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as , provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. SF - for short-term firm transmission service. Use this category for all firm services, where the duration of each period of commitment for service is less than one year. Year of Report Dee. 31 2002 Name of Respondent PacifiCorp Line No. Payment By (Company of Public Authority) (Footnote Affiliation) (a) Energy Received From (Company of Publie Authority) (Footnote Affiliation) (b) Energy Delivered To (Company of Publie Authority) (Footnote Affiliation) (c) Statistical Classifi- cation (d) 1 Powerex 2 PPL Montana, LLC 3 Public Service Co. of Colorado 4 Public Service Co. of Colorado 5 Public Service Co. of Colorado 6 Public Service Co. of Colorado 7 Puget Sound Energy 8 San Diego Gas & Electric 9 Seawest Windpower, Inc. 10 Sempra Energy Trading Corp. 11 Sheridan-Johnson Rural Elec Assoc 12 Sierra Pacific Power Company 13 Sierra Paeific Power Company 14 Southern Califorinia Edison Co. 15 Southern Califorinia Edison Co. 16 Southern Califorinia Edison Co. 17 State of South Dakota Westem Area Power Admin.Black Hills Power & Light Co. TOTAL FERC FORM NO.1 (ED. 12-90)Page 328. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 LONG-TERM DEBT (Account 221 , 222, 22 and 224) (Continued) 10. Identify separate undisposed amounts applicable to issues which were redeemed in prior years. 11. Explain any debits and credits other than debited to Account 428, Amortization and Expense, or credited to Account 429, Premium on Debt - Credit. 12. In a footnote, give explanatory (details) for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a) principal advanced during year, (b) interest added to principal amount, and (c) principle repaid during year. Give Commission authorization numbers and dates. 13. If the respondent has pledged any of its long-term debt securities give particulars (details) in a footnote including name of pledgee and purpose of the pledge. 14. If the respondent has any long-term debt securities which have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. 15. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (i). Explain in a footnote any difference between the total of column (i) and the total of Account 427, interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. 16. Give particulars (details) conceming any long-term debt authorized by a regulatory commission but not yet issued. AMORTIZATION PERIOD uI!ISIarlP~n LineNominal Date Date of (Total amount outstan ing without Interest for Year No.of Issue Maturity Date From Date To reduction for amounts lield by Amount (d)(e)(f) (g) resP?Mdent)(i) 040 643 532 823,464 223 270 934 061196 063036 061196 063036 223,712 000 18,456,240 080497 093037 080497 093037 139 176 000 10,716,552 362,888 000 895 711,464 252 443 726 FERC FORM NO.1 (ED. 12-96)Page 257. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) nA Resubmission 04/30/2003 RECONCILIATION OF REPI RTED NET INCOME WITH TAXABLI INCOME FOR FEDERAL INCOME TAXES 1. Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as fumished on Schedule M-1 of the tax retum for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount. 2. If the utility is a member of a group which files a consolidated Federal tax retum, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members. 3. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote. ,-me Particulars (Details)Amount No.(a)(b) 1 Net Income for the Year (Page 117)219,663,631 lTaxable Income Not Reported on Books 5 Contributions in Aid of Construction 534,443 Cholla APS Safe Harbor Lease (Disc)498,753 9 Deductions Recorded on Books Not Deducted for Retum 248,729 447 Income Recorded on Books Not Included in Return Deferred Income Tax 164 271 Equity in Eamings of Subsidiary Companies 3,402 234 19 Deductions on Return Not Charged Against Book Income Federal Tax Net Income 373,212 854 Show Computation of Tax: :ei/..' FERC FORM NO.1 (ED. 12-96)Page 261 Blank Page (Next Page is: 262) Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 04/30/2003 TAXES ACCRUED, PREPAID AND CHARGED DURING YEAR 1. Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are know, show the amounts in a footnote and designate whether estimated or actual amounts. 2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes. Enter the amounts in both columns (d) and (e). The balancing of this page is not affected by the inclusion of these taxes. 3. Include in column (d) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts. 4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained. ,-me Kind of Tax BALANCE AT BEGINNING OF YEAR ;1~xes Adjust-C argedNo.(See instruction 5). axes Accru~~~repald Taxes ~~~g ~ring ments(Account 236)(Include In Account 165)ear(a)(b)(c)(d)(e)(f) Federal: Income 15,918 028 92,430 569 947 374 .~Ia;t~ FICA 26,741 974 30,375,048 633,074 Unemployment 110,300 295 047 278,754 020 Excise Tax - Coal 38,130 757 540 626,926 6 SUBTOTAL 15,769,598 123,225 130 126,228 102 090,594 Arizona: Property 259 152 183,551 351,017 Income Tax 121 318 466,803 58,913 SUBTOTAL 380,470 650,354 2,409 930 California: Property 814 245 584 184 591 070 Unemployment 13,282 13,282 Bank/Corp. Franchise 522 062 555 875 065 Sales and Use Tax 709 037 90,485 Local Franchise Tax 622 505 874 736 763 209 SUBTOTAL 963,521 114 114 528 111 395 135 Colorado Property 000 000 067 816 2,467 816 Income 993 205 808 SUBTOTAL 993,205 067 816 2,465 008 Idaho: Property 614 547 919 688 867 291 Unemployment 531 531 Income 759,564 026 019 129 032 KWH 643 111 997 Regulatory Commission 188 514 350 416 308,445 Road Use 121,413 119,824 SUBTOTAL 374 754 188 514 4,457 178 3,463,120 11,458 Montana: Property 107 263 296,279 256 209 Wholesale Energy 28,734 156,982 149,028 Corporate License 002,693 257 000 SUBTOTAL 138 690 710,261 405,237 TOTAL 10,725,128 10,540,607 250 523 934 240 271,476 930,776 FERC FORM NO.1 (ED. 12-96)Page 262 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 TAXES ACCRUED, PREPAID AND CHARGED DURING YEAR (Continued) 5. If any tax (exclude Federal and State income taxes)- covers more then one year, show the required information separately for each tax year identifying the year in column (a). 6. Enter all adjustments of the accrued and prepaid tax accounts in column (f) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses. 7. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority. 8. Report in columns (i) through (I) how the taxes were distributed. Report in column (I) only the amounts charged to Accounts 408.1 and 409. pertaining to electric operations. Report in column (I) the amounts charged to Accounts 408.1 and 109.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (I) the taxes charged to utility plant or other balance sheet accounts. 9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax. BALANCE AT END OF YEAR DISTRIBUTION OF TAXES CHARGED Line (Taxes accrued Prepaid Taxes Electric Extraordinary Items Adjustments to Ret.Other No. Acco~nt 236)(Incl. in Account 165)(Account 408., 409.(Account 409.Eammgs (Account 439) (h)(i) (j) (k)(I) 886,333 93,566 061 135,492 26,741 974 120,573 295,047 168,744 838,162 120 603,082 135,492 757 540 091 685 183 551 529 208 466 803 620 893 650 354 807 359 545 109 282 007 872 555 875 803 ,ii ":;'/~$!)~? 337 355 874 736 154 389 989 002 125 112 600 000 066 772 996 013 596 013 066 772 044 666,944 917 588 ,:"e 2;'~OQ 531 656,551 026 019 757 111 146 543 . 350,416 046 A"~ 338 298 146,543 983,249 473 929 147 333 296,039 ;:;:r' ;;. . :': ~4Q 688 t~;1$6;~2 259 693 257 000 443,714 553 039 157 222 154 000 622 705 235 671 210 135,492 15,988,218 FERC FORM NO.1 (ED. 12-96)Page 263 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31, 2002(2) 0 A Resubmission 04130/2003 TAXES ACCRUED, PREPAID AND CHA GED DURING YEAR 1. Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are know, show the amounts in a footnote and designate whether estimated or actual amounts. 2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes. Enter the amounts in both columns (d) and (e). The balancing of this page is not affected by the inclusion of these taxes. 3. Include in column (d) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts. 4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained. Kind ofTax BALANCE AT BEGINNING OF YEAR :1?es ~~ras Adjust-C argedNo.(See instruction 5). axes Accru~~~repat(11 axes ~nng ~~~g ments(Account 236)(Include m Account 165)ear(a)(b)(c)(d)(e)(f) New Mexico: Property 838 12,000 534 Income -69,299 22,000 4 SUBTOTAL -65,461 000 534 6 Oregon: Property 939,439 16,229,850 346,555 Regulatory Commission 632,112 269,004 2,401 044 Unemployment 055 917 055 917 Tri-Met 749,430 749,430 Lane Transit 602 602 Workers Benefit Fund 149,900 149 900 Excise Tax 1,472,753 201 279 080,720 ;d;tqi~~J.~; City of Portland 614 216 303 45,719 Local Franchise Tax 328,302 401 722 297 794 SUBTOTAL 824 669 571 551 276,007 129 681 736 856 Utah: Property 320,849 945 145 672 740 Income 264 085 395 537 931 879 Unemployment 260 260 Regulatory Commission 346 628 757 352 905 526 Road Use 154,206 350 194 2,400 380 Gross Receipts Tax 1,456,150 992 351 716 719 SUBTOTAL 025,422 346 628 536 839 723 504 440 Washington: Property 500,150 730 718 867 434 Unemployment 109 124 109 124 Business 329 034 26,604 Public Utility Tax (Rev.883,076 642 399 647,782 :' ';;. 3'5;1)10 Regulatory Commission 106 144 384,570 400 606 Use Tax 638 187 941 182 303 Local Franchise Tax 833 208 766 202 423 SUBTOTAL 5,421 026 106 144 280,552 11,436 276 35,010 Washington D. Unemployment 649 649 Franchise 697 SUBTOTAL 697 649 649 TOTAL 10,725,128 10,540,607 250 523 934 240,271 476 930 776 FERC FORM NO.1 (ED. 12-96)Page 262. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 04/30/2003 TAXES ACCRUED, PREPAID AND CHARGED DU ING YEAR (Continued) 5. If any tax (exclude Federal and State income taxes)- covers more then one year, show the required information separately for each tax year identifying the year in column (a). 6. Enter all adjustments of the accrued and prepaid tax accounts in column (f) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses. 7. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority. 8. Report in columns (i) through (I) how the taxes were distributed. Report in column (I) only the amounts charged to Accounts 408.1 and 409. pertaining to electric operations. Report in column (I) the amounts charged to Accounts 408.1 and 109.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (I) the taxes charged to utility plant or other balance sheet accounts. 9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax. BALANCE AT END OF YEAR DISTRIBUTION OF TAXES CHARGED Line (Taxes accrued Prepaid Taxes Electric Extraordinary Items AOJustments to Ket.Other No. Acco~nt 236)(Incl. in Account 165)(Account 408.409.(Account 409.Earnings (Account 439) (h)(i)(k)(I) 304 12,000 -47 299 000 38,995 000 962 061 015 252 880 ~ .~:: 764 152 . I",.. 1 ,055,917 749,430 602 149 900 709 996 201,279 194 198 216,303 052,402 16,401 722 961 558 825 167 030,033 245,975 951 557 29,710 184 199 573 395,537 96,260 1,494 802 98,580 731 782 992,351 981 492 1,494 802 194,332 342 508 363 434 656 398 "ti'J." 109 124 241 842 683 642 399 122,180 276 176 208 766 246,328 122 180 10,616 687 663 865 649 697 697 649 154 000 10,622 705 235 671 210 135,492 988,218 FERC FORM NO.1 (ED. 12-96)Page 263. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr) Dec. 31 2002(2) Fi A Resubmission 04/30/2003 TAXES ACCRUED, PREPAID AND CHA GED DURING YEAR 1. Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are know, show the amounts in a footnote and designate whether estimated or actual amounts. 2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes. Enter the amounts in both columns (d) and (e). The balancing of this page is not affected by the inclusion of these taxes. 3. Include in column (d) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts. 4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained. Kind of Tax BALANCE AT BEGINNING OF YEAR ;\,?es ,J~~Adjust-C argedNo.(See instruction 5)TaxesAccrued Prepald Taxes ~nng ~~~g ments(Account 236)(Include In Account 165)ear(a)(b)(c)(d)(e)(f) Wyoming: Property 002 488 893;768 037 389 Unemployment 202 202 Regulatory Commission 327 770 846,037 552 281 Glenrock Production Tax 379,420 590 Local Franchise Tax 75,967 996,460 945 301 Sales and Use Tax 58,934 241,082 213,516 9 SUBTOTAL 516 809 327 770 10,014 549 849 279 694 Goshute Possessory 006 Sho-Ban Possessory 150 132 862 133,012 Navajo Possessory Interest 884 28,204 985 Ute Possessory Interest 13,116 13,462 Crow Utility Tax 738 36,369 90,923 Umatilla 448 41 ,448 Franchise Taxes Assoc. with Unbilled Revenues 832 251 1,420,735 Misc. Taxes 318,215 318,215 SUBTOTAL 918 924 843,515 625 045 151 217 TOTAL 10,725 128 540,607 250,523,934 240 271,476 930 776 FERC FORM NO.1 (ED. 12-96)Page 262. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04130/2003 TAXES ACCI UED, PREPAID AND CHARGED DU ,ING YEAR (Continued) 5. If any tax (exclude Federal and State income taxes)- covers more then one year, show the required information separately for each tax year identifying the year in column (a). 6. Enter all adjustments of the accrued and prepaid tax accounts in column (f) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses. 7. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority. 8. Report in columns (i) through (I) how the taxes were distributed. Report in column (I) only the amounts charged to Accounts 408.1 and 409. pertaining to electric operations. Report in column (I) the amounts charged to Accounts 408.1 and 109.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (I) the taxes charged to utility plant or other balance sheet accounts. 9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax. BALANCE AT END OF YEAR DISTRIBUTION OF TAXES CHARGED Line (Taxes accrued Prepaid Taxes Electric Extraordinary Items AOjUstments to Ret.Other No.Acco~nt 236)(Incl. in Account 165)(Account 408.1 , 409.(Account 409.Eammgs (Account 439) (h)(i)(k)(I) 858 867 759 864 tIJ~4?f;g~ 202 r---013 r---315,830 127 126 996,460 806 386,629 34,013 793 526 221 023 006 006 132 862 102 204 -445 116 18,184 369 41 ,448 000,000 1,420 735 260,299 318,215 299 146 843,515 25,154,000 622 705 235,671 210 135,492 15,988,218 FERC FORM NO.1 (ED. 12-96)Page 263. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 ACCUMULA ED DEFERRED INVESTMENT TAX REDITS (Account 255) Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and non utility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized. ,,-Ine Account No.subd lvisions of Year Deferred for Year Current Year's Income Adjustments(b) Accour:1t NO. Amour'if Accou~t NO. Amount ( ) (c) (d) (e) (f) 1 Electric Utility 23% 34%114,146 411.4 324 81~ 47% 510%73,240 836 411.4 & 420 464, 7 Idaho 235,945 411.65,431 8 TOTAL 590,927 854,86; 9 Other (List separately and show 3%, 4%, 7%, 10% and TOTAL) Nonutility 10%697 616 420 065 Total Nonutility 697 616 065 FERC FORM NO.1 (ED. 12-89)Page 266 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 ACCUMULATED D FERRED INVESTMENT TAX CRED TS (Account 255) (continued) ADJUSTMENT EXPLANATION Lineof Year of A ocabon No.to Income 789 334 776 221 30&35 170,509 70,736,064 632 356 632 356 FERC FORM NO.1 (ED. 12-89)Page 267 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04/30/2003 0 HER DEFFERED CREDITS (Account 253) 1. Report below the particulars (details) called for conceming I?ther deferred credits. 2. For any deferred credit being amortized, show the period of amortization. 3. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $10,000, whichever is greater) may be grouped by classes. Line Description and Other Balance at DEBITS Balance at No.Deferred Credits Beginning of Year Contra Amount Credits End of Year (b)Account (a)(c)(d)(e)(f) Cogeneration Bonds - Sunnyside 413,417 413,417 Working Capital Deposit DG& T 851 000 034,000 885,000 Working Capital and Coal Pile Deposits from Provo City 273,000 273 000 Working capital deposit from UAMPS 075,000 600,000 675,000 Reclamation Costs - Dave Johnston Coal Mine 26,823 934 151 336,726 487,208 Reclamation Costs - Trapper Mine 227 734 237 081 2,464,815 Reclamation Costs - Deer Creek Mine 344 919 191 225 536,144 Reclamation Costs - Deseret Mine 677 120 151 321 769 355 351 Reclamation Costs - Trail Mountian Mine 146,738 146,738 Deferred Compensation - PPL 570,052 131 273,114 296 938 401 (k) Plan administrative costs 170,757 131 101 96,656 Building Rent Revenues - Portland 566 566 Mill Fork Tract Lease Bonus Paymnt 10,080 000 131 040,000 040 000 Pension administrative costs 351 236 218 079 133 157 Transmission Service Deposit 375,400 142 779,975 595,425 Deferred Excise Tax 850 000 465 099 315 099 Def. Credits - Pricing Dispute 505 000 094 000 599 000 MCI F.G. wire lease 559,735 454 836 558,899 Firth Cogeneration Buyout 367 230 131 319,990 047 240 Redding Contract 700,044 447 549,996 150,048 Footcreek Contract 806,422 456.137 640 668 782 TOTAL 343,559 666 272,475,717 937 380 021 329 FERC FORM NO.1 (ED. 12-94)Page 269 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04130/2003 0 HER DEFFERED CREDITS (Account 253) 1. Report below the particulars (details) called for conceming C?ther deferred credits. 2. For any deferred credit being amortized, show the period of amortization. 3. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $10,000, whichever is greater) may be grouped by classes. Line Description and Other Balance at DEBITS Balance at No.Deferred Credits Beginning of Year Contra Amount Credits End of Year (b)Account(a)(c)(d)(e)(f) University of Wyoming Electric Prepayment 879 816 445 879 816 Lakeview Buyout 220 000 131 55,000 165,000 Environmental Liabilities -937 009 182 12,539 924,470 Centralia Plant Environmental Liabilities -243 777 994 246 771 Centralia Mine Stock Incentive Plan - 1999 328 123 530 40,798 Stock Incentive Plan - 2000 160,120 123 323 110 797, Stock Incentive Plan - 2001 878 123 907 53,971 Stock Incentive Plan - 2002 120,390 309 136,699 Wyoming Joint Powers Water Board Settlement 400 000 232 225,000 175,000 FAS 133 Derivative Net Liability Non-Current 251 409 455 251,409,455 Comp Reduct 621 193 712 065 333,258 Weather Derivative Liability Non-Current 557 362 962 362 962 47 TOTAL 343,559,666 272 475 717 937 380 021 329 FERC FORM NO.1 (ED. 12-94)Page 269. Name of Respondent PacifiCorp Year of Report Dec. 31 2002 This ~rt Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/3012003 ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPER (Account 281) 1. Report the information called for below concerning the respondent's accounting for deferred income taxes rating to amortizable property. 2. For other (Specify),include deferrals relating to other income and deductions. CHANGES DURING YEAR Line No. Account Balance at Beginning of Year (a) 1 Accelerated Amortization (Account 281 2 Electric (b) Amounts Debited to Account 410. (c) Amounts Credited to Account 411. (d) 3 Defense Facilities 4 Pollution Control Facilities 971 602 334 279 5 Other (provide details in footnote): 8 TOTAL Electric (Enter Total of lines 3 thru 7) 9 Gas 10 Defense Facilities 971 602 334 279 11 Pollution Control Facilities 12 Other (provide details in footnote): 15 TOTAL Gas (Enter Total of lines 10 thru 14) 17 TOTAL (Acct 281) (Total of 8 15 and 16) 18 Classification of TOTAL 971 602 334 279 19 Federal Income Tax 20 State Income Tax 971 602 334,279 21 Local Income Tax NOTES FERC FORM NO.1 (ED. 12-96)Page 272 This ~ort Is: Date of Report Year of Report(1) ~An Original (Mo, Da, Yr) Dec. 31 2002 (2) A Resubmission 04/30/2003 ACCUMULATED DEFERRED INCO E TAXES ACCELERATED AMORT ZATION PROPERTY (Account 281) (Continued) 3. Use footnotes as required. Name of Respondent PacifiCorp CHANGES DURING YEAR Amounts Debited Amounts Credited to Account 410.to Account 411. ADJUSTMENTS Amount Amount Balance at End of Year Line No.Debits 637 323 637 323 637,323 637 323 NOTES (Continued) FERC FORM NO.1 (ED. 12-96)Page 273 Name of Respondent PacifiCorp Year of Report Dec. 31 2002 This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/30/2003 ACCUMULATE DEFFERED INCOME TAXES - OTHER PROPERTY (Account 282) 1. Report the information called for below concerning the respondent's accounting for deferred income taxes rating to property not subject to accelerated amortization 2. For other (Specify),include deferrals relating to other income and deductions. CHANGES DURING YEAR Line No. Account Balance at Beginning of Year (a)(b) Amounts Debited to Account 410. (c) Amounts Credited to Account 411. (d) 1 Account 282 2 Electric 3 Gas 990,401 188 33,793,273 954,787 4 FAS 109 5 TOTAL (Enter Total of lines 2 thru 4) 6 Nonutility 535,109 030 525 510,218 845,444 155 443 40,948,716 15,544 15,344,746 299,533 882,582 9 TOTAL Account 282 (Enter Total of lines 5 thru 10 Classification ofTOT AL 11 Federal Income Tax 533,355,662 40,964,260 182,115 533,355,662 40,964,260 182,115 12 State Income Tax 13 Local Income Tax NOTES FERC FORM NO.1 (ED. 12-96)Page 274 Name of Respondent PacifiCorp Year of Report Dec. 31 2002 This ~rt Is: Date of Report(1) ~ An Original (Mo, Da, Yr) (2) A Resubmission 04130/2003 ACCUMULATED DEFERRED INCO E TAXES - OTHER PROPERTY (Account 282) (Continued) 3. Use footnotes as required. CHANGES DURING YEAR Amounts Debited Amounts Credited to Account 410.to Account 411. ADJUSTMENTS Amount Amount Balance at End of Year Line No.Debits 182 & 254 NOTES (Continued) FERC FORM NO.1 (ED. 12-96)Page 275 Name of Respondent PacifiCorp This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/30/2003 ACCUMULATED DEFFERED INCOME TAXES - OTHER (Account 283) 1. Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283. 2. For other (Specify),include deferrals relating to other income and deductions. Year of Report Dec. 31 2002 (a) Balance at Beginning of Year (b) Line No. Account 1 Account 283 2 Electric 3 UPLlPPL Merger Amortization 4 Loss on Reacquired Debt 5 Expense of Pollution Control 6 Property Taxes (Califomia and 137 447 168,916 192 071 069,402 9 TOTAL Electric (Total of lines 3 thru 8) 10 Gas 17 TOTAL Gas (Total of lines 11 thru 16) 19 TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18) 20 Classification of TOTAL 21 Federal Income Tax 449 076 53,764 501 702 210 449 076 53,764 501 702,210 22 State Income Tax 23 Local Income Tax NOTES FERC FORM NO.1 (ED. 12-96)Page 276 This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/30/2003 ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283) (Continued) 3. Provide in the space below explanations for Page 276 and 277. Include amounts relating to insignificant items listed under Other. 4. Use footnotes as required. Name of Respondent PacifiCorp Year of Report Dec. 31 2002 CHAN ES DURING YEAR Amounts Debited Amounts Credited to Account 410.to Account 411. ADJUSTMENTS Balance at End of Year (k) Line No. 137,447 291,585 540,923 18,386 785 386,785 NOTES (Continued) FERC FORM NO.1 (ED. 12-96)Page 277 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) nA Resubmission 04/30/2003 0 HER REGULATORY LIABILITIES (Account 254) Reporting below the particulars (Details) called for C9ncerning other regulatory liabilities which are created through the rate-making actions of regulatory agencies (and not includable in other amounts) For regulatory Liabilities being amortized show period of amortization in column (a). Minor items (5% of the Balance at End of Year for Account 254 or amounts less than $50 000, whichever is Less) may be grouped by classes. Line Description and Purpose of DEBITS Balance at No.Other Regulatory Liabilities Account Amount Credits End of Year Credited (d)(e)(a)lb\(c) 1996 Depreciation Study 403 527 352 FAS 109 Income Tax Regulatory Liab 182.008,932 39,322,456 Centralia Gain Giveback 456.917 601 71,615 147 Merger Credits ~ltrlJ..j 680,867 13,135,615 Utah Rate Refund .~!(8 26,973,000 OR Share Hermiston Gain Cr.846,551 846,551 OR Gain on Sale of Assets to EPUD 387 782 387 782 Property Inssurance Reserve 005 000 005 000 BPA Washington Balancing Account 668,207 299,783 TOTAL 101 107 752 10,907,540 139,612 334 FERC FORM NO.1 (ED. 12-94)Page 278 Blank Page (N ext Page is: 300) Name of Respondent PacifiCorp Year of Report Dec. 31 2002 This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/30/2003 E ECTRIC OPERATING REVENUES (Account 400) 1. Report below operating revenues for each prescribed account, and manufactured gas revenues in total. 2. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The -average number of customers means the average of twelve figures at the close of each month. 3. If increases or decreases from previous year (columns (c),(e), and (9)), are not derived from previously reported figures, explain any inconsistencies in a footnote. Line No. OPERATING REVENUESTitle of Account (a) 1 Sales of Electricity 2 (440) Residential Sales 3 (442) Commercial and Industrial Sales 4 Small (or Comm.) (See Instr. 4) 5 Large (or Ind.) (See Instr. 4) 6 (444) Public Street and Highway Lighting 7 (445) Other Sales to Public Authorities 8 (446) Sales to Railroads and Railways 9 (448) Interdepartmental Sales 10 TOTAL Sales to Ultimate Consumers 11 (447) Sales for Resale 12 TOTAL Sales of Electricity 13 (Less) (449.1) Provision for Rate Refunds 14 TOTAL Revenues Net of Provo for Refunds 913,925 17,337 853 564 314 537 343 972,105,329 286,642,672 10,202 000 276,440 672 747,478,882 720 008,423 846 317 301 159 363,472 824 052 663,496 416 136,320 972 980 389,163 340 15 Other Operating Revenues 16 (450) Forfeited Discounts 6,431 738 298,47417 (451) Miscellaneous Service Revenues 18 (453) Sales of Water and Water Power 19 (454) Rent from Electric Property 20 (455) Interdepartmental Rents 21 (456) Other Electric Revenues 14,541 981 115 796 387 26 TOTAL Other Operating Revenues 27 TOTAL Electric Operating Revenues 143 068 580 3,419,509,252 FERC FORM NO.1 (ED. 12-96)Page 300 353,184 052,319 15,452 307 152 061,819 180,919 629 570 082,969 Name of Respondent PacifiCorp Year of Report Dec. 31 2002 This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/30/2003 ELECTRIC OPERATING REVENUES (Account 400) 4. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. , (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote. 5. See pages 108-109, Important Changes During Year, for important new territory added and important rate increase or decreases. 6. For Lines 2,4,and 6, see Page 304 for amounts relating to unbilled revenue by accounts. 7. Include unmetered sales. Provide details of such Sales in a footnote. Amount for Year MEGAWATT HOURS SOLD Amount for Previous Year AVG.NO. CUSTOMERS PER MONTH Number for Year Number for Previous Year Line No. 146,608 510 288 752 540 956 202 148,433 560,347 4,403 501 159 501,257 501 257 029,924 30,533,466 563,390 708,462 22,850,898 559 360 522 448 522,541 563 390 559,360 522 541 Line 12, column (b) includes $ Line 12, column (d) includes 734,000 321,496 of unbilled revenues. MWH relating to unbilled revenues FERC FORM NO.1 (ED. 12-96)Page 301 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 30D-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. ,-me NumDer ana IlIIe or Kate scneaUie Mvvn ::;OIC Revenue Average Number !Swn. or ~ales ~~~olderNo.(a)(b)(c)of Cus&omers Per 9~stomer (f) 1 Commercial Sales 2 CA-PPL 3 Unbilled Revenue 946 272 000 0689 4 06CHCKOOON-CA NRES CHECK 5 06GNSYOA32-GEN SRYC-20 KW 232 037,822 846 79,470 0898 6 06GNSYO025-CA GEN SRYC 58,982 923 169 6,465 123 1004 7 06GNSY025F-GEN SRYC-c:: 20 855 107,162 10,823 1253 8 06LGSYOA36-LRG GEN SRYC-85,298 389,313 210 406 181 0749 9 06LNXO0102-LlNE EXT 80% G 16,573 06LNXO0103-LlNE EXT 80% G 718 06LNXO0105-CNTRCT $ MIN G 628 06LNXO0109-REF/NREF ADY +571 06LNXO011D-REF/NREF ADY +588 060AL T015N-OUTD AR LGT SR 784 134,069 582 347 1710 06RCFLOO42-AIRWAY & ATHLE 163 20,695 405 1270 06WHSYO031-COMM WTR HEATI 302 992 389 0828 06LGSYO48T-LRG GEN SERY 60,962 391 900 542 000 0556 ID-UPL UNBILLED REYENUE 290 133,000 -0.1031 BPA BALANCING ACCOUNT 275 070 07CISHO019-COMM & IND SPA 933 882,456 332 955 0682 07GNSYOO06-GEN SRYC-LRG P 189,720 174 084 849 223 463 0536 07GNSYOO09-GEN SRYC-HI YO 23,952 895,521 952 000 0374 07GNSYO023-GEN SRYC-SML P 83,285 010 854 582 177 0842 07GNSYO035-GEN SRYCOPTION 713 79,358 856 500 0463 07GNSYO06A-GEN SRYC-LRG P 805 296,538 183 102,760 0689 07GNSYO06A-GEN SRYC-LRG P 538,891 07GNSY023A-GEN SRYC-SML P 261 111 664 021 12,009 0907 07GNSY023A-GEN SRYC-SML P 339,825 07GNSY023F-GEN SRYC SML P 2,460 2,429 1447 070AL TO07N-SECURITY AR LG 260 817 205 268 2455 070AL T07AN-SECURITY AR LG 059 688 2781 070ALT07AN-SECURITY AR LG 335 07GNSYO06M-GNSY LRG POWER 10,592 420 245 296 000 0397 07GNSYO09M-MANL HIGH VOLT 394 07LNXO0111-80%MIN+ADV+BTW 462 07LNXO0112-80%ANN+ADV+BTW 048 07LNXOO035-ADV 80%MO GUAR 86,024 07LNXO001 O-MNTHL Y 80%GUAR 10,015 07LNXOO040-ADV + REFC H G+80%28,754 TOTAL Billed 351,42(2,463,077 923 522 44E 10;"052C Total Unbilled Rev.(See Instr. 6)321 49€15,734,000 0486 TOTAL 029,92.1 2,447 343 923 522,44E 30,891 0520 FERC FORM NO.1 (ED. 12-95)Page 304 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. ,,-Ine NumDer ana Ime 01 Kale scneaUie Mwn SOld Revenue Average Number Kwn ot :sales ~~~olderNo.(a)(b)(c)of C~~)omers Per C(~stomer (f) 1 07ZZMERGCR-MERGER CREDITS 188 100 2 07LNXOO015-ANNUAL 80%GUAR 273 3 OR-PPL UNBILLED REVENUE 37,019 407 000 0650 5 BPA BALANCING ACCOUNT 204 630 6 OR ENRGY COST RECOV AMORT 13,639 801 7 01 CHCKOOON-NRES CHECK MTR 01 GNSVO024-GEN SRVC DOM/F 19,206 592 260 832 295 2912 01GNSVO024-GEN SRVC DOMIF 155 786 01 GNSVO025-GEN SRVC 242 022 50,272,738 115 735 2077 01GNSV025F-GEN SRVC-FL RA 533 025 293 938 13,361 0818 01 GNSV025M-GEN SRVC MANUA 767 000 0748 01 LGSVO48M-LRG GEN SRVC 1 50,005 181 025 002 500 0436 01 LGSV048T-LRG GEN SRVC T 65,873 000 4397 01 LNXO01 OO-LiNE EXT 60% G 274 01LNX00102-LlNE EXT 80% G 261 154 01 LNXO01 OJ-LINE EXT 80% G 867 01LNXO0105-CNTRCT $ MIN G 202 01 LNXO01 09-REF/NREF ADV +990 735 01LNXO0110-REFINREF ADV +645 01 LPRS047M-PART REO SRVC 124 319,106 062 000 1502 010ALT014N-OUTD AR LGT NR 606 260,424 345 938 0999 010AL T014N-OUTD AR LGT NR 973 010ALT015N-OUTD AR LGT NR 750 844 485 463 815 0866 01 PRSV036M-SML PART REO S 1,405 195 702 500 0678 01 RCFLO054-REC FIELD LGT 939 82,895 102 206 0883 01GNSVO026-LRG GENSRV DIF 894 220 328 140 386 4836 01 GNSVO026-LRG GENSRV D/F 020,625 01GNSVO027-L GENSRV -c:1Q00 210,009 754,823 087 100 627 1988 30 01GNSV027M-GNSV -c:1000 MAN 364 000 364 000 0565 31 01 LNXO0114-TEMP SVC 12MO:-291 32 01 BLSKY01 N-BLUESKY ENERGY 378 33 01ZZMERGCR-MERGER CREDITS 092 571 34 MERGR CREDIT AMORT-OR(JV)092 571 35 01XTRNO017-BLUESKY ANNUAL 877 36 01 LGSVOO48-1 OOOKW AND OVR 53,779 356 621 578,269 2298 37 01 COSTO026 - 01 GNSVO026 98,960 341 509 0338 38 01COSTO024 - 01GNSVO024 131 664 726 441 0359 39 01COSTO025 - 01GNSVO025 665 185 56,917 885 0342 40 01 COST0027 - 01 GNSVO027 381 612 647 46C 0338 TOTAL Billed 351,42C 2,463 077 923 522 44E 052 Total Unbilled Rev.(See Instr. 6)321 49E 734 000 048 TOTAL 029,9241 447 343,923 522 44E 891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31,2002(2) n A Resubmission 04/3012003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. Numcer ana Ime or Kate scneaUie Mwn ::IOla Kevenue Average Numcer ISWf( Of Sales ~G~oNo.(a)(b)(c)of cus~omers Per 1~stomer (f) 1 01COST025F - 01GNSV025F 737 109,264 0399 2 01 COSTOO48 - 01 LGSV0048 642,606 19,152 095 0298 3 01SEAFLX25 - 01GNSVO025 127 78,973 0371 4 01 FXRENEWN - Fixed Renewable 914 5 01HABIT024 - 01GNSV0024 870 0398 6 01 HABIT025 - 01 GNSVO025 572 378 0374 01RENEW024 - 01GNSVO024 19:3 0394 8 01 RENEW025 - 01 GNSVO025 015 39,527 0389 9 01PTOUO025 - 01GNSV0025 293 40,079 0310 01SEAFLX24 - 01GNSVO024 537 0394 01STDAY025 - 01GNSV0025 15,437 01STDAY027 - 01GNSVO027 817 01STQTR025 - 01GNSVO025 2,407 01STQTR027 - 01GNSVO027 976 01GNSV025T - TOU Portfolio Option 710 122 01GNSV024T - TOU Portfolio Option 354 01 GNSV024T - TOU Portfolio Option 086 01 PTOUO024 - 01 GNSVO024 200 858 0293 01GNSV024L-General Service, ;:. 30 340,278 395 01 GNSV024L-General Service, ;:. 30 391,482 01 GNSV025L - General Service - ;:. 231 808,575 290 98.7384 01LNXO0120 - Line Extension 60% G 506 UT-UPL UNBILLED REVENUE 39,761 872 000 0471 08CHCKOOON-UT NRES CHECK 08CISHO019-COMM & IND SPA 189 544 94,500 0770 08GNSVOO06-GEN SRVC-DISTR 920 942 248 015 931 10,039 490,182 0504 08GNSVOO09-GEN SRVC-HI VO 233 090 326 059 284,063 0357 08GNSVO023-GEN SRVC-DISTR 997 605 367,436 373 19,048 0655 08GNSVO06A-GEN SRVC-ENERG 139 032 588 925 286 108 112 0690 08GNSVO06B-GEN SRVC-DEM&605 426,453 422 500 0561 08GNSVO09A-GEN SRVC HI VO 15,812 605,033 812 000 0383 08GNSVO09B-GEN SERVHI VOL 119 024 59,500 0758 08GNSV023F-GEN SRVC FIXED 022 173 696 132 15,318 0859 080AL TO07N-SECURITY AR LG 828 583 932 133 915 1612 08SLCU1202-TRAF & OTHER S 552 508 274 664 0596 08SLCU1203-MTR OUTDONIGHT 642 498 288 229 29,004 0750 08LNXO0150-AGR MTH GUAR M 119 332 08LNXO0151-AGR MTH+ADV+BT 261,438 08LNXO0152-AGR ANN GUAR M 139 TOTAL Billed 351,42C 2,463 077 923 522 441 052 Total Unbilled Rev.(See Instr. 6)321,49E 734 000 048 TOTAL 47,029,92~447 343,923 522 441 891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues " Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. Numcer ana Iitie or Kate scneaUie Mwn ::soia Kevenue Average Numcer ~wn oc ;:)ales ~G~oNo.(a)(b)(c)of c~~omers Per I(~stomer (f) 1 08LNXO0157-SUBD ADV + AIC 574 2 08PTLDOOON-POST TOP LIGHT 075 500 0746 3 OBSLC1202F-TRAFFIC SIG NM 214 12,927 903 0604 4 08CFROO051-MTH FAC SRVCHG 58,430 5 08GNSVO06M-MNL DIST VOL TG 459 948,495 247 071 0451 6 08GNSVO09M-MANL HIGH VOLT 111 812,352 26,111 000 0311 7 08POLEO075-POLES W/LiGHT 859 8 08GNSV06AM-MNL ENERGY TOD 216 175,392 216,000 0545 9 08GNSV09AM-MAN TOD HIVOL T 957 94,482 957 000 0483 08GNSV09LM-GEN TOD LAGOON 535 298 270 535,000 0396 08PRSV031 M-BKUP MNT&SUPPL 694 445 717 694,000 0513 08GNSV023M-GNSV DIST VOLT 279 16,749 857 0600 08GNSV06BM-MNL DEMAND TOD 679 355 277 226 333 0532 08CFROO052-ANN FAC SVCCHG 08LNXOO153-AGR ANN+ADV+BT 1 ,494 08LNX00158-ANNUALCOST MTH 402 08RFND1999-UTAH RATE RFND 652 000 08ZZMERGCR-MERGER CREDITS 294 674 MERGR CREDIT AMORT-UT(JV)388,703 08BLSKY01 N-BLUESKY ENERGY 26,345 08GNSV06MN-GNSV DIST VOLT 020 355 727 0533 08LNXOO014-80% MIN MNTHL Y 481 006 08LNXOOO02-MTHL Y 80% GUAR 186,019 08LNXOO017 -ADV/REF&80%ANN 524 08LNXOOO06-FIXD MTHL Y MIN 254 08LNXOOOO4-ANNUAL 80%GUAR 163 08LNXOOO08-ANNUALMIN GUAR 790 08FCBUYOUT-FAC CHG BUYOUT 060 08LNXO0154 - LINE EXT CNTRC WA-PPL UNBILLED REVENUE 967 -887 000 0494 BPA BALANCING ACCOUNT 994 02GNSVO024-WA GEN SRVC 436,673 25,638 026 143 961 0587 02GNSVO025-WA GEN SRVC DO 160 027,453 289 643 0629 02GNSVO025-WA GEN SRVC DO 515,572 02GNSV024F-WA GEN SRVC-722 592 128 641 0867 02GNSV025F-GEN SRVC DOM/F 531 564 087 0764 02GNSV025F-GEN SRVC DOM/F 804 39 02LGSVO035-WA LRG GEN SRV 097 806 240 801 293 0467 02LGSVO035-WA LRG GEN SRV 641 230 TOTAL Billed 351,42C 463 077 923 522 44!10.052 Total Unbilled Rev.(See Instr. 6)321 49€734 000 048 TOTAL 029,92~447 343 923 522 44!891 0520 FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04130/2003 SALES OF ELECTRICITY BY RATE S( HEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. NumDer ana Illie Of Kate scneoUie Mvvn 0::.010 Revenue Average "Number ISWn ot ~ales ~~lgbrrNo.(a)(b)(c)of cus~omers Per r~stomer (f) 1 02LGSVO036-WA LRG GEN SRV 617 996 095 974 757 816,375 0471 2 02LGSVO48M-WA LRG GEN SRV 140 820 140,000 0844 3 02LGSVO48T -LRG GEN SRVC 1 131 736 527 103 5,489 000 0420 4 02LNXO0102-LlNE EXT 80% G 39,064 5 02LNX00103-LlNE EXT 80% G 98~ 6 02LNXO0105-CNTRCT $ MIN G 462 7 02LNXO0109-REF/NREF ADV +88,813 8 02LNX0011 O-REFINREF ADV +467 9 02LNXO0112-YR INCURRED CH 669 020AL T013N-WA OUTD AR LGT 867 061 664 306 0970 020AL T013N-WA OUTD AR LGT 102 020AL T015N-WA OUTD AR LGT 146 191,685 935 295 0893 02RCFLOO54-WA REC FIELD L 348 685 10,545 0681 02SPWHO038-WA SPACE & WTR 190 095 111 0584 02WHCHO042-WA CNTRLD WTR 185 920 868 0806 02WHCHOO42-WA CNTRLD WTR 940 02WHCH042X-WA CNTRLD WTR 387 936 348 0774 02GNSV24FP-GNSV SEASONAL 300 60,245 132 273 2008 02BLSKY01 N-BLUESKY ENERGY 154 02ZZMERGCR-MERGER CREDITS 125 379 MERGR CREDIT AMORT-WA(JV)125,379 02RFNDCENT - CENTRALIA RFND -651 734 WY-PPL UNBILLED REVENUE 11,536 509 000 0441 05GNSVO025-WY GEN SRVC 557 227 31,749,159 18,653 29,873 0570 05GNSV025F-GEN SRVC-FL RA 880 98,107 224 929 1115 05LGSVO045-LRG GEN SRVC 351 010 16,583 789 372 943 575 0472 05LGSVO46M-WY LRG GEN SRV 177 188 437 177 000 0364 05LNXO010D-LINE EXT 60% G 248 05LNXO0102-LlNE EXT 80% G 113 943 05LNXO0105-CNTRCT $ MIN G 871 05LNXO0109-REF/NREF ADV +384,510 05LNX0011 O-REF/NREF ADV +118 050AL T015N-OUTD AR LGT SR 927 406,683 99~964 1036 05RCFLO054-WY REC FIELD L 570 441 10,556 0622 05WAHTOO43-COMM WTR HEA TI 242 000 0484 37 09GNSV0206-GEN SRVC-SINGL 016 500 1451 38 05LGSVO46T-LRG GEN SERV 122 987 545,284 460,538 0370 39 05UOFWYNON-U OF WYO SPECL 40 05LNX-ABL -APPLlCNT BUILT 367 TOTAL Billed 351,42C 2,463 077 923 522 44f 052 Total Un billed Rev.(See Instr. 6)321,49E 15,734,000 048 TOTAL 029 92~447 343 923 522 44E 891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 04/3012003 SALES OF ELECTRICITY BY RATE S( HEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. Number and Title Of Kate scnedule Mwn ::;010 Kevenue Iwerage NumDer ~vvn oT ~ales ~~'g!o lderNo.(a)(b)(c)of c~~\omers Per 9~stomer (f) 1 05BLSKY01 N-BLUESKY ENERGY 792 2 05RFNDCENT-CENTRALIA RFND 228 961 3 09RFNDCENT-CENTRALIA RFND 4 WY-UPL 5 UNBILLED REVENUE -634 35,000 0552 6 05GNSVO025-WY GEN SRVC 680 889 0710 7 05LNXO0102-LlNE EXT 80% G 004 8 05LNXO0103-LlNE EXT 80% G 992 9 05LNX00109-REF/NREF ADV +368 05LNXO011 O-REF/NREF ADV +036 09GNSV0206-GEN SRVC-SINGL 639 681 915 101 569 0714 09GNSV206F-GEN SRVC-FIXED 234 29,439 158 1258 090AL T207N-SECURITY AR LG 297 74,27:!146 034 2501 1.11 09SLCU2123-MTR OUTDONIGHT 939 500 1620 09LGSV0208-LGSV OPTIONAL 542 509,434 757 000 0483 09GNSV206M-GENSERV MANUAL 264 759 88,000 0862 09INVCHGON-INVEST MNT CHG 09LGSV208M-LGS OPTNL MANL 098 114,360 098 000 0545 05RFNDCENT-CENTRALIA RFND 101 09RFNDCENT -CENTRALIA RFND 140 901 Less Multiple Billings 853 Total Account 442.1 Commercial S 059 854 760,813,738 183 388 667 0541 Forfeited Discounts CA-PPL Late Fee 162 953 ID-UPL Late Fee 243 065 OR-PPL Late Fee 395 583 UT-UPL Late Fee 832 060 WA-PPL Late Fee 381 699 WY-PPL Late Fee 352,421 WY-UPL Late Fee 63,957 Total Account 450 Forfeited Disco 6,431 738 TOTAL Billed 351,42C 2,463,077 923 522 441:0520 Total Unbilled Rev.(See Instr. 6)321,49E 15,734,000 0489 TOTAL 029,92.11 447 343 923 522 44f 30,891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. ..me Numoer ana Illie Of Rate scheClule MWh ~OICl t(evenue Average Numoer lSWf(Of Sales ~6~oNo.(a)(b)(c)of cus~omers Per '(~stomer (f) 1 Industrial Sales 2 CA-PPL 3 UNBILLED REVENUE -808 -47 000 0582 4 06GNSVOA32-GEN SRVC-20 KW 226 142 879 55,727 1165 5 06GNSVO025-CA GEN SRVC 152 115,336 110 473 1001 6 06LGSVOA36-LRG GEN SRVC-O 264 818,810 540,211 0798 7 06LNXO01 09-REFINREF ADV +334 8 060AL T015N-OUTD AR LGT SR 228 444 1467 9 06LGSVO48T-LRG GEN SERV 640 017 067 940 000 0562 ID-UPL UNBILLED REVENUE 399 532 000 2218 BPA BALANCING ACCOUNT 56,673 07CFROOO01-MTH FACILITY S 161 07CISHO019-COMM & IND SPA 243 182 714 0707 07GNSVOO06-GEN SRVC-LRG P 258 118 376 117 745,795 0472 07GNSVOO08-GEN SRVC-MEDIU 562 136,559 640,500 0533 07GNSVOOO9-GEN SRVC-HI VO 56,733 265,651 673,300 0399 07GNSVO023-GEN SRVC-SML P 658 715,071 383 606 0826 07GNSVO06A-GEN SRVC-LRG P 816 415 449 170,400 0610 07GNSVO06A-GEN SRVC-LRG P 193 717 07GNSV023A-GEN SRVC-SML P 799 267 245 284 856 0955 07GNSV023A-GEN SRVC-SML P 79,611 070AL TO07N-SECURITY AR LG 416 850 2598 070ALT07AN-SECURITY AR LG 522 667 2610 070ALT07AN-SECURITY AR LG 07SLCU1201-TRAF SIGNAL SY 341 667 1018 07SPCLOO02 111 192 882 974 111,192 000 0349 07SPCLOO01 398 600 902 099 398,600 000 0185 07GNSVO06M-GNSV LRG POWER 515 517 0515 07GNSVO09M-MANL HIGH VOLT 4,454 176,714 4,454 000 0397 07LNXO0111-80%MIN+ADV+BIW 459 07LNXO0108-ANN COST MTHL Y 940 07LNXO0112-80%ANN+ADV+BIW 386 07LNXOO035-ADV 80%MO GUAR 904 07ZZMERGCR-MERGER CREDITS -69 632 OR-PPL UNBILLED REVENUE 003 1,497 000 0468 BPA BALANCING ACCOUNT 169,089 OR ENRGY COST RECOV AMORT 239,855 01GNSVO024-GEN SRVC DOM/F 25,224 797 4275 TOTAL Billed 351,420 2,463,077 923 522,44S 052 Total Unbilled Rev.(See Instr. 6)321,498 734,000 0489 TOTAL 029 924 447 343,923 522 44S 30,891 0520 FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescnbed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. ..Ine Numoer ano Ime OT t(ate scneoUie Mvvn ;)010 Revenue "AVerage""Number lSWh~OT ;:)ales ~R~oNo.(a)(b)(c)of Cus~omers Per ~~stomer (f) 1 01 GNSV0024-GEN SRVC DOM/F -4,453 2 01 GNSV0025-GEN SRVC 966 038 198 442 911 2045 3 01GNSV025F-GEN SRVC-FL RA 591 4 01GNSV025M-GEN SRVC MANUA 132 602 132 000 2167 5 01 LGSVO48M-LRG GEN SRVC 1 675,275 25,171,402 225 091 667 0373 6 01LGSVO48T-LRG GEN SRVC T 449 589 133 612 250 0914 7 01 LNXO01 02-LlNE EXT 80% G 831 8 01LNXO0103-LlNE EXT 80% G 990 9 01LNXO0109-REF/NREF ADV +28,237 01 LPRSO47M-PART REO SRVC 115,107 876,492 23,021,400 0597 010ALT014N-OUTD AR LGT NR 167 222 1061 010AL T014N-OUTD AR LGT NR 010AL T015N-OUTD AR LGT NR 670 55,438 192 3,490 0827 01 PRSV036M-SML PART REO S 45,186 46,000 4912 01GNSVO026-LRG GENSRV D/F 863 01 GNSVO026-LRG GENSRV D/F 920 01GNSVO027-L GENSRV -==1000 47,550 10,606,503 357 133 193 2231 01 BLSKY01 N-BLUESKY ENERGY 560 01 SPCLOOO3-117 299 275,409 117 299 000 0364 01ZZMERGCR-MERGER CREDITS 073 581 MERGR CREDIT AMORT-OR(JV)073,581 01 LGSVO048-1 OOOKW AND OVR 236,831 150,612 123 925,455 1315 01COSTO026 - 01GNSVO026 111 105 136 0338 01COSTO024 - 01GNSVO024 591 20,764 0351 01 COSTO025 - 01 GNSVO025 062 573 531 0330 01COSTO027 - 01GNSVO027 320 028 10,805 O6E 0338 01COST025F - 01GNSV025F 142 0355 01COSTOO48 - 01LGSVOO48 593,024 283,706 0291 01SEAFLX25 - 01GNSV0025 0230 01 FXRENEWN - Fixed Renewable 033 01HABIT025 - 01GNSVO025 741 0390 01RENEW024 - 01GNSVO024 0380 01RENEW025 - 01GNSVO025 785 0366 01 PTOUO025 - 01 GNSVO025 126 0315 35 01STDAY027 - 01GNSVO027 695 36 01STOTR027 - 01GNSVO027 745 37 01GNSV025T - TOU Portfolio Option 302 38 01 GNSV024L-General Service, ";. 30 328 39 01 GNSV024L-General Service, ";. 30 225 4C 01GNSV025L - General Service - ";. 814 126 415 259.1609 TOTAL Billed 351,42C 463,077,923 522 44f 052 Total Unbilled Rev.(See Instr. 6)321,49E 734 000 048 TOTAL 029 92~447 343 923 522 44f 891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifrCorp (1) An Original (Mo, Da, Yr)Dec. 31,2002(2) 0 A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues " Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. Lme Numcer ano Ime OT M:ale scneoUie Mvvn ;:,010 M:evenue 1\verage NumDer ~vvn oT ?ales ~~~olderNo.(a)(b)(c)of cus~omers Per 9~stomer (f) 1 UT-UPL 2 UNBILLED REVENUE 25,948 392 000 -0.0536 3 08EFOPO021-ELEC FURNACE 0 864 164,804 621 333 0884 4 08GNSVOOO6-GEN SRVC-DISTR 461,252 339,189 515 964 523 0509 5 08GNSVOO09-GEN SRVC-HI VO 893,566 240,557 101 748,178 0323 6 08GNSVO023-GEN SRVC-DISTR 60,962 102 667 063 15,004 0673 7 08GNSVO06A-GEN SRVC-ENERG 44,454 249,555 170 261,494 0731 8 08GNSVO06B-GEN SRVC-DEM&323 138,366 464,600 0596 9 08GNSVO09A-GEN SRVC HI VO 702 637 103 175,500 0502 08GNSV023F-GEN SRVC FIXED 252 500 2504 080AL T007N-SECURITY AR LG 786 265 739 623 867 1488 08SLCU1202-TRAF & OTHER S 746 125 0576 08SLCU1203-MTR OUTDONIGHT 3,453 286 3837 08LNXO0150-AGR MTH GUAR M 110,223 08LNXO0151-AGR MTH+ADV+BT 654 08LNXO0152-AGR ANN GUAR M 000 08LNXO0157-SUBD ADV + AIC 35,998 08CFROO051-MTH FAC SRVCHG 13,728 08GNSVO06M-MNL DIST VOL TG 48,661 346,257 4,423,727 0482 08GNSVO09M-MANL HIGH VOLT 835,219 210,603 601 583 0326 08GNSV06AM-MNL ENERGY TOD 440 1108 08SPCLOO01 556 264 15,506,710 556,264 000 0279 08SPCLOO02 308 667 802,680 308,667 000 0220 08SPCLOO03 509 241 863,200 254 620 500 0351 08SPCLOO05 242 753 7,428,748 242,753 000 0306 08GNSV09AM-MAN TOD HIVOL T 081 92,822 081,000 0859 08PRSV031M-BKUP MNT&SUPPL 109 104 781 109,000 0945 08EFOP021M-ELEC FURNACE 0 884 89,255 442,000 1010 08LNX00153-AGR ANN+ADV+BT 053 08LNXO0158-ANNUALCOST MTH 10,775 08SPCLOOO9-224 805 823 166 987 000 0304 08GNSV09BM-DMD TOD -::10000 23,220 814 081 220,000 0351 08RFND1999-UTAH RATE RFND 726,000 08ZZMERGCR-MERGER CREDITS -695,845 MERGR CREDIT AMORT-UT(JV)185 772 08GNSV06MN-GNSV DIST VOLT 199 73,000 0575 08LNXOO014-80% MIN MNTHL Y 107 08LNXOOO02-MTHL Y 80% GUAR 702 08LNXOO017-ADVlREF&80%ANN 172 WA-PPL TOTAL Billed 351,42C 2,463,077 923 522 44€0520 Total Unbilled Rev.(See Instr. 6)321,49E 15,734,000 0489 TOTAL 029,92~447 343 923 522 30,891 052 FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh , excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues " Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of un billed revenue as of end of year for each applicable revenue account subheading. I Line Numoer ana Iltle or Kate scneoUie Mwn ::;010 Kevenue Average NumDer lSWff. c:)TS"ales ~B~olderNo.(a)(b)(c)of C~~\omers Per y~stomer (f) 1 UNBILLED REVENUE 13,824 344 OOC 0249 2 BPA BALANCING ACCOUNT 388 3 02GNSV0024-WA GEN SRVC 20,734 242 713 392 893 0599 4 02GNSVO025-WA GEN SRVC DO 344 360,630 142 634 0675 5 02GNSVO025-WA GEN SRVC DO 304 6 02GNSV024F-WA GEN SRVC-916 250 1490 7 02LGSVO035-WA LRG GEN SRV 749 183 310 468,625 0489 8 02LGSVO035-WA LRG GEN SRV -40 336 9 02LGSV0036-WA LRG GEN SRV 166,087 939 203 152 092 678 0478 02LGSVO48M-WA LRG GEN SRV 116,432 508,416 216,000 0387 02LGSVO48T -LRG GEN SRVC 1 689 988 26,191 444 20,293,765 0380 02LNXO0102-LlNE EXT 80% G 608 02LNXO0109-REF/NREF ADV +2,473 020AL T013N-WA OUTO AR LGT 224 913 0960 020AL T013N-WA auTO AR LGT -405 020AL T015N-WA OUTD AR LGT 181 220 549 0841 02WHCHO042-WA CNTRLD WTR 243 000 0810 02WHCHOO42-WA CNTRLD WTR 02WHCH042X-WA CNTRLD WTR 973 000 0572 02PRSV47TM-LRG PART REOMT 400 307,634 400 000 2197 02SPCLOO01-596 793 586 596,000 0229 02GNSV24FP-GNSV SEASONAL 927 000 1545 02ZZMERGCR-MERGER CREDITS -622 878 MERGR CREDIT AMORT-WA(JV)622 878 02RFNDCENT - CENTRALIA RFND -403 010 WY-PPL UNBILLED REVENUE 398 607 000 0370 05GNSVO025-WY GEN SRVC 382 4,487 988 642 999 0526 05GNSV025F-GEN SRVC-FL RA 784 882 0938 30 05LGSVO045-LRG GEN SRVC 150 304 719 367 102 1,473,569 0447 31 05LGSV045M-LRG GEN SRVC 832 336,879 610,667 0430 32 05LGSVO46M-WY LRG GEN SRV 642 288 330,986 228,800 0363 33 05LNXO0100-LlNE EXT 60% G 589 34 05LNXO0102-LlNE EXT 80% G 344 797 35 05LNXO0105-CNTRCT $ MIN G 877 36 05LNXO0109-REF/NREF ADV +152 482 37 050AL T015N-OUTD AR LGT SR 109 10,734 817 0985 38 05LGSV046T-LRG GEN SERV 532 645 627 644 22,538 897 0343 39 05PRSV033M-PART SERV REO 614 028 651 699 153 507 000 0353 40 05LGSVO48T-LRG GENSRV TIM 054 621 101 881 210 924 200 0285 TOTAL Billed 351 463,077 923 522 441 052 Total Unbilled Rev.(See Instr. 6)321 15,734,000 048 TOTAL 029,92~2,447,343 923 522 44E 891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. LIne Numoer ana litre ot Rate scneaule Mwn::;ola I"(evenue Average NumOer ISwn ot ::;ales ~G~older No.(a)(b)(c)of Cus~omers Per r~stomer (CI (f) 1 05LGSVO48M- TOU:.1 OOOKW MAN 13,443 747 179 13,443 000 0556 2 05CONTSPEC-SPECL CONTRACT 9,494 360,687 279,235 0380 3 05SPCLOO01-392,938 10,609,326 392,938,000 0270 4 05SPCLOO02-821 327 821,000 0263 5 05RFNDCENT-CENTRALIA RFND 367 358 6 WY-UPL 7 UNBILLED REVENUE 511 924 000 0313 8 05LNXO0102-LlNE EXT 80% G 975 9 05LNXO0109-REF/NREF ADV +21,478 09GNSV0206-GEN SRVC-SINGL 32,987 989,153 389 84,799 0603 09GNSV0209-GEN SRVC-HI VO 886 263 886 000 0533 09GNSV0217-LRG POWER SRVC 484,317 16,878 359 53,813 000 0348 090AL nO7N-SECURITY AR LG 175 833 2886 09LGSV0208-LGSV OPTIONAL 17,881 836,800 4,470,250 0468 09GNSV217M-LRG POWER SRVC 261 646 079,036 65,411 500 0347 09GNSV206M-GENSERV MANUAL 098 157 514 516 333 0508 09PRSV218M-BKUP MNT SUPPL 559 872 002 279,500 1286 09LGSV208M-LGS OPTNL MANL 018 204 117 018,000 0407 09SPCLOO02-3,456 114 043 456,000 0330 09SPCLOOO3-518 036,680 518,000 0377 09RFNDCENT -CENTRALIA RFND 927 263 Less Multiple Billings 362 Total Account 442.2 Industrial Sa 17,402 646 617 361 869 12,056 443,484 0355 INTERDEPARTMENTAL OR-PPL 01COSTO025 - 01GNSVO025 634 0396 UT-UPL 08GNSVO023-GEN SRVC-DISTR 0237 08ZZMERGCR-MERGER CREDITS Total Account 448 Interdepartment 564 0434 IRRIGATION SALES CA-PPL UNBILLED REVENUE -457 -48,000 1050 06APSVO020-AG PMP SRVC 68,974 779,120 305 52,854 0693 06LNXO0103-LlNE EXT 80% G 829 06LNXO0109-REF/NREF ADV +367 06LNXO011 O-REF/NREF ADV +690 06SLXOOO01-KLAM FALLS MIN 610 TOTAL Billed 351,42C 2,463,077,923 522 44S 052 Total Unbilled Rev.(See Instr. 6)321 496 734 000 048 TOTAL 47,029,924 447 343 923 522 44S 30,891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 04/3012003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. I Line NumDer ana Iitle or Kate scneaUie Mwn ;:soia Kevenue Average NumDer ~vvn Or 9ales l')W~fo lderNo.of Cus~omers Per r~stomer(a)(b)(c)(f) 1 06SLXOOO02-KLAM FALLS IRG 378 2 06UKRBOO40-KLAM IRG ONPRJ 27,462 164,772 579 47,430 0060 3 06USBR033T USBR 938 349 306,103 0037 4 06UKRBO035-KLAM OFF PROJ 5 ID-UPL 6 IRRIGATION BPA BAL ACCT 827 223 7 07APSV010L-PUMP LRG W/BPA 483 796 30,324,024 907 123,828 0627 8 07APSV010L-PUMP LRG W/BPA 20,749,316 9 07APSV010S-PUMP SML W/BPA 150 289,510 507 213 0919 07APSV010S-PUMP SML WIBPA 134 983 07 APSV01 OX-IRG&PUMP SMALL 733 250 0816 07APSV010Y-IRG&PUMP LARGE 097 000 1097 07LNXO0103-LlNE EXT CNTRC 984 07APSVCNLL-LRG LOAD CANAL 29,63€740 336,773 0001 07APSVCNLL-LRG LOAD CANAL 241 034 07APSVCNLS-SML LOAD CANAL 578 5,438 0871 07APSVCNLS-SML LOAD CANAL 090 07BPADEBIT -BPA ADJUST FEE 983 444 07LNXO0111-80%MIN+ADV+B1W 181 07LNXO0112-80%ANN+ADV+B1W 16,793 07LNXO0107-SUBD ADV & AIC 097 0 7L NX 00 040-ADV + RE F CH G+80%380 07LNXOO015-ANNUAL 80%GUAR 513 07APSV10AL-PUMP LRG W/BPA 897 832 124 736 016 0631 07APSV10AL-PUMP LRG WIBPA 933,922 07APSV10AS-PUMP SML WIBPA 771 848 48,188 0685 07APSV10AS-PUMP SML W/BPA 33,165 07APSV10AX-IRG&PUMP SMALL 826 167 0635 07APSV10AY-IRG&PUMP LARGE 162 000 0540 07APSV10BL-PUMP LRG W/BPA 314 036 170 847 0543 07APSV10BL-PUMP LRG WIBPA 13,523 07APSV10BS-PUMP SML W/BPA 513 292 0733 33 07APSV10BS-PUMP SML W/BPA 290 34 07APSV10BX-IRG&PUMP SMALL 405 000 0579 35 07APSV10BY-IRG&PUMP LARGE 201 000 0503 36 07APSV10CL-PUMP IRG W/BPA 285 733 871 597 366 0465 37 07APSV10CL-PUMP LRG W/BPA 603 125 38 07APSV10CS-PUMP SML W/BPA 421 880 409 029 0543 39 07APSV10CS-PUMP SML W/BPA 116 40 07APSV10CX-IRG&PUMP SMALL 103 874 102 010 0570 TOTAL Billed 351,42C 463,077 923 522 44f 0520 Total Unbilled Rev.(See Instr. 6)321,49E 734 000 048 TOTAL 029,92~447 343 923 1 ,522,44f 891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. I Line Numcer ana Iltle or Kate scneaUie Mwn ::;ola Kevenue Average, Numcer ~wlJ.oT;;:oales ~W~olderNo.(a)(b)(c)of cu(~\omers Per ?~stomer (f) 1 07APSV1OCY-IRG&PUMP LARGE 974 45,397 219 0466 2 07ZZMERGCR-MERGER CREDITS 990 3 07APSC10LX - was 07APSV10CY 114 190 0631 4 07APSC10SX - was 07APSV10CX 100 1000 5 07APSCL 10X - was 07APSC10LX 508 334,991 72,710 0743 07APSCS10X -was 07APSC10SX 219 34,545 212 1577 7 07APSBS10X -IRG & PUMP - Sm 909 000 0938 8 07APSBL 10X -IRG & PUMP - Large 837 500 0892 9 07APSAL 10X -IRG & PUMP - Large 500 0340 07APSAS10X - IRG & PUMP - Small 718 875 1026 07APSA010L -IRG & Pump Large 525 158,266 116 388 0449 07APSA010L -IRG & Pump BPA 151 785 07APSA010S -IRG & Pump Small 106 760 609 0449 07APSA010S -IRG & Pump BPA 550 07APSB010L -IRG & Pump Large 286 277 860 148 35,716 0526 07APSB010L -IRG & Pump BPA 227 587 07APSB010S -IRG & Pump Large 963 136 0843 07APSB010S -IRG & Pump BPA 028 07APSC010S -IRG PUMP SRV 100 4,435 420 238 O. 0444 07APSC010S -IRG PUMP Srv BPA 302 07APSC010L - IRG PUMP Srv Large 282 10,427 534 -80 0370 07APSC010L - IRG PUMP Srv BPA 112 OR-PPL IRRIGATION BPA BAL ACCT 181 702 OR ENRGY COST RECOV AMORT -467 269 01APSVO041-AG PMP SRVC BP 344 2,467 833 509 1739 01APSVOO41-AG PMP SRVC BP -678 988 01APSV041X-AG PMP SRVC 151 102,348 256 590 6778 01 LNXO01 02-LlNE EXT 80% G 578 01LNXO0103-LlNE EXT 80% G 327 01LNXO0109-REF/NREF ADV +3,495 01 LNXO011 O-REF/NREF ADV +43,902 01SLXOOOO5-KLAMATH FALLS 202,572 01SLXOO013-K FALLS IRG MI 955 35 01SLXOO014-K FALLS IRG MI 841 36 01UKRBO035-KLAMATH BASIN 853 433,897 685 84,457 0075 37 01UKRBO035-KLAMATH BASIN 296 108 38 01UKRBO040-KLAMATH BASIN 070 366,422 343 45,473 0060 39 01UKRBOO40-KLAMATH BASIN 221 218 40 01GNSVO024-GENSRV DIF IRG 435 TOTAL Billed 351,42 2,463,077,923 522,44E 10~052 Total Unbilled Rev.(See Instr. 6)321,496 15,734 000 048 TOTAL 029 924 447 343,923 522 44E 891 0520 FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. LIne Numcer ana Ime or Kate scneaUie Mvvn ::,ola Kevenue Average, Numcer ~vvn or :;sales v ~~olderNo.(a)(b)(c)of C~~\omers Per 1~stomer (f) 1 01 GNSVO024-GENSRV DIF IRG -43 2 01 USBR33TX-IR TOU W/O BPA 891 10,749 289,100 0037 3 01 BPADEBIT-BPA ADJUST FEE 54,502 4 01GNSVO025-GEN SRVC -IRG 1,417 143 1.4170 5 01ZZMERGCR-MERGER CREDITS 127 538 6 MERGR CREDIT AMORT-OR(JV)127 538 7 01COSTO024 - 01GNSVO024 236 0393 8 01COSTO025 - 01GNSVO025 765 0403 9 01COSTOO41 123,348 006 361 0325 01RENEW041 - 01APSVO041 AG 2,488 0327 01PTOUOO41 - 01APSV0041 AG 398 10,412 0262 01 SEAFLX41 - 01APSVO041 AG 743 069 0324 01APSVO41T - AGR PUMP 15,415 01APSV041T - AGR PUMP SRV -4,080 01GNSV024T - TOU Portfolio Option 01 GNSV024T - TOU Portfolio Option 01PTOUO024 - 01GNSVO024 0320 01GNSV025L - General Service - ;:. 01APSV41 XL-OR Pumping Serv no 148,068 01APSVO41L-OR Pumping Serv 003 375 983 01APSVO41L-OR Pumping Serv 554 802 UT-UPL 08APSVO010-IRR & SOIL DRA 198 036 457 080 248 094 0427 08LNXO0153-AGR ANN+ADV+BT 26,869 08LNXO0151-AGR MTH+ADV+BT 045 08LNXO0152-AGR ANN GUAR M 294 08LNXO0159-TEMPSVC -=12MTH 214 08LNXO0150-AGR MTH GUAR M 376 08RFND1999-UTAH RATE RFND 000 08ZZMERGCR-MERGER CREDITS 661 MERGR CREDIT AMORT-UT(JV)387 08LNXOOO02-MTHL Y 80% GUAR 413 08LNXOO017 -ADV/REF&80%ANN 484 08LNXOOO04-ANNUAL 80%GUAR 531 08LNXOO014-80% MIN MNTHL Y 707 08APSV10NS-lrg Soil Drain Pump N 432 201 000 0398 WA-PPL IRRIGATION BPA BALACCT 138,129 39 02APSVOO40-WA AG PMP SRVC 142 878 532 674 937 940 0527 02APSVOO40-WA AG PMP SRVC 605,416 TOTAL Billed 351,42C 463 077 923 522 44E 052 Total Unbilled Rev.(See Instr. 6)321,49E 15,734,000 048 TOTAL 029 924 447 343,923 522,44E 30,891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04130/2003 SALES OF ELECTRICITY BY RATE S(HEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. Ine Numcer ana ,me or Kate scneaUie Mvvn ;:1010 Revenue Average Number ISwn. of ::iales ~W~olderNo.(a)(b)(c)of Cus~omers Per ?~stomer (f) 1 02APSVO40X-WA AG PMP SRVC 13,812 723 122 414 33,362 0524 2 02LNXO0102-LlNE EXT 80% G 665 3 02LNX00103-LlNE EXT 80% G 51E 4 02LNX00105-CNTRCT $ MIN G 5 02LNXO0109-REF/NREF ADV +391 6 02LNXO0110-REF/NREF ADV +37,761 7 02LGSV0035-LRG GENSRV IRG 086 137 683 028 667 0446 8 02LGSVO035-LRG GENSRV IRG 34,715 02GNSVO025-GENSRV DIF IRG 101 128 050 0706 02GNSV0025-GENSRV DIF IRG 133 02BPADEBIT-BPA ADJUST FEE 789 02GNSV24FP-GNSV SEASONAL 365 250 0730 02ZZMERGCR-MERGER CREDITS 141 488 MERGR CREDIT AMORT-WA(JV)141,488 02RFNDCENT - CENTRALIA RFND 139 WY-PPL UNBILLED REVENUE 000 0000 05LNXO0103-LlNE EXT 80% G 973 05LNXO0109-REFINREF ADV +133 05LNXO011 O-REFINREF ADV +804 05APSOOO40-AG PUMPING SVC 480 750 743 527 29,374 0485 05RFNDCENT-CENTRALIA RFND 22,949 WY-UPL 05LNXO0103-LlNE EXT 80% G 190 05LNXO0109-REF/NREF ADV +180 05LNXO0110-REFINREF ADV +469 09APSV0210-IRR & SOIL DRA 1 ,401 129,358 56,040 0923 09RFNDCENT -CENTRALIA RFND 349 Less Multiple Billings 741 Total Account 442.3 Irrigation Sa 338,059 384 624 680 997 0391 MISCELLANEOUS SERVICE REV CA-PPL Weatherization Loans 8%168 Energy Finanswer Com 784 Industrial Finanswer 048 37 Home Comfort 862 38 Irrigation Finanswer 903 39 06CFROOOO3-MTH MAINTENANC 454 4C 06CONN0300-CA RECONNECTIO 518 TOTAL Billed 351 42C 2,463,077 923 522,44E 10~052 Total Unbilled Rev.(See Instr. 6)321,49f 734,000 048 TOTAL 029 924 447 343 923 522 44€30,891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues " Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. ..me NUmDer ana Iitle Of Kate scneaUie Mvvn ::;ola Kevenue Average NUmDer ~vvn of :;sales ~W~olderNo.(a)(b)(c)of Cus~omers Per r~stomer (f) 1 06RCHK0300-CA RET CHK CHR 5,408 06TAMP0300-CA TAMP & UNAU 824 3 06TEMP0300-CA TEMP SRVC C 10,655 06TRBL0300-CA TROUBLE CAL 53C 5 ID-UPL 6 Weatherization Loans 268 7 Energy Finanswer Com 853 8 07CONN0300-ID RECONNECTIO 530 9 07RCHK0300-ID RET CHK CHR 760 07TEMPO014-TEMP SRVC CONN 575 07CFROOO01-MTH FAC SRVCHG 100 07LONGFORM-BILL PRINT 07TAMP0300 125 OR-PPL Other 939 Weatherization Loans 6.316 Weatherization Loans 8% Weatherization Loans Variable 4,492 Weatherization Loans Low Int 596 Weatherization Loans New 0%104 Weatherization Loans 108 Energy Finanswer Com 140,731 Pacific Environments 964 Industrial Finanswer 038 Home Comfort 110 Energy Finanswer 600 Irrigation Finanswer 246 Retrofit energy Finanswer 16,409 Hassel Free Water Heater 9,490 01CFROOO03-MTH MAINTENANC 885 01 CFROO013-MTH MISC CHRG 39,544 01CFROO014-YR MISC CHRG 01 CONN0300-RECONNECTION C 490,315 01 FHFGO011-FROlEN HSLE FR 171 638 01HAFGO011-HSLE FREE GUAR 999 408 01 RCHK0300-RETURNED CHECK 83,510 01TAMP0300- TAMP & UNAUTH 18,900 01TEMP0300-TEMP SRVC CHRG 252 675 01TRBL0300-TROUBLE CALL C 379 01 DPAC0300-DEMAND PULSE 500 TOTAL Billed 351,42C 2,463,077 923 522 052C Total Unbilled Rev.(See Instr. 6)321,49f 734 000 0485 TOTAL 029 92~447 343,923 522 44f 30,891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SC HEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. Ine NumDer ana Iitie Of Kate scneaUie Mvvn ;:)010 Revenue Average Number ~vvn. Of ~ales 1)W~~e lderNo.(a)(b)(c)of C~~~omers Per 9~stomer (f) 1 01 HAFG011A-HASS FREE-ANNL 910 2 01MTRVR300-METR VERIF FEE 88C 3 01 ESSC0600 - ESS charges 400 4 UT-UPL 5 Other 034 6 Energy Finanswer Com 297 791 7 Industrial Finanswer 632 8 Energy Finanswer 4,424 9 Retrofit energy Finanswer 7,417 08CFRO0013-MTH MISC CHRG 187 08RCHK0300-UT RET CHK CHR 201 735 08TEMPO014-TEMP SRVC CONN 730 245 08CFROO051-MTH FAC SRVCHG 199 934 08CFROO056-MTH EQUIP RENT 1 ,422 08CFROO063-MTH MISC CHARG 16,497 08SPCLOO07-SPECL FAC CHRG 059 08CFROO052-ANN FAC SVCCHG 424 08CON N 0300- RE CO N N& DISCO N N 318 825 08CFROOO64-ANN MISC CHARG 660 08RCONOOO1-CONNECT FEE 512 38C 081NFO0300-CUST/3RD P REQ 10e 08FCBUYOUT-FAC CHG BUYOUT 264 08T AMP0300- T AMPERING&UNAU 600 08MTRVR300 - Meter Verification F 975 WA-PPL Other 421 Energy Finanswer Com 032 Industrial Finanswer 069 Home Comfort 23,462 02CFROOOO3-MTH MAINTENANC 320 02CFROO013-MTH MISC CHRG 32 02CONN0300-WA RECONNECTIO 121 050 33 02RCHK0300-WA RET CHK CHR 154 34 02TAMP0300-WA TAMP & UNAU 450 35 02TEMP0300-WA TEMP SRVC C 260 36 WY-PPL 37 Other 15,111 38 Energy Finanswer Com 058 39 05CFROOO03-MTH MAINTENANC 032 40 05CFROO013-MTH MISC CHRG 186 TOTAL Billed 351,42C 2,463 077 923 522,052C Total Unbilled Rev.(See Instr. 6)321 734 000 O48~ TOTAL 029,92.01 447 343,923 522 44€891 0520 FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues " Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. ..me Numoer ana I me or Kate scneoUie Mvvn ::;010 Kevenue Average Numoer ~vvn or ~ales ~BfoNo.(a)(b)(c)of Cus~omers Per y~stomer (f) 1 05CONN0300-WY RECONNECTIO 115 2 05METR0300-WY FEE MTR TES 3 05RCHK0300-WY RET CHK CHR 035 4 05SERV0300-WY SRVC CALLS 220 5 05TEMP0300-WY TEMP SRVC C 085 6 05TAMP0300 175 7 05FCBUYOUT - FAC CHG BUYOUT 052 8 WY-UPL 9 Energy Finanswer 692 05CONN0300-WY RECONNECTIO 580 05RCHK0300-WY RET CHK CHR 670 05TEMP0300-WY TEMP SRVC C 380 09CFRO0014-YR MISC CHRG 09TEMP0214- TEMP SRVC CONN 09CFROOO01-MTH FAC SRVCHG 616 05TAMP0300 150 Less Multiple Billings Total Account 451 Misc. Services 298,474 OTHER ELECTRIC REVENUE OFFICE - PPL Post-Merger Firm Wheeling 009,056 Other Elec Excluding Wheeling 15,297 599 Short-Term Firm Wheeling 235,126 Wheeling Estimate 910 Other Elec Estimate 338 614 Other Elec-Def Net Power Cost 11,452 912 Green Credit 209 860 Trading Netted 605,251 CA-PPL Fish & Wildlife 773 Other Elec Excluding Wheeling 298 ID-UPL Other Elec Excluding Wheeling 494,775 OR-PPL Colstrip Unit 3 349 Post-Merger Firm Wheeling 919,292 Rec Wheeling - UPD 372,857 Other Elec Excluding Wheeling 323,602 Pre-Merger Firm Wheeling - PPL 947 877 TOTAL Billed 351 463,077 923 522,052 Total Unbilled Rev.(See Instr. 6)321,496 15,734,000 048 TOTAL 029 92-4 447 343,923 522 44S 891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold , revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. LIne Numcer ana Iltle or Kate scneaUie l\IIWIfSOI(f Kevenue Average NumDer IS.wn or ~ales ~B~olderNo.(a)(b)(c)of Cus~omers Per y~stomer (f) 1 Pre-Merger Firm Wheeling - UPL 11,840,720 2 Other Elec-DSR Carrying Chrgs 185 3 Other Elec-DSR Def Amort 18,120 780 4 DSR Net Lost Revenue 5 Non-Firm Wheeling 443,828 6 Dsr Incentive Mechanisms 878,487 7 Short-Term Firm Wheeling 933,184 8 DECOUPLING DEFERRD 930,009 9 DSR RENEWABLES DSR DEFERRED EXPEN -420 914 LINE LOSS TRANSMIS 128 055 01CFROOO01-MTH FACILITY S 15,937 01 CFROOO04-EMRGNCY ST&BY 206 01 CFROOOO5-INTERMTNT SRVC 147 UT-UPL Other Elec 69,841 Fish & Wildlife 220 Other Elec Excluding Wheeling 204 776 Other Elec-DSR Carrying Chrgs 242 538 Flyash & By-Product 363 08XTRNO016-0UTBIL SVC REN 253,549 08CFROO053-MTHL Y MAINTFEE 619 WA-PPL Colstrip Unit 3 -47 839 Fish & Wildlife 330 Other Elec Excluding Wheeling 609 206 Other Elec-DSR Carrying Chrgs 313 DSM Revenue 766 198 02CFROOO04-EMRGNCY ST&BY 655 02CFROOOO5-INTERMTNT SRVC 119 WY-PPL Other Elec 123 Other Elec Excluding Wheeling 840,041 Flyash & By-Product 534,089 05CFROOOO4-EMRGNCY ST&BY 809 05CFROOO05-INTERMTNT SRVC 098 09CFROOO05-INTERMTNT SRVC 341 WY-UPL Flyash & By-Product 161 ACCOUNTING ACCRUAL 738,406 TOTAL Billed 351,42C 2,463,077 923 522 448 052 Total Unbilled Rev.(See Instr. 6)321 ,49~15,734,000 0489 TOTAL 029 92~447 343,923 522 448 891 0520 FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 04130/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported, customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. Lme Numoer ana 'itie or Kate scneOUJe ~ola Kevenue Average Numoer ~wn or ::;ales ~6~0IderNo.(a)(b)(c)of Cus~omers Per '(~stomer (f) 1 Total Account 456 Other Electric 115 796,387 3 OTHER SALES TO PUBLIC AUTH 4 UT-UPL 5 UNBILLED REVENUE 576 000 0622 6 08GNSVOO06-GEN SRVC-DISTR 48,682 077 518 5,409 111 0427 08GNSVOO09-GEN SRVC-HI VO 012 237,239 012,000 0338 8 08GNSVO023-GEN SRVC-DISTR 615 444 0661 9 080AL TOO7N-SECURITY AR LG 043 667 1838 08GNSV009M-MANL HIGH VOLT 426 962 14,288,738 85,392,400 0335 08ZZMERGCR-MERGER CREDITS -68 194 MERGR CREDIT AMORT-UT(JV)19,789 WY-PPL OTHER SALES PUBLIC AUTH 101 871 105 0299 Less Multiple Billings Total Account 445 Other Sales 510 288 337 853 224 571 0340 PUBLIC STREET&HIGHWAY CA-PPL 06COSLO052-CO-OWND STR LG 027 500 6697 06CUSL053F-SPECIAL CUST 0 1,485 131 861 130 11,423 0888 06CUSL058F-CUST OWND STR 244 907 760 1062 06HPSVO051-HI PRESSURE SO 726 143 901 190 1982 060AL T015N-OUTD AR LGT SR 812 000 2030 ID-UPL UNBILLED REVENUE -5,000 5556 07CFROO012-STR LGTS (CONV 429 07SLCOO011-STR LGT CO-OWN 122 091 357 2876 07SLCU1201-TRAF SIGNAL SY 212 20,415 10,095 0963 07SLCU122A-STR LGT CUST-178 13,596 13,692 0764 07SLCU122B-STR LGT CUST-576 202 362 184 565 1284 07ZZMERGCR-MERGER CREDITS 216 OR-PPL OR ENRGY COST RECOV AMORT 157 707 01 COSLO052-STR LGT SRVC C 2,490 220,961 110 22,636 0887 01CUSL053F-STR LGT SRVC C 395 475 798 174 65,489 0418 01 HPSVO051-HI PRESSURE SO 634 474 260 656 930 1260 01 MVSLO050-MERC VAPSTR LG 16,637 311 392 328 50,723 0788 010AL T014N-OUTD AR LGT NR 1,478 750 2111 010ALT014N-OUTD AR LGT NR TOTAL Billed 351,42C 2,463 077 923 522,052C Total Unbilled Rev.(See Instr. 6)321,49E 734,000 0485 TOTAL 029,924 447 343 923 1 ,522 44~30,891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04/3012003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same. revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. Numoer ana I fIle or Kate scneaUie Mvvn ~ola Kevenue Average""NUmcer lSWfl OTSales ~~~olderNo.(a)(b)(c)of cu(~)omers Per !(~stomer (f) 1 010ALT015N-OUTD AR LGT NR 078 818 0993 2 01 CUSLO053-CUS-OWNED MTRD 596 267 190 0659 3 01ZZMERGCR-MERGER CREDITS -67 743 4 MERGR CREDIT AMORT -OR(JV)743 5 UT-UPL 6 UNBILLED REVENUE 36C 28,000 -0.0778 7 08CFROO012-STR LGTS (CONV 8 080AL TO07N-SECURITY AR LG 235 43,634 119 975 1857 9 08SLCOO011-STR LGT CO-OWN 393 468,590 067 22,861 1832 08SLCU1202-TRAF & OTHER S 089 503,417 564 451 0499 08SLCU1203-MTR OUTDONIGHT 1,461 869 525 0670 08SLCU121A-STR LGT CUST-550 738,770 387 24,677 0774 08SLCU121B-STR LGT CUST-15,875 393,985 640 24,805 0878 08SLC1202F-TRAFFIC SIG NM 137 63,418 125 096 0558 08CFROO051-MTH FAC SRVCHG 529 08CFROO062-STREET LIGHTS 08THIKOO77-STR LIGHT SPEC 141 17 ,277 141,000 1225 08CFROO061-UIG AREA LIGHT 127 08HAXT0060-LI GHTN G-HAX TON 465 000 4650 08ZZMERGCR-MERGER CREDITS 30,096 MERGR CREDIT AMORT-UT(JV)985 08SLD13ES2-DECOR CUST-OWN 652 165,701 182 600 0454 08SLD13MS2-DECOR CUST-OWN 118 12,574 750 1066 08SLD13FS2-DECOR CaMP-OWN 10,143 750 6762 08SLD13MS1-DECOR CUST-OWN 098 10,000 1033 08SLD13ES1-DECOR CUST-OWN 176 36,131 98,000 0307 08SLD13FS1-DECOR COMP-OWN 568 000 4280 WA-PPL 02CFROO012-STR LGTS (CONV 02COSLO052-WA STR LGT SRV 454 38,562 21,619 0849 02CUSL053F-WA STR LGT SRV 961 176,314 150 26,407 0445 02CUSL053M-WA STR LGT SRV 948 686 561 0524 02HPSVO051-WA HI PRESSURE 059 402 592 116 26,371 1316 02MVSLO057-WA MERC VAPSTR 572 204 523 188 0795 02ZZMERGCR-MERGER CREDITS 14,724 MERGR CREDIT AMORT-WA(JV)724 02RFNDCENT - CENTRALIA RFND 864 WY-PPL 05COSLO057-CO-OWND STR LG 605 93,193 794 1540 05CUSL058F-CUST OWND STR 385 68,87C 109 0497 TOTAL Billed 351,42(463,077 92~522 44E 31,10~052 Total Unbilled Rev.(See Instr. 6)321 49E 15,734,OOC 048 TOTAL 029,92~447 343 92~522 44E 30,891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04130/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh , excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues " Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. Line I'IUmDer ana Ime Or ~ate scneoUie MWn ~OIO Kevenue Average Numcer ~wn oT i=iales ~~~olderNo.(b)(c)of Cus Oomers Per 1~stomer(a)(f) 1 05CUSL058M-CUST OWND STR 101 870 14,429 0482 2 05HPSVO051-HI PRESSURE SO 187 597 088 185 632 1426 3 05MVSLO053-WY MERC VAPSTR 4 050AL T015N-OUTD AR LGT SR 615 000 1025 5 09SLCU2122-TRAF & OTHER S 055 000 0659 6 05MVSOO053-MERCURY VAPOR 099 450,606 231 22,074 0884 7 05RFNDCENT-CENTRALIA RFND -6,256 8 09RFNDCENT -CENTRALIA RFND 9 WY-UPL UNBILLED REVENUE 111 29,000 2613 09SLCO0211-STR LGT CO-OWN 264 338,272 364 2676 09SLCU2121-STR LGT CUST-267 133 1333 09SLCU2122-TRAF & OTHER S 114 352 143 0645 09RFNDCENT -CENTRALIA RFND -844 Less Multiple Billings 2,462 Total Account 444 Street & Highwa 146 608 913 925 403 33,297 1017 RENT FROM ELEC PROPERTIES CA-PPL MCI Fiber Optic Ground Wire 978 072 Joint use of Poles 422 983 Hydro 157 854 Transmission 06CFROOO06-MTH RNTAL CHRG 710 06CFROOO02-ANN FAC SVCCHG 189 ID-UPL Joint use of Poles 141 686 Hydro 21'i Distribution General 100 07CFROOO09-YR LSE CHRG-951 07LOOPO014-MTH FEE PRE-159 07POLEO075-STEEL POLES US 317 34 07XTRNO013-RNT/LSE L& PRO 516 35 07INVCHGOO-INVEST MNT CHG 179 36 OR-PPL 37 Rent 320 708 38 MCI Fiber Optic Ground Wire 816 421 39 Joint use of Poles 086 828 40 Hydro 761 TOTAL Billed 47,351,2,463 077 923 522 44f 052 Total Unbilled Rev.(See Instr. 6)321,15,734 000 048 TOTAL 029 924 447 343 923 522,44f 30,891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SC HEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues " Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. ,L.lne NumDer ana IlIIe or Kate scneaUie Mvvn ;:)010 Kevenue Average-Wumcer lSWf( orsares ~B'g!o lderNo.(a)(b)(c)of Cus~omers Per C(~stomer (f) 1 Transmission 243,343 2 Distribution 729 3 General 404 4 Non-Utility 39,137 5 01CFROOOO6-MTH RNTAL CHRG 591 590 6 01XTRNO013-RNT/LSE L& PRO 653 7 UT-UPL 8 Rent 22,323 9 Non Common 127 Joint use of Poles 360 227 Steam 136 100 Hydro 140,471 Transmission 419,969 Distribution 99,768 General 347 381 Corporate 000 Non-Utility 28,083 08LOOPO014-MTH FEE PRE- 08POLEOOQ4-POLE ATTACHMEN 540 08POLEO075-STEEL POLES US 116 959 08XTRNO013-RNTILSE L& PRO 445 08INVCHGON-INVEST MNT CHG 821 08LOOP014N-TEMP SERV CONN 015 08CFROO058-MTH EQUIP LEAS 658,282 08CFROO057-ANN EQUIP RENT 356 08INVCHGOR-INVEST MNT CHG 404 WA-PPL Non Common 358 Joint use of Poles 177 296 Hydro 271 943 Transmission 45C Distribution 11,762 General 34,420 Non-Utility 16,050 02CFROOO06-MTH RNTAL CHRG 758 02CFROOO01-MTH FACILITY S 114 WY-PPL Joint use of Poles 239 037 39 Steam 40,626 General 919 TOTAL Billed 351,42(463,077 923 522,44S 052 Total Unbilled Rev.(See Instr. 6)321 49E 15,734,000 048 TOTAL 47,029,92l 447 343 923 522 44S 30,891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. line NumDer ana Iltle OT Kate scheaule Mvvn ~ola Kevenue Average NumDer ~oT~ales ~B~olderNo.(a)(b)(c)of Cus&omers Per 9~stomer (f) 1 Non-Utility 000 2 05CFROOO01-MTH FACILITY S 20,661 3 05CFROOO06-MTH RNTAL CHRG 291 4 WY-UPL 5 Joint use of Poles 30,513 6 Steam 278 7 Transmission 500 8 Non-Utility 048 9 09LOOP0214-MTH FEE PRE-931 09POLEO075-STEEL POLES US 20,879 09POLEOO04-POLE A TT CABTV 2,466 Total Account 454 Rent Elect. Pro 541 981 RESIDENTIAL SALES CA-PPL UNBILLED REVENUE -6,042 301 000 0498 06LNXO0109-REF/NREF ADV +080 060AL T015R-OUTD AR LGT SR 436 015 464 940 1698 06RESDDC7A-CA RES CLEAN A 653 232 942 077 13,795 0779 06RESDDL06-CA LOW INCOME 713 291,429 010 300 0569 06RESDOOOD-RES SRVC 319 331 23,953,787 29,620 781 0750 06RESDDM9M-MUL TI FAMILY 440 027 29,333 0705 06RESDDS8M-MUL T FAM SBMET 270 162 79,375 0663 ID-UPL UNBILLED REVENUE 373 324 000 0603 BPA BALANCING ACCOUNT 260,027 07CFROOO01-MTH FACILITY S 146 07CFROOO02-YR FACILITY SR 588 070AL TO07R-SECURITY AR LG 650 789 3100 070ALT07AR-SECURITY AR LG 119 925 151 788 2683 070ALT07AR-SECURITY AR LG 482 07RESDOO01-RES SRVC 285,695 246 602 758 601 0849 07RESDOO01-RES SRVC 982 831 07RESDO036-RES SRVC-OPTIO 302,499 20,595 053 060 18,836 0681 07RESDO036-RES SRVC-OPTIO 251 334 07LNXOO035-ADV 80%MO GUAR 232 07LNXO01 07 -SUBDIV ADV+AIC 344 07ZZMERGCR-MERGER CREDITS 390 618 070ALCOO07 -CUST OWN LIGHT 2,480 000 2480 OR-PPL TOTAL Billed 351,42C 2,463,077 923 522,44 052 Total Unbilled Rev.(See Instr. 6)321 496 734 000 0489 TOTAL 029 924 447 343 923 1 ,522 44~30,891 0520 FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PaciflCorp (1) An Original (Mo, Da, Yr)Dec. 31,2002(2) 0 A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. l'Iumoer ana line or Kate scneaule Mwn ::;010 Kevenue Average NumDer ~wn or :;sales ~~~olderNo.(a)(b)(c)of C~~~omers Per 9~stomer (f) 1 UNBILLED REVENUE -62,611 958,000 0792 2 BPA BALANCING ACCOUNT 639,161 3 OR ENRGY COST RECOV AMORT 14,451 690 4 01 LNXO01 02-LlNE EXT 80% G 333 5 01 LNXO01 05-CNTRCT $ MIN G 203 6 01 LNXO01 09-REF/NREF ADV +046 7 01LNXO0110-REF/NREF ADV +138 8 010ALT014R-OUTDAR LGT RE 4,408 427,205 3,471 270 0969 9 010AL T014R-OUTD AR LGT RE 32,122 010ALT015R-OUTD AR LGT RE 10,156 644 1047 01 RESDOO04-RES SRVC 642,726 264 015,872 427 20..505 4108 01 RESDOOO4-RES SRVC 959 952 1:3 01RESD0013-3 PHASE RES SR 403 35,450 686 0880 01RESDO013-3 PHASE RES SR 934 01RESD013X-3 PHASE RES10K 340 27,487 234 0808 01RESD013X-3 PHASE RES10K 374 01 UPPLOOOR-BASE SCH FALL 01ACTSETUP-NEW SRVC SETUP 01 NETMT135-NET METERING 088 077 5063 01 BLSKY01 R-BLUESKY ENERGY 30,614 161 01ZZMERGCR-MERGER CREDITS 986 689 MERGR CREDIT AMORT-OR(JV)986 689 01NETMT135-NET METERING 886 01COSTOOO4 - 01RESDOO04 373 692 129 352 134 0296 01 SEAFLXO4 - 01 RESDOOO4 008 315 176 0286 01 HABITOO4 - 01 RESDOOO4 444 208 673 0280 01 RENEWO04 - 01 RESDOO04 27,488 765,881 0279 01 FXRENEWR - Fixed Renewable 177 346 879 01 PTOUOOO4 - 01 RESDOOO4 051 228,131 0283 01 RESDO04T - RES Time Option 403,614 889 01 RESDOO4T - RES Time Option 85,809 UT-UPL UNBILLED REVENUE 777 198,000 0.4314 34 08CFROOO01-MTH FACILITY S 007 35 08LNXO0103-LlNE EXT CNTRC 553 36 08MHTPO025-MOBILE HOME &10,978 616,906 998 000 0562 37 080AL TO07R-SECURITY AR LG 331 660,258 811 874 1982 38 08RESDOO01-RES SRVC 098 510 341,479,307 586 392 695 0670 39 08RESDOO02-RES SRVC-OPTIO 107 160 10,700 0763 40 08RESD0150-RES ALL E NOT5 743 7430 TOTAL Billed 351,42C 2,463,077 923 522,44 10~052 Total Unbilled Rev.(See Instr. 6)321,49€15,734 000 048 TOTAL 029 92~447 343 923 522 44S 30,891 0520 FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) nA Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues " Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (.d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. ..lne NumDer and Iitle ot Kale scneoUie Mvvn ;)010 N:evenue p\verage. Numcer ~~~~sr;::r ~G~oNo.(a)(b)(c)of Cus~omers (f) 1 08LNXO0101-AGR MTH+ADV+BT 7,470 2 08LNX00916-MTHL Y AGR ONLY 421 3 08PTLDOOOR-POST TOP LIGHT 242 086 27C 0747 4 08LNXO0107-SUBD ADV & AIC 057 5 08SEAMINOO-SEASNL ANN MIN 6 08LNXO010S-ANN COST MTHL Y 963 7 08LNXO0109- TEMPSVC "12MTH 125 8 08LNX-ABLR-APPLlCNT BUILT 233 9 08RFND1999-UTAH RATE RFND 739 000 08ACTSETUP-NEW SRVC SETUP 08ZZMERGCR-MERGER CREDITS 297 550 MERGR CREDIT AMORT-UT(JV)520,422 08BLSKY01 R-BLUESKY ENERGY 188 635 641 08RESDOOO3-LlFELINE PRGRM 140,223 9,406,456 18,937 7,405 0671 08LNXOOOO5-MTHL Y MIN GUAR 240 08LNXOO013-80% MNTHL Y MIN 16C 08LNXOOO01-MTHL Y 80% GUAR 224 08NETMT135 - Net Metering WA-PPL UNBILLED REVENUE 649 195 000 0485 BPA BALANCING ACCOUNT 921 408 02CHCKOOOR-WA RES CHECK M 02LNXO01 09-REF/NREF ADV +413 020AL T013R-WA OUTD AR LGT 1 ,487 143 383 376 081 0964 020AL T013R-WA OUTD AR LGT 730 020AL T015R-WA OUTD AR LGT 205 200 1004 02RESDO016-WA RES SRVC 461 748 083 953 641 126 0562 02RESDO016-WA RES SRVC 297 550 02RESDO018-WA 3 PHASE RES 669 163 025 105 25,419 0611 02RESDO018-WA 3 PHASE RES 311 02RESD018X-WA 3 PHASE RES 708 978 26,222 0607 02RESD018X-WA 3 PHASE RES 7,430 02BLSKY01 R-BLUESKY ENERGY 320 421 02ZZMERGCR-MERGER CREDITS 408 326 MERGR CREDIT AMORT-WA(JV)1,408,326 36 02RESDO017 -BILL ASSIST ANC 068 187 766 199 571 0564 37 02RESDO017-BILL ASSISTANCE 214 839 38 02RFNDCENT - CENTRALIA RFND 737 009 39 WY-PPL UNBILLED REVENUE 954 640,000 0535 TOTAL Billed 351,42C 2,463 077 923 522 052C Total Unbilled Rev.(See Instr. 6)321,49E 734 000 048~ TOTAL 029,92l 447 343,923 522 44€891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SALES OF ELECTRICITY BY RATE SC HEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues " Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. NumDer ana Ime or Kate scneaUie Mwn ~ola Kevenue Average. Numcer ~wn..or?ales ~B~olderNo.(a)(b)(c)of Cu(~\omers Per 9~stomer (f) 1 05LNXO0109-REF/NREF ADV +126 2 050AL T015R-OUTD AR LGT SR 304 135,844 348 967 1042 3 05RESDOO02-WY RES SRVC 683 776 45,346 844 982 240 0663 4 05RESDOO03-WY OPTIONAL RE 118 012 6,498 927 136 977 0551 5 05RESDO018-RES 3 PHASE SR 585 36,489 786 0624 6 05RESD018X-RES 3 PHASE SR 117 080 29,250 0605 7 09RESD0201-RES SRVC 111 515 692 0842 8 05UOFWYRES-U OF WYO SPECL 410 09LNXO0108-ANN COST MTHL Y 327 05UOFWYLlT-OUTD LIGHT RES 05ACTSETUP-NEW SRVC SETUP 05BLSKY01 R-BLUESKY ENERGY 749 749 09BLSKY01 R-BLUESKY ENERGY 207 05RESDOO05-NET METERING 799 250 0615 05RFNDCENT -CENTRALIA RFND 984 567 09RFNDCENT -CENTRALIA RFND 128 05RESD0135 - Experimental Partial 950 500 0633 WY-UPL UNBILLED REVENUE 633 000 0537 05LNX00109-REF/NREF ADV +6,430 05RESDOO02-WY RES SRVC 29,870 922 0656 05RESDOO03-WY OPTIONAL RE 080 500 0583 05RESDO018-RES 3 PHASE SR 682 10,000 0682 090AL T207R-SECURITY AR LG 219 108 852 2633 09RESD0201-RES SRVC 918 445 576 673 254 0866 09RESD0205-RES SRVC ALL E 081 788 258 229 18,430 0679 09INVCHGOR-INVEST MNT CHG 05ACTSETUP-NEW SRVC SETUP 05BLSKY01 R-BLUESKY ENERGY 132 05RFNDCENT -CENTRALIA RFND -669 09RFNDCENT-CENTRALIA RFND 124 954 Less Multiple Billings 33,562 Total Account 440 Residential Sal 572,456 841 522 770 299,893 10,441 0620 TOTAL Billed 351 463 077 923 1 ,522,44~10~052 Total Unbilled Rev.(See Instr. 6)321 734,000 048 TOTAL 47,029,924 447 343,923 522 44E 30,891 052C FERC FORM NO.1 (ED. 12-95)Page 304. Blank Page (Next Page is: 310) Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31, 2002 (2) n A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) 1. Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Line Name of Company or Public Authority Statistical FERC Rate Avera Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly illing AVera Aver cation Tariff Number Demand (MW)Monthly NC Deman Monthly C emand (a)(b)(c)(d)(e)(f) Requirement Sales Blanding City T-6 Brigham City 318 Deaver, Town of T-4 Helper City T-6 Helper City Annex T-6 Navajo Tribal Utility Authority (Mexica T-6 Navajo Tribal Utility Authority (Red Me T-6 Portland General Electric Company .",......, 147 Portland General Electric Company 147 Price City T-6 Accrual adjustment Nonrequirement Sales Subtotal RO Subtotal non- Total FERC FORM NO.1 (ED. 12-90)Page 310 Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2)0 A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) (Continued) as - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RO sales together and report them starting at line number one. After listing all RO sales, enter "Subtotal - RO" in column (a). The remaining sales may then be listed in any order. Enter IISubtotal-Non-RO" in column (a) after this Listing. Enter Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RO sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (50-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column 0). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RO/Non-RO grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RO" amount in column (g) must be reported as Requirements Sales For Resale on Page 401 , line 23. The "Subtotal - Non-RO" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401 ,iine 24. 10. Footnote entries as required and provide explanations following all required data. MegaWatt Hours REVENUE Total ($)Line Sold Demand Charges Energy Charges Other Charges (h+i+j)No. ($)($)($) (9)(h)(i)(k) 659 310 904 214 100 985 565,570 759 166 324 736 920 13,151 16,607 758 946 107 293 105 353 212 646 883 764 805 141 569 979 173 061 234 187 689 940 142 629 -43 559 240 956 273 956 273 796 007 536 147 364 154,900 349 104,654,"\'c"' 198,901 880,486 172,473 135 213 188 172 30,334 565 114 731 005 956,769,059 106 582 907 964 917 157 30,533,466 117 611,491 960,941,532 106,447,694 972,105,329 FERC FORM NO.1 (ED. 12-90)Page 311 Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) 1. Report all sales for resale (Le., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Line Name of Company or Public Authority Statistical FERC Rate Avera Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly iIIing Avera Avera cation Tariff Number Demand (MW)Monthly NC Deman Monthly CP emand (a)(b)(c)(d)(e)(f) Allegheny Energy Supply Company, LLC WSPP American Electric Power Co., Inc.WSPP American Electric Power Co., Inc.WSPP Anaheim, City of WSPP Anaheim, City of WSPP Aquila Power Corporation WSPP Aquila Power Corporation WSPP 8 Arizona Electric Power Cooperative 9 Arizona Public Service Company WSPP Avista Corporation WSPP Avista Corporation WSPP Avista Energy, Inc.WSPP Avista Energy, Inc.WSPP Axia Energy, LP WSPP Subtotal RQ Subtotal non- Total FERC FORM NO.1 (ED. 12-90)Page 310. Name of Respondent This 'OOort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) nA Resubmission 04/3012003 SALES FOR RESALE (Account 447) (Continued) OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RO" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column 0). Explain in a footnote all components of the amount shown in column 0). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401 , line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401 iine 24. 10. Footnote entries as required and provide explanations following all required data. MegaWatt Hours REVENUE Total ($)Line Sold Demand Charges Energy Charges Other Charges (h+i+j)No. ($)($)($)(g) (h)(i)(k) 200 960 372 786 35,372 786 125 440 440 659 688 73,243,412 73,243,412 990 030 030 18,256 627 850 627 850 585 060 060 355 985 179,815 179 815 15,624 523 500 261 702 785 202 198,550 699 792 699,792 150 150 150 937 868 654 868 654 158 880 670 134,334 068 161 069 449 153,975 337 385 337 385 198,901 880 486 172,473 135 213 188 172 334,565 114,731 005 956 769 059 106 582 907 964 917 157 30,533,466 117,611,491 960,941 532 106,447,694 972,105,329 FERC FORM NO.1 (ED. 12-90)Page 311. Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/3012003 SALES FOR RESALE (Account 447) 1. Report all sales for resale (Le., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RO - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Line Name of Company or Public Authority Statistical FERC Rate Avera Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly illing I'\vera Aver cation Tariff Number Demand (MW)Monthly NC Deman Monthly C mand (a)(b)(c)(d)(e)(f) 1 Azusa Light and Water Department 2 Azusa Light and Water Department WSPP 3 BP Energy Company WSPP 4 Basin Electric Power Company III5 Basin Electric Power Company WSPP 6 Basin Electric Power Company 7 Basin Electric Power Company WSPP 8 Black Hills Power and Light Company 236 9 Black Hills Power and Light Company :L:r:236 Black Hills Power and Light Company :\;. 246 Black Hills Power and Light Company 424 Black Hills Power and Light Company g,~ Black Hills Power and Light Company Black Hills Power and Light Company WSPP Subtotal RQ Subtotal non- Total FERC FORM NO.1 (ED. 12-90)Page 310. Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2)0 A Resubmission 04/3012003 SALES FOR RESALE (Account 447) (Continued) OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column 0). Explain in a footnote all components of the amount shown in column 0). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401 iine 24. 10. Footnote entries as required and provide explanations following all required data. MegaWatt Hours REVENUE Total ($)Line Sold Demand Charges Energy Charges Other Charges (h+i+j)No. ($)($)($)(g) (h)(i)(k) 194 632 632 494 13,638 13,638 741,889 22,469 649 22,469 649 240 240 598 598 949 78,010 78,010 919 963 963 280 331 425,913 725,575 4,469 399 194 974 640 733 14,733 760 540 000 585,792 125,792 690 13,080 13,080 605 13,805 13,805 019 650 821 650,821 198,901 880,486 172,473 135,213 188 172 334,565 114 731 005 956 769,059 106 582,907 964 917 157 30,533,466 117,611,491 960,941 532 106,447,694 972,105,329 FERC FORM NO.1 (ED. 12-90)Page 311. Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr) Dec. 31, 2002(2) n A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) 1. Report all sales for resale (Le., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as , or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Line Name of Company or Public Authority Statistical FERC Rate Avera Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly iIIing JWera Avera cation Tariff Number Demand (MW)Monthly NC Deman Monthly CP emand (a)(b)(c)(d)(e)(f) 1 Black Hills Power and Light Company Black Hills Power and Light Company WSPP 3 Blanding City Bonneville Power Administration 5 Bonneville Power Administration 543 Bonneville Power Administration Bonneville Power Administration WSPP Bonneville Power Administration WSPP Burbank, City of WSPP California ISO Cheyenne Light, Fuel and Power Company 421 Clark County Public Utility District Clark County Public Utility District Colorado Springs Utilities WSPP Subtotal RQ Subtotal non- Total FERC FORM NO.1 (ED. 12-90)Page 310. Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002(2) n A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) (Continued) OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature ofthe service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service , enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401 , line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401 iine 24. 10. Footnote entries as required and provide explanations following all required data. MegaWatt Hours REVENUE Total ($)Line Sold Demand Charges Energy Charges Other Charges (h+i+j)No. ($)($)($)(g) (h)(i)(k) 120 120 125,883 063 988 063,988 345 135 000 216 132 351 132 , , 834,547 473,040 21,404 034 21,404 034 919 288,981 288 981 375 875 875 26,495 760 620 760,620 140 713 280 713,28C 903 755 53,755 I , ! ' 583 /",,;.,,;,;,;\; ~t , 092 577,577 378 526 11 ,212,375 12,461 301 440 655 655 198 901 880,486 172,473 135 213 188,172 334 565 114 731 005 956 769 059 106 582 907 964 917 157 30,533,466 117,611,491 960,941,532 106,447 694 972 105,329 FERC FORM NO.1 (ED. 12-90)Page 311. Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2) CiA Resubmission 04/30/2003 SALES FOR RESALE (Account 447) 1. Report all sales for resale (Le., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projected load for this servic:.e in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF , provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Line Name of Company or Public Authority Statistical FERC Rate Avera Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly illing Avera Aver cation Tariff Number Demand (MW)Monthly NC Deman Monthly C emand (a)(b)(c)(d)(e)(f) Colorado Springs Utilities WSPP ConAgra Energy Services, Inc.WSPP Conoco Inc.WSPP Constellation Power Source, Inc.WSPP Coral Power, L.L.C.WSPP Coral Power, L.L.C.WSPP Cowlitz County Public Utility District Cowlitz County Public Utility District Deseret Generation & Transmission Coope 462 Deseret Generation & Transmission Coope 462 Deseret Generation & Transmission Coope 462 Duke Energy Trading & Marketing, LLC WSPP Duke Energy Trading & Marketing, LLC WSPP Duke Energy Trading & Marketing, LLC WSPP Subtotal RQ Subtotal non- Total FERC FORM NO.1 (ED. 12-90)Page 310. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) OA Resubmission 04/30/2003 SALES FOR RESALE (Account 447) (Continued) OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature )f the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (6o-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column 0). Explain in a footnote all components of the amount shown in column 0). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401 iine 24. 10. Footnote entries as required and provide explanations following all required data. MegaWatt Hours REVENUE Total ($)Line Sold Demand Charges Energy Charges Other Charges (h+i+j)No. ($)($)($)(g) (h)(i)(k) 847 144 060 144 060 000 617 900 617 900 024 60,864 60,864 636,140 18,604 819 604 819 960 960 641 613 465,071 21,465,071 146 ~:,,:,':\, 816 559 389 391 651 434 040 740 295 246,498 936 743 936 743 33,609 402 630 402,630 150 111 111 761 164 922 149 922 149 198,901 880,486 172,473 135,213 188 172 30,334 565 114 731 005 956,769,059 106,582 907 964,917 157 30,533,466 117,611,491 960,941,532 106,447,694 972,105,329 FERC FORM NO.1 (ED. 12-90)Page 311. Name of Respondent This 'OOort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31,2002(2) 0 A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) 1. Report all sales for resale (Le., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Line Name of Company or Public Authority Statistical FERC Rate Avera Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly iIIing Avera Avera cation Tariff Number Demand (MW)Monthly NC Deman Monthly CP emand (a)(b)(c)(d)(e)(f) Dynegy Power Marketing, Inc.WSPP Eagle Mountain City Edison Mission Marketing & Trading, Inc EI Paso Electric Company WSPP EI Paso Electric Company WSPP EI Paso Energy Marketing Company WSPP Eugene Water & Electric Board ",...,., .., "';-G"..WSPP ';"' 8 Eugene Water & Electric Board WSPP 9 Flathead Electric Cooperative, Inc. ~'~.":.,:;;" Gray s Harbor Public Utility District WSPP Green Mountain Energy Resources, LLC Green Mountain Energy Resources, LLC Hermiston, City of Hinson Power Company, Inc. Subtotal RO Subtotal non- Total FERC FORM NO.1 (ED. 12-90)Page 310. Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) (Continued) as - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (50-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column 0). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401 iine 24. 10. Footnote entries as required and provide explanations following all required data. MegaWatt Hours REVENUE Total ($)Line Sold Demand Charges Energy Charges Other Charges (h+i+j)No. ($)($)($)(g) (h)(i)(k) 880 081 159 159 159 159 987 389,731 389,731 970 692 860 695 690 885 770 770 148,879 802,376 802 376 059 ~F""";X"70,357 833 604,623 604 623 149 146 656,446 656,446 602 394 33,394 129 834i""" 468 005 468 005 677 690 690 788 218 680 218 680 198 901 880,486 172 473 135,213 188,172 334 565 114 731 005 956,769 059 106,582 907 964,917 157 30,533,466 117,611,491 960,941,532 106,447,694 972 105,329 FERC FORM NO.1 (ED. 12-90)Page 311. Name of Respondent This 00/ Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 04/3012003 SALES FOR RESALE (Account 447) 1. Report all sales for resale (Le., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projected load for this service in its system resource planning). In addition , the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service , aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Line Name of Company or Public Authority Statistical FERC Rate Avera Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly illing Avera Aver cation Tariff Number Demand (MW)Monthly NC Deman Monthly C emand (a)(c)(d)(e)(f) 1 Hurricane, City of 2 Hurricane, City of IDACORP Energy loP.WSPP Idaho Power Company WSPP 5 Idaho Power Company WSPP 6 Los Angeles Department of Water and Pow 301 7 Los Angeles Department of Water and Pow WSPP 8 Los Angeles Department of Water and Pow WSPP 9 MIECO Inc.WSPP Metropolitan Water District of Southern WSPP Mirant Americas Energy Marketing, LP WSPP Mirant Americas Energy Marketing, LP WSPP Modesto Irrigation District WSPP Morgan Stanley Capital Group, Inc.WSPP Subtotal RO Subtotal non- Total FERC FORM NO.1 (ED. 12-90)Page 310. Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) (Continued) OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RO sales together and report them starting at line number one. After listing all RO sales, enter "Subtotal - RO" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RO" in column (a) after this Listing. Enter Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RO sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column 0). Explain in a footnote all components of the amount shown in column 0). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RO/Non-RO grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RO" amount in column (g) must be reported as Requirements Sales For Resale on Page 401 , line 23. The "Subtotal - Non-RO" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401 ,iine 24. 10. Footnote entries as required and provide explanations following all required data. MegaWatt Hours REVENUE Total ($)Line Sold Demand Charges Energy Charges (h+i+j)No. ($)($)($)(g) (h)(i)(k) 631 668 10,379 290 612 290,612 206,377 163,453 163,453 202 161 041 161 041 318,682 36,265 689 36,266 552 499,668'403,536 21,403,536 656 849,643 849,643 784 811 682 811 682 108 551 660,885 660 885 800 25,100 100 100 000 000 632,846 18,316,439 18,316,439 6,470 174 330 174 330 995 952 631 084 631,084 198 901 880,486 172,473 135,213 188,172 334 565 114 731 005 956,769,059 106,582 907 964 917 157 30,533,466 117 ,611,491 960,941,532 106,447,694 972,105,329 FERC FORM NO.1 (ED. 12-90)Page 311. Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) 1. Report all sales for resale (Le., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity (Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Line Name of Company or Public Authority Statistical FERC Rate Avera Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly iIIing Avera AveracationTariff Number Demand (MW)Monthly NC Deman Monthly CP emand (a)(b)(c)(d)(e)(f) 1 Municipal Energy Agency of Nebraska WSPP 2 Municipal Energy Agency of Nebraska WSPP 3 Nevada Power Company OS;");;'! ,WSPP 4 Nevada Power Company WSPP 5 Northern California Power Agency WSPP 6 PPL Energy Plus LLC ~.'+c WSPP 7 PPL Energy Plus LLC WSPP 8 PPL Montana, LLC WSPP 9 PPL Montana, LLC WSPP Pacific Northwest Generating Cooperativ WSPP PacifiCorp Pinnacle West Capital Corporation .......--:? WSPP Pinnacle West Capital Corporation WSPP Portland General Electric Company OS .,, ;:pi WSPP Subtotal RQ Subtotal non- Total FERC FORM NO.1 (ED. 12-90)Page 310. Name of Respondent PacifiCorp This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) (Continued) OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401 , line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401 iine 24. 10. Footnote entries as required and provide explanations following all required data. Year of Report Dec. 31, 2002 MegaWatt Hours Sold (g) Demand Charges ($) (h) REVENUE Energy Charges ($) Other Charges ($)(j) Total ($) (h+i+j) (k) Line No. 390 920 70,454 429 574 158 000 781 399 692 548 63,801 505,461 257 33,975 121 020 577 114 12,448,243 208,325 699 862 200 604 313 606 215 33,975 121 020 577 114 448,243 208 325 699 862, 58,334 313,606 215 109,622 562 509 187 721 348 783 198 901 30,334,565 880,486 114 731 005 172,473 956,769,059 135,213 106 582 907 188,172 964,917 157 30,533 466 117,611,491 960,941,532 106,447 694 972,105,329 FERC FORM NO.1 (ED. 12-90)Page 311. Name of Respondent This ~rt Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 04130/2003 SALES FOR RESALE (Account 447) 1. Report all sales for resale (Le., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Line Name of Company or Public Authority Statistical FERC Rate Avera Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly iIIing Avera Avera cation Tariff Number Demand (MW)Monthly NC Deman Monthly CP emand (a)(b)(c)(d)(e)(f) Portland General Electric Company WSPP PowerEX WSPP PowerEX WSPP Public Service Company of Colorado 320 176 176 176 Public Service Company of Colorado Public Service Company of Colorado WSPP Public Service Company of Colorado WSPP NJ! 8 Public Service Company of New Mexico WSPP 9 Public Service Company of New Mexico WSPP NJ! Public Utility District No.1 of Benton WSPP NJ! Public Utility District No.1 of Chelan '......". WSPP'7'" Public Utility District No.1 of Dougla NJ! Public Utility District No.1 of Dougla WSPP NJ! Public Utility District No.1 of Frankl WSPP Subtotal RO Subtotal non- Total FERC FORM NO.1 (ED. 12-90)Page 310. Name of Respondent PacifiCorp This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/3012003 SALES FOR RESALE (Account 447) (Continued) OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (50-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (BO-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401 , line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,iine 24. 10. Footnote entries as required and provide explanations following all required data. Year of Report Dec. 31 2002 MegaWatt Hours REVENUE Total ($)Line Sold Demand Charges Energy Charges Other Charges (h+i+j)No. ($)($)($)(g) (h)(i)fj)(k) 873 144 129,271 23,129,271 343 735 735 757,227 861 322 17,861 322 154,928 688 320 094 611 54,766,799 100 000 000 52,690 544 524 545,024 824,490 23,102 227 102 227 123,354 962 240 996 555 211 564 300 918 092 .930 772 273 592 592 125 942 15,002 002 150 270 270 715 730 730 198,901 334,565 880,486 114 731,005 172 473 956 769 059 135,213 106,582,907 188,172 964,917 157 30,533,466 117,611,491 960,941 532 106 447,694 972,105,329 FERC FORM NO.1 (ED. 12-90)Page 311. Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2) n A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) 1. Report all sales for resale (Le., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Line Name of Company or Public Authority Statistical FERC Rate Avera Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly illing 1\vera Avera cation Tariff Number Demand (MW)Monthly NC Deman Monthly CP emand (a)(b)(c)(d)(e)(f) 1 Public Utility District No.2 of Grant WSPP Public Utility District No.2 of Grant WSPP 3 Puget Sound Energy 254 200 200 196 Puget Sound Energy 5 Puget Sound Energy WSPP 6 Puget Sound Energy WSPP 7 Redding, City WSPP 8 Redding, City WSPP 9 Reliant Energy Services, Inc.WSPP Riverside, City of WSPP Riverside, City of WSPP Sacramento Municipal Utility District 250 ' , Sacramento Municipal Utility District 250 Sacramento Municipal Utility District WSPP Subtotal RQ Subtotal non- Total FERC FORM NO.1 (ED. 12-90)Page 310. Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) (Continued) OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature ofthe service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column 0). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401 , line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401 ,iine 24. 10. Footnote entries as required and provide explanations following all required data. MegaWatt Hours REVENUE Total ($)Line Sold Demand Charges Energy Charges Other Charges (h+i+j)No. ($)($)($)(g) (h)(i) (j) (k) 500 600 60C 250 653 76-672,765 051 901 192 000 18,439,423 631 423 109 757 17,757 750 300 20,385 491 321 151 298 151 298 172 359,684 357 250 250 838 675 23,480 066 480 066 102 270 270 060 445 445 200,611 456 378 078,423 078,423 225 050 050 198 901 880,486 172,473 135 213 188,172 334 565 114 731 005 956 769 059 106 582 907 964 917 157 30,533 466 117,611,491 960,941 532 106,447 694 972 105,329 FERC FORM NO.1 (ED. 12-90)Page 311. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) 1. Report all sales for resale (Le., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF. provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Line Name of Company or Public Authority Statistical FERC Rate Avera Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly iIIing Avera Avera cation Tariff Number Demand (MW)Monthly NC Deman Monthly CP emand (a)(b)(c)(d)(e)(f) 1 Sacramento Municipal Utility District WSPP Salt River Project "",C\\"WSPP 3 Salt River Project WSPP San Diego Gas & Electric Company WSPP 5 San Diego Gas & Electric Company WSPP 6 Santa Clara, City of WSPP 7 Seattle City Light WSPP 8 Seattle City Light WSPP 9 Sempra Energy Trading Corporation ;.; WSPP Sempra Energy Trading Corporation WSPP Sierra Pacific Power Company 258 N,o Sierra Pacific Power Company 267 N,o Sierra Pacific Power Company 258 Sierra Pacific Power Company 267 Subtotal RQ Subtotal non- Total FERC FORM NO.1 (ED. 12-90)Page 310. Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04130/2003 SALES FOR RESALE (Account 447) (Continued) OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RO sales together and report them starting at line number one. After listing all RO sales, enter "Subtotal - RO" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RO" in column (a) after this Listing. Enter "Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RO sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (50-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column 0). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RO/Non-RO grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - Ran amount in column (g) must be reported as Requirements Sales For Resale on Page 401 , line 23. The "Subtotal - Non-RO" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401 ,iine 24. 10. Footnote entries as required and provide explanations following all required data. MegaWatt Hours REVENUE Total ($)Line Sold Demand Charges Energy Charges Other Charges (h+i+j)No. ($)($)($)(g) (h)(i)(k) 227 736 499,885 499 885 77,487 979 360 979,360 199,126 6,428,445 6,428,445 556 000 318 670 318,670 137,560 548 680 548,680 000 247 047 234 047 234 317 706 706 746,450 23,399,622 399 622 130 960 349 30,466 459,960 643,000 741,953 384 953 200 049 049 198 901 880,486 172 473 135,213 188 172 334 565 114 731 005 956,769 059 106,582 907 964 917 157 30,533,466 117 611 491 960,941 532 106,447,694 972,105,329 FERC FORM NO.1 (ED. 12-90)Page 311. Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) nA Resubmission 04/30/2003 SALES FOR RESALE (Account 447) 1. Report all sales for resale (Le., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Line Name of Company or Public Authority Statistical FERC Rate Avera Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly iIIing , Avera AveracationTariff Number Demand (MW)Monthly NC Deman Monthly CP emand (a)(c)(d)(e)(f) 1 Sierra Pacific Power Company Sierra Pacific Power Company WSPP 3 Sierra Pacific Power Company WSPP Snohomish County Public Utility Distric WSPP 5 Southem Califomia Edison Company 248 6 Southwestern Public Service Company WSPP Springfield Utility Board 423 Springfield Utility Board 9 State of California 311 State of California 311 100 100 100 Tacoma, City of WSPP Tractebel Energy Marketing, Inc.WSPP TransAlta Energy Marketing Corporation WSPP TransAlta Energy Marketing Corporation WSPP Subtotal RQ Subtotal non- Total FERC FORM NO.1 (ED. 12-90)Page 310. Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) (Continued) OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (t). For all other types of service, enter NA in columns (d), (e) and (t). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (t) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column 0). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401 iine 24. 10. Footnote entries as required and provide explanations following all required data. MegaWatt Hours REVENUE Total ($)Line Sold Demand Charges Energy Charges Other Charges (h+i+j)No. ($)($)($)(g) (h)(i)(k) 100 650 650 113 534,857 535 257 639,927 734 398 734,398 968 201 218 201 218 955 888 353 280 353 280 800 28,000 000 210,240 570 500 718 224 288 724 000 446 520 446,52C 852 316 613 163 920,000 053 696 973,696 785 340 340 200 441 810 441 810 189 094 094 379 828 082 888 39,082 888 198 901 880,486 172,473 135,213 188 172 334 565 114 731 005 956,769 059 106,582,907 964 917,157 30,533,466 117,611,491 960,941,532 106,447,694 972,105,329 FERC FORM NO.1 (ED. 12-90)Page 311. Name of Respondent This ooort Is:Date of Report Year of Report PacifiCorp (1) X An Original (Mo, Da, Yr)Dec. 31 2002 (2) t=1 A Resubmission 04/30/2003 SALES FOR RESALE (Account 447) 1. Report all sales for resale (Le., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( Le., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF , provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Line Name of Company or Public Authority Statistical FERC Rate Avera Actual Demand (MW) No.(Footnote Affiliations)Classifi-Schedule or Monthly iIIing p.vera AvercationTariff Number Demand (MW)Monthly NC Deman Monthly C emand (a)(c)(d)(e)(f) 1 Tri-State Generation and Transmission A WSPP Tri-State Generation and Transmission A WSPP 3 Tri-State Generation and Transmission A WSPP 4 Tucson Gas & Electric Company WSPP"7' ."; 5 Tucson Gas & Electric Company WSPP 6 UBS AG WSPP Utah Associated Municipal Power Systems -cc:WSPP Nfl Utah Associated Municipal Power Systems WSPP Utah Municipal Power Agency 433 Utah Municipal Power Agency 433 Utah Municipal Power Agency Utah Municipal Power Agency Wafertech Western Area Power Administration ~".." .'Y'313 Subtotal RQ Subtotal non- Total FERC FORM NO.1 (ED. 12-90)Page 310. INSTRUCTIONS FOR FILING THE FERC FORM NO. GENERAL INFORMATION I. Purpose This form is a regulatory support requirement (18 CFR 141.1). It is designed to collect financial and operational information from major electric utilities, Licensees and others subject to the jurisdiction of the Federal Energy Regulatory Commission. This report is also secondarily considered to be a nonconfidential public use form supporting a statistical publication (Financial Statistics of Selected Electric Utili ties), published by the Energy Information Administration. II. Who Must Submit Each maj or electric utility, licensee, or other, as classified in the Commission s Uniform System of Accounts Prescribed for Public Utilities and Licensees Subject to the Provisions of The Federal Power Act (18 CFR 101), must submit this form. Note: Maj or means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the following: (1)one million megawatt (2)100 megawatt hours of (3)500 megawatt hours (4)500 megawatt hours hours of total annual sales, annual sales for resale, annual power exchanges delivered, or annual wheeling for others (deliveries plus Losses). III. What and Where to Submit(a) Submi t this form electronically through the Form 1 conformed paper copies, properly filed in and attested, to: Office of the Secretary Federal Energy Regulatory Commission 888 First Street, NE. Room lA Submission Software and an original and six (6) Washington, DC 20426 Retain one copy of this report for your files. Include with the original and each conformed paper copy of this form the :subscription statement required by 18 R. 385.2011(c) (5). Paragraph (c) (5) of 18 C.R. 385.2011 requires each respondent submitting data electronically to file a subscription stating that the paper copies contain the same, information as the electronic filing, that the signer knows the contents of the paper copies and electronic filing" and that the contents as stated in the copies and electronic filing are true to the best knowledge and belief of the signer. (b) Submit, immediately upon publication, four (4) copies of the Latest annual report to stockholders and any annual financial or statistical report regularly prepared and distributed to bondholders, security analysts, or industry associations. (Do not include monthly and quarterly reports. Indicate by checking the appropriate box on Page 4, List of Schedules, if the reports to stockholders will be submitted or if no annual report to stockholders is prepared.) Mail these reports to: Chief Accountant Federal Energy Regulatory Commission 888 First Street, NE. Washington, DC 20426 (c) For the CPA certification, submit with the original submission, or within 30 days after the filing date for this form, a Letter or report (not applicable to respondents classified as Class C or Class D prior to January 1984) : (i) Attesting to the conformity, in all material aspects, of the below listed (schedules and) pages with the Commission s applicable Uniform Systems of Accounts (including applicable notes relating thereto and the Chief Accountant I s published accounting releases) and (ii) Signed by independent certified public accountants or an independent Licensed public accountant certified or Licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 CFR 41.10-41.12 for specific qualifications. FERC FORM NO.(REV. 12-99)Page GENERAL INFORMATION (continued) III. What and Where to Submit (Continued) (c) Continued Schedules Reference Pages Comparati ve Balance Sheet Statement of Income Statement of Retained Earnings Statement of Cash Flows Notes to Financial Statements 110-113 114-117 118-119 120-121 122-123 When accompanying this form, insert the Letter or report immediately following the cover sheet. When after the filing date for this form, send the letter or report to the office of the Secretary at the indicated at III (a). Use the following format for the Letter or report u~less unusual circumstances or conditions, explained in the Letter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported. submi t ting address In connection with our regular examination of the financial statements of for the year ended on which we have reported separately under date of . We have also reviewed schedules of FERC Form No.1 for the year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances. Based on our review, in our opinion the accompanying schedules identified in the preceding paragraph (except as noted below) conform in all material respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uni form System of Accounts and published accounting releases. State in the letter or report, which, if any, of the pages above do not conform to the Commission ' requirements. Describe the discrepancies that exist. (d) Federal, State and Local Governments and other authorized users may obtain additional blank copies to meet their requirements free of charge from: Public Reference and Files Maintenance Branch Federal Energy Regulatory Commission 888 First Street, NE. Room 2A ES- Washington, DC 20426 (202) 208-2474 IV. When to Submit Submit this report form on or before April 30th of the year following the year covered by this report. V. Where to Send Comments on Public Reporting Burden The public reporting burden for this collection of information is estimated to average 1,217 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data needed, and completing and reviewing the collection of information. Send comments regarding this burden estimate or any aspect of this collection of information, including suggestions for reducing this burden, to the Federal Energy Regulatory Commission, 888 First Street N. E., Washington, DC 20426 (Attention: Mr. Michael Miller, CI-l); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if this collection of information does not display a valid control number. (44 U.C. 3512 (a)). FERC FORM NO.(REV. 12-99)Page GENERAL INSTRUCTIONSI. Prepare this report in conformity with the Uniform System of Accounts (18 CFR 101) all accounting words and phrases in accordance with the U. S. of A. (U.S. of A.). Interpret II. Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes , use for balance sheet accounts the balances at the end of the current reporting year, and use for statement of income accounts the current year s amounts. III. Complete each question fully and accurately, even if it has been answered in a previous annual report. Enter the word "None " where it truly and completely states the fact. IV. For any page (s) that is not applicable to the respondent, omit the page (s) and enter "NA, " " NONE," or "NotApplicable" in column (d) on the List of Schedules, pages 2, 3, and 4. V. Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below). The date of the resubmission must be reported in the header for all form pages, whether or not they are changed from the previous filing. VI. Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, mustbe reported as posi ti ve. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses. VII. For any resubmissions, submit the electronic filing using the Form 1 Submission Software and an original andsix (6) conformed paper copies of the entire form, as well as the appropriate number of copies of the subscription statement indicated at instruction III (a). Resubmissions must be numbered sequentially on the cover page of the paper copies of the form. In addition , the cover page of each paper copy must indicate that the filing is a resubmission. Send the resubmissions to the address indicated at instruction III (a). VIII. Do not make references to reports of previous years or to other reports in lieu of required entries, except as specifically authorized. IX. Wherever (schedule) pages refer to figures from a previous year , the figures reported must be based upon those shown by the annual report of the previous year, or an appropriate explanation given as to why the different figures were used. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - DEFINITIONS - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- I. Commission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any other Commission. Name the commission whose authorization was obtained and give date of the authorization. II. Respondent -- The person, corporation, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report is made. FERC FORM NO.(REV. 12-99)Page iii EXCERPTS FROM THE LAW Federal Power Act, 16 U.C. 791a-825r) Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to wit: . . . (3) "Corporation" means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shalt not include 'municipalities, as hereinafter defined; (4) "Person" means an individual or a corporation; (5) "Licensee " means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor in interest thereof; (7) "Municipality" means a city, county, irrigation or agency of a State competent under the Laws thereof unitizing, or distributing power;... (11) "Project" means a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or forebay reservoirs directly connected therewith, the primary line or Lines transmi tting power therefrom to the point of j unction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit; district, drainage district, or other political subdivision to carry an the business of developing, transmitting, Sec. 4. The Commission is hereby authorized and empowered: (a) To make investigations and to collect and record data concerning the utilization of the water ' resources of any region to be developed, the water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity, development costs, and relation to markets of power sites; to the extent the Commission may deem necessary or useful for the purposes of this Act. Sec. 304. (a) Every Licensee and every public utility shall file with the Commission such annual and other periodic or special reports as the Commission may be rules and regulations or other prescribe as necessary or appropriate to assist the Commission in the proper administration of this Act. The Commission my prescribe the manner and form in which such reports shalt be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shall include, among other things, full information as to assets and Liabilities, capitalization, net investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The commission may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission otherwise specifies. Sec. 309. The Commission shall have power to perform any and all acts, and to prescribe, issue, make, and rescind such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this Act; and may prescribe the form or forms of all statements, declarations, applications, and reports to be filed with the commission, the information which they shall contain, and the time within which they shall be filed... - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - -- - - -- - - - --- - - - - - - -- - - - - - - - - - - - - - -- - - -- - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - General Penal ties - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - -- - - -- - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - -- - - - - - - - - - - - - - -- -- - - - - - - - - - -- - - - - - -- - - --- -- - -- Sec. 315. (a) Any licensee or public utility which willfully fails, within the time prescribed by the Commission, to comply with any order of the Commission, to file any report required under this Act or any rule or regulation of the Commission thereunder, to submit any information of document required by the Commission in the course of an investigation conducted under this Act ... shall forfeit to the United States an amount not exceeding $1,000 to be fixed by the Commission after notice and opportunity for hearing... FERC FORM NO.(ED. 12-91)Page iv FERC FORM NO. ANNUAL REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER IDENTIFICATION 01 Exact Legal Name of Respondent PacifiCorp 02 Year of Report Dec. 31 2002 03 Previous Name and Date of Change (if name changed during year) / / 04 Address of Principal Office at End of Year (Street, City, State, Zip Code) 825 N.E. Multnomah , Suite 2000 Portland, OR 97232 05 Name of Contact Person Henry Lay 06 Title of Contact Person Accounting Director 07 Address of Contact Person (Street, City, State, Zip Code) 825 N.E. Multnomah , Suite 1900 Portland, OR 97232 08 Telephone of Contact Person,lncluding 09 This Report Is Area Code (1) 00 An Original (503) 813-6179 (2) 0 A Resubmission 10 Date of Report (Mo, Da, Yr) 04/30/2003 ATTESTATION The undersigned officer certifies that he/she has examined the accompanying report: that to the best of his/her knowledge, information, and belief, all statements of fact contained in the accompanying report are true and the accompanying report is a correct statement of the business and affairs of the above named respondent in respect to each and every matter set forth therein during the period from and including January 1 to and including December 31 of the year of the report. 01 Name 03 Signature 04 Date Signed (Mo, Da, Yr)Jeffrey K. Larsen 02 Title Vice President, Compliance II 7j Title 18, U.C, 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction. FERC FORM No.1 (ED. 12-91)Page 1 Name of Respondent This i!Jort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31,2002(2) nA Resubmission 04/30/2003 LIST OF SCHEDULES (Electric Utility) Enter in column (c) the terms "none, " " not applicable " or "" as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none, " " not applicable," or "NA" Line Title of Schedule Reference Remarks No.Page No. (a)(b)(c) Generallnformation 101 Control Over Respondent 102 Corporations Controlled by Respondent 103 Officers 104 Directors 105 Important Changes During the Year 108-109 Comparative Balance Sheet 110-113 Statement of Income for the Year 114-117 Statement of Retained Eamings for the Year 118-119 Statement of Cash Flows 120-121 Notes to Financial Statements 122-123 Statement of Accum Comp Income, Comp Income, and Hedging Activities 122(a)(b) Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep 200-201 Nuclear Fuel Materials 202-203 Electric Plant in Service 204-207 Electric Plant Leased to Others 213 Electric Plant Held for Future Use 214 Construction Work in Progress-Electric 216 Accumulated Provision for Depreciation of Electric Utility Plant 219 Investment of Subsidiary Companies 224-225 Materials and Supplies 227 Allowances 228-229 Extraordinary Property Losses 230 Unrecovered Plant and Regulatory Study Costs 230 Other Regulatory Assets 232 Miscellaneous Deferred Debits 233 Accumulated Deferred Income Taxes 234 Capital Stock 250-251 Other Paid-in Capital 253 Capital Stock Expense 254 Long-Term Debit 256-257 Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax 261 Taxes Accrued, Prepaid and Charged During the Year 262-263 Accumulated Deferred Investment Tax Credits 266-267 Other Deferred Credits 269 Accumulated Deferred Income Taxes-Accelerated Amortization Property 272-273 FERC FORM NO.1 (ED. 12-96)Page 2 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) 0 A Resubmission 04/30/2003 LI ;jT OF SCHEDULES (Electric Utility) (continued) Enter in column (c) the terms "none " " not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none, " " not applicable " or "NA" Line Title of Schedule Reference Remarks No.Page No. (a)(b)(c) Accumulated Deferred Income Taxes-Other Property 274-275 Accumulated Deferred Income Taxes-Other 276-277 Other Regulatory Liabilities 278 Electric Operating Revenues 300-301 Sales of Electricity by Rate Schedules 304 Sales for Resale 310-311 Electric Operation and Maintenance Expenses 320-323 Purchased Power 326-327 Transmission of Electricity for Others 328-330 Transmission of Electricity by Others 332 Miscellaneous General Expenses-Electric 335 Depreciation and Amortization of Electric Plant 336-337 Regulatory Commission Expenses 350-351 Research, Development and Demonstration Activities 352-353 Distribution of Salaries and Wages 354-355 Common Utility Plant and Expenses 356 Electric Energy Account 401 Monthly Peaks and Output 401 Steam Electric Generating Plant Statistics (Large Plants)402-403 Hydroelectric Generating Plant Statistics (Large Plants)406-407 Pumped Storage Generating Plant Statistics (Large Plants)408-409 Generating Plant Statistics (Small Plants)410-411 Transmission Line Statistics 422-423 Transmission Lines Added During Year 424-425 Substations 426-427 Footnote Data 450 Stockholders' Reports Check appropriate box: !!I Four copies will be submitted No annual report to stockholders is prepared FERC FORM NO.1 (ED. 12-96)Page 3 Name of Respondent PacifiCorp This Report Is: (1) 00 An Original(2) 0 A Resubmission Date of Report (Mo, Da, Yr) 04/30/2003 Year of Report Dec. 31 2002 GENERAL INFORMATION 1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept. Richard Peach, Chief Financial Officer 825 N.E. Multnomah, Suite 2000 Portland, Oregon 97232-4116 Corporate books are kept at: 825 N.E. Multnomah, Suite 2000 Portland, OR 97232-4116 2. Provide the name of the State under the laws of which respondent is incorporated , and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized. Incorporated on January 9, 1989 in the State of Oregon. 3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee , (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created , and (d) date when possession by receiver or trustee ceased. Not Applicable Not Applicable. 4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated. The Company is an electric utility that conducts a retail electric utility business through Pacific Power and utah Power and engages in power production and sales on a wholesale basis under the name PacifiCorp. The Company furnishes electric service in portions of California, Idaho, Oregon, utah, Washington, and Wyoming. 5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements? (1) 0 Yes...Enter the date when such independent accountant was initially engaged: (2) 00 FERC FORM No.1 (ED. 12-87)PAGE 101 Name of Respondent PacifiCorp This Report Is: (1) 00 An Original(2) 0 A Resubmission Date of Report (Mo, DB, Yr) 04/30/2003 Year of Report Dec. 31 2002 CONTROL OVER RESPONDENT 1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the repondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s) , state name of trustee(s) , name of beneficiary or beneficiearies for whom trust was maintained, and purpose of the trust. Scottish Power pic Scottish Power NA 1 Limited Scottish Power NA 2 Limited NA General Partnership PacifiCorp Holdings, Inc. PacifiCorp (100% controlled) FERC FORM NO.1 (ED. 12-96)Page 102 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31,2002(2) DA Resubmission 04/30/2003 RPORATIONS CONTROLLED BY RESPONDENT Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent at any time during the year.If control ceased prior to end of year, give particulars (details) in a footnote. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held , naming any intermediaries involved. If control was held jointly with one or more other interests , state the fact in a footnote and name the other interests. Definitions See the Uniform System of Accounts for a definition of control. Direct control is that which is exercised without interposition of an intermediary. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other.Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party. Line Name of Company Controlled Kind of Business Percent Voting Footnote No.Stock Owned Ref. (a)(b)(c)(d) 8i~~ '-:m~' ;.:' Mining 100 ' :, ,, :,,, " ;7" \'. ':f':;'fi:':;' "'", Energy West Mining Company Mining 100 Glenrock Coal Company Mining 100 Interwest Mining Company Mining 100 Pacific Minerals, Inc,Mining 100 ~'COOj Mining 66. ' ... '. '". :. p~~ffi~~r Environmental Services 90. ~C()rpFuglte~: ~~q . Rain Forest Carbon Credits 100 PacifiCorp Investment Management, Inc Management Services for PERCO 100 pacifico rp qrq tiP ~~ 9; PPm~11y3 . .,'" Holding Company 100 PacifiCorp Capital I Financing Company 100 PacifiCorp Capital II Financing Company 100 FERC FORM NO.1 (ED. 12-96)Page 103 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) CiA Resubmission 04/30/2003 OFFICERS 1. Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer" of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions. 2. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made. LIne Iltle Name Of ulTlcer ::Sc ary No.for Year(a)(b)(c) President and Chief Executive Officer Judith A. Johansen Executive Vice President William D. Landels Senior Vice President, General Counsel and Corporate Andrew P. Haller Secretary ==== Senior Vice President Michael J. Pittman Senior Vice President A. Richard Walje Executive Vice President Andrew N. MacRitchie Executive Vice President ;",;, Senior Vice President Senior Vice President Donald N. Furman Senior Vice President Robert A. Klein Senior Vice President Vice President ~'";..:" Vice President Donald D. Larson Vice President Stan Watters Vice President Emest E. Wessman Treasurer Bruce N. Williams VP & Principal Financial Officer ~ffrayb;Huggih$. , ' FERC FORM NO.1 (ED. 12-96)Page 104 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04130/2003 DIRECTORS 1. Report below the information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), abbreviated titles of the directors who are officers of the respondent. 2. Designate members of the Executive Committee by a triple asterisk and the Chairman of the Executive Committee by a double asterisk. IL. ~~. Name (an~ :ntle) of Director PrInCIpal Business Aaaress (a)(b) PacifiCorp Board of Directors: l1IiiIl1S1"1 Atlantic Quay",,'r'f10'7h... Glasgow, Scotland G28SP *** Judith A. Johansen (President & CEO)825 NE Multnomah Portland, Oregon 97232 *** William D. Landels (Executive Vice President)201 South Main, Ste 2300 Salt Lake City, UT 84140 *** Andrew N. MacRitchie (Executive Vice President)825 NE Multnomah Portland, Oregon 97232 Matthew R. Wright (Executive Vice President)825 NE Multnomah Portland, Oregon 97232 825 NE Multnomah Portland, Oregon 97232 *** Michael J. Pittman (Senior Vice President)825 NE Multnomah Portland, Oregon 97232 A. Richard Walje (Senior Vice President)825 NE Multnomah Portland, Oregon 97232 Nolan E. Karras 4695 South 1900 West #3 Roy, Utah 84067 "-. 1 Atlantic Quay Glasgow, Scotland G2 8SP FERC FORM NO.1 (ED. 12-95)Page 105 This Report Is: Date of Report (1) 129 An Original(2) 0 A Resubmission 04/30/2003 1M ~ORTANT CHANGES DURING THE YEAR Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none " " not applicable " or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears. 1. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact. 2. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization. 3. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission. 4. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization. 5. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc. 6. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization , as appropriate, and the amount of obligation or guarantee. 7. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments. 8. State the estimated annual effect and nature of any important wage scale changes during the year. 9. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year. 10. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer director, security holder reported on Page 106, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest. 11. (Reserved. 12. If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page. Name of Respondent PacifiCorp Year of Report Dec. 31 2002 PAGE 108 INTENTIONALLY LEFT BLANK SEE PAGE 109 FOR REQUIRED INFORMATION. FERC FORM NO.1 (ED. 12-96)Page 108 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec 31 2002 IMPORTANT CHANGES DURING THE YEAR (Continued) 1. The following PacifiCorp franchise agreements were renewed or newly adopted in 2002 Renewal Date Expiration Date Fee % (Fee attached to franchise agreement) California None Idaho Ashton 2002 02 13 2031 0301 Oregon Adams Aumsville Central Point Medford Redmond 2002 08 13 2002 08 13 20020128 2002 08 05 2002 05 28 2022 08 13 20120813 2012 01 01 20120805 2007 05 28 5% Fr/3.0% Lie 5% Fr/3.5% Lie 5% Fr 5% Fr/1.5% Lie 5% Fr/3.5% Lic UtahAlta 2002 04 11Levan 2002 10 04 Marriott-Slatterville 2002 01 North Salt Lake City 2002 02 05 Rocky Ridge 2002 07 15 20120415 2051 0410 202601 31 2006 11 01 2052 0715 Washington Benton County 2002 03 18 2007 03 01 Wyoming None 2. None 3. None 4. In May 2002, the Company entered into a 15 year operating lease for an electric generation facility with West Valley Leasing Company LLC, a subsidiary of PPM, which received all necessary approvals. The Company, at its sole option may terminate the lease, or purchase the facility, after three years or after six years. The facility consists of five generation units, each rated at 43.4 MW, and is located in Utah. 5. None 6. On August 22, 2002, the Board of Directors of the Company approved the issuance of up to 50 million additional shares of its common stock ("Shares ) to be sold, from time to time, to its direct parent, PHI, in such amounts and at such times as would be determined by the Company, subject to regulatory approval, which has been received. Issuance and sale of the Shares is subject to the receipt of cash for the Shares in an amount per share not less than the book value of the Shares at the end of the month prior to the date of the issuance. On December 19, 2002, the Company issued 14 851,485 Shares to PHI , receiving $150.0 million in cash proceeds, equal to $10.10 per share, the book value of the Shares at the end of November 2002. Proceeds were used to repay debt and for general corporate purposes. The Company entered into new revolving credit agreements that became effective June 4, 2002; one for $500.0 million having a 364-day term plus a one-year term loan option, and the other for $300.0 million having a IFERC FORM NO.1 (ED. 12-96) Page 109 Name of Respondent This Report is:Date of Report Year of Report (1)~An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec 31 2002 IMPORTANT CHANGES DURING THE YEAR (Continued) three-year term. Other provisions are similar to the Company s prior credit agreements. The interest on advances under these facilities is based on LlBOR plus a margin that varies based on the Company s credit ratings. As of December 31 , 2002, these facilities were fully available and there were no borrowings outstanding. 7. None 8. During 2002, wage increases went into effect with the International Brotherhood of Electric Workers, Local 57 of 75%, Local 125 of 3.00%, Local 659 of 4.50%, and Local 415 of 3.00%. Wage increases went into effect with the Utility Workers Union of America, Local 197 of 3.50%, Local 127 (Casper, Wyoming) of 4.00%, and Local 127 (Wyodak Plant, Wyoming) of 2.50%. Financial Impact IBEW 125 IBEW 659 UWUA 197 UWUA 127 (WY) IBEW 415 IBEW 57 (PD) IBEW 57 (PS) IBEW 57 (WV) Total $ 842 141 380 671 $ 48 886 720 597 $ 17 210 156 747 $1,484 068 $ 19.583 669 902 9. From time to time, the Company and its subsidiaries are parties to various legal claims, actions and complaints , certain of which involve material amounts. Although the Company is unable to predict with certainty whether or not it will ultimately be successful in these legal proceedings or, if not, what the impact might be management currently believes that disposition of these matters will not have a materially adverse effect on the Company s financial position or results of operations. The Company is also a party to a FERC proceeding that is investigating potential refunds for energy transactions in the California market during past periods of high energy prices. The Company s ultimate exposure to refunds is dependent upon any order issued by the FERC in this proceeding. 10. None 12. The Company has made progress toward recovering the deferred net power costs incurred during the period of extreme volatility and unprecedented high price levels beginning in the summer of 2000 and extending through the summer of 2001. These costs are being recovered as follows: $147.0 million in Utah; $136.5 million in Oregon; and $25.0 million in Idaho. The Oregon rate order is the subject of a court appeal by intervening parties, which , if successful, would require refund of those amounts collected after January 22, 2003. In Wyoming, the Company request for recovery of deferred net power costs was denied and, as a result, the Company wrote-off the remaining net asset of $48.3 million during the year ended March 31 , 2003. The Company filed a petition for rehearing on the Wyoming decision on April 4 , 2003. In Washington , the Company had requested recovery of approximately $17. million of excess power costs, which have not been deferred. . This request was subsequently reduced to approximately $15.9 million based on revised estimates. A final decision in Washington is expected in May 2003, and based on an affirmative outcome, the requested amount will be recognized on the balance sheet as a regulatory asset. The FERC's June 19, 2001 order also required that all public utility sellers and buyers (the "Party" or "Parties ) in the California Independent System Operators ' (" CaIISO") markets participate in settlement discussions to complete the task of settling past accounts and structuring the new arrangements for California s energy future. The FERC appointed an Administrative Law Judge ("ALJ") to serve as a settlement judge. On July 12 , 2001 , an ALJ issued a recommendation to the FERC based upon the settlement conference, proposing a methodology to calculate refunds for spot sales to the CallSO and California Power Exchange ("CPX") between October 2, 2000 and June 20, 2001. IFERC FORM NO.1 (ED. 12-96)Page 109. Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec 31 2002 IMPORTANT CHANGES DURING THE YEAR (Continued) The FERC agreed with an ALJ-proposed methodology. A proceeding before a second ALJ was held beginning August 2002 to determine each Party's refund liability. On November 20,2002, the FERC allowed all Parties to engage in 100 days of additional discovery into market manipulation. On December 12, 2002, an ALJ issued a Certification of Proposed Findings on California Refund liability in which an AU preliminarily determined that $1.2 billion was still owed to suppliers by CallSO and CPX, which was calculated by offsetting a $1.8 billion refund from the $3.0 billion owed to suppliers. On March 3, 2003, the Parties filed supplemental evidence of market manipulation and proposed new findings of fact. On March 20, 2003, the Parties responded to the March 3, 2003 filings. On March 26, 2003, the FERC staff issued a final report on price manipulation in western markets ("Staff's Final Report"). Following issuance of the Staffs Final Report, the FERC issued an Order on Proposed Findings on Refund liability adopting many of an AU's December 12 2002 Proposed Findings and clarifying the method for calculating refunds for purchases made in the CallSO and CPX spot markets. In its order, the FERC adopted recommendations from the Staffs Final Report including a new proxy for gas prices, which could increase the amount of refunds, if any, owed by all Parties. The FERC expects that refunds will be distributed by the end of the summer of 2003. The Company s exposure to refunds is dependent upon any final order issued by the FERC in response to the outcome of these proceedings. The Company s hydroelectric portfolio consists of 53 plants with a total nameplate capacity of 1 119.3 MW. Ninety-seven percent of the installed capacity is regulated by the FERC through 20 individual licenses. Nearly all of the Company s hydroelectric projects are in some stage of relicensing under the FPA. Hydroelectric relicensing and the related environmental compliance requirements are subject to uncertainties. The Company expects that future costs relating to these matters may be significant and consist primarily of additional relicensing costs, operations and maintenance expense and capital expenditures. Power generation reductions may result from the additional environmental requirements. The Company has accumulated approximately $90.0 million in costs for on going hydroelectric relicensing that are reflected as an asset on the Balance Sheet. The Company expects that these and future costs will be included in rates and, as such, will not have a material adverse impact on the Company consolidated results of operations. On April 21 , 2002, a failure occurred in the Swift power canal on the Lewis River in the state of Washington. The power canal and associated 70 MW hydroelectric facility ("Swift No.) are owned by Cowlitz County Public Utility District Cowlitz"). Investigations suggest that Swift No.2 will be out of service for an extended period of time. At this time, it is anticipated that Cowlitz will repair Swift No.2 in time for a calendar year 2006 startup. This failure has impacted the Company s owned and operated 240 MW Swift No.1 hydroelectric facility ("Swift No.), which is upstream of the Swift power canal, by restricting both flow and generation flexibility ("shaping ). Cowlitz and the Company reached agreement on power canal repairs. Such repairs were completed and Swift No.1 was returned to full capacity levels as of mid-July 2002 (though with limited shaping capabilities). Environmental, operations safety and fish mitigation issues remain to be resolved before full use of Swift No.1 can be resumed. The Company will continue to seek ways to mitigate any capacity and shaping limitations and also to recover any business losses. The full impact of the Swift outage and plans for repair of the Swift No.2 facility are being determined. This event is not expected to have a significant impact on the Company s consolidated financial position or results of operations. The Company has separated its non-utility operations from its regulated utility operations through corporate restructuring, in order to facilitate an increased focus on its regulated energy businesses in the western United States. On December 31 , 2001 , NA General Partnership ("NAGP") transferred all of the common stock of the Company to PHI. The Company then transferred all of the capital stock of PacifiCorp Group Holdings Company ("PGHC") to PHI in February 2002. PGHC includes the wholly owned subsidiary, PFS, a financial services business. IFERC FORM NO.1 (ED. 12-96)Page 109. Blank Page (Next Page is: 110) Name of Respondent This Report Is:Date of Report Year of Report PacifiCorp (1)(ZI An Original (Mo, Da, Yr) (2)A Resubmission 04/30/2003 Dec. 31 2002 COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS) Line Title of Account Ref.Balance at Balance at No.(a)Page No.Beginning of Year End of Year (b)(c)(d) UTILITY PLANT Utility Plant (101-106, 114)200-201 424 027 867 875,185,187 Construction Work in Progress (107)200-201 298,201 330 323,348,493 TOTAL Utility Plant (Enter Total of lines 2 and 3)12,722 229 197 198 533,680 (Less) Accum. Provo for Depr. Amort. Depl. (108, 111 , 115)200-201 914 429 624 301 630 066 Net Utility Plant (Enter Total of line 4 less 5)807 799,573 896,903,614 Nuclear Fuel (120.120.120.202-203 (Less) Accum. Provo for Amort. of Nucl. Fuel Assemblies (120.202-203 Net Nuclear Fuel (Enter Total of line 7 less 8) Net Utility Plant (Enter Total of lines 6 and 9)807 799 573 896,903,614 Utility Plant Adjustments (116)122 Gas Stored Underground - Noncurrent (117) OTHER PROPERTY AND INVESTMENTS Nonutility Property (121)221 359,971 940,934 (Less) Accum. Provo for Depr. and Amort. (122)396 681 171,144 Investments in Associated Companies (123)120,424 982 107 Investment in Subsidiary Companies (123.224-225 702 714 155 283 187 (For Cost of Account 123., See Footnote Page 224, line 42) Noncurrent Portion of Allowances 228-229 Other Investments (124)82,898,390 414 689 Special Funds (125-128)711 862 431 040 TOTAL Other Property and Investments (Total of lines 14-19-21)805 408,121 173,880 813 CURRENT AND ACCRUED ASSETS Cash (131)868 233 224,599 Special Deposits (132-134)29,133,500 Working Fund (135)189,632 23,447 Temporary Cash Investments (136)125 131 751 60,000,000 Notes Receivable (141)386 294 344,611 Customer Accounts Receivable (142)266,619,450 270 987 245 Other Accounts Receivable (143)304 928 503 510 (Less) Accum, Prov, for Uncollectible Acct,Credit (144)18,577 699 329,990 Notes Receivable from Associated Companies (145)838,304 321 261 Accounts Receivable from Assoc. Companies (146)507 413 519,188 Fuel Stock (151)227 176,475 69,561 552 Fuel Stock Expenses Undistributed (152)227 Residuals (Elec) and Extracted Products (153)227 Plant Materials and Operating Supplies (154)227 828 440 509 235 Merchandise (155)227 Other Materials and Supplies (156)227 Nuclear Materials Held for Sale (157)202-203/227 Allowances (158.1 and 158.228-229 (Less) Noncurrent Portion of Allowances Stores Expense Undistributed (163)227 Gas Stored Underground - Current (164. Liquefied Natural Gas Stored and Held for Processing (164.164, Prepayments (165)521 357 178 610 Advances for Gas (166-167) Interest and Dividends Receivable (171)332 821 58,994 Rents Receivable (172)805 249 Accrued Utility Revenues (173)146 572,000 130 838 000 Miscellaneous Current and Accrued Assets (174)219 058 550 989 Derivative Instrument Assets (175)204 941 760 FERC FORM NO.1 (ED. 12-94)Page 110 Name of Respondent This Report Is:Date of Report Year of Report PacifiCorp (1)IZI An Original (Mo, Da, Yr) (2)A Resubmission 04130/2003 Dec. 31 2002 COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)Continued) Line Title of Account Ref.Balance at Balance at No.(a)Page No.Beginning of Year End of Year (b)(c)(d) Derivative Instrument Assets - Hedges (176) TOTAL Current and Accrued Assets (Enter Total of lines 24 thru 53)730 579 916 842 074 890 DEFERRED DEBITS Unamortized Debt Expenses (181)39,680,151 35,807 597 Extraordinary Property Losses (182.230 Unrecovered Plant and Regulatory Study Costs (182.230 273,539 15,371,861 Other Regulatory Assets (182.232 363 246,472 511 120,463 Prelim. Survey and Investigation Charges (Electric) (183)666 122 719,710 Prelim. Sur. and Invest. Charges (Gas) (183., 183. Clearing Accounts (184)161 909 386 085 Temporary Facilities (185)140,786 170,184 Miscellaneous Deferred Debits (186)233 100,497 507 123,117,377 Def. Losses from Disposition of Utility PIt. (187) Research, Devel. and Demonstration Expend. (188)352-353 Unamortized Loss on ReaQuired Debt (189)41,098,577 636,219 Accumulated Deferred Income Taxes (190)234 588,096 821 569 Unrecovered Purchased Gas Costs (191) TOTAL Deferred Debits (Enter Total of lines 56 thru 69)629,353,159 765,378,895 TOTAL Assets and Other Debits (Enter Total of lines 10,12,22,70)10,973,140,769 10,678,238,212 FERC FORM NO.1 (ED. 12-94)Page 111 Name of Respondent This Report Is:Date of Report Year of Report PacifiCorp (1)IZI An Original (Mo, Da, Yr) (2)A Resubmission 04/30/2003 Dec. 31 2002 COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS) Line Title of Account Ref.Balance at Balance at No.(a)Page No.Beginning of Year End of Year (b)(c)(d) PROPRIETARY CAPITAL Common Stock Issued (201)250-251 350 188,743 933,226,675 Preferred Stock Issued (204)250-251 116,463 300 108 963 300 Capital Stock Subscribed (202, 205)252 Stock Liability for Conversion (203, 206)252 Premium on Capital Stock (207)252 Other Paid-In Capital (208-211)253 45,637,600 Installments Received on Capital Stock (212)252 (Less) Discount on Capital Stock (213)254 (Less) Capital Stock Expense (214)254 42,121 516 42,037,473 Retained Eamings (215, 215., 216)118-119 811 336 300 939,900 721 Unappropriated Undistributed Subsidiary Earnings (216.118-119 -668,931 851 -665,529 617 (Less) Reaquired Capital Stock (217)250-251 Accumulated Other Comprehensive Income (219)122(a)(b)122 308 TOTAL Proprietary Capital (Enter Total of lines 2 thru 13)612,572 576 274,401 298 LONG-TERM DEBT Bonds (221)256-257 672,744 531 532 823,464 (Less) Reaquired Bonds (222)256-257 Advances from Associated Companies (223)256-257 362 888 000 362 888 000 Other Long-Term Debt (224)256-257 Unamortized Premium on Long-Term Debt (225)57,309 54,590 (Less) Unamortized Discount on Long-Term Debt-Debit (226)190,056 616 384 TOTAL Long-Term Debt (Enter Total of lines 16 thru 21)030,499,784 891 149,670 OTHER NONCURRENT LIABILITIES Obligations Under Capital Leases - Noncurrent (227)345 575 621 393 Accumulated Provision for Property Insurance (228.616,567 381 108 Accumulated Provision for Injuries and Damages (228.641,977 11,410 326 Accumulated Provision for Pensions and Benefits (228.144 852 758 224 983,255 Accumulated Miscellaneous Operating Provisions (228.937 116 153 816 Accumulated Provision for Rate Refunds (229) TOTAL OTHER Noncurrent Liabilities (Enter Total of lines 24 thru 29)258 393,993 276,549 898 CURRENT AND ACCRUED LIABILITIES Notes Payable (231)610,980 167 895 000 Accounts Payable (232)293 641 911 285 185 856 Notes Payable to Associated Companies (233)183,607 400 155 Accounts Payable to Associated Companies (234)669,357 107 952 Customer Deposits (235)585,148 516 662 Taxes Accrued (236)262-263 725,128 154 000 Interest Accrued (237)967 913 819,945 Dividends Declared (238)220 645,376 171 539 Matured Long-Term Debt (239) Matured Interest (240) Tax Collections Payable (241)10,133 470 801 072 Miscellaneous Current and Accrued Liabilities (242)100 188,693 533 752 Obligations Under Capital Leases-Current (243)71,835 095 FERC FORM NO.1 (ED. 12-89) Page 112 Name of Respondent This Report Is:Date of Report Year of Report PacifiCorp (1)(ZI An Original (Mo, Da, Yr) (2)A Resubmission 04/30/2003 Dec. 31 2002 COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)(Continued) Line Title of Account Ref.Balance at Balance at No.(a)Page No.Beginning of Year End of Year (b)(e)(d) Derivative Instrument Liabilities (244)738 107 564 Derivative Instrument Liabilities - Hedges (245) TOTAL Current & Accrued Liabilities (Enter Total of lines 32 thru 44)851,279 748 375 732 592 DEFERRED CREDITS Customer Advances for Construction (252)298,129 745,506 Accumulated Deferred Investment Tax Credits (255)266-267 101 288,543 93,368 420 Deferred Gains from Disposition of Utility Plant (256) Other Deferred Credits (253)269 343,559 666 021 329 Other Regulatory Liabilities (254)278 229,812 545 139 612,334 Unamortized Gain on Reaquired Debt (257)557 597 398,530 Accumulated Deferred Income Taxes (281-283)272-277 532 878 188 538 258,635 TOTAL Deferred Credits (Enter Total of lines 47 thru 53)220 394 668 860,404 754 TOTAL Liab and Other Credits (Enter Total of lines 14 30,45 54)973 140 769 678,238,212 FERC FORM NO.1 (ED. 12-89)Page 113 This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/30/2003 STATEMENT OF INCOME FOR THE YEAR 1. Report amounts for accounts 412 and 413, Revenue and Expenses from Utility Plant Leased to Others, in another Utility column (i , m, 0) in a similar manner to a utility department. Spread the amount(s) over Lines 02 thru 24 as appropriate. Include these amounts in columns (c) and (d) totals. 2. Report amounts in account 414, Other Utility Operating income, in the same manner as accounts 412 and 413 above. 3. Report data for lines 7 9, and 10 for Natural Gas companies using accounts 404.404.404.407.1 and 407. 4. Use pages 122-123 for important notes regarding the statement of income or any account thereof. 5. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in a material refund to the utility with respect to power or gas purchases. State for each year affected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power and gas purchases. 6. Give concise explanations concerning significant amounts of any refunds made or received during the year Name of Respondent PacifiCorp Year of Report Dec. 31 2002 (Ref.TOTAL Page No. (b) 300-301 320-323 013,451,930 289 108,892 320-323 257,529,377 213,546,538 336-337 368,266,698 349,992,527 336-337 789,397 067 420 336-337 507 086 571 724 Line No. Account (a) 1 UTILITY OPERATING INCOME 2 Operating Revenues (400) 3 Operating Expenses 4 Operation Expenses (401) 5 Maintenance Expenses (402) 6 Depreciation Expense (403) 7 Amort. & Depl. of Utility Plant (404-405) 8 Amort. of Utility Plant Acq. Adj. (406) 9 Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407) 10 Amort. of Conversion Expenses (407) 11 Regulatory Debits (407. 12 (Less) Regulatory Credits (407.4) 13 Taxes Other Than Income Taxes (408. 14 Income Taxes - Federal (409.15 -Other (409. 16 Provision for Deferred Income Taxes (410. 17 (Less) Provision for Deferred Income Taxes-Cr. (411. 18 Investment Tax Credit Adj. - Net (411. 19 (Less) Gains from Disp. of Utility Plant (411. 20 Losses from Disp. of Utility Plant (411. 21 (Less) Gains from Disposition of Allowances (411. 22 Losses from Disposition of Allowances (411. 23 TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 22) 24 Net Util Oper Inc (Enter Tot line 2 less 23) Carry fwd to P117 line 25 997 525 184 686 262-263 262-263 262-263 234, 272-277 234 272-277 266 405,982 38,263,254 854 863 566 761 939 833 557 479,675 695 FERC FORM NO.1 (ED. 12-96)Page 114 102,268 353 351 128,380 502 954,282 905,000 376 245,053 158,220,693 873 148 634 620 151 073 830 419,009,139 Name of Respondent PacifiCorp This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/30/2003 STATEMENT OF INCOME FOR THE YEAR (Continued) resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts. 7. If any notes appearing in the report to stockholders are applicable to this Statement of Income, such notes may be included on pages 122-123. B. Enter on pages 122-123 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also give the approximate dollar effect of such changes. 9. Explain in a footnote if the previous year's figures are different from that reported in prior reports. 10. If the columns are insufficient for reporting additional utility departments , supply the appropriate account titles, lines 2 to 23, and report the information in the blank space on pages.122-123 or in a footnote. Year of Report Dec. 31 2002 ELECTRIC UTILITY GAS UTILITY OTHER UTILITY Line No. 566 761 634 620 013,451,930 257 529,377 368,266,698 789 397 507,086 289,108 892 213,546 538 349 992 527 067,420 571 724 997,525 184,686 123,964,333 566 061 140 816 24,405,982 38,263 254 854 863 102 268 353 351 128 380,502 954 282 905 000 376 245,053 158 220 693 873 148 939 833 557 479 675,695 151 073,830 419,009 139 FERC FORM NO.1 (ED. 12-96)Page 115 OTHER UTILITY This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04130/2003 STATEMENT OF INCOME FOR THE YEAR (Continued) OTHER UTILITY Year of Report Dec. 31 2002 Name of Respondent PacifiCorp Line No. OTHER UTILITY FERC FORM NO.1 (ED. 12-96)Page 116 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr) Dec. 31 2002(2) riA Resubmission 04/30/2003 TATEMENT OF INCOME FOR THE YEAR (Continued) Line Account (Ref.TOTAL No.Page No.Current Year Previous Year (a)(b)(c)(d) Net Utility Operating Income (Carried forward from page 114)479,675 695 419 009 139 Other Income and Deductions Other Income Nonutilty Operating Income Revenues From Merchandising, Jobbing and Contract Work (415)472 306 380 613 (Less) Costs and Exp. of Merchandising, Job, & Contract Work (416)235 565 212 321 Revenues From Nonutility Operations (417)651 863 520 753 (Less) Expenses of Nonutility Operations (417.39,978 39,556 Nonoperating Rental Income (418)56,384 210,212 Equity in Earnings of Subsidiary Companies (418.119 402 234 138,589,499 Interest and Dividend Income (419)636 130 023 249 Allowance for Other Funds Used During Construction (419.878,807 Miscellaneous Nonoperating Income (421)109 171 362 835 555 Gain on Disposition of Property (421.514 294 717 249 TOTAL Other Income (Enter Total of lines 29 thru 38)132 559 205 156,604 829 Other Income Deductions Loss on Disposition of Property (421,773,728 968,266 Miscellaneous Amortization (425)340 581,716 21,769 Miscellaneous Income Deductions (426.1-426.340 96,848,716 646,166 TOTAL Other Income Deductions (Total of lines 41 thru 43)100,656,704 699,669 Taxes Applic. to Other Income and Deductions Taxes Other Than Income Taxes (408.262-263 Income Taxes-Federal (409.262-263 Income Taxes-Other (409.262-263 246 Provision for Deferred Inc. Taxes (410.234, 272-277 593, (Less) Provision for Deferred Income Taxes-Cr. (411.2)234, 272-277 Investment Tax Credit Adj.Net (411.065,258 (Less) Investment Tax Credits (420)065,260 TOTAL Taxes on Other Income and Deduct. (Total of 46 thru 52)706,429 325 803 Net Other Income and Deductions (Enter Total lines 39, 44, 53)608 930 159 230 963 Interest Charges Interest on Long-Term Debt (427)223 270,934 186 225 383 Amort. of Debt Disc. and Expense (428)666 130 143 306 Amortization of Loss on Reaquired Debt (428.462,357 5,462,357 (Less) Amort. of Premium on Debt-Credit (429)718 (Less) Amortization of Gain on Reaquired Debt-Credit (429.159,067 257 046 Interest on Debt to Assoc. Companies (430)340 29,572,50€36,433,069 Other Interest Expense (431)340 584 023 25,144 331 (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)629,673 541,450 Net Interest Charges (Enter Total of lines 56 thru 63)293,764 492 249 607 232 Income Before Extraordinary Items (Total of lines 25, 54 and 64)221 520,133 328 632 870 Extraordinary Items 67 Extraordinary Income (434)991 994 68 (Less) Extraordinary Deductions (435) 69 Net Extraordinary Items (Enter Total of line 67 less line 68)991 994 70 Income Taxes-Federal and Other (409.262-263 135,492 71 Extraordinary Items After Taxes (Enter Total of line 69 less line 70)856,502 72 Net Income (Enter Total of lines 65 and 71)219 663,631 328,632,870 FERC FORM NO.1 (ED. 12-96)Page 117 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 STA EMENT OF RETAINED EARNINGS f OR THE YEAR 1. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year. 2. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436 - 439 inclusive). Show the contra primary account affected in column (b) 3. State the purpose and amount of each reselVation or appropriation of retained earnings. 4. List first account 439, Adjustments to Retained Eamings. reflecting adjustments to the opening balance of retained earnings.Follow by credit, then debit items in that order. 5. Show dividends for each class and series of capital stock. 6. Show separately the State and Federal income tax effect of items shown in account 439, Adjustments to Retained Earnings. 7. Explain in a footnote the basis for determining the amount reselVed or appropriated. If such reselVation or appropriation is to be recurrent, state the number and annual arnounts to be reselVed or appropriated as well as the totals eventually to be accumulated. 8. If any notes appearing in the report to stockholders are applicable to this statement, include them on pages 122-123. Line Item Contra pnmary Amount No.ccount Affected (a)(b)(c) UNAPPROPRIATED RETAINED EARNINGS (Account 216) 1 Balance-Beginning of Year 807 760,490 2 Changes 3 Adjustments to Retained Earnings (Account 439) 9 TOTAL Credits to Retained Earnings (Acct. 439) TOTAL Debits to Retained Earnings (Acct. 439) Balance Transferred from Income (Account 433 less Account 418.216,261 397 Appropriations of Retained Earnings (Acct. 436) TOTAL Appropriations of Retained Earnings (Acct. 436) Dividends Declared-Preferred Stock (Account 437) Preferred Dividends (Various Series & Rates)238 7,419 333 TOTAL Dividends Declared-Preferred Stock (Acct. 437)419,333 Dividends Declared-Common Stock (Account 438) Common Dividends 238 277,644 TOTAL Dividends Declared-Common Stock (Acct. 438)80,277,644 Transfers from Acct 216., Unapprop. Undistrib. Subsidiary Eamings Balance - End of Year (Total 1 ,15,29,36,37)936 324 910 FERC FORM NO.1 (ED. 12-96)Page 118 Name of Respondent PacifiCorp Year of Report Dec. 31 2002 This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 0413012003 STATEMENT OF RETAINED EARNINGS OR THE YEAR 1. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year. 2. Each credit and debit during the year should be identified as to the retained eamings account in which recorded (Accounts 433, 436 - 439 inclusive). Show the contra primary account affected in column (b) 3. State the purpose and amount of each reservation or appropriation of retained earnings. 4. List first account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items in that order. 5. Show dividends for each class and series of capital stock. 6. Show separately the State and Federal income tax effect of items shown in account 439, Adjustments to Retained Earnings. 7. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated. 8. If any notes appearing in the report to stockholders are applicable to this statement, include them on pages 122-123. No.Item (a) APPROPRIATED RETAINED EARNINGS (Account 215) 45 TOTAL Appropriated Retained Earnings (Account 215) APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215. 46 TOTAL Approp. Retained Earnings-Amort, Reserve, Federal (Acct. 215. 47 TOTAL Approp. Retained Eamings (Acct. 215, 215.1) (Total 45 46) 48 TOTAL Retained Eamings (Account 215, 215., 216) (Total 38, 47) UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account 216. 49 Balance-Beginning of Year (Debit or Credit) 50 Equity in Earnings for Year (Credit) (Account 418. 51 (Less) Dividends Received (Debit) 53 Balance-End of Year (Total lines 49 thru 52) -668 931 851 402 234 -665,529,617 FERC FORM NO.1 (ED. 12-96)Page 119 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) fiA Resubmission 04/30/2003 STATEMENT OF CASH FLOWS 1. If the notes to the cash flow statement in the respondents annual stockholders report are applicable to this statement, such notes should be included in page 122-123. Information about non-cash investing and financing activities should be provided on Page 122-123. Provide also on pages 122-123 a reconciliation between "Cash and Cash Equivalents at End of Year" with related amounts on the balance sheet. 2. Under "Other" specify significant amounts and group others. 3. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show on Page 122-123 the amount of interest paid (net of amounts capitalized) and income taxes paid. I LIne uescnptlon (See Instruction NO. b Tor I:xplanation of Codes)Amounts No.(a)(b) Net Cash Flow from Operating Activities: Net Income 219,663 631 Noncash Charges (Credits) to Income: Depreciation and Depletion 368,457 923 Amortization (See footnote for details) Deferred Income Taxes (Net)269,120 Investment Tax Credit Adjustment (Net)920,123 Net (Increase) Decrease in Receivables 635,002 Net (Increase) Decrease in Inventory 11,065,872 Net (Increase) Decrease in Allowances Inventory Net Increase (Decrease) in Payables and Accrued Expenses 11,236 816 Net (Increase) Decrease in Other Regulatory Assets 156,030 422 Net Increase (Decrease) in Other Regulatory Liabilities -81 868 274 (Less) Allowance for Other Funds Used During Construction 878,807 (Less) Undistributed Earnings from Subsidiary Companies 10,498,772 Other (provide details in footnote):'Ue les. ;", ,;:..:.:".'" Net Cash Provided by (Used in) Operating Activities (Total 2 thru 21)665 975,338 Cash Flows from Investment Activities: Construction and Acquisition of Plant (including land): Gross Additions to Utility Plant (less nuclear fuel)549 739,599 Gross Additions to Nuclear Fuel Gross Additions to Common Utility Plant Gross Additions to Nonutility Plant (Less) Allowance for Other Funds Used During Construction Other (provide details in footnote): Cash Outflows for Plant (Total of lines 26 thru 33)549 739 599 Acquisition of Other Noncurrent Assets (d) Proceeds from Disposal of Noncurrent Assets (d)311 545 Investments in and Advances to Assoc. and Subsidiary Companies 257 083 Contributions and Advances from Assoc. and Subsidiary Companies Disposition of Investments in (and Advances to) Associated and Subsidiary Companies Purchase of Investment Securities (a) Proceeds from Sales of Investment Securities (a) FERC FORM NO.1 (ED. 12-96)Page 120 Name of Respondent PacifiCorp This ~ort Is:(1) ~An Original (2) A Resubmission STATEMENT OF CASH FLOWS Date of Report (Mo, Da, Yr) 04/3012003 Year of Report Dec. 31 2002 4. Investing Activities include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed on pages 122-123. Do not include on this statement the dollar amount of Leases capitalized per US of A General Instruction 20; instead provide a reconciliation ofthe dollar amount of Leases capitalized with the plant cost on pages 122-123. 5. Codes used:(a) Net proceeds or payments. (c) Include commercial paper. (b) Bonds, debentures and other long-term debt. (d) Identify separately such items as investments, fixed assets, intangibles, etc. 6. Enter on pages 122-123 clarifications and explanations. escnptlon ee nstructlon o. or p anation 0 mounts (a)(b) 46 Loans Made or Purchased 47 Collections on Loans 56 Net Cash Provided by (Used in) Investing Activities 57 Total of lines 34 thru 55) 66 Net Increase in Short-Term Debt (c) 67 Other (provide details in footnote): 70 Cash Provided by Outside Sources (Total 61 thru 69) 78 Net Decrease in Short-Term Debt (c) 85 Net Increase (Decrease) in Cash and Cash Equivalents 86 (Total of lines 22 57 and 83) 88 Cash and Cash Equivalents at Beginning of Year 90 Cash and Cash Equivalents at End of Year Net (Increase) Decrease in Receivables Net (Increase) Decrease in Inventory Net (Increase) Decrease in Allowances Held for Speculation Net Increase (Decrease) in Payables and Accrued Expenses Other (provide details in footnote): Cash Flows from Financing Activities: Proceeds from Issuance of: Long-Term Debt (b) Preferred Stock Common Stock Other (provide details in footnote): 219 904 150,000,000 Payments for Retirement of: Long-term Debt (b) Preferred Stock Common Stock Other (provide details in footnote): 92,206 386 139,886,318 500,000 Dividends on Preferred Stock Dividends on Common Stock Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81) 7,472 995 298 613 775 201 152 FERC FORM NO.1 (ED. 12-96)Page 121 Name of Respondent PacifiCorp Date of Report 04/30/2003 Year of Report Dec. 31 2002 This Report Is:(1) ~ An Original (2) 0 A Resubmission NOTES TO FINANCIAL STATEMENTS 1. Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement. 2. Fumish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock. 3. For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Cormmission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof. 4. Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts. 5. Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions. 6. If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121 , such notes may be included herein. PAGE 122 INTENTIONALLY LEFT BLANK SEE PAGE 123 FOR REQUIRED INFORMATION. FERC FORM NO.1 (ED. 12-96)Page 122 Name of Respondent This Report is:Date of Report Year of Report (1) ~ An Original (Mo, Da, Yr) PacifiCorp (2)A Resubmission 04/30/2003 Dec 31 2002 NOTES TO FINANCIAL STATEMENTS (Continued) See Supplemental Filling IFERC FORM NO.1 (ED. 12-88)Page 123 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04/30/2003 STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, At D HEDGING ACTIVITIES 1. Report in columns (b) (c) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate. 2. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges. 3. For each category of hedges that have been accounted for as "fair value hedges , report the accounts affected and the related amounts in a footnote. Line Item Unrealized Gains and Minimum Pension Foreign Currency Other No.Losses on Available-Liability adjustment Hedges Adjustments for-Sale Securities (net amount) (a)(b)(c)(d)(e) 1 Balance of Account 219 at Beginning of Preceeding Year 2 Preceding yr. Reclassification from Account 219 Net Income 3 Preceding Year Changes in Fair Value 4 Total (lines 2 and 3) 5 Balance of Account 219 at End of Preceding Yr/Beginning of Current Yr 6 Current Year Reclassification From Account 219 to Net Income 7 Current Year Changes in Fair Value 122 308 8 Total (lines 6 and 7)122 308 9 Balance of Account 219 at End of Current Year FERC FORM NO.1 (NEW 06-02)Page 122a Name of Respondent This ~ort Is: Date of Report Year of Report(1) ~AnOriginal (Mo, Da,Yr) Dec. 31 2002PacifiCorp (2) A Resubmission 04/30/2003 STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES Line No. Other Cash Flow Hedges (Specify) (f) 290,455 664,293 664,293 954 748 954 748) 23,954 748) FERC FORM NO.1 (NEW 06-02) Other Cash Flow Hedges (Specify) Totals for each category of items recorded in Account 219 (h) 290 455 664 293 (g) 664 293 954 748 954 748) 122 308 832 440) 122 308 Page 122b Net Income (Carried Forward from Page 117, Line 72) Total Comprehensive Income (i) (j) Name of Respondent PacifiCorp This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/30/2003 SUMMA Y OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION Year of Report Dec. 31 2002 (a)(b) Electric (c) Line No. Classification Total 1 Utility Plant 2 In Service 3 Plant in Service (Classified) 4 Property Under Capital Leases 5 Plant Purchased or Sold 6 Completed Construction not Classified 7 Experimental Plant Unclassified 8 Total (3 thru 7) 9 Leased to Others 10 Held for Future Use 11 Construction Work in Progress 12 Acquisition Adjustments 13 Total Utility Plant (8 thru 12) 14 Accum Prov for Depr, Amort, & Depl 15 Net Utility Plant (13 less 14) 16 Detail of Accum Prov for Depr, Amort & Depl 17 In Service: 18 Depreciation 19 Amort & Depl of Producing Nat Gas Land/Land Right 20 Amort of Underground Storage Land/Land Rights 21 Amort of Other Utility Plant 22 Total In Service (18 thru 21) 23 Leased to Others 24 Depreciation 25 Amortization and Depletion 26 Total Leased to Others (24 & 25) 27 Held for Future Use 690,448,686 697 610 12,690,448,686 697 610 12,715 146,296 715,146,296 845,111 323,348,493 157 193,780 13,198,533,680 301 630,066 896 903 614 845 111 323,348,493 157 193,780 198,533,680 301 630,066 896 903,614 28 Depreciation 29 Amortization 30 Total Held for Future Use (28 & 29) 31 Abandonment of Leases (Natural Gas) 32 Amort of Plant Acquisition Adj 33 Total Accum Prov (equals 14) (22 30,32) 57,971,402 301 630 065 971 402 301 630,065 FERC FORM NO.1 (ED. 12-89)Page 200 Gas This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/30/2003 SUMMARY OF UTIUTY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION Other (Specify) Other (Specify) Other (Specify) Year of Report Dec. 31, 2002 Name of Respondent PacifiCorp Common FERC FORM NO.1 (ED. 12-89)Page 201 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 ELECTRI PLANT IN SERVICE (Account 101 102 103 and 106) 1. Report below the original cost of electric plant in service according to the prescribed accounts. 2. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric. 3. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year. 4. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts. 5. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) reversals of tentative distributions of prior year of unclassified retirements. Show in a footnote the account distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above ILine Account No.Beginning of Year (a)(b) (c) 1. INTANGIBLE PLANT (301) Organization 288,163 (302) Franchises and Consents 486,584 77,335 (303) Miscellaneous Intangible Plant 392 714,950 420 450 TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)433,489,697 44,497 785 2. PRODUCTION PLANT A. Steam Production Plant (310) Land and Land Rights 79,925 549 606 (311) Structures and Improvements 751 565 112 184,571 (312) Boiler Plant Equipment 371 135 964 307 635 (313) Engines and Engine-Driven Generators (314) Turbogenerator Units 635,402,973 403 108 (315) Accessory Electric Equipment 318 316 145 555,206 (316) Misc. Power Plant Equipment 684 186 745,223 TOTAL Steam Production Plant (Enter Total of lines 8 thru 14)188,029 929 85,233 349 B. Nuclear Production Plant (320) Land and Land Rights (321) Structures and Improvements (322) Reactor Plant Equipment (323) Turbogenerator Units (324) Accessory Electric Equipment (325) Misc. Power Plant Equipment TOTAL Nuclear Production Plant (Enter Total of lines 17 thru 22) C. Hydraulic Production Plant (330) Land and Land Rights 19,210,373 345,400 (331) Structures and Improvements 73,691 153 442,985 (332) Reservoirs, Dams, and Waterways 262 965 816 2,451 109 (333) Water Wheels, Turbines, and Generators 977,082 842 988 (334) Accessory Electric Equipment 28,045,451 191 959 (335) Misc. Power PLant Equipment 682 238 66,107 (336) Roads, Railroads, and Bridges 338,908 172 330 TOTAL Hydraulic Production Plant (Enter Total of lines 25 thru 31)473 911 021 512 878 D. Other Production Plant (340) Land and Land Rights 842 880 (341) Structures and Improvements 11,224 005 1,454 660 (342) Fuel Holders, Products, and Accessories 210,083 (343) Prime Movers 94,719 851 842 963 (344)Generators 81,007 189 878,371 (345) Accessory Electric Equipment 274 455 FERC FORM NO.1 (ED. 12-95)Page 204 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106) (Continued) instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent's plant actually in service at end of year. 6. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications. 7. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages. 8. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed joumal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date of such filing. LineEnd Year No.(d) (e) (f) 26,288,163 326 558 593 710,023 163,969 435 589,346 715,349 163 969 476,436,102 120 79,961,035 055 205 124 943 752 819,421 441 454 860 631 399,141 514 815 131 173 050 644 164,000 432 045 53,668 319,385,638 407 223 745,309 31,276,877 153 178 361 615 226,748,485 20,555,773 336 428 178,993 74,976,703 529 956 190 544 264 696,425 026 905 149,066 942 231 524 816 233,151 30,945 745 581 573 750 139 014 113 088 11,398,150 566 774 203,084 480,654,041 . " 842 880 12,678,665 210,083 311 652 414,626 199 665,788 561 859 36,580 543 43,743 158 420 843 695 298 FERC FORM NO.1 (ED. 12-95)Page 205 Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) Fi A Resubmission 04/3012003 ELECTRIC PLANT IN SERVICE (Account 101 102 103 and 106) (Continued) Ine Account Balance 7\CCITtions No.Beginning of Year (a)(b)(c) (346) Misc. Power Plant Equipment 534,784 TOTAL Other Prod. Plant (Enter Total of lines 34 thru 40)200,813 247 175,994 TOTAL Prod. Plant (Enter Total of lines 15, 23, 32, and 41)862 754 197 169 922,221 3. TRANSMISSION PLANT (350) Land and Land Rights 110,963 139,509 (352) Structures and Improvements 786 669 157 239 (353) Station Equipment 754 133,594 30,534,768 (354) Towers and Fixtures 345 882 010 523 054 (355) Poles and Fixtures 417 325,807 855 085 (356) Overhead Conductors and Devices 567 686,425 235,049 (357) Underground Conduit 014 642 349,622 (358) Underground Conductors and Devices 316,215 597 979 (359) Roads and Trails 10,989,660 434 446 TOTAL Transmission Plant (Enter Total of lines 44 thru 52)232,245,985 826,751 4. DISTRIBUTION PLANT (360) Land and Land Rights 26,241,431 746 (361) Structures and Improvements 32,394,498 350,308 (362) Station Equipment 519,093,169 008,511 (363) Storage Battery Equipment (364) Poles, Towers, and Fixtures 669,415;583 592 462 (365) Overhead Conductors and Devices 511 770,514 624 585 (366) Underground Conduit 210 298 371 993,863 (367) Underground Conductors and Devices 474,396 702 172,855 (368) Line Transfonners 760,680 120 717 563 (369) Services 305,634,494 552,152 (370) Meters 173,867 616 10,260 798 (371) Installations on Customer Premises 858 296 173 307 (372) Leased Property on Customer Premises 658 (373) Street Lighting and Signal Systems 105 941 078,729 TOTAL Distribution Plant (Enter Total of lines 55 thru 68)740,806 393 173,529,879 5. GENERAL PLANT (389) Land and Land Rights 081 830 (390) Structures and Improvements 195 162 149 680 146 (391) Office Furniture and Equipment 107 748,034 17,403 202 (392) Transportation Equipment 545,693 551 549 (393) Stores Equipment 290,598 152 907 (394) Tools, Shop and Garage Equipment 886,841 955 365 (395) Laboratory Equipment 508 107 853 130 (396) Power Operated Equipment 88,694,946 892 666 (397) Communication Equipment 197 233,545 793,021 (398) Miscellaneous Equipment 818,850 311 618 SUBTOTAL (Enter Total of lines 71 thru 80)761,970 593 66,593 604 (399) Other Tangible Property 257 919 691 753,902 TOTAL General Plant (Enter Total of lines 81 and 82)019,890,284 347 506 TOTAL (Accounts 101 and 106)12,289,186 556 531 124 142 (102) Electric Plant Purchased (See Instr. 8) (Less) (102) Electric Plant Sold (See Instr. 8) (103) Experimental Plant Unclassified TOTAL Electric Plant in Service (Enter Total of lines 84 thru 87)12,289,186 556 531 124 142 FERC FORM NO.1 (ED. 12-95)Page 206 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04/30/2003 ELECTRIC PLANT IN SERVICE (Account 101 , 102, 103 and 106) (Continued) Retirements Adjustments Transfers Balance at Line End ~fYear No.(d)(e)(f) 534,784 873 511 745,074 272 370,656 49,593,463 309,773 979,773,182 334,910 -8,409 86,907,153 449 415,149 46,303 608 763,373 415,198 782 320,187 391 997 893,466 353,906,533 624 168 610,660 427,946,064 551,806 717,194 584,086,862 364,264 914,194 424 106 721 703 821 938 299,172 971 739 892 26,246,330 251 074 304 843 798,575 7,426,198 -400,284 545,275,198 892,469 115 688,112,461 286,264 523 108,835 446,462 217 845,772 723,959 494,845 598 585,780 787,811,903 165,380 330 021 266 737 842 28,036 179,362 536 88,462 562 940 579 658 567,338 562 619,894 176,967 120,700 884,038,605 081 830 343 821 125,316 204 373,158 190,308 95,777 119 056 705 215,415 270,084 151,911 236,586 70,020 276,939 814,061 198,999 45,829,146 183,579 783 32,182,441 646,847 804 906 98,745,671 155,749 278,494 208,149,311 74,736 50,320 005,412 861 102 149 429 810,852 524 794 245 704 046 655,347 445,383 051 027 826 129 862,829 817 690 448,686 129 862,829 817 690 448,686 FERC FORM NO.1 (ED. 12-95)Page 207 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr) Dec. 31 2002 (2) Fi A Resubmission 04/30/2003 El CTRIC PLANT HELD FOR FUTURE USE (Account 105) 1. Report separately each property held for future use at end of the year having an original cost of $250,000 or more.Group other items of property held for future use. 2. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105. Line LJescnJ)tlon and location I Date O~lnailY Include I Date Expected to be used j:Salance at No.Of prorrty in is Account in UtilitY Service End of Year (b) (c)(d) 1 land and Rights: 3 NORTH HORN MOUNTAIN COAL PROPERTIES 1975 939,014 SOUTHEAST SUBSTATION 1975 273,612 9 MISCELLANEOUS, EACH UNDER $250,000 147 449 Other Property: EASEMENTS - SWIFTfTROUTDAlE TRANSM. l17 1971 341 349 MISCELLANEOUS , EACH UNDER $250 000 :.": 143 687 Total 845 111 FERC FORM NO.1 (ED. 12-96)Page 214 Blank Page (Next Page is: 216) Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107) 1. Report below descriptions and balances at end of year of projects in process of construction (107) 2. Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Unifonn System of Accounts) 3. Minor projects (5% of the Balance End of the Year for Account 107 or $100,000, whichever is less) may be grouped. Line Description of Project Construction work in progress - No.Electric (Account 107) (a)(b) Intangible: North Umpqua Relicensing 50,175,343 Klamath Re~censing 10,524,952 Lewis River Relicensing 546,453 EMS/SCADA Phase II 5,413,471 Merwin Relicensing 843,407 Swift Relicensing 494,960 Powerdale Relicensing 224 250 C& T Portfolio Management System 615,171 Rogue Relicensing 534,132 Frontline Program Office (PMO)200,006 Oneida Relicensing 082 227 Handheld Replacement Project (HRP)915,639 Grace Relicensing 754,738 PDITA CAPEX - IMAP/Discovery (OCHIP)691 662 EP Work Station 1,498 197 GRID Technology Ver. 2.415,753 Soda Relicensing 208,950 CSS Release 3.0 & 3.034,378 SAPCON SAP Business Connectors 015 763 Production: Prospect Wood Penstock Replacement 925,563 Craig 1 & 2 Emission Control Upgrades 551 770 Huntington U2 Control Modernization (DCS)073,461 Jim Bridger U3 Controls Upgrade 479 171 Jim Bridger FGDS Pond Capacity Increase 468 848 JC Boyle - Replace Headgate 203 920 Huntington U2 Main Condenser Replacement 080 741 Gadsby Gas Turbine Peakers 844,536 Huntington U2 Boiler Overhaul 793 953 Huntington U2 Economizer Replacement 342 911 Cholla Flyash Slurry Sys Piping - Common 002 971 Transmission: Wyoming 4A14B Capacitor Bank Installation 186 940 Monument Phase Shifter SW WY Ld Growth 721 073 Platte Sub: 230kV Capacitor Split 501 635 Gadsby Gas Turbine Peakers Interconnect Facilities 378,101 Yellowtail- Casper Rpl105 Structures 141,460 Ninety So. 3&4 Incr. 345 - 138kV Tmsf. Cap 095,739 TOTAL 323 348,493 FERC FORM NO.1 (ED. 12-87)Page 216 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) nA Resubmission 04/30/2003 CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107) 1. Report below descriptions and balances at end of year of projects in process of construction (107) 2. Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts) 3. Minor projects (5% of the Balance End of the Year for Account 107 or $100 000, whichever is less) may be grouped. Line Description of Project Construction work in progress - No.Electric (Account 107) (a)(b) Distribution: Rattlesnake Add DG to Feeder #22 444 017 General: SCC to Cutler Replace Microwave 153 712 Network HW/SW 4 Yr Replacement Cycle 1,479 425 Yakima Service Center Relocate to Keyes Rd 208,415 TD066: Regional Logistics Model 606,846 Miscellaneous Projects each under $1 000,000 163,473,833 TOTAL 323,348 493 FERC FORM NO.1 (ED. 12-87)Page 216. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31,2002 (2) Fi A Resubmission 04130/2003 ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108) 1. Explain in a footnote any important adjustments during year. 2. Explain in a footnote any difference between the amount for book cost of plant retired, Line 11 , column (c), and that reported for electric plant in service, pages 204-207, column 9d), excluding retirements of non-depreciable property. 3. The provisions of Account 108 in the Uniform System of accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications. 4. Show separately interest credits under a sinking fund or similar method of depreciation accounting. Section A. Balances and Changes During Year ,-Ine nem 18~~)t:le~~lc I:'lant In EI~ctnc I:'lan~ Hela t:lec:pc) 'OfRtNo.ervlce for Future Use Lease to ers (a)(b)(c)(d)(e) 1 Balance Beginning of Year 692 063 311 691 902,955 160,35€ 2 Depreciation Provisions for Year, Charged to 3 (403) Depreciation Expense 372,066,133 4 (413) Exp. of Elec. PIt. Leas. to Others 5 Transportation Expenses-Clearing 6 Other Clearing Accounts 7 Other Accounts (Specify, details in footnote):120 137 231 8 (151) Fuel Stock 621 041 621 041 9 TOTAL Deprec. Prov for Year (Enter Total of 383 810 542 383,807,311 231 lines 3 thru 8) Net Charges for Plant Retired: Book Cost of Plant Retired 127 657 578 127,651 578 Cost of Removal 869,383 869,383 Salvage (Credit)366 642 366,642 TOTAL Net Chrgs. for Plant Ret. (Enter Total 139 160 319 139,160 319 of lines 11 thru 13) Other Debit or Cr. Items (Describe, details in 40,554 796 footnote): Balance End of Year (Enter Totals of lines 1 977 268 330 977 104,743 163,587 15, and 16) Section B.Balances at End of Year According to Functional Classification Steam Production 023 265 354 023 265 354 Nuclear Production Hydraulic Production-Conventional 210 517 142 210,517 142 Hydraulic Production-Pumped Storage Other Production 450 302 450,302 Transmission 847 094 846 846 931 259 163, Distribution 1,420 827 664 1,420 827 664 General 439 113 022 439 113 022 TOTAL (Enter Total of lines 18 thru 25)977 268 330 977 104 743 163 587 FERC FORM NO.1 (ED. 12-88)Page 219 Blank Page (N ext Page is: 224) Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31,2002(2) nA Resubmission 04130/2003 INVESTM NTS IN SUBSIDIARY COMPANIES (Account 123. 1. Report below investments in Accounts 123., investments in Subsidiary Companies. 2. Provide a subheading for each company and List there under the information called for below. Sub - TOTAL by company and give a TOTAL in columns (e),(f),(g) and (h) (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal. 3. Report separately the equity in undistributed subsidiary earnings since acquisition.The TOTAL in column (e) should equal the amount entered for Account 418. DesCription of Investment Date Acquired Date Of Amount of .Investment at No.(a)(b)l~ity Beginning of Year(d) PACIFICORP GROUP HOLDINGS COMPANY Common Stock 99,483,436 Capital Contributions 919 883 Equity in Earnings 529,773,773 SUBTOTAL 632,177 092 PACIFIC POWER & LIGHT COMPANY Common Stock 100 SUBTOTAL 100 CENTRALIA MINING COMPANY Capital Contributions 000 SUBTOTAL 000 ENERGY WEST Capital Contributions 000 SUBTOTAL 000 PMI-BRIDGER COAL Common Stock Capital Contribution 995,421 SUBTOTAL 995,422 GLENROCK COAL Common Stock SUBTOTAL INTERWEST MINING Common Stock 000 SUBTOTAL 000 PACIFICORP CAPITAL I Capital Contributions 712 000 Equity in Earnings SUBTOTAL 712 000 PACIFICORP CAPITAL II Capital Contributions 176,000 Equity in Earnings SUBTOTAL 176,000 Total Cost of Account 123.1 $TOTAL 702,714 155 FERC FORM NO.1 (ED. 12-89)Page 224 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2) riA Resubmission 04/30/2003 Dec, 31 INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1) (Continued) 4. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge. 5. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number. 6. Report column (f) interest and dividend revenues form investments, including such revenues form securities disposed of during the year. 7. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if difference from cost) and the selling price thereof, not including interest adjustment includible in column (f). 8. Report on Line 42, column (a) the TOTAL cost of Account 123. Equity In Subsidiary Kevenues for Year Amount or Investment at Gain or Loss from Investment Line Eamin~s of Year End ftf Year Disp~sed of No.(f) 99,483 436 919 883 713 032 531,486 804 713 032 -633,890,123 100 100 000 000 000 000 057 927 053,348 057 927 053,349 000 000 712 000 553 740 553 740 553 740 553,740 712 000 176 000 321 552 321 552 321 552 321 552 176,000 402 234 -630 833,201 75,283,187 FERC FORM NO.1 (ED. 12-89)Page 225 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr) Dec. 31 2002 (2) Fi A Resubmission 04/30/2003 INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123. 1. Report below investments in Accounts 123., investments in Subsidiary Companies. 2. Provide a subheading for each company and List there under the information called for below. Sub - TOTAL by company and give a TOTAL in columns (e),(f),(g) and (h) (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal. 3. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418. I,-me Description or Investment Date Acquired Date Of Amount or Investment at No.(a)(b)l~ity Beginning of Year (d) 2 PACIFICORP INVESTMENT MANAGEMENT INC. Capital Contributions 100 000 Equity in, Earnings 25,027 SUBTOTAL 125,027 7 PACIFICORP ENVIRONMENTAL REMEDIATION COMPANY Capital Contributions 900 000 Equity in Earnings 625 949 SUBTOTAL 525,949 PACIFICORP FUTURE GENERATIONS INC Common Stock Capital Contributions Equity in Earnings -436 SUBTOTAL -436 IITotal Cost of Account 123.1 $TOTAL 702,714 155 FERC FORM NO.1 (ED. 12-89)Page 224. Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2) nA Resubmission 04/30/2003 Dec. 31 INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1) (Continued) 4. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge. 5. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number. 6. Report column (f) interest and dividend revenues form investments, including such revenues form securities disposed of during the year. 7. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if difference from cost) and the selling price thereof, not including interest adjustment includible in column (f). 8. Report on Line 42, column (a) the TOTAL cost of Account 123. EqUity In SUI)Slcliary Kevenues tor Year Amount ot Investment at ~aln or LOSS trom Investment LineEarnin~s of Year End ~f Year Disp~sed of No.(f) 100 000 686 25,713 686 125,713 900 000 815 336 4,441 285 815 336 341 285 112 548 112 548 3,402 234 -630,833 201 283 187 FERC FORM NO.1 (ED. 12-89)Page 225. Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002 (2)0 A Resubmission 04/30/2003 Dec. 31 MATERIALS AND SUPPLIES 1. For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material. 2. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable. Line Account Balance Balance Department or No.Beginning of Year End of Year Departments which Use Material (a)(b)(c)(d) Fuel Stock (Account 151)176,475 69,561 552 Electric Fuel Stock Expenses Undistributed (Account 152) Residuals and Extracted Products (Account 153) Plant Materials and Operating Supplies (Account 154) Assigned to - Construction (Estimated)29,627 461 319 414 Electric Assigned to - Operations and Maintenance Production Plant (Estimated)551 828 869,566 Electric 8 Transmission Plant (Estimated)130,232 851,449 Electric Distribution Plant (Estimated)054 296 682,296 Electric Assigned to - Other (provide details in footnote)464,623 Electric TOTAL Account 154 (Enter Total of lines 5 thru 10)88,828,440 509 235 Merchandise (Account 155) Other Materials and Supplies (Account 156) Nuclear Materials Held for Sale (Account 157) (Not applic to Gas UtiI) Stores Expense Undistributed (Account 163) TOTAL Materials and Supplies (Per Balance Sheet)151 004 915 162 070 787 FERC FORM NO.1 (ED. 12-96)Page 227 Blank Page (Next Page is: 228) Name of Respondent This ~rt Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)2002(2) 0 A Resubrnission 04/30/2003 Dec. 31, Allowances (Accounts 158.1 and 158. 1. Report below the particulars (details) called for concerning allowances. 2. Report all acquisitions of allowances at cost. 3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. 4. Report the allowances transactions by the period they are first eligible for use: the current year's allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns G)-(k). 5. Report on line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Line Allowances Inventory Current Year 2003 No.(Account 158.NO.Amt.We.Amt. (a)(b)(c)(d)(e) Balance-Beginning of Year .......... Acquired During Year: Issued (Less Withheld Allow) Returned by EPA PurchasesfTransfers: Total Relinquished During Year: Charges to Account 509 98. Other: Cost of SalesfTransfers: Total Balance-End of Year 101,071.103,552. Sales: Net Sales Proceeds(Assoc. Co. Net Sales Proceeds (Other) Gains Losses Allowances Withheld (Acct 158. Balance-Beginning of Year 259.259. Add: Withheld by EPA Deduct Retumed by EPA 259. Cost of Sales Balance-End of Year 259. Sales: Net Sales Proceeds (Assoc. Co. Net Sales Proceeds (Other)259. Gains 259. Losses FERC FORM NO.1 (ED. 12-95)Page 228 Name of Respondent PacifiCorp Year of Report Dec. 31 2002 This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr)(2) 0 A Resubmission 04/30/2003 Allowances (Accounts 158.1 and 158.2) (Continued) 6. Report on Lines 5 allowances returned by the EPA. Report on Line 39 the EPA's sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gainsl1osses resulting from the EPA's sale or auction of the withheld allowances. 7. Report on Lines 8-14 the names of vendorsltransferors of allowances acquire and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). 8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of an identify associated companies. 9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and salesltransfers. 10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.2004 2005 Future Years TotalsNo. Amt. No. Amt. No. Amt. No. Amt.(f) (g) (h) (i) (j) (k) (I) (m) 85,844.00 90,032.00 3,808,274.00 4 285,846.00 Line No. 259.00 2,259.00 110 928.00 119,964.00 528.00 4 528.00 276.00 4,535.00 259.00 259.00 98, 9. FERC FORM NO.1 (ED. 12-95)Page 229 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 0413012003 UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182. Line Description of Unrecovered Plant Total Costs WRITTEN OFF DURING YEAR Balance at No.and Regulatory Study Costs (Include Amount Recognisedin the description of costs, the date of of Charges During Year Account Amount End of Year Commission Authorization to use Ace 182.Charged and period of amortization (mo, yr to mo, yr)) (a)(b)(c)(d)(e)(f) Unrecovered plant: Trojan Nuclear 273 539 407.901,678 15,371 861 Plant located near Portland, OR Date of retirement: 12/31192 Date of Commission Authorization: ~12011993 I\mortization period: 1193 through 112011 TOTAL 273 539 901 678 371,861 FERC FORM NO.1 (ED. 12-88)Page 230b Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) nA Resubmission 04/30/2003 0 HER REGULATORY ASSETS (Account 182. 1. Report below the particulars (details) called for con~ming other regulatory assets which are created through the rate making actions of regulatory agencies (and not includable in other accounts) 2. For regulatory assets being amortized, show period of amortization in column (a) 3. Minor items (5% ofthe Balance at End of Year for Account 182.3 or amounts less than $50 000, whichever is less) may be grouped by classes. Line Description and Purpose of Debits CREDITS Balance at No.Other Regulatory Assets Account Amount End of Year Charged (a)(b)(c)(d)(e) Demand Side Resources: Califomia DSM Reg Assets All Less Than 50 000 908.190 470 218,414 Idaho 101302 Super Goodcents 1990 (12)908.171 85,197 101303 Super Goodcents 1991 (12)908.20,150 141 051 101304 Super Goodcents 1992 (12)908.36,302 254,116 101305 Weatherization Cash Grants 1993 (12)908.79,296 555,070 101314 Cash Grant 1990 (12)908.983 104,883 101324 Discount Early Loan Payoff 1992 (12)908.292 401 045 101330 Regional Mobile Home (MAP) 1993 (12)908.42,780 299 459 101331 Regional Mobile Home (MAP) 1994 (12)908.572 165 002 101332 Regional Mobile Home (MAP) 1995 (12)908.926 83,481 101333 Regional Mobile Home (MAP) 1996 (12)908.823 243,764 101370 NEEA 1998 (12)908.550 116,402 101374 Super Goodcents 1993 (12)908.25,238 176,663 101375 Super Goodcents 1994 (12)908.628 151,395 101376 Super Goodcents 1995 (12)908.12,395 86,763 101914 NEEA 1999 (12)908.180 289,620 101955 NEEA 2000 (12)908.019 260 193 102065 Low Income WZ 2001 (12)908.162 392 102079 NEEA 2001 (12)908.495 247 448 102184 NEEA 2002 253,991 253 361 101391 DSR Carrying Charge 908.278 796 951 575 DSM Reg Assets All Less Than 50 000 996 908.170 690,870 Oregon 101906 Enhanced Audit 2001 267 503 101943 Cash Rebate 2001 220 641 102047 HEA Analysis 2001 877 102048 Industrial Finanswer 2001 102 718 102049 Energy Finanswer 2001 980 504 102051 Commercial Retrofit Lighting 2001 941,411 102052 Small Retrofit (EF 12 000) 2001 795,210 102053 Industrial Retrofit Lighting 2001 511 102054 Hasslefree Efficency 2001 167 102058 Low Income WZ 2001 908.18,354 317 308 102073 Compact Fluorescent Bulbs (CLF) 2001 361 145 102078 NEEA 2001 904 168 102151 Enhanced Audit 2002 228,251 228 251 102154 Energy Finanswer 2002 314 783 314 783 102155 Small Retrofit (EF 12 000) 2002 636 152 636 152 TOTAL 521 565 894 373 691 903 511 120 463 FERC FORM NO.1 (ED. 12-94)Page 232 Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) riA Resubmission 04/30/2003 0 HER REGULATORY ASSETS (Account 182. 1. Report below the particulars (details) called for concerning other regulatory assets which are created through the rate making actions of regulatory agencies (and not includable in other accounts) 2. For regulatory assets being amortized, show period of amortization in column (a) 3. Minor items (5% of the Balance at End of Year for Account 182.3 or amounts less than $50,000, whichever is less) may be grouped by classes. Line Description and Purpose of Debits CREDITS Balance at No.Other Regulatory Assets Account Amount End of YearCharged (a)(b)(e)(d)(e) 102163 Industrial Finanswer 2002 472 451 1,472,452 102165 Industrial Retrofit Lighting 2002 766 767 102167 Low Income WZ 2002 108,801 908.089 108,801 102169 Cash Rebate 2002 57,422 57,423 102171 Commercial Retrofit Lighting 2002 614,087 614 088 102173 WZ Loans 0% Int 2002 696 695 102176 NEEA 2002 395,557 395,558 101719 HIP Rebate WZ 1998 246,408 101728 Small Retrofit 1998 209,736 101729 Norwest Energy Eft. 1998 763,128 101730 Low Income WZ 1998 199,812 101731 Hasslefree Efficiency 1998 260 101732 Energy Finanswer 1998 277 680 101733 RFP Low Income 1998 147 264 101734 Industrial Finanswer 1998 197 904 101737 Super Goodcents 1998 129,696 101977 Hasslefree Efficiency 1999 384 101978 Low Income RFP 1999 556,604 . 101979 Low Income WZ 1999 241 620 101981 Rebate WZ 1999 241 332 101984 Energy Finanswer 1999 265,272 101985 Industrial Finanswer 1999 141 144 101986 Small Retrofit (EF 12 000) 1999 302 832 101987 NEEA Def. Amortization 1999 682 880 101991 Cash Rebate WZ 1999 788 102018 Econ Reg. Delayed Amort. 93-99 366 101998 Decoupling 287 142 102203 Oregon Rev. Recovery Offset 182.29,842 802 14,078,957 DSM Reg Assets All Less Than 50 000 490 908.295,013 71,490 Utah 101182 Industrial Finanswer 1993 (15)908.15,610 662 101183 Industrial Finanswer 1994 (15)908.842 152 896 101184 Industrial Finanswer 1995 (15)908.374 170,996 101185 Industrial Finanswer 1996 (15)908.10,276 92,485 101199 RFP CESIWAY 1995 (10)908.45,462 136 386 101200 RFP CESIWAY 1996 (10)908.33,360 133,440 101214 Energy Finanswer 1992 (15)908.387 156 935 101215 Energy Finanswer 1993 (15)908.60,450 362 698 101216 Energy Finanswer 1994 (15)908.650 487 553 101217 Energy Finanswer 1995 (15)908.745 333 959 101218 Energy Finanswer 1996 (15)908.24,824 223 417 101221 Commercial Competitive 1993 (15)908.19,609 117 655 TOTAL 521 ,565 894~373 691 903 511 120,463 FERC FORM NO.1 (ED. 12-94)Page 232. Name of Respondent This i!Jort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 0 HER REGULATORY ASSETS (Account 182. 1. Report below the particulars (details) called for concerning other regulatory assets which are created through the rate making actions of regulatory agencies (and not includable in other accounts) 2. For regulatory assets being amortized, show period of amortization in column (a) 3. Minor items (5% of the Balance at End of Year for Account 182.3 or amounts less than $50,000, whichever is less) may be grouped by classes. Line Description and Purpose of Debits CREDITS Balance at No.Other Regulatory Assets Account Amount End of Year Charged (a)(b)(c)(d)(e) 101223 Energy Finanswer 12,0001992 (15)908.10,586 52,932 101245 ECONS 1994 (10)908.276,237 552,474 101249 RFP EUA Onsite 1995 (10)908.149 838 449 514 101250 RFP EUA Onsite 1996 (10)908.788 223 152 102131 Energy Finanswer 2001/2002 895 415 280,484 102133 Industrial Finanswer 2001/2002 027 159 353,184 102138 Compact Fluorescent Lamps 2001/2002 949,571 201 685 102147 Commercial Small Retrofit 2001/2002 663,475 847 943 102149 Commercial Retrofit Lighting 2001/2002 436,565 497 810 102150 Industrial Retrofit Lighting 2001/2002 54,693 799 102195 Industrial Retrofit Lighting 2002 70,546 546 102196 Power Forward 2002 121 489 121,489 102146 UT Carrying Charge 2001/2002 242 538 253,517 101663 Utah Net Lost Rev. Comm. Fin 1995 908.935 167 483 101664 Utah Net Lost Rev. Comm. Fin 1996 908.10,490 413 101678 Utah Net Lost Rev. Major Accounts 1995 908.890 669 101679 Utah Net Lost Rev. Major Accounts 1996 908.717 202,869 101680 Utah Net Lost Rev. Major Accounts 1997 908.105 85,523 101683 Utah Net Lost Rev. Comm. Spec, 1996 908.21,419 192 774 101691 Utah Net Lost Rev. EF Retrofit 1996 908.013 54,114 101693 Utah Net Lost Rev. CES WAY 1996 908.18,772 75,087 101695 Utah Net Lost Rev. EF Custom 1996 908.961 89,650 101696 Utah Net Lost Rev. EF Custom 1997 908.825 251 101700 Utah Net Lost Rev. EF Commercial 1997 908.433 329 DSM Reg Assets All Less Than 50 000 605 908.308 232 003,197 Washington 102030 Energy Finanswer 555 580 968,381 102032 Industrial Finanswer 2,450,345 264 700 102033 Low Income 544,698 363 231 102036 Commercial Small Retrofit 327 236 467 198 102038 Commercial Retrofit Lighting 191 984 253,468 102040 NEEA 344 852 778,883 102044 Home Comfort 212 70,239 102045 Weatherization 692 114,596 102072 CFL Bulbs 811 182,411 102185 Web Audit Pilot 205 257 205,257 102128 SBC Rev. Recovery 182.766 198 145 066 102188 Carrying Charge Penalty 313 313 DSM Reg Assets All Less Than 50 000 48,677 119 592 Wyoming 102069 Industrial Finanswer 2001 (10)908.706 93,965 TOTAL 521 565 894 373,691 903 511 120,463 FERC FORM NO.1 (ED. 12-94)Page 232. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Fi A Resubmission 04/3012003 OTHER REGULATORY ASSETS (Account 182. 1. Report below the particulars (details) called for con~ming other regulatory assets which are created through the rate making actions of regulatory agencies (and not includable in other accounts) 2. For regulatory assets being amortized, show period of amortization in column (a) 3. Minor items (5% ofthe Balance at End of Year for Account 182.3 or amounts less than $50,000, whichever is less) may be grouped by classes. Line Description and Purpose of Debits CREDITS Balance at No.Other Regulatory Assets ~ccount Amount End of Year Charged (a)(b)(c)(d)(e) DSM Reg Assets All Less Than 50 000 878 908.145,659 520 958 Other Regulatory Assets Transition Costs Retirement & Displacement 182.114 469,843 Transition Plan - CA 753,235 753 235 Transition Plan - ID (5)808 219 930.583 992 224 227 Transition Plan - OR (10)929 933 930.104,201 38,825,732 Transition Plan - UT (5)624 615 930.911 251 29,713,364 Transition Plan - WY West (5)993 181 930.123 708 869,473 Transition Plan - WY East (5)122 150 930.552 729 569,421 FAS 109 Income Taxes Electric Various 327 945 557 634,708 SB 1149 Implementation Costs OR Retail Access 295 885 191 826 Glenrock Mine Reclamation UT (5)930.300 787 Y2K Expense 98-00 UT (2)930.735 97 Computer Mainframe Writedown UT (4)930.843,274 98 Early Retirement UT (4)930.683,020 FAS 87/88 Pension UT (10)930.159 014 15,795,070 Y2K Expense 98-00 OR (7)930.268 659 537 318 BSIP/SAP UT (4)930.268,913 071 290 Glenrock Mine Excluding Reclamation UT (10)930.302 399 940 819 Software Writedown 1997 UT (4)930.514 363 900,136 Software Writedown 1998 UT (4)930.367 023 642,290 Transition Team Costs UT (4)930.485 905 850,333 Deferred Excess Net Power Costs OR UM 421 45,596,736 101 745 173 Deferred Excess Net Power Costs UT 421 846 209 613 677 Deferred Excess Net Power Costs WY 421 459,239 139,611 Deferred Excess Net Power Costs ID 421 474 841 13,896,103 Deferred Excess Net Power Costs OR UE 421 078,161 398 653 Oregon UE134 Power Costs 878 064 878 064 Environmental Costs (10)925 906 761 902 927 FAS 106 WY UPL (7)369 444 FAS 106 WY PPL (7)136 906 IDAI Costs No. CA Direct Access 665,523 Cholla Contract Review (4)923 198,572 Cholla Plant Transaction Costs (26)557 122,425 16,368 700 Washington Colstrip #3 (22)456.188 943 763 Cholla Plant Transaction Costs CA (26)23,016 335,644 Cholla Plant Transaction Costs MT (26)228 309,500 Trail Mountain Mine Closure Costs 933 547 12,933,547 Contra Regulatory Assets 000 000 -65 000 000 FAS 133 Derivative Net Regulatory Asset 265 591 837 533,975,697 FAS 87 Deferred Pension Costs 577 611 155,885 TOTAL 521 565 894 373 691 903 511 120 463 FERC FORM NO.1 (ED. 12-94)Page 232. Name of Respondent This ~rt Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31,2002(2) 0 A Resubmission 04/30/2003 0 HER REGULATORY ASSETS (Account 182. 1. Report below the particulars (details) called for con~rning other regulatory assets which are created through the rate making actions of regulatory agencies (and not includable in other accounts) 2. For regulatory assets being amortized, show period of amortization in column (a) 3. Minor items (5% of the Balance at End of Year for Account 182.3 or amounts less than $50,000, whichever is less) may be grouped by classes. Line Description and Purpose of Debits CREDITS Balance at No.Other Regulatory Assets ~~count Amount End of Year Charged (a)(b)(c)(d)(e) FAS 88 Deferred Pension Costs Earty Retirement 182.577 611 36,763,423 FAS 87 Deferred Pension Costs - CA Gen -462 694 FAS 88 Deferred Pension Costs - CA Gen Early Ret.722,983 FAS 87 Deferred Pension Costs - MT Gen 330,388 FAS 88 Deferred Pension Costs - MT Gen Early Ret.516 247 FAS 87 Deferred Pension Costs - Write Down 906 451 FAS 88 Deferred Pension Costs Early Ret. Write 980,545 Trail Mountain Mine Unrecovered Investment (5)238,339 238,339 TOTAL 521 565 894 373 691 903 511 120 463 FERC FORM NO.1 (ED. 12-94)Page 232. This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) n A Resubmission 04/3012003 MISCELLANEOUS DEFFERED DEBITS (Account 186) 1. Report below the particulars (details) called for con~ming miscellaneous deferred debits. 2. For any deferred debit being amortized, show period of amortization in column (a) 3. Minor item (1 % of the Balance at End of Year for Account 186 or amounts less than $50,000, whichever is less) may be grouped by classes. Name of Respondent PacifiCorp Year of Report Dec. 31 2002 (a) 1 BPA Balancing Account Utah Div. Mill Fork Mine Rights Lease Payments 11 California Property Taxes 12 (amortized over 6 months) 14 Joseph Settlement (20) 16 Idaho Customer Balancing 18 Cove Hydro Projects - Amortized 19 throuah 1-31-2002 25 Lacomb Irrigation (24) 27 Option purchases 29 Property Damage Repairs - 30 Insurance Losses 32 Sales of Electric Utility 33 Facilities and Properties 35 BoQUS Creek (42) 36 Bogus Creek settlement (7) trccountCharged(c) (d) 155,696 533 ~u~i~l,~IJ CREDITS Amount (e) 165 679,015 Balance at End of YearLine No. Description of Miscellaneous Deferred Debits Balance at Beginning of Year (b) 982 482 Debits (f) Water Assessment Payment to Emery Water Conservancy District (Amortization Period 12 months)129,862 397 506 227,259 799,355 350,960 26,150 315 817 199 165.817 199 209,542 557 137 381 072,161 073 202 073 202 461 555.461 Firth Cogeneration Buyout (10) Firth Cogeneration Buyout - CA Firth Cogeneration Buyout - MT 776 320 33,415 33,757 557 444,080 332 240 25,063 25,321 352 8,436 918 210 557 720 872 490 700 000 555 700 000 150 150 390,342 Various 315 385 027 572 080 -472,000 557 280 530,800 -472 000 Intangible Pension Asset: SERP Plan Pension Intangible Asset 330 000 006,000 330 000 006,000 Business Energy Tax Credit: Super Good Cents (10) Wz Tax Credit Loan Prog, (13) Energy Finanswer (13) Industrial Finanswer (13) 623 094 145 466 534,707 421. 421. 421. 2,478 391 839 145 703 128,627 908,570373,863 47 Misc. Work in Progress 48 Deferred Regulatory Comm, Expenses (See pages 350 - 351) 49 TOTAL 100,497,507 123 117,377 FERC FORM NO.1 (ED. 12-94)Page 233 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) FiA Resubmission 04/30/2003 MISCELLANEOUS DEFFERED DEBITS (Account 186) 1. Report below the particulars (details) called for con~ming miscellaneous deferred debits. 2. For any deferred debit being amortized, show period of amortization in column (a) 3. Minor item (1 % of the Balance at End of Year for Account 186 or amounts less than $50,000, whichever is less) may be grouped by classes. Line Description of Miscellaneous Balance at Debits CREDITS Balance at No.Deferred Debits Beginning of Year ~~unt Amount End of YearChar~ed (a)(b)(c)(e)(f) Cash Rebatellncentive (13)505 031 421.129,417 375 614 Commercial Retrofit (6)430,719 421.292 416,427 Industrial Retrofit (6)767 421.16,405 362 Commercial Small Retrofit (6)281 655 421.26,226 255,429 Industrial Small Retrofit (6)423 421.264 159 Tri-State Firm Wheeling (16)090 150 565.059,480 030,670 Mead Phoenix Availability & Trans Charge (50)156 600 565.377 760 778,840 Financing Costs Deferred 101 532 508,725 610,257 Biomass COD Prepayment 170 555 170 Buffalo Settlement (7)131 764 557 45,177 587 Lakeview Buyout (13)306 565 557 43,280 263,285 TGS Buyout (20)279 794 557 402 264 392 TGS Buyout - CA (20)245 288 957 TGS Buyout - MT (20)310 288 022 Hermiston Swap (20)868 768 557 539 572 329 196. Deferred Longwall Costs 730,457 365 135 151 095,592 Transition Costs - WA (5)223,453 930.055 409 168,044 Hayden Settlement (6)294 643 151.363,404 931,239 Northwest Power Pool 111 720 074 118,794 Other Deferred Debits with Amounts less than $50,000 448 369 900 538 269 Yakima Hydro - Transaction Cost 002 055 930.002 055 Deferred Aquila Streamflow Hedge Costs 1,458 330 895 833 555 895 833 1,458 330 Oregon Customer Balancing 848,401 848,401 242 Point to Point Transmission 335,009 565.801 834 533 175 Deferred Projects New Misc. Work in Progress . Deterred Regulatory Comm. Expenses (See pages 350 - 351) TOTAL 100,497 507 123 117 377 FERC FORM NO.1 (ED. 12-94)Page 233. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04130/2003 M SCELLANEOUS DEFFERED DEBITS (Account 186) 1. Report below the particulars (details) called for conc~rning miscellaneous deferred debits. 2. For any deferred debit being amortized, show period of amortization in column (a) 3. Minor item (1 % of the Balance at End of Year for Account 186 or amounts less than $50 000, whichever is less) may be grouped by classes. Line Description of Miscellaneous Balance at Debits CREDITS Balance at No.Deferred Debits Beginning of Year ~ccoum Amount End of Year Char~ed (a)(b)(c)(e)(f) Generation 081,451 Capital 081,451 Deferred Costs Wyodak Settlement (22)038 819 151.118 335 183 703,636 Jim Boyd Hydro Buyout (11)966 616 557 48,251 918,365 Misc. Work in Progress ueferred Regulatory Comm. Expenses (See pages 350 - 351) TOTAL 100,497 507 123,117 377 FERC FORM NO.1 (ED. 12-94)Page 233. Name of Respondent PacifiCorp This ~rt Is: Date of Report(1) ~An Original (Mo, Da, Yr) (2) A Resubmission 04/30/2003 ACCUMULATED DEFERRED INCOME TAXES (Account 190) 1. Report the infonnation called for below concerning the respondent's accounting for deferred income taxes. 2. At Other (Specify), include deferrals relating to other income and deductions. Year of Report Dec. 31 2002 No. Electric 2 Bond Refinancing Deferred Compensation 4 Bad Debt Obsolete Parts Cholla/GE Contract Amortization ocatlon (a) 8 TOTAL Electric (Enter Total of lines 2 thru 7) 9 Gas 15 Other 16 TOTAL Gas (Enter Total oflines 10 thru 15 211 607 255 501 623,570 359 582 639 621 208,305 56,298,186 151,243 071 370 150 856 774 012 567 519 015,239 699,761 10,289,910 588 096 121 808 821 569 Notes FERC FORM NO.1 (ED. 12-88)Page 234 Name of Respondent PacifiCorp This ~ort Is:(1) ~An Original(2) DA Resubmission CAPITAL STOCKS (Account 201 and 204) 1. Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (Le., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible. 2. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year. Date of Report(Mo, Da, Yr) 04/30/2003 Year of Report Dec. 31 2002 Line No. Class and Series of Stock and Name of Stock Series Number of shares Authorized by Charter Par or Stated Value per share Call Price at End of Year (a)(b) 750 000 000 (c)(d) 1 Common Stock (Account 201) 2 (PacifiCorp is a fully owned indirect 3 subsidiary of ScottishPower) 4 Common Stock (Mines) 6 TOTAL COMMON STOCK 10 5% Cumulative Preferred (American Stock Exch. 11 Serial Preferred, Cumulative: 12 4.52% Series 13 7.00% Series 14 6.00% Series 15 5.00% Series 16 5.40% Series 17 4.72% Series 18 4.56% Series 20 No Par Serial Preferred, Cumulative: 21 $7.48 Series 23 TOTAL PREFERRED STOCK 34 '~ili~()ri,(:~aodij6~SQ'~j~pitaIStocl("e: 750 000 000 126,533 500 000 1 00.110. 100.00 103. 100.00~ 100.00~ 100.00 100. 100.00 101. 100.00 103. 100.00 102. 16,000,000 100. 626 533 .....:. FERC FORM NO.1 (ED. 12-91)Page 250 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31,2002(2) 0 A Resubmission 04/30/2003 CAPITAL STOCKS (Account 201 and 204) (Continued) 3. Give particulars (details) concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued. 1. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or non-cumulative. 5. State in a footnote if any capital stock which has been nominally issued is nominally outstanding at end of year. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purposes of pledge. OUTSTANDING PER BALANCE SHEET HELD BY RESPONDENT Line (Total amount outstanding without reduction AS REACQUIRED STOCK (Account 217)IN SINKING AND OTHER FUNDS No.for amounts held by respondent) ~I'\ares Amount ares ~pst Sh;ires Amount (e)(f) (g) (h)(i) 312 176 089 933,223,674 001 001 312 179 090 933,226,675 126,243 624 300 065 206,500 046 804 600 930 593 000 908 190,800 959 595,900 69,890 989 000 84,592 8,459,200 675,000 500 000 089 633 108,963 300 FERC FORM NO.1 (ED. 12-88)Page 251 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) nA Resubmission 04/3012003 CAPITAL STOCK EXPENSE (Account 214) 1. Report the balance at end of the year of discount on capital stock for each class and series of capital stock. 2. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged. Llne \,;Iass ana ::ienes Of ::itoCK Balance at End of Year No.(a)(b) Common Stock 093 938 Preferred Stock: 00% Serial 98,049 52% Serial 676 72% Serial 30,349 56% Serial 49,071 $7.48 Serial 756,390 22 TOTAL 037 473 FERC FORM NO.1 (ED. 12-87)Page 254b Blank Page (Next Page is: 256) Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Ei A Resubmission 04/30/2003 LONG-TERM DEBT (Account 221 , 222, 223 and 224) 1. Report by balance sheet account the particulars (details) concerning long-term debt included in Accounts 221 , Bonds, 222 Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other long-Term Debt. 2. In column (a), for new issues , give Commission authorization numbers and dates. 3. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds. 4. For advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received. 5. For receivers, certificates, show in column (a) the name of the court -and date of court order under which such certificates were issued. 6. In column (b) show the principal amount of bonds or other long-term debt originally issued. 7. In column (c) show the expense, premium or discount with respect to the amount of bonds or other long-term debt originally issued. 8. For column (c) the total expenses should be listed first for each issuance, then the amount of premium (in parentheses) or discount. Indicate the premium or discount with a notation, such as (P) or (D). The expenses, premium or discount should not be netted. 9. Furnish in a footnote particulars (details) regarding the treatment of unamortized debt expense, premium or discount associated with issues redeemed during the year. Also, give in a footnote the date of the Commission s authorization of treatment other than as specified by the Uniform System of Accounts. Line Class and Series of Obligation, Coupon Rate Principal Amount Total expense No.(For new issue, give commission Authorization numbers and dates)Of Debt issued Premium or Discount (a)(b)(c) Bonds (Account 221): First Mortgage Bonds: 750% Series due April 1 , 2005 150 000 000 177 203 196 500 D 650% Series due November 1 , 2006 200 000,000 185,966 670,000 D 271% Series due October 1 2010 48,972 000 978% Series due October 1 2011 4,422 000 900% Series due November 15, 2011 500 000,000 567,009 735 000 D 493% Series due October 1 , 2012 19,772 000 797% Series due October 1 , 2013 16,203 000 734% Series due October 1 2014 218 000 294% Series due October 1 , 2015 946 000 635% Series due October 1 , 2016 750,000 470% Series due October 1 , 2017 609 000 700% Series due November 15, 2031 300 000 000 874 150 864 000 D First Mortgage and Collateral Trust Bonds: 20% Series D Medium-Term Notes due Aug. 15,2002 000,000 552 20% Series D Medium-Term Notes due Aug. 15,2002 500,000 41,466 20% Series D Medium-Term Notes due Aug. 15 2002 000 000 793 20% Series D Medium-Term Notes due Aug. 15 2002 000 000 38,276 18% Series D Medium-Term Notes due Aug. 15 2002 000 000 63,793 18% Series D Medium-Term Notes due Aug. 15,2002 500,000 22,328 12% Series D Medium-Term Notes due Aug. 15 2002 000 000 25,517 25% Series E Medium-Term Notes due Sept. 9, 2002 20,000,000 150,295 25% Series E Medium-Term Notes due Sept. 9, 2002 20,000,000 150,295 21% Series E Medium-Term Notes due Sept. 9 2002 10,000,000 148 14% Series E Medium-Term Notes due Sept. 10 2002 500 000 272 98% Series E Medium-Term Notes due Sept. 16,2002 000 000 148 TOTAL 136 600,000 309 953 FERC FORM NO.1 (ED. 12-96)Page 256 Name of Respondent This (!Jort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr) Dec. 31, 2002(2) nA Resubmission 04/30/2003 LONG-TERM DEBT (Account 221 , 222, 22 and 224) (Continued) 10. Identify separate undisposed amounts applicable to issues which were redeemed in prior years. 11. Explain any debits and credits other than debited to Account 428 , Amortization and Expense, or credited to Account 429, Premium on Debt - Credit. 12. In a footnote, give explanatory (details) for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a) principal advanced during year, (b) interest added to principal amount, and (c) principle repaid during year. Give Commission authorization numbers and dates. 13. If the respondent has pledged any of its long-term debt securities give particulars (details) in a footnote including name of pledgee and purpose of the pledge. 14. If the respondent has any long-term debt securities which have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. 15. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (i). Explain in a footnote any difference between the total of column (i) and the total of Account 427, interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. 16. Give particulars (details) concerning any long-term debt authorized by a regulatory commission but not yet issued. AMORTIZATION PERIOD uu(s(analn Line Nominal Date Date of (Total amount outstan ing without Interest for Year No.of Issue Maturity Date From Date To reduction for amounts held by Amount (d)(e)(f) (g) resp?~dent)(i) 040193 040105 040193 040105 150 000 000 125,000 110698 110106 110698 110106 200,000,000 300,000 041592 100110 041592 100110 276 000 577,553 041592 100111 041592 100111 769,000 233,177 111501 111511 111501 111511 500,000,000 404 167 041592 100112 041592 100112 299 000 182,098 041592 100113 041592 100113 11,477,000 049,680 041592 100114 041592 100114 708,000 871 522 041592 100115 041592 100115 35,162 000 008,462 041592 100116 041592 100116 571 000 292,465 041592 100117 041592 100117 15,555 000 349,843 111501 111531 111501 111531 300,000 000 035,833 081492 081502 081492 081502 537 600 081492 081502 081492 081502 291 200 081492 081502 081492 081502 448,000 081492 081502 081492 081502 268,800 081492 081502 081492 081502 446 756 081492 081502 081492 081502 156 364 081492 081502 081492 081502 177 209 090892 090902 090892 090902 998 889 090492 090902 090492 090902 998 889 090992 090902 090992 090902 496,689 091092 091002 091092 091002 078 091592 091602 091592 091602 494,417 895,711,464 252 443,726 FERC FORM NO.1 (ED. 12-96)Page 257 Name of Respondent This (!Jort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31,2002(2) nA Resubmission 04130/2003 LONG-TERM DEBT (Account 221 222 223 and 224) 1. Report by balance sheet account the particulars (details) concerning long-term debt included in Accounts 221 , Bonds, 222 Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other long-Term Debt. 2. In column (a), for new issues, give Commission authorization numbers and dates. 3. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds. 4. For advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received. 5. For receivers, certificates, show in column (a) the name of the court -and date of court order under which such certificates were issued. 6. In column (b) show the principal amount of bonds or other long-term debt originally issued. 7. In column (c) show the expense, premium or discount with respect to the amount of bonds or other long-term debt originally issued. 8. For column (c) the total expenses should be listed first for each issuance, then the amount of premium (in parentheses) or discount. Indicate the premium or discount with a notation, such as (P) or (D). The expenses, premium or discount should not be netted. 9. Fumish in a footnote particulars (details) regarding the treatment of unamortized debt expense, premium or discount associated with issues redeemed during the year. Also, give in a footnote the date of the Commission s authorization of treatment other than as specified by the Uniform System of Accounts. Line Class and Series of Obligation, Coupon Rate Principal Amount Total expense No.(For new issue, give commission Authorization numbers and dates)Of Debt issued Premium or Discount (a)(b)(c) 97% Series E Medium-Term Notes due Sept 16,2002 000,000 030 95% Series E Medium-Term Notes due Sept 16 2002 000,000 148 00% Series E Medium-Term Notes due Sept 17 2002 000,000 515 97% Series E Medium-Term Notes due Sept 23, 2002 500,000 11,272 40% Series E Medium-Term Notes due Jan. 22, 2003 000,000 333 36% Series E Medium-Term Notes due Jan. 27, 2003 000 000 18,998 34% Series F Medium-Term Notes due July 28, 2003 000,000 150,051 34% Series F Medium-Term Notes due July 28, 2003 000,000 590 34% Series F Medium-Term Notes due July 28, 2003 000,000 795 34% Series F Medium-Term Notes due July 28 2003 000 000 795 34% Series F Medium-Term Notes due July 28, 2003 000,000 78,974 31% Series F Medium-Term Notes due July 28, 2003 000 000 385 31% Series F Medium-Term Notes due July 28, 2003 000,000 142 154 31% Series F Medium-Term Notes due July 28, 2003 18,000,000 142 154 31% Series F Medium-Term Notes due July 28, 2003 000,000 897 00% Series C Medium-Term Notes due Sept 1 2003 55,226 000 366 03% Series E Medium-Term Notes due Oct. 15 2003 000,000 788 27% Series E Medium-Term Notes due Oct. 21 , 2003 000 000 515 39% Series E Medium-Term Notes due Oct. 21 , 2003 000 000 33,788 30% Series E Medium-Term Notes due Oct. 22, 2003 000 000 515 86% Series D Medium-Term Notes due Feb. 16 2004 500,000 110 81% Series D Medium-Term Notes due Feb. 16,2004 20,000,000 168 880 79% Series D Medium-Term Notes due Feb. 16 2004 000,000 50,664 75% Series D Medium-Term Notes due Feb. 16,2004 000 000 25,332 75% Series H Medium-Term Notes due Jul. 15,2004 175 000 000 680 166 500 500 D 32% Series E Medium-Term Notes due Sept 3, 2004 500 000 56,361 11% Series E Medium-Term Notes due Sept 24, 2004 500 000 846 30% Series E Medium-Term Notes due Oct. 22, 2004 000,000 576 30% Series E Medium-Term Notes due Oct. 22, 2004 10,000,000 576 66% Series E Medium-Term Notes due Oct. 22, 2004 000,000 32,745 53% Series E Medium-Term Notes due Oct. 26, 2004 750,000 068 TOTAL 136,600 000 309,953 FERC FORM NO.1 (ED. 12-96)Page 256. Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 LONG- TERM DEBT (Account 221 , 222, 22 and 224) (Continued) 10. Identify separate undisposed amounts applicable to issues which were redeemed in prior years. 11. Explain any debits and credits other than debited to Account 428, Amortization and Expense, or credited to Account 429, Premium on Debt - Credit. 12. In a footnote , give explanatory (details) for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a) principal advanced during year, (b) interest added to principal amount, and (c) principle repaid during year. Give Commission authorization numbers and dates. 13. If the respondent has pledged any of its long-term debt securities give particulars (details) in a footnote including name of pledgee and purpose of the pledge. 14. If the respondent has any long-term debt securities which have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. 15. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (i). Explain in a footnote any difference between the total of column (i) and the total of Account 427, interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. 16. Give particulars (details) conceming any long-term debt authorized by a regulatory commission but not yet issued. AMORTIZATION PERIOD ul!tstan~:JIn LineNominal Date Date of (Total amount outstan ing without Interest for Year No.of Issue Maturity Date From Date To reduction for amounts tield by Amount (d)(e)(f) (g) reSp?~dent)(i) 091592 091602 091592 091602 742 091692 091602 091692 091602 492 292 091792 091702 091792 091702 49,778 092192 092302 092192 092302 089 012293 012203 012293 012203 000 000 000 012693 012703 012693 012703 000,000 220,800 072893 072803 072893 072803 19,000,000 204 600 072893 072803 072893 072803 000 000 253 600 072893 072803 072893 072803 000,000 126 800 072893 072803 072893 072803 000,000 126,800 072193 072803 072193 072803 000,000 634 000 072893 072803 072893 072803 000,000 378 600 072893 072803 072893 072803 000 000 135,800 072893 072803 072893 072803 000 000 135,800 072893 072803 072893 072803 000,000 63,100 061091 090103 061091 090103 453,107 561 348 101592 101503 101592 101503 000,000 351 500 102192 102103 102192 102103 000 000 145 400 102192 102103 102192 102103 000 000 369 500 102292 102203 102292 102203 000 000 146 000 021492 021604 021492 021604 500 000 196,500 021492 021604 021492 021604 000 000 562 000 021492 021604 021492 021604 000 000 467,400 021492 021604 021492 021604 000,000 232,500 071597 071504 071597 071504 175,000,000 812,500 090492 090304 090492 090304 500,000 549,000 092492 092404 092492 092404 500,000 462 150 102292 102204 102292 102204 10,000,000 730,000 102292 102204 102292 102204 000 000 730,000 110692 102204 110692 102204 000,000 383 000 102692 102604 102692 102604 750,000 475 895 711 464 252 443,726 FERC FORM NO.1 (ED. 12-96)Page 257. Name of Respondent This ~rt Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) F5 A Resubmission 04/30/2003 LONG-TERM DEBT (Account 221, 222, 223 and 224) 1. Report by balance sheet account the particulars (details) concerning long-term debt included in Accounts 221 , Bonds, 222 Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other long-Term Debt. 2. In column (a), for new issues, give Commission authorization numbers and dates. 3. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds. 4. For advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received. 5. For receivers, certificates, show in column (a) the name of the court -and date of court order under which such certificates were issued. 6. In column (b) show the principal amount of bonds or other long-term debt originally issued. 7. In column (c) show the expense, premium or discount with respect to the amount of bonds or other long-term debt originally issued. 8. For column (c) the total expenses should be listed first for each issuance, then the amount of premium (in parentheses) or discount. Indicate the premium or discount with a notation, such as (P) or (D). The expenses, premium or discount should not be netted. 9. Furnish in a footnote particulars (details) regarding the treatment of unamortized debt expense, premium or discount associated with issues redeemed during the year. Also, give in a footnote the date of the Commission s authorization of treatment other than as specified by the Uniform System of Accounts. Line Class and Series of Obligation, Coupon Rate Principal Amount Total expense No.(For new issue, give commission Authorization numbers and dates)Of Debt issued Premium or Discount (a)(b)(c) 71% Series E Medium-Term Notes due Oct. 27, 2004 000,000 20,273 71% Series E Medium-Term Notes due Oct. 27 2004 250 000 962 60% Series E Medium-Term Notes due Nov. 1 2004 000 000 549 72% Series E Medium-Term Notes due Nov. 2, 2004 500,000 824 7.43% Series E Medium-Term Notes due Jan. 24, 2005 000,000 333 43% Series E Medium-Term Notes due Jan. 24, 2005 500,000 15,832 34% Series E Medium-Term Notes due Oct. 17 2005 000 000 788 36% Series E Medium-Term Notes due Oct. 17 2005 000,000 788 12% Series G Medium-Term Notes due Jan. 15,2006 100,000,000 679,467 67% Series C Medium-Term Notes due Jan. 10,2007 724 000 36,625 625% Series G Medium-Term Notes due June 1 , 2007 100,000 000 267,428 630,000 D 7.43% Series E Medium-Term Notes due Sept. 11 2007 000,000 530 22% Series E Medium-Term Notes due Sept. 18,2007 500,000 412 27% Series E Medium-Term Notes due Sept. 24, 2007 000,000 059 375% Series H Medium-Term Notes due May 15, 2008 200,000,000 1,416 179 644 000 D 00% Series H Medium-Term Notes due Jul. 15 2009 125,000 000 976 904 451 250 D 15% Series C Medium-Term Notes due Aug. 9, 2011 000 000 327 95% Series C Medium-Term Notes due Sept. 1 , 2011 25;000,000 175 398 95% Series C Medium-Term Notes due Sept. 1 2011 20,000,000 132 118 92% Series C Medium-Term Notes due Sept. 1 2011 20,000,000 188 318 29% Series C Medium-Term Notes due Dec. 30, 2011 000,000 23,040 26% Series C Medium-Term Notes due Jan. 10,2012 000 000 649 28% Series C Medium-Term Notes due Jan. 10, 2012 000,000 297 25% Series C Medium-Term Notes due Feb. 1 2012 000 000 946 13% Series E Medium-Term Notes due Jan. 22, 2013 000 000 75,827 25% Series F Medium-Term Notes due Aug. 1 2013 000 000 91,474 25% Series F Medium-Term Notes due Aug. 1 , 2013 10,000 000 474 25% Series F Medium-Term Notes due Aug. 1 2013 10,000 000 91,474 25% Series F Medium-Term Notes due Aug. 1 , 2013 10,000 000 91,474 TOTAL 136 600 000 62,309 953 FERC FORM NO.1 (ED. 12-96)Page 256. Name of Respondent This wort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) DA Resubmission 04/30/2003 LONG-TERM DEBT (Account 221 222 223 and 224) (Continued) 10. Identify separate undisposed amounts applicable to issues which were redeemed in prior years. 11. Explain any debits and credits other than debited to Account 428, Amortization and Expense, or credited to Account 429, Premium on Debt - Credit. 12. In a footnote, give explanatory (details) for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a) principal advanced during year, (b) interest added to principal amount, and (c) principle repaid during year. Give Commission authorization numbers and dates. 13. If the respondent has pledged any of its long-term debt securities give particulars (details) in a footnote including name of pledgee and purpose of the pledge. 14. If the respondent has any long-term debt securities which have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. 15. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (i). Explain in a footnote any difference between the total of column (i) and the total of Account 427, interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. 16. Give particulars (details) concerning any long-term debt authorized by a regulatory commission but not yet issued. AMORTIZATION PERIOD ul!ISIanaln LineNominal Date Date of (Total amount outstan ing without Interest for Year No.of Issue Maturity Date From Date To reduction for amounts Meld by Amount (d)(e)(f) (g) reSP ?h\dent)(i) 102792 102704 102792 102704 000,000 231 300 102792 102704 102792 102704 250 000 250 575 110692 110104 110692 110104 000 000 76,000 110292 110204 110292 110204 500,000 115,800 012293 012405 012293 012405 000,000 300 012293 012405 012293 012405 500 000 185 750 101592 101705 101592 101705 000 000 367 000 101592 101705 101592 101705 000,000 368 000 012296 011506 012296 011506 100 000 000 120 000 011092 011007 011092 011007 724 000 439 031 060995 060107 060995 060107 100,000 000 625 000 091192 091107 091192 091107 000 000 148 600 091892 091807 091892 091807 500 000 180 500 092292 092407 092292 092407 000 000 290 800 051298 051508 051298 051208 200,000 000 12,750,000 071597 071509 071597 071509 125,000,000 750 000 080991 080911 080991 080911 000 000 732 000 081691 090111 081691 090111 000 000 237 500 081691 090111 081691 090111 000 000 790 000 081691 090111 081691 090111 000,000 784 000 123191 123011 123191 123011 000,000 248 700 010992 011012 010992 011012 000,000 82,600 011092 011012 011092 011012 000 000 165 600 011592 020112 011592 020112 000,000 247 500 012093 012213 012093 012213 10,000,000 813,000 072893 080113 072893 080113 10,000,000 725 000 072893 080113 072893 080113 000 000 725 000 072893 080113 072893 080113 10,000 000 725 000 072893 080113 072893 080113 10,000,000 725 000 895 711,464 252 443 726 FERC FORM NO.1 (ED. 12-96)Page 257. This ~ort Is: Date of Report(1) ~An Original (Mo, Da, Yr)(2) n A Resubmission 04/30/2003 LONG-TERM DEBT (Account 221 , 222, 223 and 224) 1. Report by balance sheet account the particulars (details) concerning long-term debt included in Accounts 221 , Bonds, 222 Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other long-Term Debt. 2. In column (a), for new issues , give Commission authorization numbers and dates. 3. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds. 4. For advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received. 5. For receivers, certificates, show in column (a) the name of the court -and date of court order under which such certificates were issued. 6. In column (b) show the principal amount of bonds or other long-term debt originally issued. 7. In column (c) show the expense, premium or discount with respect to the amount of bonds or other long-term debt originally issued. 8. For column (c) the total expenses should be listed first for each issuance, then the amount of premium (in parentheses) or discount. Indicate the premium or discount with a notation, such as (P) or (0). The expenses, premium or discount should not be netted. 9. Furnish in a footnote particulars (details) regarding the treatment of unamortized debt expense, premium or discount associated with issues redeemed during the year. Also, give in a footnote the date of the Commission s authorization of treatment other than as specified by the Uniform System of Accounts. Name of Respondent PacifiCorp Line No. Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates) (a) Principal Amount Of Debt issued (b) 15,000 000 000,000 000,000 000 000 000 000 000,000 50,000,000 000 000 10,000 000 000 000 25,000,000 000,000 000 000 53% Series C Medium-Term Notes due Dec. 16,2021 375% Series C Medium-Term Notes due Dec. 31 , 2021 26% Series C Medium-Term Notes due Jan. 7, 2022 27% Series C Medium-Term Notes due Jan. 10, 2022 05% Series E Medium-Term Notes due Sept. 1 , 2022 07% Series E Medium-Term Notes due Sept. 9, 2022 12% Series E Medium-Term Notes due Sept. 9, 2022 11 % Series E Medium-Term Notes due Sept. 9, 2022 05% Series E Medium-Term Notes due Sept. 14, 2022 08% Series E Medium-Term Notes due Oct. 14 2022 08% Series E Medium-Term Notes due Oct. 14, 2022 23% Series E Medium-Term Notes due Jan. 20, 2023 23% Series E Medium-Term Notes due Jan. 20, 2023 29 6.71% Series G Medium-Term Notes due Jan. 15 2026 3 2 *P~lltJtil) ~; ~~g, t;~Jd~.!t! ~~~~11~r$:lPi~i~ JTI~;~~~~c ;t1'.':;5i iiJ?li1~J?,~f?Z!i"V .. . 26% Series F Medium-Term Notes due July 21 2023 26% Series F Medium-Term Notes due July 21 , 2023 40% Series F Medium-Term Notes due July 28,2023 37% Series F Medium-Term Notes due Aug. 11 2023 23% Series F Medium-Term Notes due Aug. 16 2023 24% Series F Medium-Term Notes due Aug. 16 2023 75% Series F Medium-Term Notes due Sept. 14 2023 75% Series F Medium-Term Notes due Sept. 14, 2023 72% Series F Medium-Term Notes due Sept. 14 2023 75% Series F Medium-Term Notes due Oct. 26, 2023 75% Series F Medium-Term Notes due Oct. 26, 2023 75% Series F Medium-Term Notes due Oct. 26, 2023 625% Series F Medium-Term Notes due Dec. 13,2024 000 000 000 000 000 000 15,500 000 15,000 000 000 000 000 000 000 000 000 000 20,000 000 16,000,000 000 000 000,000 100,000 000 33 TOTAL 136 600 000 FERC FORM NO.1 (ED. 12-96)Page 256. Year of Report Dec. 31 2002 Total expense Premium or Discount (c) 115,202 400 243 30,594 131 471 70,118 438,238 105 177 648 208,198 200,190 914 30,331 560 P 246 981 100 622 295 141 785 137 211 274,423 38,250 300 300 152,326 121 861 396 151 025 498,600 D 904 467 309 953 Name of Respondent This ~ort Is:Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002 (2) Ei A Resubmission 04/30/2003 LONG-TERM DEBT (Account 221 222 223 and 224) (Continued) 10. Identify separate undisposed amounts applicable to issues which were redeemed in prior years. 11. Explain any debits and credits other than debited to Account 428, Amortization and Expense, or credited to Account 429, Premium on Debt - Credit. 12. In a footnote, give explanatory (details) for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a) principal advanced during year, (b) interest added to principal amount, and (c) principle repaid during year. Give Commission authorization numbers and dates. 13. If the respondent has pledged any of its long-term debt securities give particulars (details) in a footnote including name of pledgee and purpose of the pledge. 14. If the respondent has any long-term debt securities which have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. 15. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (i). Explain in a footnote any difference between the total of column (i) and the total of Account 427, interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. 16. Give particulars (details) concerning any long-term debt authorized by a regulatory commission but not yet issued. AMORTIZATION PERIOD Ul!tstan?m LineNominal Date Date of (Total amount outstan ing without Interest for Year No.of Issue Maturity Date From Date To reduction for amounts held by Amount (d)(e)(f) (g) reSP ?h\dent)(i) 121691 121621 121691 121621 15,000,000 279 500 123191 123121 123191 123121 000,000 418 750 010892 010722 010892 010722 000,000 413,000 010992 011022 010992 011022 000 000 330,800 091892 090122 091892 090122 15,000 000 207 500 090992 090922 090992 090922 000,000 645 600 091192 090922 091192 090922 000,000 060 000 091192 090922 091192 090922 12,000 000 973,200 091492 091422 091492 091422 10,000,000 805 000 101592 101422 101592 101422 26,000,000 100 800 101592 101422 101592 101422 25,000,000 020,000 012093 012023 012093 012023 000 000 411 500 012993 012023 012993 012023 000 000 329 200 072293 072123 072293 072123 000,000 960,200 072293 072123 072293 072123 000,000 798 600 072893 072823 072893 072823 000,000 148,000 081193 081123 081193 081123 15,500 000 142 350 081693 081623 081693 081623 15,000 000 084,500 081693 081623 081693 081623 30,000 000 172 000 091493 091423 091493 091423 000 000 337 500 091493 091423 091493 091423 000 000 135,000 091493 091423 091493 091423 000 000 134,400 102693 102623 102693 102623 000,000 350,000 102693 102623 102693 102623 000,000 080 000 102693 102623 102693 102623 12,000,000 810,000 121394 121324 121394 121324 000 000 725,000 012396 011526 012396 011526 100 000,000 710 000 895,711,464 252 443,726 FERC FORM NO.1 (ED. 12-96)Page 257. Name of Respondent This wort Is: Date of Report Year of Report PacifiCorp (1) An Original (Mo, Da, Yr)Dec. 31 2002(2) n A Resubmission 04/30/2003 LONG-TERM DEBT (Account 221, 222, 223 and 224) 1. Report by balance sheet account the particulars (details) concerning long-term debt included in Accounts 221 , Bonds, 222 Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other long-Term Debt. 2. In column (a), for new issues, give Commission authorization numbers and dates. 3. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds. 4. For advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received. 5. For receivers, certificates, show in column (a) the name of the court -and date of court order under which such certificates were issued. 6. In column (b) show the principal amount of bonds or other long-term debt originally issued. 7. In column (c) show the expense, premium or discount with respect to the amount of bonds or other long-term debt originally issued. 8. For column (c) the total expenses should be listed first for each issuance, then the amount of premium (in parentheses) or discount. Indicate the premium or discount with a notation , such as (P) or (D). The expenses, premium or discount should not be netted. 9. Fumish in a footnote particulars (details) regarding the treatment of unamortized debt expense, premium or discount associated with issues redeemed during the year. Also, give in a footnote the date of the Commission s authorization of treatment other than as specified by the Uniform System of Accounts. Line Class and Series of Obligation, Coupon Rate Principal Amount Total expense, No.(For new issue, give commission Authorization numbers and dates)Of Debt issued Premium or Discount (a)(b)(c) Daily Adj. Rate Poll Ctrt Revenue Refunding Bonds, Moffat County, CO, Series 1994 40,655,000 874 159 5/8% Lincoln County, WY, Series due Nov. 1,2021 300,000 228,980 197 125 D 65% Emery County, Utah, Series due Nov. 1, 2023 46,500 000 624 793 5/8% Emery County, Utah, Series due Nov. 1 2023 400 000 625,551 389,500 D Daily Adj. Rate Poll Ctrl Rev Refunding Bonds, Sweetwater County, WY, Series 1994 260,000 510,479 Daily Adj. Rate Poll Ctrt Rev Refunding Bonds, Converse County, WY, Series 1994 190 000 209 777 Daily Adj. Rate Poll Ctrt Rev Refunding Bonds, Emery County, UT, Series 1994 121 940 000 274,246 Daily Adj. Rate Poll Ctrt Rev Refunding Bonds, Carbon County, UT, Series 1994 365 000 206,519 Daily Adj. Rate Poll Ctrt Rev Refunding Bonds, Lincoln County, WY, Series 1994 15,060,000 422,858 Pollution Control Revenue Bonds: Customized Purchase Poll Ctrl Rev Refndng Bonds, Sweetwater Cnty, WY, Ser. 1992A 335 000 147 642 Customized Purchase Poll Ctrt Rev Refndng Bonds, Sweetwater Cnty, WY, Ser. 1992B 305 000 138,478 Customized Purchase Poll Ctrl Rev Refndng Bonds, Converse County, WY, Series 1992 22,485 000 194 271 Customized Purchase Poll Ctrt Rev Refndng Bonds, Sweetwater Cnty, WY, Ser. 1988B 500 000 822 Customized Purchase Poll Ctrt Rev Refndng Bonds, Converse County, WY, Series 1988 000 000 155 970 Daily Adjustable Rate Poll Ctrl Revenue Bonds, Sweetwater County, WY, Series 1984 000 000 122 887 105 000 D Weekly Adj. Rate Poll Ctrt Rev Refndng Bonds, Sweetwater County, WY, Ser. 1990A 000 000 660 750 Customized Purchase Poll Ctrt Rev Refunding Bonds, Emery County, UT, Series 1991 000 000 872 505 Customized Purchase Poll Ctrt Rev Refunding Bonds, Lincoln Cnty, WY, Series 1991 45,000 000 771 836 Flexible Rate Demand Poll Ctrl Revenue Bonds, City of Forsyth, MT, Series 1986 500,000 304 824 Customized Purchase Poll Ctrt Rev Refndng Bonds , Sweetwater Cnty, WY, Ser. 1988A 50,000 000 422,443 Customized Purchase Poll Ctrl Rev Refndng Bonds, City of Forsyth, MT, Series 1988 45,000 000 380 198 Customized Purchase Poll Ctrt Rev Refndng Bonds, City of Gillette, WY, Ser. 1988 200,000 351 905 Daily Adj. Rate Environ. Imprvmnt Rev Bonds, Converse County, WY, Series 1995 300 000 132,043 Daily Adj. Rate Environ. Imprvmnt Rev Bonds, Lincoln County, WY, Series 1995 000 000 404,262 Daily Adj. Rate Environ. Imprvmnt Rev Bonds, Sweetwater County, WY, Series 1995 400 000 225,000 15% Emery County, Utah, Series due September 1 , 2030 12,675 000 556,549 178,464 D TOTAL 136 600 000 309,953 FERC FORM NO.1 (ED. 12-96)Page 256. 825 E. Mu/tnomah Portland, Oregon 97232 (503) 813-5000 P.ECEIVEO FILED 7G(13 idjA ~ \ 6 PM 3: \ 0 ill - PACIFICORP PACIFIC POWER UTAH POWER ;r:;U FL;?:L. TIt r; ;~' 5 CQrlhiSJ ION11\...11 ... May 14 2003 Paul Kjellander President Idaho Public Utilities Commission 472 West Washington Boise, ID 83702-5983 Dear Mr. Kjellander: SUBJECT:Annual Reports for 2002 Enclosed is a copy of our Idaho-Utah Division Annual State Report. If you have any questions, please don t hesitate to call me at 503-813-6061 or Mike Hamlin at 503- 813-6082. David L. Taylor Director, Revenue Requirements and Cost of Service ptp Enclosurec: Mike Hamlin STATE DAHO Utah Form 1 Pages 114-115 Utah Power & Light Company State of Idaho STATEMENT OF INCOME FOR THE YEAR 1. Report amounts for accounts 412 and 413, Revenue and Expenses from Utility Plant Leased to Others, in another utility column (i o) in a similar manner to a utility department. Spread the amount(s) over lines 01 thru 20 as appropriate. In- clude these amounts in columns (c) and (d) totals. 2. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above. 3. Report data for lines 7,9, and 10 for Natural Gas com- panies using accounts 404.404., 404.3, 407., and 407. 4. Use page 122 for important notes regarding the state- ment of income or any account thereof. 5. Give concise explanations concerning unsettled rate pro- Line No.Account UTILITY OPERATING INCOME 2 Operating Revenues (400) 3 Operating Expenses Operation Expenses (401) Maintenance Expenses (402) Depreciation Expense (403) Amort. & Depl. of Utility Plant (404-405) Amort. of Utility Plant Acq. Adj. (406) Amort. of Property Losses, Unrecovered Plant and Regulatory Study Costs (407) 10 Amort. of Conversion Expenses (407) 11 Taxes Other Than Income Taxes (408. 12 Income Taxes - Federal (409.13 - Other (409.14 Provision for Deferred Inc. Taxes (410. 15 (Less) Provision for Deferred Income Taxes - Cr.(411. 16 Investment Tax Credit Adj. - Net (411.17 (Less) Gains from Disp. of Utility Plant (411. 18 Losses from Disp. of Utility Plant (411. 19 Other Interest Income & Expense - Net ceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in a material refund to the util- ity with respect to power or gas purchases. State for each year affected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power and gas purchases. 6. Give concise explanations concerning significant amounts of any refunds made or received during the year Ref. Page No. TOTAL Current Year 300 $130,498,594 232,243,987 320-323 320-323 336 336 70,372,715 12,206,213 17,694 687 141,750 242,154 38,163 262-263 262-263 262-263 234,274-277 234,274-277 266 999,222 (129,598) (17 610) 681,235) 764,692 (546,458) (165,833) Dec. 31, 2002 Previous Year 175 072,558 12,280,247 19,817 368 247,326 330,991 722 095,784 561 192 359 041 767,545 (5,943,537) (735,548) (241 103) 109,918,862 218,664 586TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 19) Net Utility Operating Income (Enter Total of line 2 less 20) (Carryforward to page 117, line 21)$20,579,732 $13,579,401 Page 114 Utah Power & Light Company State of Idaho STATEMENT OF INCOME FOR THE YEAR Dec. 31, 2002 resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas pur- chases, and a summary of the adjustments made to balance sheet, income, and expense accounts. 7. If any notes appearing in the report to stockholders are applicable to this Statement of Income, such notes may be attached at page 122. 8. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of ELECTRIC UTILITY Current Year Previous Year Current Year $130,498,594 $232 243,987 70,372,715 175,072,558 206,213 280,247 17,694 687 19,817,368 141,750 247 326 242,154 330 991 38,163 52,722 999,222 095,784 (129,598)561,192 (17,610)359,041 (1,681,235)767 545 764 692 (5,943,537) (546,458)(735,548) (165,833)(241,103) 109,918,862 218,664 586 $20,579,732 $13,579,401 allocations and apportionments from those used in the pre- ceding year. Also give the approximate dollar effect of such changes. 9. Explain in a footnote if the previous year s figures are different from that reported in prior reports. 10. If the columns are insufficient for reporting addi- tional utility departments, supply the appropriate account titles, lines 1 to 19, and report the information in the blank space on page 122 or in a supplemental statement. GAS UTILITY OTHER UTILITY Previous Year Current Year Previous Year Page 115 Utah Form 1 Pages 200-201 Utah Power & Light Company State of Idaho SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION Line Item (a)No. UTILITY PLANT 2 In Service 3 Plant in Service (Classified) 4 Property Under Capital leases 5 Plant Purchased or Sold 6 Completed Construction not Classified 7 Experimental Plant Unclassified TOTAL (Enter Total of lines 3 thru 7) 9 leased to Others 10 Held for Future Use 11 Construction Work in Progress 12 Acquisition Adjustments 13 TOTAL Utility Plant (Enter Total of lines 8 thru 12 ) 14 Accum. Provo for Depr., Amort., & Dep!. 15 Net Utility Plant (Enter total of line 13 less 14)16 DETAil OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION 17 In Service: 18 Depreciation 19 Amort Depl. of Producing Nat. Gas Land and land Rights 20 Amort. of Underground Storage land and land Rights 21 Amort. of Other Utility Plant 22 TOTAL in Service (Enter Total of lines 18 thru 21) 23 Leased to Others 24 Depreciation 25 Amortization and Depletion 26 TOTAL Leased to Others (Enter Total of lines 24 and 25) 27 Held for Future Use 28 Depreciation 29 Amortization30 TOTAL Held for Future Use (Ent. Tot. of lines 28 and 29) 31 Abandonment of leases (Natural Gas) 32 Amort. of Plant Acquisition Adjustment 33 TOTAL Accumulated Provisions (Should agree with line 14 above)(Enter Total of lines 22, 26, 30, 31 , and 32) (1) Capitalized leases are not included in rate base; they are charged to operating expense. Page 200 Total (b) 613,441 ,846 613,441 ,846 101 817 13,834 164 056,573 631,434 400 268 325 281 363 109 119 Dec. 31 , 2002 Electric (c) 613,441 846 613,441 846 101 817 13,834 164 056,573 589 589,807 268 325 281 321 264 526 256,249 542 256,249,542 075 739 075 739 268,325,281 268,325 281 268,325,281 268,325,281 Utah Power & Light Company State of Idaho Gas (d) SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION (Continued) Steam HeatinJther (Specify)ther (Specify(e) (f) (g) Page 201 Dec. 31, 2002 Common (h) Line No. 0 13 0 15 0 22 0 26 0 30 Uta h F o r m 1 P a g a a 2 O 4 . 2D 5 Ut a h P o w a r & L l g h l C o m p a n y St a I B 0 1 I d a h o Ela c t r l c P l a n t I n S a r v l c a ( A c c o u n t . I D I , 1 0 2 , I D 3 , 1 0 6 ) De c . 3 1 , 2 0 0 2 Be g i n n i n g Ba l a n c e a t Un a Ac c o u n t Ba l a n c e Ad d i l i o n . Ra l l r e m a n t . Ad J u . ' m a n t . Tr s n . l a r s En d o f Y e a r Fa r c Un a No . (a ) (b ) (c ) (d ) (a ) (f) (g ) Ac c l No . 1. I N T A N G I B L E P L A N T (3 D I ) O r g . n l z a l l o n 60 0 , 52 6 60 0 , 52 6 (3 D 1 ) (3 0 2 ) F r s n c h l . a . . n d C o n a a n l a 69 2 , 24 9 52 0 , 17 5 (3 0 2 ) (3 D 3 ) M l a c a l l a n a o u a l n l . n g l b l a P I . n t 20 , 61 8 , 02 4 19 , 71 5 , 42 6 (3 D 3 ) TO T A L I n t a n g l b l a P l a n l ( E n l a r T o l a l oi l l n . . 2 , 3 , an d 4 ) 23 , 91 0 , 79 9 22 , 83 6 , 12 7 2. P R O D U C T I O N P L A N T A. S t a . m P r o d u c t i o n P l a n l (3 1 D ) L a n d a n d L a n d R l g h l a 78 3 , 48 0 04 4 , 36 6 (3 1 D ) (3 1 1 ) S l r u c l u r s a a n d I m p r o v a m a n l . 52 , 26 2 , 09 5 38 , 96 3 , 36 9 (3 1 1 ) (3 1 2 ) B o l l a r P l a n t E q u l p m a n l 14 4 04 3 , 81 0 11 2 , 92 8 , 09 5 (3 1 2 ) (3 1 3 ) E n g l n a . a n d E n g l n a D r l v a n G e n e r s l o r s (3 1 3 ) (3 1 4 ) T u r b o g e M r s l o r U n l l . 39 , 28 0 , 94 5 30 , 73 1 , 07 4 (3 1 4 ) (3 1 5 ) A c c a . . o r y E l e c t r l c E q u l p m e n l 23 , 02 8 , 94 9 17 , 60 4 , 30 2 (3 1 5 ) (3 1 6 ) M I . c . P o w e r P l a n t E q u l p m a n l 32 1 , 18 2 70 6 , 76 0 (3 1 6 ) TO T A L S t a a m P r o d u c t i o n P l a n t ( E n l a r T o l . 1 o t II n . . 9 t h r u 1 4 ) 26 7 , 72 0 , 46 1 20 6 , 97 7 , 96 6 B. N u c l e a r P r o d u c t i o n P I . n t (3 2 D ) L a n d a n d L . n d R i g h t . (3 2 D ) (3 2 1 ) S l r u c t u r e . . n d I m p r o v a m e n l . (3 2 1 ) (3 2 2 ) R a . c l o r P I . n l E q u l p m a n t (3 2 2 ) (3 2 3 ) T u r b o g a n a r s t o r U n l l . (3 2 3 ) (3 2 4 ) A c c e . . o r y E l e c l r l c E q u l p m a n l (3 2 4 ) (3 2 5 ) M I . c . P o w a r P I . n l E q u l p m a n l (3 2 5 ) TO T A L N u c l e a r P r o d u c t i o n P l a n l ( E n t e r T o t . 1 oi l l n . . 1 7 th r u 2 2 ) C. H y d r s u l l c P r o d u c t i o n P I . n t (3 3 D ) L a n d . n d L a n d R i g h I . 77 8 , 30 2 66 5 , 71 5 (3 3 D ) (3 3 1 ) S t r u c t u r e . a n d I m p r o v a m e n l . 42 5 , 79 9 59 6 , 81 1 (3 3 1 ) (3 3 2 ) R a . e r v o l r s , D a m . , a n d W . ' a r w . y a 15 7 , 12 2 39 4 , 44 0 (3 3 2 ) (3 3 3 ) W . l a r W h . . I . , T u r b i n e . , . n d O a n e r s l o r s 12 4 , 69 8 35 0 , 05 0 (3 3 3 ) (3 3 4 ) A c c e . . o r y E l e c l r l c E q u l p m e n l 55 7 98 7 30 3 , 13 6 (3 3 4 ) (3 3 5 ) M I . c . P o w e r P l a n t E q u l p m a n t 12 9 , 58 7 73 , 74 6 (3 3 5 ) (3 3 6 ) R o . d a , R a l l r o . d a , a n d B r l d g a . 43 5 , 69 6 32 6 , 68 1 (3 3 6 ) TO T A L H y d r s u l l c P r o d u c t i o n P I . n t ( E n l a r T o t e l 0 1 t i n s . 2 5 t h r u 3 1 ) 16 , 60 9 , 19 1 12 , 71 0 , 57 9 D. O t h e r P r o d u c t i o n P I . n t (3 4 D ) L a n d a n d L a n d R i g h t . 50 , 11 4 37 , 09 4 (3 4 D ) (3 4 1 ) S t r u c t u r s . . n d I m p r o v a m e n l . 67 8 , 21 9 56 6 , 08 4 (3 4 1 ) (3 4 2 ) F u a l H o l d e r s , P r o d u c l . e n d A c c e a a o r l a . 19 8 , 68 5 14 7 , 14 1 (3 4 2 ) (3 4 3 ) P r i m a M o v a r s 68 9 , 99 4 82 6 , 89 6 (3 4 3 ) (3 4 4 ) O e n e r s l o r s 91 7 , 96 8 92 7 , 78 2 (3 4 4 ) (3 4 5 ) A c c a . a o r y E l e c t r i c E q u l p m a n l 56 1 , 65 8 52 2 , 28 4 (3 4 5 ) (3 4 6 ) M I . c . P o w e r P l a n t E q u l p m e n l 34 , 23 4 25 , 36 3 (3 4 6 ) TO T A L O t h a r p r o d u c t i o n P I . n l ( E n l e r T o l . 1 0 1 l i n e . 3 4 I h r u 4 D ) 12 , 13 0 , 87 2 05 2 , 64 4 TO T A L P r o d u c t i o n P l a n l ( E n l e r T o l . 1 0 1 l i n e . 1 5 , 2 3 , 3 2 , . n d 4 1 ) 29 6 , 46 0 , 52 4 23 1 , 74 1 , 18 9 Pa g e 2 0 4 mo h P o w e r & L I g h t C o m p o n y St o t o o f I d o h o Ele c t r i c P l o n l I n S e r v l c o ( A c c o u n t e 1 0 1 , 10 2 , 1 0 3 , 1 0 6 ) Ll n o No . Ac c o u n l (e ) 3. T R A N S M I S S I O N P L A N T (3 5 0 ) L a n d o n d L a n d R l g h t o (3 5 2 ) S t ! \ l c t u r e o o n d I m p r o v e m e n t e (3 5 3 ) S t o t l o n E q u i p m e n t (3 5 4 ) T o w e r e o n d F l x t u r e o (3 5 5 ) P o l e o o n d F l x t u r e o (3 5 6 ) O v e r h e o d C o n d u c t o r o o n d D e v l c e o (3 5 7 ) U n d e r g r o u n d C o n d u i t (3 5 6 ) U n d e r g r o u n d C o n d u c t o r o e n d D e v l c e o (3 5 9 ) R o o d o o n d T r o U o TO T A L T r o n o m l o o l o n P l o n t ( E n t e r T o t o l o f U n . . 4 4 t h ! \ l 5 2 ) 4. D I S T R I B U T I O N P L A N T (3 6 0 ) L a n d o n d L a n d R l g h t o (3 6 1 ) S t ! \ l c l u r o o o n d I m p r o v e m e n t o (3 6 2 ) S i o t l o n E q u i p m e n t (3 6 3 ) S i o r o g e B o l l e r y E q u l p m o n t (3 6 4 ) P o l e o , T o w e r o , o n d F l x t u r o o (3 6 5 ) O v o r h e o d C o n d u c t o r o a n d D o v l c e a (3 6 6 ) U n d e r g r o u n d C o n d u i t (3 6 7 ) U n d o r g r o u n d C o n d u c t o r o a n d D e v l c e o (3 6 6 ) L i n e T r o n a ! o r m e r o (3 6 9 ) S e r v l c e o (3 7 0 ) M e t e r o 66 (3 7 1 ) I n o t o U o t l o n o o n C u o t o m e r P r e m l o e o 67 (3 7 2 ) L e . . e d P r o p e r t y o n C u o t o m e r P r e m l o e o (3 7 3 ) S t r e e l L i g h t i n g a n d S i g n o l S y o t e m o TO T A L D l o t r l b u t l o n P l a n l ( E n l e r T o t a l o f U n e o 5 5 I h ! \ l 8 9 ) 5. G E N E R A L P L A N T (3 6 9 ) L a n d o n d L a n d R l g h t o (3 9 0 ) S I ! \ I c l u r e o a n d I m p r o v e m e n t o (3 9 1 ) O l l l c e F u r n l l u r e o n d E q u i p m e n t (3 9 2 ) T r o n o p o r t a t l o n E q u i p m e n t 75 (3 9 3 ) S t o r e o E q u l p m o n t 76 (3 9 4 ) T o o l o , S h o p a n d G o r o g o E q u i p m e n t 17 (3 9 5 ) L a b o r o l o r y E q u i p m e n t 79 (3 9 6 ) P o w e r O p e r e l e d E q u l p m o n t 79 (3 9 7 ) C o m m u n i c a t i o n E q u l p m e n l 90 (3 9 9 ) M l o c e U o n B O u o E q u l p m o n t 91 SU B T O T A L ( E n t e r T o t a l o f U n e o 7 1 t h ! \ l 6 0 ) 82 (3 9 9 ) O t h e r T o n g l b l e P r o p e r t y TO T A L G e n e r e ' P l o n t ( E n t e r T o t o ' o r U n e o 6 1 a n d 9 2 ) TO T A L A c c o u n t 1 0 1 (1 0 1 . 1) C a p i t o l L e a o o o (1 0 2 ) E l o c t r t c P l o n t P u r c h o o e d (L e . . ) ( 1 0 2 ) E l e c l r t c P l o n t S o l d (1 0 3 ) E x p e r l m e n t o l P l o n t U n c l o . . l l l e d (1 0 6 ) P l o n t U n c l o . . l l l e d TO T A L E l e c t r i c P l o n l I n S e r v i c e Be g i n n i n g Ba l a n c e (b ) 18 7 , 29 9 34 4 , 81 8 49 , 82 0 , 63 5 19 , 63 4 57 4 28 , 35 2 , 83 1 31 , 72 9 , 83 5 13 0 , 01 7 20 4 , 65 8 57 0 , 45 1 14 0 , 97 5 , 11 8 14 9 , 29 4 71 6 , 07 7 17 , 08 2 , 45 2 53 2 , 94 8 27 , 67 0 , 07 8 17 2 , 24 3 17 , 42 8 , 16 2 48 , 03 4 06 4 13 , 83 1 , 95 2 10 , 75 4 , 85 9 15 0 , 03 4 87 3 47 9 , 10 7 18 5 , 00 6 , 14 3 76 4 , 55 2 15 , 20 5 , 41 6 08 3 , 08 8 36 6 , 86 6 55 9 , 89 2 36 1 , 54 7 45 0 , 66 0 55 6 , 30 4 11 , 83 2 , 44 4 30 7 , 75 5 49 , 48 8 , 52 4 17 , 10 5 , 39 6 66 , 59 3 , 92 0 71 2 , 94 6 , 50 4 16 , 45 2 71 2 , 96 2 , 95 6 Pa g e 2 0 5 Ad d l t l o n o (c ) De c . 3 1 , 2 0 0 2 Ba l a n c e a t Re t l r e m e n t o Ad J u o l m e n t o Tr e n o r o r o En d o f Y e a r Fe r e LI n e (d ) (e ) (g ) Ac c t No . 32 1 44 0 (3 5 0 ) 55 4 55 6 (3 5 2 ) 38 , 25 3 71 4 (3 5 3 ) 14 , 96 7 , 65 0 (3 5 4 ) 21 , 53 3 , 36 9 (3 5 5 ) 24 , 31 3 , 30 3 (3 5 6 ) 11 1 , 71 3 (3 5 7 ) 22 2 , 39 6 (3 5 6 ) 44 1 , 66 2 (3 5 9 ) 0 1 0 7 , 71 9 , 80 3 14 9 , 29 4 (3 8 0 ) 72 3 , 08 3 (3 8 1 ) 17 , 12 7 , 68 3 (3 5 2 ) (3 5 3 ) 43 , 67 3 , 11 9 (3 6 4 ) 28 , 22 2 , 35 9 (3 6 5 ) 24 9 , 51 9 (3 6 6 ) 17 , 89 1 10 1 (3 6 7 ) 49 , 78 2 , 93 4 (3 6 6 ) 14 , 93 8 , 13 0 (3 6 9 ) 13 , 41 3 , 71 7 (3 7 0 ) 15 4 , 33 6 (3 7 1 ) 87 3 (3 7 2 ) 47 4 , 78 8 (3 7 3 ) 0 1 9 2 80 4 , 93 6 70 9 , 59 7 (3 6 9 ) 14 , 50 6 , 36 1 (3 9 0 ) 71 5 , 59 6 (3 9 1 ) 03 5 , 24 9 (3 9 2 ) 56 9 , 69 9 (3 9 3 ) 00 1 , 97 8 (3 9 4 ) 30 2 , 64 7 (3 9 5 ) 08 6 , 36 0 (3 9 6 ) 11 , 07 0 , 46 6 (3 9 7 ) 26 7 , 63 1 (3 9 6 ) 47 , 26 5 , 58 3 11 , 07 4 , 20 8 (3 9 9 ) 58 , 33 9 , 79 1 0 6 1 3 , 44 1 , 84 6 (1 0 1 ) 0 ( 1 0 1 . (1 0 2 ) (1 0 2 ) (1 0 3 ) (1 0 6 ) 0 6 1 3 , 44 1 , 84 6 Utah Power & Light Company State of Idaho NON UTILITY PROPERTY (Account 121)Dec. 31, 2002 1. Give a brief description and state the location of non utility property included in Account 121, 2, Designate with an asterisk any property which is leased to another company, State name of lessee and whether lessee is an associated company, 3. Furnish details concerning sales, purchases, or transfers of Nonutility Property during the year, 4, List separately all property previously devoted to public service and give date of transfer to Account 121, Nonutility Property, 5, Minor items (5% of the Balance at the End of the Year for Account 121 or $100,000, whichever is less) may be grouped by (1) previously devoted to public service (line 43), or (2) other nonutility property (line 44). (a) Balance at Purchases,Balance at Beginning Sales,End of of Year Transfers, etc.Year (b)(c)(d) 556 556 11,553 553 13,742 742 10,007 007 Line No. Description and Location 1 1307 Lava Development 2 1312 Mink Development 3 1339 East River Substation Site 461 Soda HE Plant and Substation - Project 36 TOTAL Misc. Items Less Than $10,000 338 338 $58,196 $58 196 Page 221 Utah Form 1 Pages 227 Utah Power & Light Company State of Idaho Dec. 31 , 2002 MATERIALS AND SUPPLIES 1, For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable, In column (d), designate the departments which use the class of material. 2. Give an explanation of important inventory adjustments during year (on a supplemental page) showing general classes of material and supplies and the various accounts (operating expense, clearing accounts plant, etc.) affected - debited or credited. Show seperately debits or credits to stores expense-clearing, if applicable, Line No. Account (a) 1 Fuel Stock (Account 151) 2 Fuel Stock Expenses Undistributed (Account 152) 3 Residuals and Extracted Products (Account 153) 4 Plant Materials and Operating Supplies (Account 154) Assigned to - Construction (Estimated) Assigned to - Operations and Maintenance Production Plant (Estimated) Transmission Plant (Estimated) Distribution Plant (Estimated)10 Assigned to - Other11 TOTAL Account 154 (Enter Total of lines 5 thru 12 Merchandise (Account 155) 13 Other Materials and Supplies (Account 156) 14 Nuclear Materials Held for Sale (Account 157) (Not applicable to Gas Utilities) 15 Stores Expense Undistributed (Account 163) Total Materials and Supplies (per Balance Shee' Page 227 Balance Department or Beginning Balance Departments of Year End of Year Using Material (b)(c)(d) $3,929,529 $2,997,147 Electric 136,737 641,953 916,306 (410,086) 284,910 409 736 555,981 067,577 (270,260) 763,034 Electric Electric Electric Electric (17 139)Electric $8,197,300 $7,760,181 Pages 262-263 Utah Power & Light Company State of Idaho TAXES ACCRUED, PREPAID AND CHARGED DURING YEAR Dec. 31, 2002 1. Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not in- clude gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts. 2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes). Enter the amounts in both columns (d) and (e). The balancing of this page is not affected by the inclusion of these taxes. 3. Include in column (d) taxes charged during the year taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b) amounts credited to proportions of prepaid taxes chargeable to current year and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts. 4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can read- ily be ascertained. BALANCE AT BEGINNING OF YEAR Line No, Kind of Tax (a) Taxes Accrued (b) Federal Income Tax Other State Income Tax 10 Property Taxes 12 Governmrnt Charges & Levies 14 Payroll Taxes 16 Franchise Tax 18 Misc State & Local Taxes 20 sub-total 36 TOTAL Prepaid Taxes (c) Taxes Charged During Year (d) Adjustments (f) Paid During Year (e) (129,598) (17 610) 160,330 335 307 407 439 (68 290) 164 436 999 222 852 014 Page 262 Utah Power & Light Company State of Idaho TAXES ACCRUED, PREPAID AND CHARGED DURING YEAR (Continued) Dec, 31, 2002 5. If any tax (exclude Federal and state income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (a). 6. Enter all adjustments of the accrued and prepaid tax accounts in column (f) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses. 7. Do not include on this page entries with respect to de- ferred income taxes or taxes collected through payroll de- ductions or otherwise pending transmittal of such taxes to the taxing authority. 8. Enter accounts to which taxes charged were distributed in BALANCE AT END OF YEAR columns (i) thru (I). In column (i), report the amounts charged to Accounts 408.1 and 409.1 for Electric Dept. only. Group the amounts charged to 408., 409., 408.2 and 409.2 under other accounts in column (I). For taxes charged to other accounts or utility plant, show the number of the appropriate balance sheet account, plant account or subaccount. 9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax. (Taxes Accrued Account 236) (g) Prepaid Taxes (incl. in Acct, 165) (h) DISTRIBUTION OF TAXES CHARGED (Show utility dept, and acct. charged,Electric Adjustment toAccount Extrao. Items Ret, Earnings (408,409,1) (Account 409,3) (Account 439)(i) (j) (k) (129 598) (17,610) 160 330 335,307 407 439 (68,290) 164 436 999,222 852 014 (I) Page 263 Line No, Form 1 Pages 300-301 Utah Power & Light Company State of Idaho Dec. 31 , 2002 ELECTRIC OPERATING REVENUES (Account 400) 1, Report below operating revenues for each prescribed account, and manufactured gas revenues in total. 2, Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month, OPERATING REVENUES Amount for Line Title of Account Amount for Year Previous Year No.(a)(b)(c) Sales of Electricity (440) Residential Sales 674 727 35,753,973 (442) Commercial and Industrial Sales Small (or Commercial)20,611,018 21 ,584 645 Large (or Industrial)087,500 609,856 (444) Public Street and Highway Lighting 266 678 292,914 (445) Other Sales to Public Authorities (446) Sales to Railroads and Railways (448) Interdepartmental Sales TOTAL Sales to Ultimate Consumers 82,639,923 102 241,388 (447) Sales for Resale 461,850 121 870,505 TOTAL Sales of Electricity 125 101 773 224 111,893 (Less) (449.1) Provision for Rate Refunds TOTAL Revenue Net of Provision for Refunds 125,101,773 224,111 893 Other Operating Revenues (450) Forfeited Discounts 243,065 421 406 (451) Miscellaneous Service Revenues 59,015 121 823 (453) Sales of Water and Water Power (454) Rent from Electric Property 377,851 235 846 (455) Interdepartmental Rents (456) Other Electric Revenues 716 890 353,019 TOTAL Other Operating Revenues 396,821 132 094 TOTAL Electric Operating Revenues $130 498 594 $232 243,987 Page 300 Utah Power & Light Company State of Idaho Dec. 31, 2002 ELECTRIC OPERATING REVENUES (Account 400) (Continued) 4. Commercial and Industrial Sales, Account 442, may be classified according to the basis of classification (SI or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand, (See Account 442 of the Uniform System of Accounts, Explain ba~ classification on a footnote, 5, See page 108, for important changes During the Year; Le, new territory added and rate increases or decrea 6, For lines 2, 4, 5, and 6, see page 304 for amounts relating to unbilled revenue by accounts, 7. Include unmetered sales. Provide details of such sales in a footnote. MEGAWATT HOURS SOLD AVERAGE NUMBER OF CUSTOMERS Amount for Number for Amount for Year Previous Year Number for Year Previous Year Line (d)(e)(f) (g) No. 582 965 562 481 45,606 44,644 354,840 333,269 578 379 368 091 1 ,264,886 411 411 079 161 188 164 307 975 162,797 783 56,598 1 ,398 692 502 185 706,667 664 982 57,787 56,604 706 667 664,982 787 56,604 Page 301 Utah Power & Light Company State of Idaho ELECTRIC OPERATION AND MAINTENANCE EXPENSES Account (1) POWER PRODUCTION EXPENSES A, Steam Power Generation 3 Operation 4 (500) Operation Supervision and Engineering 5 (501) Fuel 6 (502) Steam Expenses 7 (503) Steam from Other Sources 8 (Less) (504) Steam Transferred-Cr. 9 (505) Electric Expenses 10 (506) Miscellaneous Steam Power Expenses 11 (507) Rents12 TOTAL Operation 13 Maintenance 14 (510) Maintenance Supervision and Engineering 15 (511) Maintenance of Structures 16 (512) Maintenance of Boiler Plant 17 (513) Maintenance of Electric Plant 18 (514) Maintenance of Miscellaneous Steam Plant19 TOTAL Maintenance20 TOTAL Power Production Expenses-Steam Plant21 B. Nuclear Power Generation 22 Operation 23 (517) Operation Supervision and Engineering 24 (518) Fuel 25 (519) Coolants and Water 26 (520) Steam Expenses 27 (521) Steam from Other Sources 28 (less) (522) Steam Transferred-Cr. 29 (523) Electric Expenses 30 (524) Miscellaneous Nuclear Power Expenses 31 (525) Rents32 TOTAL Operation 33 Maintenance 34 (528) Maintenance Supervision and Engineering 35 (529) Maintenance of Structures 36 (530) Maintenance of Reactor Plant Equipment 37 (531) Maintenance of Electric Plant 38 (532) Maintenance of Miscellaneous Nuclear Plant39 TOTAL Maintenance40 TOTAL Power Production Expenses-Nuclear Power41 C. Hydraulic Power Generation 42 Operation 43 (535) Operation Supervision and Engineering 44 (536) Water for Power 45 (537) Hydraulic Expenses 46 (538) Electric Expenses 47 (539) Miscellaneous Hydraulic Power Generation Expenses 48 (540) Rents49 TOTAL Operation Page 320 Dec. 31, 2002 Amount for Current Year Amount for Previous Yr 302 890 750,161 20,969,248 30,914,002 966,173 492 665 176,075 536,143 153,837 119,407 336,048 267,950 33,751 26,484 24,938,022 38,106 812 274 555 144,908 891,864 667,500 735,386 450,041 179,234 223,097 407,023 215,170 488,062 700,716 31,426,084 45,807,528 (104 823)318,072 495 85,028 28,218 550,803 354,861 561 6,407 533,064 707,558 Account ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued) 50 C. Hydraulic Power Generation (Continued) 51 Maintenance 52 (541) Maintenance Supervision and Engineering 53 (542) Maintenance of Structures 54 (543) Maintenance of Reservoirs, Dams, and Waterways 55 (544) Maintenance of Electric Plant 56 (545) Maintenance of Miscellaneous Hydraulic Plant57 TOTAL Maintenance58 TOTAL Power Production Expenses-Hydraulic Power59 D. Other Power Generation 60 Operation 61 (546) Operation Supervision and Engineering 62 (547) Fuel 63 (548) Generation Expenses 64 (549) Miscellaneous Other Power Generation Expenses 65 (550) Rents66 TOTAL Operation 67 Maintenance 68 (551) Maintenance Supervision and Engineering 69 (552) Maintenance of Structures 70 (553) Maintenance of Generating and Electric Plant 71 (554) Maintenance of Misc. Other Power Generation Plant72 TOTAL Maintenance73 TOTAL Power Production Expenses-Other Power74 E, Other Power Supply Expenses 75 (555) Purchased Power 76 (556) System Control and Load Dispatching 77 (557) Other Expenses78 TOTAL Other Power Supply Expenses79 TOTAL Power Production Expenses80 2, TRANSMISSION EXPENSES 81 Operation 82 (560) Operation Supervision and Engineering 83 (561) Load Dispatching 84 (562) Station Expenses 85 (563) Overhead Line Expenses 86 (564) Underground Line Expenses 87 (565) Transmission of Electricity by Others 88 (566) Miscellaneous Transmission Expenses 89 (567) Rents90 TOTAL Operation 91 Maintenance 92 (568) Maintenance Supervision and Engineering 93 (569) Maintenance of Structures 94 (570) Maintenance of Station Equipment 95 (571) Maintenance of Overhead Lines 96 (572) Maintenance of Underground Lines 97 (573) Maintenance of Miscellaneous Transmission Plant98 TOTAL Maintenance99 TOTAL Transmission Expenses100 3, DISTRIBUTION EXPENSES 101 Operation 102 (580) Operation Supervision and Engineering 103 (581) Load Dispatching Page 321 Amount for Current Year Dec. 31, 2002 Amount for Previous Year 230 071 55,114 26,642 521 73,462 69,647 79,352 956 73,276 297,468 256,803 830,532 964,361 792 651 006,350 684,572 341 931 67,405 77,209 219 20,657 627,847 446,147 264 129 496 889 629,736 446 147 18,617 202 114 099,381 150 27,638 463,828 042,799) 20,086,180 110,084,220 55,972,532 160,302,256 158,700 283,054 157 300 216,588 958 69,517 129,284 125,073 386 755 674,382 575 688 33,136 (11,010) 989,708 445,292 175 298 170 27,268 323,564 447,713 291,431 590,328 165 790 618,505 067,400 608 213 512 692 189,803 287,825 269,356 262,707 ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued) Account 104 3. DISTRIBUTION EXPENSES (Continued) 105 (582) Station Expenses 106 (583) Overhead Line Expenses 107 (584) Underground Line Expenses 108 (585) Street Lighting and Signal System Expenses 109 (586) Meter Expenses 110 (587) Customer Installations Expenses 111 (588) Miscellaneous Distribution Expenses 112 (589) Rents113 TOTAL Operation 114 Maintenance 115 (590) Maintenance Supervision and Engineering 116 (591) Maintenance of Structures 117 (592) Maintenance of Station Equipment 118 (593) Maintenance of Overhead Lines 119 (594) Maintenance of Underground Lines 120 (595) Maintenance of Line Transformers 121 (596) Maintenance of Street Lighting and Signal Systems 122 (597) Maintenance of Meters 123 (598) Maintenance of Miscellaneous Distribution Plant124 TOTAL Maintenance125 TOTAL Distribution Expenses126 4. CUSTOMER ACCOUNTS EXPENSES 127 Operation 128 (901) Supervision 129 (902) Meter Reading Expenses 130 (903) Customer Records and Collection Expenses 131 (904) Uncollectible Accounts 132 (905) Miscellaneous Customer Accounts Expenses133 TOTAL Customer Accounts Expenses134 5. CUSTOMER SERVICE & INFORMATIONAL EXPENSES 135 Operation 136 (907) Supervision 137 (908) Customer Assistance Expenses 138 (909) Informational and Instructional Expenses 139 (910) Misc. Customer Service and Informational Expenses140 TOTAL Cust. Service and Informational Expenses141 6. SALES EXPENSES 142 Operation 143 (911) Supervision 144 (912) Demonstrating and Selling Expenses 145 (913) Advertising Expenses 146 (916) Miscellaneous Sales Expenses147 TOTAL Sales Expenses148 7. ADMINISTRATIVE AND GENERAL EXPENSES 149. Operation 150 (920) Administrative and General Salaries 151 (921) Office Supplies and Expenses 152 (Less) (922) Administrative expenses Transferred-Cr. 153 (923) Outside Services Employed 154 (924) Property Insurance 155 (925) Injuries and Damages 156 (926) Employee Pensions and Benefits Page 322 Amount for Amount for Current Year Previous Year 159,753 17,649 712,127 305,513 794 310,265 30,539 257 487 (1,120,192)349,063) 063 23,904 559,226 580,561 (192)520 291,036 516,574 324 199 513,700 443,981 354,834 55,035 12,008 140,271 104 130 566,262 (369,560) 820,592 132,206 379,818 712 767 305,058 343,935 166,457 473 823 338,191 214,025 762,794 659,781 46,339 918 618,839 746,482 959,749 926,319 23,270 599 088 185 007 107 970,103 (938) 19,730 29,733 18,847 29,733 991,146 522,347 191 505 384,495 790,085)(1,830,803) 226,753 073,193 897 279 384 362 032 762 717,215 (137,718) ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued) Account 157 7. ADMINISTRATIVE AND GENERAL EXPENSES 158 (927) Franchise Requirements 159 (928) Regulatory Commission Expenses 160 (less) (929) Duplicate Charges-Cr. 161 (930,1) General Advertising Expenses 162 (930.2) Miscellaneous General Expenses 163 (931) Rents164 TOTAL Operation 165 Maintenance 166 (935) Maintenance of General Plant167 TOTAL Administrative and General Expenses168 TOTAL Electric Operation and Maintenance Expenses Page 323 Amount for Amount for Current Year Previous Year 419,340 491 ,527 (288,336)(171,512) 88,692 226,173 162,260 117,677 62,526 178,694 11,993,875 10,955,650 979,697 123,122 973,572 11,078,772 82,578,928 187,352 805 Utah Form 1 Pages 336 Utah Power & Light Company State of Idaho Dec. 31, 2002 DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Accounts 403, 404, 405) (Except amortization of acquisition adjustments) 1. Report in Section A for the year the amounts for. (a) Depreciation Expense (Account 403); (b) Amortiza- tion of Limited-Term Electric Plant (Account 404); and (c) Amortization of Other Electric Plant (Account 405). 2. Report in section B the rates used to compute amor- tization charges for electric plant (Accounts 404 and 405). State the basis used to compute the charges and whether any changes have been made in the basis or rates used from the preceding report year. 3. Report all available information called for in section C every fifth year beginning with report year 1971, report- ing annually only changes to columns (c) through (g) from the complete report of the preceding year. Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classifica- tion, as appropriate, to which a rate is applied. Identify at the bottom of section C the type of plant included in any subaccounts used. In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional classifications and showing a composite total. Indicate at the bottom of section C the manner in which column (b) balances are obtained. If average balances, state the method of averaging used. For columns (c), (d), and (e) report available in- formation for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service lives, show in column (f) the type mortality curve selected as most appropriate for the account and in column (g), available, the weighted average remaining Ine of surviving plant, If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis. 4. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related. A. Summary of Depreciation and Amortization Charges Depreciation Amortization of Amortization of Line Functional Classification Expense Limited-Term Electric Other Electric Total Line No.(Account 403)Plant (Acct. 404)Plant (Acel. 405)No, (a)(b)(c)(d)(e) 1 Intangible Plant 093,279 093,279 2 Steam Production Plant 812,575 812,575 3 Nuclear Production Plant 4 Hydraulic Production - Conventional 368,183 243 369,426 5 Hydraulic Production - Pumped Storage 6 Other Production Plant 271,717 271,717 7 Transmission Plant 110,124 110,124 8 Distribution Plant 833,901 833,901 9 General Plant 298,188 47,228 345,416 10 Common Plant-Electric TOTAL $17,694,687 $2,141,750 $19,836,437 Page 336 PACIFICORP SOURCE AND DISPOSITION OF ENERGY MEGAWATT-HOURS 2002 SOURCES OF ENERGY Generation: Steam Nuclear Hydro-Conventional Hydro-Pumped Storage Other Less Energy for Pumping Net Generation IDAHO 166,466 (5,012) 161,454 Purchases 041,904 Power Exchanges: Recei ved Delivered Net Exchanges 273,615 (1,169,440) 104,175 Trans. for Others (Wheeling): Received Delivered 185,096 185,096) Net Transmission Trans. by Others Energy rec. from Sub-Total Energy del. to other states Total Sources of Energy for Others - Lossesother states 052,747 360,280 484 038) 876,242 DISPOSITION OF ENERGY Sales to Ultimate Consumers Requirement Sales for Resale Non-Requirement Sales for Resale Energy furnished without charge Energy used by the Company Total energy losses Total Disposition of Energy 225,369 334,861 736 314,276 876,242 05/09/03 S: \REGULATN\ER\FERC\02StFERC\ (Sdis02 .xls) A Page 401