interoffice memorandum engineering & system … memorandum engineering & system operations...

Interoffice Memorandum Engineering & System Operations

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DATE: June 30, 2004 TO: Officers, Directors, and Project Team FROM: David James, x4185 MSC 24 SUBJECT: 230 kV Project Update – Status Report June 2004 Attached is a report that highlights the 230 kV upgrade projects. The report includes a high-level progress summary along with financial information, milestone dates, and a risk profile. Since feasibility estimates were derived in March of 2002, this collection of transmission projects has evolved into a comprehensive package and now includes the control infrastructure necessary to operate these interconnected systems. A detailed description of the “cost-evolution” of the project is included in this report. In the late 1950’s and early 1960’s, the Company constructed the majority of our 230 kV transmission system to deliver energy from the recently constructed Noxon Rapids and Cabinet Gorge dams. Since that time, demand for electricity has quadrupled on Avista’s system without corresponding capacity increases in the 230 kV transmission system. Simply put, our transmission system has reached its capacity to serve our customers and to support the interconnected NW system. Through your efforts, we are constructing facilities that serve the needs of our customers, support economic development initiatives, and increase reliability on the bulk transmission grid. If you have any questions or comments about the material, please call me on extension 4185 or stop by my office. Thanks, David James

Avista 230 kV Upgrade ProjectsStatus Report – June 2004

Bell (BPA)

Cabinet Gorge

Noxon

Benewah

Pinecreek

Westside

Rathdrum

Shawnee

Moscow 230

Hatwai (BPA)

Lolo

N. Lewiston

Beacon

SubstationTransmission Line

Avista's 230 kV Facilities2002 Baseline

2003-2006 West of Hatwai & Load Service 230 kV System Upgrade Projects

Executive Summary

In August of 2002, Avista and the Bonneville Power Administration agreed on a plan to strengthen the region’s transmission system. Generally known as “West of Hatwai”, the combined BPA and Avista plan is expected to cost two hundred and fifty million dollars with all capital projects complete before 2007. Since the signing of that agreement, Avista has reconstructed the Beacon-Rathdrum 230 kV line and BPA has made steady and measured progress on the Grand Coulee-Bell 500 kV line. This report will document the progress to date, identify revisions to original scope, highlight the project risks, and provide other baseline information. Though all of the current Avista 230 kV projects are usually referenced under the umbrella of “West of Hatwai”, this is a common misconception. The Avista transmission plan through 2006 includes the West of Hatwai agreement with BPA but also investments necessary for continued load service to our customers and to meet regional & national reliability standards. However, in order to separately track the cost and budget of these projects, West of Hatwai has been separated from load service and compliance initiatives.

Tower Ready for Conductor on the Beacon to Rathdrum 230 kV Transmission Line

Following the successful effort to reconstruct the Pinecreek and Rathdrum Substations, work is underway at Dry Creek and Boulder Substations. Below is a brief synopsis of current construction efforts.

• Dry Creek – G&P crews are constructing a 250 MVA / 200Mvar substation in southeast Clarkston, WA. This substation will allow area transmission lines to form a “ring” around the L/C Valley and significantly increase both transmission capacity and reliability. Construction is 33% complete. Energization of the 230 kV bus and transmission lines is scheduled for December of 2004. The 200 Mvar capacitor bank will follow in April of 2005. Current cost estimate for Dry Creek and transmission upgrades is $11.8M

• Boulder – In May 2004, site grading was completed for the 500 MVA substation. G&P mechanic crews are now mobilizing to begin work on concrete foundations for steel supports and equipment. Energization of the first of two 230/115 kV autotransformers is scheduled for May of 2005. The cost estimate for Boulder and transmission lines is $14.2M

• “Southern Ring” – Wilson Construction has begun adding fiber optic cable on the 11-mile transmission line between Dry Creek and Lolo. This is the first project of a two-year effort to install fiber optic cables on transmission lines in the L/C Valley. The fiber optic connection between Dry Creek and Lolo will be complete by July 31, 2004. The expected cost to complete the thirty-five mile fiber ring is $1.2M.

Cost Projections In August of 2002, feasibility estimates were developed for the 230 kV Upgrade Project at a forecasted cost of $87.6M. The June 2004 cost projection of $105.4M is a compilation of life-to-date costs (B-R), refined engineering estimates (e.g. Boulder and Dry Creek) and additional budget block estimates (fiber optic & RAS). A detailed explanation of the variances between August 2002 and the present forecast is included in the financial performance section. The primary variances are:

• Remedial Action Scheme. $1.7M. Not included in the August 2002 forecast. The Clark Fork RAS is specified in the WoH agreement and will be used to control generation at Noxon & Cabinet for planned and contingency outages on the transmission system. Since Avista has never developed a RAS scheme, the cost estimate for design, material, and labor was unknown until October 2002.

• Fiber Optic & Digital Microwave $6.1M. Not included in the August 2002 forecast. Control and communication systems for RAS and protective relays require redundant, or “ringed”, high speed systems. Avista has chosen to install fiber optic cable on transmission lines to meet this WECC/NERC requirement.

• Beacon-Rathdrum $3.4M. Actual cost to construct. Winter construction on the transmission line ($1M Wilson contract) coupled with increased material costs ($1M steel & aluminum) during the Iraq war drive actual costs above the August 2002 estimate.

• Boulder Substation $3.1M. Increase in Scope. In April of 2003, Avista announces plans to construct a new substation near Boulder Park instead of expanding Otis Orchards. This decision is prompted by both community support of the Boulder site and Avista’s need for three 230 kV lines into the substation instead of the original two lines.

• Lolo Substation $2.0M. Increase in Scope. In August of 2002, the project scope for Lolo included upgrading protective relays and replacing three power circuit breakers to match transmission line capacities. Subsequent engineering analysis shows that the existing busswork at Lolo is insufficient to withstand the force of certain types of 230 kV transmission faults. Replacing the pipe bus and associated supports significantly increases the scope of this project.

The chart below illustrates the cost variances between the feasability estimate compiled in August 2002 and the current forecast.

Aug 02 - Jun 04 Cost Projections

87.6

1.76.1

3.43.1

2 1.5

80

90

100

110

Aug 02 RAS Fiber B-R Otis Lolo Jun 04

$ M

Aug 02Base

$87.6M

June 04Update

$105.4M

Captial Budget In 2003, the Beacon-Rathdrum project entered the construction phase and accounted for nearly 70% of the $21 million dollars spent in 2003. In addition, $2.2 million dollars were spent to complete the reconstruction at Pinecreek substation and another $2.1 million dollars spent on power circuit breakers and the Dry Creek autotransformer. The chart below compares the actual spend versus budget for all of the 230 kV projects for 2003 and through May of 2004. One reason for the variance in 2003 was the effort to capture material and associated labor costs in 2003 to better align with expectations for the overall capital budget. In 2004, financials through May indicate that the 230 kV projects are $470k under-spent which is 6.3% of YTD budget. In 2003, the total T&D electric specific budget was $29.2M with an actual spend of $33.5M.

230 kV Upgrade Project, Budget to Actual

-- -

$22,045

$16,776

$42,063

$16,857

-

6,947

21,040

7,418

-

5,000

10,000

15,000

20,000

25,000

30,000

35,000

40,000

45,000

2003 2004 2005 2006

$000

's

Budget Actual YTD Budget YTD

“Round the Wheel” On June 8, 2004, project team members convened to brainstorm on ideas that might reduce cost or increase efficiencies for the project. “Rounding the Wheel” is a process to reshape and rethink basic assumptions, project requirements, and to challenge traditional approaches to design and constrution of transmission facilities. Before the end of July 2004, the team will evaluate the feasability of and the cost savings associated with these concepts. A recommendation is forthcoming. Project Risk In January of 2004, Avista announced the line route for the Benewah-Shawnee 230 kV line. Similar to the earlier announcement to construct Boulder substation, the final line route was shaped by public input from meetings held in October 2003 at Latah, WA. By rebuilding forty-five miles of existing 115 kV lines Avista reduces new corridor development to fifteen miles and minimizes the “risk” associated with acquiring land rights. However, acquiring easement rights for any transmission line is a significant undertaking and is detailed in the “risk profile” portion of this report. Along with Palouse 230, risk probability and outcomes have been identified for the significant projects and contingency plans have been or are being developed to account for project risk.

Major Milestones The Beacon-Rathdrum 230 kV line was energized on March 29, 2004 two days in advance of the milestone date of 3/31/04 established in the fall of 2002. Incredible timing! Other projects like the effort to construct Dry Creek Substation are well underway while others such as Boulder Substation and Palouse 230 are just getting started or in a pre-construction phase. Energization milestone dates for the most significant projects are shown below:

Beacon-Rathdrum Ground Breaking

June 2004

West of Hatwai Project “Kick Off”

April 2004

2003 2004

Pinecreek Substation 230 kV Bus & Trans Lines

Nov 2003

Cabinet Substation Upgrade R-322 Relays

Oct 2004

Dry Creek Substation 230 kV Bus & Tran Lines

Dec 2004

2005

Dry Creek-Lolo Install Fiber Optic

July 2004

Beacon-Rathdrum 2000 MVA Trans Line

Mar 2004

2005 2006

Dry C tion 200 Mvar Cap Bank

reek Substa

April 2005

Dry tion 2 r

Creek Substa50 MVA Xfm

May 2006

Boulder Substation250 MVA Xfmr #2

Feb 2006

Boul tion250

der Substa MVA Xfmr #1 May 2005

Benewah Sub 230 kV Bus & Tran Lines

April 2006

Bene tion200 Mvar Cap Ban

wah Substak

Oct 2006

2007

Hatwai-Lolo Upgrade to 800 MVA

May 2005

Beacon-Bell #4 Upgrade to 800 MVA

Dec 2005

Benewah-Shawnee1000 MVA Tran Line

Nov 2006

Hatwai-N Lew Upgrade to 800 MVA

Jan 2006

2003-2006 230 kV Upgrade Project Milestone Dates and Project Costs

June 2004

Bell (BPA)

Cabinet Gorge

Noxon

Benewah

Pinecreek

Westside

Shawnee

Moscow 230

Hatwai (BPA)

Lolo

N. Lewiston

BeaconBoulder


Avista's 230 kV Facilities

Dry Creek

1

Beacon-Rathdrum 230 (2000 MW), $18.5M25 mile Beacon-Rathdrum 230 kV Line, Mar 2004 Rathdrum Sub, Reconstruct to DB/DB, Mar/Apr 2004Beacon Relay Upgrade, Feb 2004Cabinet Relay Upgrade, Sep 2004Bea-Ben-Rath 230 Line Energized Mar 31, 2004

Beacon-Bell 230 (1600 MW), $2.4MBell #4 Reconductor to 800 MW, Dec 2005Bell #5 Reconductor to 800 MW, Dec 2006Upgrade Relay equipment at Beaconconcurrent with line construction

Spokane Valley Reinforcement (500 MW), $14.2MBoulder Substation, Energize 230/115 Auto #1, May 2005Integrate 3-230 and 5-115 kV transmission lines, May 2005Integrate 2-115 kV lines, Dec 2005Complete Construction, Feb 2006

Palouse Reinforcement (1000 MW), $33.3MBenewah Substation, Reconstruct to DB/DB, Apr 2006Benewah 230 kV Capacitor Bank, Oct 2006Shawnee and Moscow 230, Upgrade Relays, Oct 200660 mile Benewah-Shawnee 230 kV Line, Nov 2006

Dry Creek (250 MW / 200 Mvar), $11.8MLolo 230 kV Substation, R-347 to Dry Creek, Nov 2004Dry Creek 230 kV DB/DB Substation, Dec 2004N. Lewiston Relay Upgrade, Dec 2004Dry Creek 230 kV Capacitor Bank, April 2005Lolo 230 kV Substation, DB/DB to Hatwai only, May 2005Hatwai-Lolo Reconductor to 800 MW, May 2005Hatwai-N. Lewiston Reconductor to 800 MW, Jan 2006

Pinecreek Substation, $5.7MReconstruct 230 kV SubstationSubstation Complete November 2003

Other Project CostsER 256 Remedial Action Scheme (RAS) $1.7MER 283 Fiber Optic & Dig. Microwave $6.1MER 6 230/115 kV Auto Transformers $4.3M ER 7 230 & 115 kV Pwr Ckt Breakers $5.4MTotal WoH Phase 1 & Load Service/ComplianceThrough 2006 ------------------------------ $105.4MCosting source: 2004 Mid Yr Budget Update

Project sites shown with blue color highlight. Avista's 115 kV transmission lines are not shown

Rathdrum

Project Specific Update

Beacon-Rathdrum The Beacon-Rathdrum transmission line was energized on March 29, 2004 after being out of service since September 15, 2003. Over one hundred and eighty tubular steel structures were installed along with one hundred and fifty linear miles of conductor and static wire during seven months of construction. At Rathdrum, Avista G&P crews constructed the company’s first, fully redundant 230 kV substation using the most advanced Schweitzer relays together with gas circuit breakers and digital communication systems. A truly awesome achievement! Special thanks to Ken Sweigart and Terry Dudley for shepherding not only the engineering design but for also managing most aspects of the project. Special thanks also to Tom Barker for managing the line construction contract with Wilson Construction and to Tim Carlberg for filling Tom’ shoes upon his retirement in February. The project timeline and financial totals are shown below:

2005

June 2004

Foundation Installation, Tri-State Drillers

Jun - Oct 2003

2003 2004

230 kV Line Construction

Sep 15 – Apr 26, 2004

Energize “South”230 kV Circuit March 29, 2004

Complete Rathdrum Substation July 2004

G&P Mech Crews

Mar - Jun 2003

Energize “North” 230 kV Circuit April 26, 2004

Cabinet R-322 Relay Upgrade October 8, 2004

G&P Elec Crews

June 03- Jul 04

ER 255 Beacon-RathdrumActual Spend $k's

$18,495

$17,717

$14,918

Expected Total

Life-to-Date

Trans Line Only

Beacon-Rathdrum Photo Gallery

SF

Wilson Construction Installing Steel Tower

View o

6 Gas Circuit Breaker @ Rathdrum

Ready to "Pour Mud" (Tower Foundation)

f South 230 kV Bus @ Rathdrum

Ken Sweigart with Foundation Casing

Dry Creek Substation support’s mechanic and electric crews are working hard at Dry Creek to energize the substation before the end of 2004. Steve Wolfe and the mechanic crew have finished most of the station’s foundation supports, have erected steel structures, and now turn their attention to installing the panel house. Dan Weiler and the electricians have installed the station’s bus support insulators, disconnect switches, and aluminum pipe bus and will begin installing gas circuit breakers. In addition to the work at the substation, Avista plans to install thirty-five miles of fiber optic cable to form a control ring around the Lewiston-Clarkston Valley and to upgrade the thermal capacity on two of four area transmission lines. On June 6, 2004, Wilson Construction began installing fiber optic cable in the Lewiston-Clarkston area. The project timeline and financial totals are shown below: G&P

Mech Crews Dec 03 – June 04

2004

Fiber Optic on DC-Lolo Line

June 1 – July 31, 2004

Energize 230 kV Bus

December 2004

Complete Grading November 2003

Energize 200 MVAR Capacitor Bank

April 2004

2005

G&P Elec Crews

Feb 04 – Apr 05

Reconductor Hatwai-N Lew 230 Line

Sep 15 – Jan 15, 2006

2006

Fiber Optic on DC-N Lew Line Jan 1 – Feb 28, 2005

Reconductor Hatwai-Lolo 230 Line

Mar 1 – May 31, 2005 June 2004

ER 271 Dry Creek

$3,348

$2,826

$11,809Expected Total

Life-to-DateBudget

Life-to-Date Actual

Dry Creek Photo Gallery

"Swaging" Pipe Bus Fittings Moving Foundation Forms

View NE Dry Creek, April 2004 Foundation Ready to Pour

Moving Transformer to Lewiston, August 2003

Boulder Substation Site grading was complete in May of 2004 making way for Substation Support mechanical crews to begin work on concrete foundations and steel supports. In August, the first of two 230/115 kV autotransformers is scheduled to arrive at Boulder and is slated for energization in May of 2005. Electric crews will begin work in July to install equipment, wiring, and relay systems to energize the transformer and three 230 kV transmission lines. When fully complete in 2006, the station will add 500 MVA of 230/115 kV transformation to serve the growing demand for electricity in the Spokane Valley. The project timeline and financial totals are shown below:

June 2004 G&P

Mech Crews Jun 03 – Dec 04

2004


Jan – May 2005

Energize 230/115 Auto Xfmr #1

May 2005

Complete Grading May 2004


Jun - Dec 2005

Energize 230/115 Autotransformer #2

Jan 2006

2005

2006

G&P Electric Crews

Jul 04 – Jan 06

ER 948 Boulder Substation

$1,271

$1,099

$14,150Expected Total

Life-to-DateBudget

Life-to-Date Actual

Finished Site Grading at Boulder, May 2004

Palouse 230 In January of 2004, Avista announced the line route to connect the Benewah and Shawnee Substations. This announcement followed nine months of route study analysis, extensive public outreach, and a final determination by the project team. The chosen route minimizes new corridor development, avoids town sites, schools, airfields, houses, while balancing economic and other factors. Engineering, survey, permitting, and construction access planning are well underway with a construction start slated for May of 2005. In addition to the transmission line, Benewah 230 kV substation will be reconstructed as a double breaker/double bus substation (e.g. Rathdrum). The fifty-year old substation must be upgraded to meet transmission line capacities and regional reliability standards. In total, the expected investment for Palouse 230 is $33.3M with a life-to-date actual spend of $664k, or 2.0% of the overall budget. The project timeline is shown below:

230 kV Line Route Announcement

Jan 04

2004

R/W Acquisition Sep 04 – Sep 05

Transmission Line Construction

May 05- Nov 2006

Benewah Sub Grading Oct 2004

Energize 230 kV Capacitor Bank

October 2006

G&P Elec Crews

Jun 05 – Oct 06

2005

Energize New 230 kV Bus April 2006

2006 2007

Energize Benewah-Shawnee Line

November 2006

June 2004

Proposed Transmission Corridor near Spokane/Whitman County Line

Fiber Optic / Telecom Avista plans to install over 180 miles of fiber optic cable during the 230 kV upgrade project. This cable will be used for line protection and to support the Noxon and Dry Creek remedial action schemes. Traditionally, Avista has used power line carrier or microwave systems as the control path between terminal relay systems. Today, regional reliability criteria requires that control systems be “dual redundant and on diverse routing” for stability-limited transmission systems. Rather than develop redundant point-to-point systems (e.g. PLC plus microwave), Avista will form fiber optic “rings” to meet the NERC/WECC requirement for redundant systems. Several transmission lines will support either ADSS (all-dielectric self supporting) or OPGW (optical ground wire) cable. The transmission line designations and construction schedules are shown below:

2007

Benewah-Shawnee Dec 2006 Beacon-Rathdrum

April 2004 Dry Creek-Lolo

July 2004 Hatwai-Lolo

May 2005

Hatwai-N Lewiston

January 2006

Dry Creek- N Lewiston

February 2005

2005 2006

Boulder-BenewahOctober 2005

2004

Noxon-PinecreekOctober 2006

June 2004

2003-2006 230 kV Upgrade ProjectFiber Optic Control System

Bell (BPA)

Cabinet Gorge

Noxon

Benewah

Pinecreekvia Kellogg Pkand Kellogg Office

WestsideRathdrum

Shawnee

Moscow 230

Hatwai (BPA)

Lolo

N. Lewiston

BeaconBoulder

Avista HQ

SubstationTransmission LineFiber Optic CableDigital Microwave


Dry Creek

Mica, Idaho

2004 Beacon-RathdrumInstall 25 mi OPGW

(Budgeted w/ Xsmn Line ER 0255)

2006 Noxon-PinecreekInstall 29 mi OPGW and

14 mi ADSS $1030k

2004-05 Install Digital Radioat Mica Peak, Idaho plus

receiving equipment at Benewah, Kellogg office, and Pinecreek $730k

This installation completes the northern ring

2006 Benewah-ShawneeInstall 60 mi OPGW

$1140k

2004-2005 L/C 230 RingInstall 30 mi ADSS and

5 mi OPGW $1233k

2005 Boulder-BenewahInstall 26 mi ADSS

$1040k

June 2004

Feasibility cost estimates for the engineering, procurement, and installation of Fiber Optic cable on 230 kV transmission. Does not include associated costs such as transmission make-ready, permitting, real-estate, and contingency factors.

BPA Leased Fiber

Other Costs:RAS and EE $927k

Total Telecom $6.1M

2003-2006 230 kV Upgrade Project Planned Transmission Line Outages

June 2004

Bell (BPA)

Cabinet Gorge

Noxon

Benewah

Pinecreek

Westside

Rathdrum

Shawnee

Moscow 230

Lolo

N. Lewiston



Dry Creek

Beacon-Rathdrum 230 kV LineReconstruct 25 miles to Double CktDaily Outages June 1-Sep 15, 2003Permanent Outage Sep 15, 2003 - Mar 31, 2004Wilson Construction Complete Mar 31, 2004

Beacon-Bell #4 & #5 230 kV LinesReconductor w/ ACSS (6 miles each)#4 OOS Aug 19 - Dec 8, 2005#5 OOS Aug 19 - Dec 8, 2006Contract Labor

Westside 230 kV TapXing of 500 kV Bell-Coulee linerequires lowering of Avista

230 kV tap. OOS Apr 5- 16, 2004 BPA Construction

Complete Apr 9, 2004

Boulder 230 kV SubstationIntegrate (3) 230 kV and (5) 115 kV Lines plus Tie to Boulder Park Gen StaPhase 1 230 kV (Integrate 230 kV lines and energization 230/115 Xfmr #1)

Beacon-Benewah-Rathdrum 3-Terminal 230 kV OOS Jan 1 – May 31, 2005Beacon-Otis #2 (Irvin-Otis) & Otis-Rathdrum (Moab-Otis) 115 kV LinesOOS Mar 15 – May 31, 2005 Contract Labor

Phase 2 115 kV (Connect remaining 115 kV lines and Tie to Boulder Park)Beacon-Otis #1 (Barker-Otis) & 9CE-Otis (Lib Lk-Otis) OOS Jun 1 – Sep 30, 2005Beacon-Otis #1 (SIP-Barker) & Bld Park Gen TapOOS Oct 1 – Dec 31, 2005 Labor TBD

Dry Creek 230 kV SubstationReconductor North Lewiston-Hatwai-Lolo with ACSSInstall Fiber Optic Cable DC-N LewistonDC-N Lewiston 230 kV OOS Jan 1-Feb 28, 2005Hatwai-Lolo 230 kV OOS Mar 1 – May 31, 2005Hatwai-N Lewiston 230 kV OOS Sep 1, 2005 – Jan 15, 2006Contract Labor

BoulderBeacon

Hatwai (BPA)

Latah

E. Colfax

RosaliaBenewah-Shawnee 230 kV Line

Construct 60 mile 230 kV using 45 miles of existing 115 kV corridor115 kV Segment Outages:Shawnee-Sunset (Spangle-Rosalia & Rosalia-E. Colfax)Lind-Shawnee (E. Colfax-Shawnee)Benewah-Moscow (Benewah-Latah Jct & Latah Jct-Tekoa)General Outage Period May 20, 2005 – Nov 15, 2006Contract Labor

230 kV Upgrade Project - Historical Estimates

$ 000's (1) (2) (3) (4) (5) March 2002

(Estimate) August 2002

(Estimate) October 2002(2003 Budget)

October 2003(2004 Budget)

June 2004(Estimate)

1 Total 230 kV Upgrades 2002-2006 64,327 87,577 89,052 106,730 105,388 23 Total BPA/AVA W. of Hatwai Contract 54,020 65,404 67,295 78,326 76,831 45 Total Load Service / Compliance 10,307 22,173 21,757 28,404 28,557 67 Total 230 kV Upgrades ( > 2007) - 47,050 46,675 46,675 54,663 89 AVA/BPA West of Hatwai Agreement 54,020 65,404 67,295 78,326 76,831 1011 Beacon-Rathdrum ER 255 13,800 15,055 15,303 18,495 18,495 12 Rebuild Transmission Line 10,160 11,615 12,303 14,915 14,915 13 Rathdrum Substation 2,315 2,315 1,904 2,905 2,905 14 Beacon Substation 1,125 1,125 1,096 675 675 15 Loop 230 to Lancaster 200 - 16 - 17 Dry Creek ER 271 10,425 18,130 13,994 15,185 11,809 18 Dry Creek Substation 6,125 6,125 5,157 9,089 7,911 19 N.Lewiston Substation 500 6,205 3,305 189 189 20 Lolo Substation 'WoH' only 1,100 1,100 1,206 1,813 1,024 21 Nez Perce Substation Capacitors - 2,000 1,501 1,501 22 Dry Creek - N.Lewiston Rerate 1,000 1,000 680 206 206 23 Hatwai-Lolo Reconductor 1,000 1,000 980 1,031 1,031 24 Hatwai - N. Lewiston Reconductor 700 700 980 1,032 1,032 25 Integrate Transmission @ Dry Creek 55 163 163 26 Foundation to Store Auto at N Lew - - 129 69 161 27 Dry Creek - Lolo Fiber Optic Make Ready 92 92 3031 Palouse 230 ER 594 29,795 32,219 30,902 33,288 33,288 32 Transmission line - 60 miles 25,700 25,700 25,349 25,235 25,235 33 Benewah Substation 3,770 6,200 5,234 7,524 7,524 34 Shawnee Substation 325 319 319 319 319 35 Moscow 230 Sub - Upgrade Relays 210 210 3637 Remedial Action Scheme (RAS) ER 256 - - 1,702 1,710 1,710 3839 Telecom ER 283 - - - 5,138 6,100 40 N. of Benewah Fiber Ring - 70 miles 2,070 41 Southern Fiber Ring - 35 miles 1,233 42 Mica Radio & Kellogg Fiber 730 43 RAS & EE 927 44 Benewah-Shawnee - 60 miles 1,140 4546 Power Circuit Breakers ER 7 - - 5,395 4,510 5,430 474849 230/115 kV Load Service / Compliance 10,307 22,173 21,757 28,404 28,557 5051 Power Transformers ER 6 - 2,100 3,900 4,263 4,263 5253 Pinecreek Substation ER 881 - 5,583 5,569 5,692 5,692 54 Lolo Substation E 114 - 2,000 5556 Beacon-Bell #4 Reconductor ER 297 - 1,700 1,700 1,107 1,107 5758 Beacon-Bell #5 Reconductor E071 - 1,700 1,700 1,275 1,275 5960 Boulder Substation ER 948 10,307 11,020 8,825 15,997 14,150 61 Boulder Substation - - - 11,504 7,071 62 Integrate Transmission - - - 4,494 6,079 63 Otis Orchards Sub & Transmission 10,307 11,020 8,825 64 Reclamation Otis Orchards 1,000 656667 NW-WS 115 Reconductor ER 249 70 63 71 71 6869 Phase II (2007 and Beyond) 47,050 46,675 46,675 54,663 7071 Lolo Substation DB/DB E114 662 72 Nez Perce 115 kV Capacitors 1,501 73 Beacon Substation DB/DB E113 5,825 7475 Noxon-Pinecreek DC E074 18,575 18,400 18,400 18,400 76 Transmission 17,100 17,100 17,100 17,100 77 Noxon Substation 750 650 650 650 78 Pinecreek Substation 725 650 650 650 7980 Benewah-Pinecreek DC E075 28,475 28,275 28,275 28,275 81 Transmission 25,800 25,800 25,800 25,800 82 Benewah Substation 1,450 1,350 1,350 1,350 83 Pinecreek Substation 1,225 1,125 1,125 1,125

Last Updated June 17, 2004 File Name: WoH Hist Est MASTER JUNE 04.xls Financial

West of Hatwai and 230kV Project Upgrades Historical Project Cost Estimates 2002 - 2006

Introduction The chart on the previous page shows project cost estimates from March 2002 to June 2004. In March 2002, a feasibility cost estimate was developed for most of the West of Hatwai projects along with the addition of 230 kV lines and transformers at Otis Orchards Substation. Subsequent cost estimates (August 2002, October 2002, October 2003, and June 2004) represent additions and deletions to the projects, more definitive engineering estimates, and the full realization of the project scope including transmission lines, substations, and control systems infrastructure. This document will summarize changes to the project cost estimates between March 2002 and June 2004.

March 2002 - Initial Estimates

Initial Baseline Estimate March 2002West of Hatwai $54,020Load Service $10,307

Total Project $64,327 The initial cost projections developed in March of 2002 included Beacon-Rathdrum (ER 255), Dry Creek (ER 271), Benewah-Shawnee (ER 594), and Otis Orchards (ER 948). These high-level feasibility cost projections have an accuracy level of: ± 30%. In March of 2002, it was not known that several key substations would require redundant physical, relay protection, and control systems. Prior to 2002, Avista designed 230 kV stations was to construct them in a “main/auxiliary” bus configuration. In a main/auxiliary substation, there is one power circuit breaker for each transmission line plus a single power circuit breaker connected to the auxiliary bus. The auxiliary breaker is used as a backup for any of the dedicated line breakers during maintenance of line breakers. However, system planning analysis revealed that Avista’s transmission system did not meet the WECC/NERC performance standards for 230 kV bus outages at certain substations. WECC requires that key transmission substations include redundant equipment, protective relays, and control systems. Since the widespread disturbance in the summer of 1996 and the more recent east coast outage in August of 2003, there has been increased scrutiny on substation bus outages and their impact to the interconnection. Initial estimates for the Beacon-Rathdrum transmission line assumed that construction would occur during summer and fall months. However, the existing 230 kV line could not be decommissioned until mid-September 2003 because of outage limitations which forced much of the line construction activity, especially conductor stringing, into the winter months. (Explanation – Transmission Operations required a one-hour recall provision on the Beacon-Rathdrum 230 kV line from June through September 15, 2003. During summer months, a sustained outage to an underlying 115 kV line required that that the Beacon 230 line be available for backup service.) This caused the labor contract with Wilson Construction to be approximately $1M over earlier estimates. In

West of Hatwai Historical Estimates 1 Printed on 06-25-2004

addition, metal commodity prices for steel and aluminum rose during the war with Iraq resulting in another $1M variance to expected budget. In March 2002, it was known that a remedial action scheme or RAS would be required to control generation on the Clark Fork projects. Throughout the industry, generation and load dropping schemes have been implemented to help maintain transmission transfer capabilities. In the early 1990’s, BPA installed a RAS scheme at Noxon to support the WoH transfer capability and Avista’s RAS will serve a similar function. However, in March of 2002, the cost to install RAS at Noxon was unknown and not included in the cost estimates. Documents associated with the March and August 2002 cost estimates clearly indicate that the cost of RAS would be included in subsequent cost projections. On August 16, 2002, the West of Hatwai Letter Agreement was formally executed between Avista and BPA. In conjunction with that Agreement, an updated cost projection was developed.

August 2002 - Estimates

Category March 2002 August 2002 Variance West of Hatwai $54,020 $65,404 $11,384 Load Service $10,307 $22,173 $11,866

Total Project $64,327 $87,577 $23,250

The difference between the March 2002 and August 2002 estimates include the following:

ER 255 Beacon-Rathdrum

March 2002 August 2002 Variance $13,800 $15,055 $1,255

A more definitive cost estimate for the transmission line is

developed by engineering. ................................................................ $1.5M

The plan to “loop” one of the transmission lines into BPA’s Lancaster substation is eliminated. ................................................. <$0.2M>

ER 271 Dry Creek


System planning studies indicate that North Lewiston substation

must be reconstructed as a double breaker/double bus station to accommodate a second 230/115 kV autotransformer ...................... $5.7M

System planning studies indicate that 115 kV capacitor banks are

required at Nezperce Substation for voltage support ........................ $2.0M


ER 594 Benewah-Shawnee March 2002 August 2002 Variance

$29,795 $32,219 $2,424

The 230 kV bus and breaker capacities at Benewah substation are shown to be insufficient to meet the line loading requirements. The construction plan broadens from adding onto the existing substation to reconstructing the 230 kV substation........................... $2.4M

Load Service and WECC/NERC Compliance


Avista does not maintain a system spare 230/115 kV

autotransformer. The high probability that a transformer outage at Beacon Substation requires rotating customer outages prompts the inclusion of a spare transformer in the August 2002 estimate. (ER 6) ................................................................................................ $2.1M

The effort to rebuild the Pinecreek substation started

in 2001, is put on hold in 2002, and resumes in 2003. The project is included in the August 02 estimate to show a more complete picture of the investment in Avista’s 230 kV infrastructure. (ER 881) ............................................................................................ $5.6M

Neither of the Beacon-Bell line reconductor jobs are included in

the March estimate. Capacity upgrades to these lines are required by NERC (ER E036 and E071) .......................................... $3.4M

A more refined estimate for the Otis Orchards substation reveals

increased costs (ER 948) ................................................................. $0.7M


October 2002 (2003 Budget) - Estimates Following the August 2002 cost projection, estimates are prepared for the 2003 capital budget. For substation projects, the cost of power transformers and circuit breakers are transferred to ER 6 and 7. This reflects the purchase of three 230/115 autotransformers and numerous 230 kV gas circuit breakers. Prior to the 2003 budget, project estimates (March & August 2002) included the cost of this equipment in the project ERs. This change reduces the budget item estimates for substation projects at Rathdrum, Beacon, Dry Creek, North Lewiston, Benewah, and Otis Orchards but does not impact the overall system cost.

Category August 2002 October 2002 Variance West of Hatwai $65,404 $67,295 $1,891 Load Service $22,173 $21,757 <$416>

Total Project $87,577 $89,052 $1,475

The difference between the August and October 2003 estimates include the following: ER 255 Beacon-Rathdrum

August 2002 October 2002 Variance $15,055 $15,303 $250

Increase in mechanical capability of the transmission line................ $0.7M

Transfer cost of Rathdrum power circuit breakers to ER 7 .............. ($0.4M)

ER 271 Dry Creek

August 2002 October 2002 Variance $18,130 $13,994 ($4,136)

Transfer cost of Dry Creek, North Lewiston, and Nezperce power

circuit breakers to ER 7 .................................................................... ($3.1M)

Transfer cost of one autotransformer from N. Lewiston to ER 6 ...... ($1.3M)

Refined cost estimates to reconductor L/C area transmission lines and temporary storage of autotransformer at N. Lewiston ................ $0.1M


ER 594 Palouse 230

Refined estimate for transmission and transfer cost of Benewah power circuit breakers to ER 7 ......................................................... ($1.3M)

ER 256 Remedial Action Scheme

Engineering design and scope for RAS scheme is known. RAS will be WECC certified to support the transfer capability of WoH cutplane and will allow flexible hydro operations at Noxon & Cabinet HED. .................................................................................... $1.7M

ER 7 Power Circuit Breakers

The March and August estimates for substation projects include the cost of power circuit breakers. For FERC accounting and budgeting purposes, those costs are transferred to ER 7. ................ $5.4M


August 2002 October 2002 Variance $22,173 $21,757 ($416)

ER 6 Power Transformers

The cost of the N Lewiston autotransformer is transferred to ER 6. . $1.8M ER 948 Otis Orchards/Boulder Substation

The cost of circuit breakers and two autotransformers is transferred to ER 6 and 7. .................................................................. (2.2M)


October 2003 (2004 Budget) - Estimates

Between the 2003 and 2004 capital budget cycles, Avista made public its plans to upgrade the 230 kV transmission infrastructure. Public input was sought on Beacon-Rathdrum, Otis/Boulder, Dry Creek, and Palouse 230 projects. Outcomes of those public processes help shape the projects and increase the probability of successfully completing the facilities. The most notable change is in the Spokane Valley where Avista collaborated with the local community to construct a new 230 kV substation adjacent to the Boulder Park Generating Station instead of routing 230 kV transmission lines into the Otis Orchards station. The strategic location of Boulder Substation allows for the connection of three 230 kV lines instead of the two lines that were slated for Otis Orchards. This significantly enhances the reliability, capability, and operational flexibility of the substation and strategically aligns the facility for inclusion of a future, 4th 230 kV line. Also, the close proximity of the Boulder Park Generating station allows for a dedicated 115 kV tie line that increases the station’s reliability. Prior to 2003, Avista’s transmission substations were constructed using a main/auxiliary bus configuration. Continued development and analysis of WECC and NERC planning standards now require that Avista install redundant equipment and systems at four 230 kV substations (Rathdrum, Dry Creek, Boulder, and Beacon). The loss of concentrated industrial load (Kaiser Mead, Addy Metalworks) combined with increases in area generation (Rathdrum CTs) have radically changed the operation and planned use of the region’s transmission system. Historically, Avista’s transmission system was “thermally constrained” and communication systems on transmission lines were prudent but not mandated by reliability standards. Since 2000 and considering system impacts of BPA’s 500 kV addition in conjunction with Avista’s upgrades, the area 230 kV lines are now “stability limited”. This means that communication systems are required on many 230 kV lines to ensure fast tripping for contingency outages. Without these systems, there is considerable risk that transmission outages will impact generation facilities, most notably Noxon, and that a single outage will cascade to other Avista lines or even to adjacent utilities. This emerging “stability” problem has prompted the addition of fiber optic and digital microwave systems budgeted in ER 283. This project not only meets WECC standards but also forms the communication backbone of Avista’s RAS schemes.

Category October 2002 October 2003 VarianceWest of Hatwai $67,295 $78,326 $11,031Load Service $21,757 $28,404 $6,647Total Project $89,052 $106,730 $17,678

Total project cost differences between the 2003 and 2004 capital budget include the following:


ER 255 Beacon-Rathdrum October 2002 October 2003 Variance

$15,303 $18,495 $3,192

Overall, labor bid proposals are higher than expected which reflects the upswing of transmission construction activities throughout the western states. Also, because a permanent line outage could not be taken until mid-September, much of the line construction is forced into winter months. ......................................... $1.0M

In early 2003, the war with Iraq caused an increase in demand for

metals including aluminum and steel. This factor is combined with refined engineering estimates. It should be noted that current commodity prices have risen in response to China’s increased demand for metals............................................................................. $2.2M

The requirement to construct a double breaker/double bus station

at Rathdrum is partially offset by the elimination of a new line position at Beacon Substation for the 2nd Rathdrum 230 kV line. ..... $1.0M

ER 271 Dry Creek

October 2002 October 2003 Variance $13,994 $15,185 $1,191

A decision is made by system planning, transmission operations,

and engineering to install a 230/115 kV autotransformer at Dry Creek rather than at N. Lewiston. This significantly enhances the reliability and security of load service in the L/C Valley. 115 kV infrastructure and transmission integration is added to Dry Creek.... $3.9M

The cost of rebuilding the N Lewiston sub is eliminated .................. ($3.1M)

A more refined scope of work and engineering analysis at Lolo

substation reveals that the mechanical bus supports are insufficient to withstand increase fault duty stresses. Relay, communication, and control system are out-dated. ......................... $0.6M

Capacity requirements for transmission system are defined by

system planning including the avoided cost of reconductoring the Dry Creek-N Lewiston line. Net change from 03 to 04 budget for L/C transmission............................................................................... ($0.2M)

ER 594 Palouse 230

At Benewah, the WECC mandate for a redundant station requires the construction of a new substation rather than rebuilding existing facilities.............................................................................................. $2.3M


ER 283 Fiber Optic & Digital Microwave

Requirements and routing of fiber optic cable is known and included in the 2004 capital budget. Avista plans to construct a northern and southern fiber optic ring to support RAS and protective relay communication. The avoided costs of lease-line communication are yet unknown....................................................... $5.1M


The actual cost of SF6 gas circuit breakers is less than expected... ($0.9M) Load Service and WECC/NERC Compliance

October 2002 October 2003 Variance $21,757 $28,404 $6,647

ER 6 Power Transformers

The contract with VA-Tech for three 230/115 kV autotransformers is complete but exceeds the 2003 budget expectation. .................... $0.4M

ER 297 and E071 Beacon-Bell #4 & #5

Engineering analysis refines the estimate for the number of pole and x-arm replacements................................................................... ($1.0M)


As previously mentioned, Avista adopts the community plan to construct a new 230 kV substation at Boulder Park which expands the scope from two to three 230 kV lines and from five to seven 115 kV lines ..................................................................................... $7.2M


June 2004 (Mid Year Estimate) Between the October 2003 and June 2004 estimates, engineering analysis of Lolo Substation reveals that the station lacks the mechanical strength to withstand certain types of 230 kV line faults. Instead of simply increasing the circuit breaker capacities to match transmission line ratings, the project scope at Lolo increases to include construction of a new 230 kV substation. Since only a portion of the Lolo project is WoH related, the project is separated into three ERs as indicated on the historical estimate chart (West of Hatwai, Load Service construction 2002 2006, Phase II construction beyond 2007). More information about the cost of materials, labor estimates, and overall engineering design are known for both Boulder and Dry Creek Substation. Estimates for both projects are decreased based on additional and more certain information. For Telecom, the labor estimates for the installation of OPGW and ADSS were understated in the October 03 estimates. The increased estimate for Telecom project reflects additional information on the costing of materials, labor, and represents a fuller understanding of the scope of work.

Category October 2003 June 2004 VarianceWest of Hatwai $78,326 $76,831 ($1,495)Load Service $28,404 $28,557 $153Total Project $106,730 $105,388 ($1,342)

Differences between the October 2003 budget estimate and the June

2004 mid-year estimate include the following: ER 271 Dry Creek

October 2003 June 2004 Variance $15,185 $11,809 $3,376

The avoided cost of grading for a 4th capacitor bank segment is

combined with an AFE estimate for the substation at Dry Creek ..... ($1.2M)

The West of Hatwai portion of the Lolo project is better defined. The cost to reconstruct Lolo is spread over three ERs .................... ($0.8M)

The project to install 115 kV capacitors at Nezperce is planned for

2007 and is moved to Phase II construction. ................................... ($1.5M) ER 283 Telecom

The labor costs to install ADSS and OPGW fiber optic cable are better known after the Beacon-Rathdrum project and the recent contract with Wilson to install fiber on the Dry Creek-Lolo line. This combined with a better understanding of the complete project scope drive estimates higher than earlier expectations. ................... $1.0M



Additional power circuit breakers are required to reconstruct Lolo as double breaker/double bus station. Earlier estimates included only three PCBs. ............................................................................... $0.9M


October 2003 June 2004 Variance $28,404 $28,557 $153

ER 114 Lolo Substation

The non-WoH portion of Lolo construction is moved to the load service category. This includes constructing Dry Creek and Oxbow 230 kV line positions in 2006. ............................................... $2.0M


The Boulder station is sited on lands purchased by Avista Development. Previous estimates assumed that the cost of lands would be charged directly against the project. This is not the case; the ownership was simply transferred from Development to the Utility........................................................................................... ($1.45M)

No 115 kV capacitor banks are required at Boulder. The banks at Otis will remain. ................................................................................ ($1.0M)

The 2004 budget Line 7 calculation only included one of the planned 230/115 kV autotransformers and 50% of the planned PCBs. The October 03 estimate is overstated. ............................... ($2.0M)

For transmission, the actual number of transmission structures exceeds earlier estimates. The bus configuration for Boulder requires additional corner structures. The number of “specialty” steel structures is greater than anticipated........................................ $1.6M

A cost estimate to perform reclamation at Otis is established. ........ $1.0M

See chart comparison on following page.


230 kV Upgrade ProjectHistorical Cost Estimates

28,4

04

28,5

57

$76,

831

64,3

27

89,0

52 106,

730

105,

388

21,7

57

22,1

73

10,3

07

$65,

404

$78,

326

$67,

295

$54,

020

87,5

77

-

20,000

40,000

60,000

80,000

100,000

120,000

March 2002 August 2002 October 2002 October 2003 June 2004

$000

's

Load Service W. of Hatwai Total 230 kV


Pr

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General Project Overview (Results through August 31, 2003)

On June 12, Avista officially “kicked off” the West of Hatwai project with a little celebration in Mission Park. Scott Morris was on hand to make a few remarks about the legacy that the Company is building. He specifically referenced the construction of Cabinet Gorge and Noxon Rapids as key events in the Company’s history. He said that the transmission expansion associated with the West of Hatwai projects will have similar benefits for the Company and our customers, now, and well into the future. Though the project kick-off was not held until June, most of the significant 230 kV projects were well underway. This summary will provide some baseline information as to project status, schedule, financial performance, and other initiatives associated with West of Hatwai. There are over twenty-five (25) discreet 230 kV transmission line or substation projects associated with West of Hatwai. Some of the projects are modest in nature like the effort to upgrade the Cabinet Substation relays on the Cabinet-Rathdrum. At the other end of the spectrum is the Benewah-Shawnee project that involves the construction of 60 miles of transmission line and the reconstruction of the 230 kV Benewah Substation. This summary will focus in on the four (4) major projects. West of Hatwai Schedule Status 19 days behind (YTD) West of Hatwai 2003 Budget Variance $321k (under), 3.6% Variance (YTD) 1. Beacon-Rathdrum Transmission Line Work to reconstruct the 25 mile Beacon-Rathdrum 230 kV line began on June 2. The Company contracted with Wilson Construction to construct Avista’s highest capacity 230 kV transmission line (2000 MVA). Typical 230 kV lines are summer rated between 400 and 500 MW but a high temperature conductor on the new Beacon-Rathdrum line will allow each of two circuits to operate to 1000 MW. Foundation crews worked for three months (June-August) to construct 165 of 177 concrete reinforced, anchor bolt foundations. To maintain reliability, the existing Beacon-Rathdrum line was kept intact throughout the summer to meet heavy load demands and was used during line outages on the 115 kV system. Recent fires on Beacon Hill combined with some days of near record peak loading required that the Beacon-Rathdrum line be used to meet load demand. Starting September 15, the project will enter into its second phase. Wood poles and conductor on the existing 230 kV line will be removed and replaced with steel poles capable of supporting two sets of conductors (double circuit) along with overhead shield and fiber optic control cable. The line construction is expected complete on or before March 31, 2004. Along with the effort to reconstruct the transmission line, there is considerable effort at Rathdrum Substation to convert that station from main/auxiliary to a full double breaker-double bus substation. In layman’s terms, the existing substation has minimal redundant capabilities but when reconstructed as DB/DB, will have full redundancy for all 230 kV systems and will be the Company’s “first ever” DB/DB station. At Rathdrum, planning studies indicate that the electric grid is vulnerable to an outage on the 230 kV main bus or in the event of a breaker failure event (e.g. slow or “stuck” breaker) and requires a redundant system to avoid such an outage.

Photo 1: Concrete “Anchor Bolt Type” Foundation at Beacon-Rathdrum

On June 6, the mechanical/structural work was complete at the Rathdrum site and includes the construction of 150 feet of new pipe bus to accommodate four new 230 kV line/transformer positions. The electric crews have now inherited the project and have begun work on the control and panel wiring. In conjunction with the 230 kV line project, the new 230 kV station is scheduled for energization on March 31, 2004. Benewah Substation is another facility that will be converted to DB/DB for similar concerns over electric reliability (see Benewah-Shawnee project). Beacon-Rathdrum Schedule Status 19 days ahead (YTD) Beacon-Rathdrum 2003 Budget Variance $1,375k (over), 30% Variance (YTD) Overspend for Beacon-Rathdrum resulting from better than expected progress on 230 kV line construction and the higher than expected cost of steel poles and aluminum conductor. Some overspend variance at the Rathdrum Substation reflecting construction progress slightly ahead of plan. The YE 2003 overspend variance for the project (total ER 255) is expected to be $2M.

Pg 2

2. Boulder Substation In February, the Company held a series of public workshops to discuss possible 230 kV transmission routes to connect the 115 kV Otis Orchards Substation with the Beacon-Rathdrum 230 kV line. Input from the public during those meetings in combination with internal review of the project, led the Company to embrace the community’s preferred alternative to construct a new substation facility adjacent to the Boulder Park Generating Station instead of expanding the site at Otis Orchards. The increased scope of the substation will add four million dollars to the total project cost but virtually eliminates the routing constraints for 230 kV lines into the new site. In addition, the Boulder Generating Station’s overall reliability will be greatly enhanced by the close proximity of the new station. Avista has partnered with ECI consultants from Billings, MT to assist with the engineering design of both Boulder and the Dry Creek substations. Most engineering and permitting tasks are scheduled to be complete before year-end with ground breaking at the site scheduled for March of 2004. Boulder Substation Schedule Status 19 days behind (YTD) Boulder Substation 2003 Budget Variance $118k (under), 34% Variance (YTD)

Diagram 1: Proposed Routing of 230 and 115 kV Lines into Boulder Substation

Pg 3

3. Dry Creek Substation In 1982, the Company purchased the property for the development of the Dry Creek 230 kV substation. The property is located adjacent to the then Lolo-Walla Walla 230 kV Line and was determined to be a strategic location for a transmission substation. During the first West of Hatwai uprate project (1991-93), the 230 kV grid in the L/C Valley was reconfigured by routing the Walla Walla line into the North Lewiston Substation. That reconfiguration along with other 115 kV reinforcements forestalled the need to develop the substation at Dry Creek. During the 2002 system planning analysis of the L/C area, two projects were identified 1) Construct Dry Creek 2) Install a 2nd 230/115 autotransformer at N Lewiston. Subsequent discussions have led to the combination of those two projects and the planned installation of the autotransformer at Dry Creek instead of North Lewiston Substation. This decision is a net cost avoidance to the Company of two million dollars (i.e. avoids reconstruction of N. Lewiston as DB/DB station). On July 31, the Dry Creek project was announced to the general public. Subsequent direct mailing to area residents and key stakeholders announced the open house public meeting which convened on August 13. Concerns over visual obstructions and noise are being considered for their impacts. Ground breaking will occur in early October of 2003 followed by mechanical/structural work during the balance of 2003. The 230 kV bus and three (3) transmission lines will be energized in December of 2004 followed by the installation of the autotransformer, 115 kV portion of the station, and 230 kV capacitor banks in the 1st half of 2006. The installation of 200 MVar of shunt reactive (e.g. capacitor banks) is the Company’s “first-ever” 230 kV installation of these devices. Dry Creek Substation Schedule Status 0 days “spot-on” (YTD) Dry Creek Substation 2003 Budget Variance $204k (under), 55% Variance (YTD) The decision to add a 230/115 kV autotransformer at Dry Creek rather than North Lewiston created a variance between schedule and budget. However, the project plan still requires the energization of Dry Creek’s 230 kV bus in December of 2004. Concentrated engineering design and field construction are necessary in the balance of 2003 to achieve that energization goal and will drive an estimated YE 2003 overspend variance of $600k.

Pg 4

Asotin County Landfill

230 kV Transmission Lines (orange) Shown for Illustration only (NTS)

SW Clarkston

To Lolo To Walla Walla

To North Lewiston

Dry Creek

Photo 2: Aerial Photograph of Dry Creek Substation Property (red rectangle)

(blue lines indicate Avista’s 13 kV. Photo from OMT/GIS system) 4. Benewah-Shawnee Transmission Line Largest of the West of Hatwai projects, the proposed 60 mile transmission between Benewah and Shawnee along with the reconstruction of Benewah Substation is estimated to cost over 33 million dollars and require the full balance of 2003 until the end of 2006. It is the most “ambitious” of the WoH projects. In April, Avista partnered with Power Engineers (PEI) of Hailey, Idaho to perform the route study analysis between Benewah Substation and the existing 115 kV line connection Rosalia and Spangle Substations. The fruit of that effort was recently realized on August 18 when PEI delivered the draft routing study. That report will form the basis of the four (4) route alternatives that the Company will present to the local community in October. By mid to late November, a route alternative will be selected and we can then move ahead with right-of-way acquisition and design.

Pg 5

PEI will be using Itron’s “TL-Pro” design software to perform computerized design of the entire line route. Avista recently purchased this software package from Itron and this project will be the Company’s “first ever” in-house use of computer aided transmission design. This package allows for optimized spotting of structures, in depth analysis of structure & conductor loadings, and equips the designer with a myriad of mapping resources from conventional ground survey to aerial photography to GIS terrain data. Construction of the line is slated to begin the 1st quarter of 2005. Reconstruction of the Benewah Substation is scheduled in 2005 and 2006. Benewah-Shawnee Schedule Status 0 days “spot-on” (YTD) Benewah-Shawnee 2003 Budget Variance $117k (under), 42% Variance (YTD) Underspend variance does not include recent aerial photogrammetry survey work ($56k) and purchase of TL-Pro software from Itron ($60k). Including those expenses reduces the variance to null levels. Additional Information There is a West of Hatwai webpage available on AVAnet. The webpage includes detailed information as to the schedule, financial performance, and descriptions of the individual projects. (Click on link to) http://avanet/projresources/hatwai/ Team members have contributed significantly to the development and tracking of the West of Hatwai master schedule. Currently, over 400 project tasks are actively managed, and the master schedule has proven to be a great metric for the project.

West of Hatwai, Project Manager

Pg 6

http://avanet/projresources/hatwai/

West of HatwaiProject Status Report

September 2003

1

Bell (BPA)

Cabinet Gorge

Noxon

Benewah

Pinecreek

WestsideRathdrum

Shawnee

Moscow 230

Hatwai (BPA)

Lolo

N. Lewiston

BeaconBoulder



Dry Creek

Beacon-Rathdrum 230, $17.5MBeacon-Rathdrum (25 miles), 2000MW, Mar 2004Rathdrum Substation, Reconstruct to DB/DB, Mar 2004Beacon & Cabinet Substations, Relay Upgrades

Beacon-Bell 230, $3.4MBell #4, (6 miles), Uprate to 800 MW, Dec 2004Bell #5 (6 miles), Uprate to 800 MW, Dec 2005Beacon Substation, Relay Upgrades

Spokane Valley Reinforcement, $16.0MBoulder Substation, 500 MVA, Q1/ 2006Integrate 3-230 and 5-115 kV lines, 2006Scope change from Otis to Boulder, additional $4M

Palouse Reinforcement, $33.4MBenewah-Shawnee (60 miles), 2000 MW, 2006Benewah Substation, Reconstruct to DB/DB 2006Shawnee Substation, Benewah line positionMoscow 230, Upgrade Relays

Dry Creek, $16.2MHatwai-North Lewiston (7 miles), Uprate to 800 MW, May 2005Hatwai-Lolo (8 miles), Uprate to 800 MW, Jan 2006Dry Creek Substation, June 2005Scope change to add 230/115 kVtransformer at DC instead of N. Lewiston. Net savings $2.5MLolo & N. Lewiston Substations, Breaker & Relay Ugrades

Pinecreek Substation, $5.6MReconstruct Substation, December 2003

Other WoH CostsNoxon & Dry Creek Remedial Action. TBDFiber Optic cable on 230 kV Lines. $6M

Project sites shown with blue color highlight. Avista's 115 kV transmission lines are not shown

6 x 20 mile Transmission StudyArea. Establish new transmission

line corridor.

2003-2006 West of Hatwai & Load Service230 kV System Upgrade Projects

Original Document March 2003Rev# Date

Executive Summary

West of Hatwai Letter Agreement

On August 16, 2002, a Letter Agreement was executed between Avista and theBonneville Power Administration (BPA) describing a number of transmission projects tosupport the West of Hatwai transfer path. This Agreement is the culmination of manyyears of system planning work, contract negotiations, and coordinated transmissionoperations. Both Avista and BPA have committed to significant transmission upgradesbefore the end of 2006 that will increase the transfer capability across West of Hatwaifrom 2800 to approximately 4000 MW. BPA will construct an 85-mile 500 kV linebetween Bell and Grand Coulee substations while Avista will add or upgrade several 230kV lines and substations. The Avista construction projects include increasing thecapacity of some existing 230 kV facilities, constructing a 230 kV transmission linebetween Benewah and Shawnee, adding a 230 kV substation in Clarkston, Washington,and installing a remedial action scheme at Noxon Rapids Dam. Figure 1, shown on thefollowing page, indicates the location, schedule, and cost estimate for Avista’s West ofHatwai projects and related projects that are necessary to meet load service obligationsand to satisfy national & regional system planning criteria. The cost estimate toconstruct the transmission facilities ranges between 85 and 100 million dollars (3/6/03).

In order to increase the capacity rating for West of Hatwai, BPA and Avista will workjointly with other utilities to establish a new Western Electric Coordinating Council pathrating for West of Hatwai, Path #6. It is expected that the path rating will increase from2800 MW to 3600-4400 MW.

Operating Agreement with BPA

In February of 2000, Avista began operating the 115 kV transmission system in the “StarNetwork” configuration. By sectionalizing our 115 kV grid similar to lower voltagenetworks, Avista has mitigated 115 kV line overloads caused by 500 & 230 kV lineoutages. The new West of Hatwai Agreement requires that Avista continue to operate115 kV lines in the Star Network configuration.

Both parties have a need to curtail hydro production at Noxon in order to prevent lineoverloads caused by transmission line outages. Pursuant to the first West of HatwaiAgreement, BPA installed a remedial action scheme (RAS) to trip Noxon generationunits #1-4 for certain 500 kV line outages. Under the new Agreement, BPA will retaintheir RAS system and Avista will install an additional RAS scheme to curtail Noxongeneration for 230 kV line outages. In 2001, Avista installed a thermal protectionscheme at Noxon to run back generation for certain 230 kV line outages. This hardwarewill be replaced by the remedial action scheme.

This document describes each of the Avista 230 kV line & substation projects andprovides a perspective of the West of Hatwai transmission problem. This document isintended to familiarize the reader not only with the projects, but to also inform the readerabout the need for additional transmission capacity to serve Avista customers, tosafeguard the transmission system, and to support regional needs.

West of Hatwai, cont.

Page 2 of 15

(2002 BASE)

AVISTA TRANSMISSION PROJECTS ENERGIZATION DATE COST ESTIMATE

Beacon-Rathdrum Double-Circuit 230 kV Line Summer 2004 $15.6 M

Pine Creek 230 kV Substation - Rebuild Winter 2003 $5.5 M **

Beacon-Bell #4 230 kV Line - Reconductor Winter 2004 $1.7 M

Dry Creek 230 kV Switching Station Winter 2005 $16.2 M (and associated Transmission work)

Otis Orchards 230 kV Station Winter 2005 $12.6 M

Beacon-Bell #5 230 kV Line - Reconductor Winter 2005 $1.7 M

Benewah-Shawnee 230 kV Line Winter 2006 $32.2 M________

$85.5 M

** Includes Work Completed Prior to 2003

3/14/02 Rev. 1/10/03

MONTANA

Figure 1. Avista 230 kV Transmission & Substation Projects 2003 - 2006


Page 3 of 15

West of Hatwai: A Regional Problem

Definition of a Transmission Transfer Path

A transmission transfer path or “cutplane” describes a combination of transmission linesthat connect areas of generation and electric load. In order for generation to serve theload, the energy must be transported across the cutplane. A good example of thissituation is the West of Cascades cutplane that separates the hydropower generation inthe Mid Columbia (Grand Coulee to Priest Rapids) and the urban load center of Seattle,Washington. Much of the energy that serves the Seattle area is transmitted across anumber of 500, 345, and 230 kV transmission lines.

Puget Sound

West of CascadesNorth

Montana to NW

West ofHatwai

Idaho to NW

Grand CouleeBell & Beacon

Boundary Dam

Cab/Nox

Hungry Horse

HotSprings

Garrison

Hatwai

Avista

IDAHO

MT

OR

WA

Hanford

Schultz

Oxbow

Walla Walla

Pine Ck

NW Transmission Lines500 kV230 kV115 kVProposedThis drawing for information only

Shawnee

Figure 2. NW Transmission System

Transmission cutplanes are rated for their ability to transmit energy with at least oneelement out of service. For example, if a cutplane consisted of a single 500 kV line anda single 230 kV line, the overall path rating would reflect only the 230 kV line rating. Inthe West of Hatwai cutplane, there is a single 500 kV line in combination with other 230and 115 kV lines. Therefore, the path rating is limited to the simultaneous capability ofthe underlying network.


Page 4 of 15

First West of Hatwai Agreement (WoH)

In the early 1990’s, Avista and BPA embarked on an effort to raise the capacity of Westof Hatwai from 1840 to 2800 MW. BPA’s ownership in the cutplane includes the three230 kV and two 115 kV lines between Bell and Grand Coulee and the 500 kV linebetween Hatwai and Lower Granite. Avista’s portion of the cutplane includes the 115 kVlines that extend into the Othello region and the 230 kV lines south and west ofLewiston, Idaho. All transmission transfer paths must continue to meet performancecriteria even when a transmission line or substation device is forced out of service(contingency outage). In this analysis, system voltages must remain within acceptablelimits and transmission lines & substation equipment must not be overloaded. West ofHatwai is described as a thermally constrained path which means that a singletransmission outage causes an adjacent line to overload. During the first West of Hatwaiuprate project, system-planning studies indicated that Avista’s 115 kV lines becameoverloaded when subjected to outages on BPA’s 500 and 230 kV system.

As a result of the first West of Hatwai (WoH) agreement, Avista increased the capacity ofits transmission lines by reconductoring three 115 kV lines (Airway Heights-Devil’s Gap,Devil’s Gap-Westside, and East Colfax-Shawnee) and by routing the Lolo-Walla Walla230 kV Line into North Lewiston. The latter project required the construction of 8 milesof 230 kV transmission line from North Lewiston to the proposed Dry Creek substation.Also, BPA installed RAS equipment at Noxon to trip generation units #1-4 to protectAvista’s transmission system in the event of a 500 kV line outage (refer to TechnicalReference for details on RAS).

System Changes Impacting West of Hatwai

Figure 3 shows the most significant generation plants, load centers, and transmissionlines that affect the West of Hatwai cutplane. During most of year, energy flows acrossWoH from east to west because there is surplus generation in Western Montana andNorthern Idaho. As generation increases and system load decreases like during thespring season, energy flows east to west across the cutplane and oftentimesapproaches the operating limit of 2800 MW. Therefore, generation added to or loadremoved from the service territory east of the cutplane increases the burden on the WoHcutplane.


Page 5 of 15

OREGON

IDAHO MONTANAWASHINGTON

SPOKANE-CDA

MOSCOW-PULLMANLEWISTON-CLARKSTON

DWORSHAK

W. MT HYDRO(Noxon, Cabinet

Hungry Horse, Libby)

COLSTRIP

BOUNDARYDAM SCL

WEST OF HATWAITRANSMISSIONTRANSFER PATH

TO OXBOW DAMIDAHO POWER

TO WALLA WALLAPACIFICORP

230 KV (AVISTA)

500 KV (BPA)230 KV (BPA)

TRANSMISSION LINES

THIS MAP FOR ILLUSTRATIONPURPOSES ONLY 1-10-03

TO LOWER GRANITE

TO GRAND COULEE

BENEWAHSUBSTATION

Figure 3. Significant Load Centers and Generation that Impact WoH

After the first West of Hatwai Agreement, hydro units were upgraded at Cabinet Gorge(35 MW) & Hungry Horse (100 MW) and natural gas combustion turbines were added atRathdrum (130 MW) & Lancaster (260 MW). During the summer of 2001, the aluminumsmelter load at Mead (400 MW) and Columbia Falls (300 MW) was shutdown as part ofthe federal energy buy-pack program. This combination of added generation and loadloss amounts to more than 1,200 MW of additional energy that flows east to west acrossthe cutplane. Load growth in the Avista system has been marginal with gains in theresidential & commercial sectors being offset by the load reductions in wood products,mining, and manufacturing (45 MW).

In August of 2002, BPA and Avista executed a new West of Hatwai contract. Unlike thefirst WoH contract, the list of equipment upgrades focuses attention on Avista’s 230 kVnetwork including: a capacity upgrade on the Beacon-Rathdrum 230 kV line, theaddition of the Benewah-Shawnee 230 kV line, adding the Dry Creek 230 kV substationnear Clarkston, reinforcing the 230 kV lines in the L/C Valley, and Avista’s firstinstallation of 230 kV capacitor banks at both Dry Creek & Benewah substations. Asmentioned, Avista has sectionalized its 115 kV system so that energy can no longertransfer across those 115 kV transmission lines. This mitigates the problem ofoverloading 115 kV lines for 500 kV outages but has increased the burden on Avista’s230 kV lines, hence the construction focus on the 230 kV system.


Page 6 of 15

WoH Project Descriptions

The process to develop a regional transmission solution allows for input by a number ofstakeholder groups. Since the open-access ruling by the Federal Energy RegulatoryCommittee in the 1990’s (FERC Order 888/889), this stakeholder group has expanded toinclude generation-only companies, energy marketers, consumer advocates, end-users,state regulators, NERC, WECC, and other parties interested in the development and useof the bulk electric system. The 500 & 230 kV construction projects included in the newWoH Agreement were studied, evaluated, and assessed through open forums like theNorthwest Power Pool Transmission Planning Committee (NWPP TPC) and the WesternElectric Coordinating Council (WECC). Improvements to West of Hatwai have been afocus of not only BPA & Avista, but also the NW region.

A brief description is included for each of Avista’s WoH construction projects and related230 kV projects required for load service.

1. Beacon-Rathdrum 230 kV Line Reconstruction

Outages to BPA’s 500 kV linefrom Taft to Bell or their 230 kVline from Lancaster to Bell canoverload Avista’s 230 kV linebetween Beacon and Rathdrum.To increase the capacity of thisline, Avista will reconstruct thesingle circuit line with two circuitseach capable of transmitting 800MW (the existing line capacity is300 MW). The new line willoccupy the same right-of-way butwood H-frame structures will bereplaced with single tubular steelpoles. At Rathdrum substation, itis important that a 230 kV busoutage (e.g. failed potentialtransformer or bushing insulator)not affect the Beacon or Cabinet230 kV lines. In the existing single bus configuration, a 230 kV bus outage results in thecomplete loss of transformer load (200-350 MW). Therefore, the 230 kV auxiliary buswill be reconstructed as a second “main” bus and the station converted from amain/auxiliary type to a double breaker/double bus configuration (see TechnicalReference). This means that each 230 kV transmission line will be connected to two230 kV main busses and will ensure that at least one autotransformer remains energizedfor a 230 kV bus outage. The double breaker/double bus arrangement will also be usedat Dry Creek, Benewah, and Otis Orchards substations.

Photo 1. 230 kV "H" Structure Lookingtowards Beacon Substation


Page 7 of 15

2. Dry Creek Substation

During the first WoH negotiation, the future need for a 230 kV station near Clarkston,Washington was identified. Avista purchased & permitted property near the intersectionof 230 kV lines that extend to Walla Walla, North Lewiston, and Lolo substations. Byconnecting those 230 kV lines at a new substation called Dry Creek, a ring of 230 kVlines is formed around the L/C valley which mitigates 230 and 115 kV line overloadscaused by area transmission line outages. In addition, a 230/115 kV autotransformerwill be installed to relieve transformer loading at the North Lewiston substation. DryCreek will be connected to the area’s 115 kV system by looping the 115 kV line betweenDry Gulch and Pound Lane substations. The property for Dry Creek is locatedsouthwest of Clarkston, Washington. Dry Creek will be constructed in a doublebreaker/double bus configuration.

CapacitorBank Area200 MVar

230 kV Bus #1

230 kV Bus #2

to Lolo Sub

toNorth Lewiston Sub

to Walla Walla Sub (PAC)

230/115 kV Xfmr250 MVA

This diagram shows a possible230 kV Double Breaker/Double Bus layout including 230 kV Cap Bank and 230/115 Xfmr.For Illustration Purposes Only

Dry Creek Substation

115 kV to Dry Gulch& Pound Lane

115 kV Bus

Circuit Breakers230 kV 115 kV

Figure 4. Electric Diagram of the Dry Creek Substation


Page 8 of 15

3. Lewiston 230 kV Transmission Line upgrades

Related to the work at Dry Creek, the 230 kV lines from Hatwai to North Lewiston andfrom Hatwai to Lolo will be reconductored for a capacity increase from 400 to 800 MW.The line segment from North Lewiston to Dry Creek must be uprated from 400 to 483MW. This latter project will require survey and engineering analysis to determine if theline can be operated at a higher maximum conductor temperature. For the circuitsbetween Hatwai and North Lewiston and from Hatwai to Lolo, the conductor will bereplaced with a new type cable called ACSS (see Technical Reference). This conductorwill also be used in other transmission projects including the Beacon-Rathdrum and theBenewah-Shawnee 230 kV lines to achieve line ratings higher than conventional all-aluminum (AAC) or steel reinforced conductor (ACSR). Also, a 230 kV power circuitbreaker at Lolo will be replaced to accommodate the increased 800 MW Hatwai linerating.

LewistonClarkston

IdahoWashington

Reconductor 8.3 milesfrom Hatwai to LoloIncrease capacity from 400 to 800 MW

Reconductor 7 miles from Hatwai to North Lewiston. Increasecapacity from 400 to 800 MW

Operate at higher maxtemperature from DryCreek to N. Lewiston.Increase capacity from400 to 480 MW.

Dry Creek

North Lewiston

Lolo

1-500 and 2-230 kV Transmission Linesfrom BPA's HatwaiSubstation

Substation500 kV (BPA)230 kV (Avista)RoadwayRiver

Figure 5. 230 kV Transmission Lines in the L/C Valley Region


Page 9 of 15

4. 200 MVAR Capacitor Banks at Benewah and Dry Creek

The emergency line rating of the Beacon-Rathdrum and Benewah-Shawnee 230 kVlines and the 230 kV line upgrades near Lewiston, Idaho require additional reactivesupport at both Benewah and Dry Creek substations. Avista operates several 115 kVshunt capacitor banks but this installation will be the first application at the 230 kVvoltage level. Installations at both Benewah and Dry Creek will include 200 MVar of totalreactive in switchable segments of 100 MVar or less. A transient analysis study (EMTP)will determine the maximum size of capacitor banks at each station.

5. Remedial Action Scheme at Noxon

BPA has a remedial actionscheme (RAS) at Noxon to run-back generation units #1-4 in theevent of a 500 kV line outage.BPA has similar schemes atBoundary, Dworshak and Libby toprevent the overload of underlying230 and 115 kV lines. Avistaneeds this same treatment atNoxon to prevent the loss of theCabinet-Rathdrum or Noxon-Pinecreek 230 kV lines fromoverloading parallel pathtransmission lines. In addition, theplant shutdown at Kaiser Mead(400 MW) created a load-stabilityproblem at Noxon. Planningstudies now indicate that certain230 kV line outages cause thegenerating units at Noxon to trip off-line due to instability. The RAS scheme allows for acontrolled trip of generating units and helps to protect that equipment.

A dual redundant, diverse path communication system (see Technical Reference) isrequired to meet WECC requirements for “certified RAS”. Though still in the planningstage, the communication system will probably use both fiber optic cable and digitalmicrowave technology to create a communications loop from Beacon to Noxon viaRathdrum (North) and from Noxon to Beacon via Pinecreek & Benewah (South). Withthe loss of 600-800 MW of aluminum smelter load, the generation units at Noxon canbecome unstable for the loss of area 230 kV lines. In order to ensure that the Noxonunits remain on-line during transmission outages, the existing protective relaying andcommunications paths need to be fully redundant. The construction of a dualcommunications path satisfies the WECC requirements for both RAS and protectiverelaying.

Photo 2. Noxon Rapids Dam


Page 10 of 15

6. Benewah-Shawnee 230 kV Line

Adding a 230 kV transmission linebetween the Benewah and Shawneesubstations provides a secondtransmission path between north andsouth load centers (Spokane-Lewiston). A second line mitigatesoverloads on the Benewah-Moscow230 kV line and ensures transmissionservice to the L/C valley after a Hatwai500/230 kV transformer outage.Preliminary route analysis fromBenewah to Shawnee suggests that20 miles of new right-of-way will berequired west of Benewah along withthe reconstruction of 40 miles of 115kV line from Rosalia to Shawnee. Thenew transmission line will utilizetubular steel poles similar to thoseused between Beacon and Rathdrum.In addition to increasing the north-south transmission capacity, thealternate 230 kV feed to the Shawneesubstation will improve overallreliability in the Moscow-Pullman area.Currently, outages that impact the 230kV line between North Lewiston andShawnee affect customers served byEast Colfax, Diamond, Ewan,Chambers, and Armstrongsubstations. With a second line toShawnee, customers won’t beimpacted for a single 230 kV lineoutage. Also, improved reliability atShawnee will allow the transfer ofPullman area load from the Moscow230 kV substation back to Shawnee.To meet reliability criteria for 230 kVbus outages, Benewah will bereconstructed as a doublebreaker/double bus substation.

Figure 6. Avista 230 & 115 kV Lines in the Palouse Region

Spangle

Latah

Rockford

Fairfield

Oakesdale

Waverly

Farmington

Tekoa

Garfield

Palouse

Colfax

Moscow230 Sub

Rosalia

Latah Sub

Benewah Sub

Pullman Sub

S. Pullman Sub

Shawnee Sub

Steptoe

195

27

278

271

27

27

27

27

195

195

Latah Ck

Rock Ck

Road Way115 kV Line115 kV Substation

230 kV Line (proposed)230 kV Substation230 kV Line (existing)

STUDY AREAFOR NEW 230 KVALIGNMENT


Page 11 of 15

Avista Load Service Projects

All of the 230 kV projects that are specified in the West of Hatwai letter agreement alsosupport Avista’s obligation to reliably serve our electric customers. In fact, the Benewahto Shawnee line project is critical to Avista’s ability to serve south system loads in theevent of a Moscow 230 substation line outage or during a transformer outage at Hatwaisubstation. Likewise, the reconstruction and capacity increases to the Beacon-Rathdrum line play a pivotal role in the ability to serve customers in the Spokane andCoeur d’ Alene areas. Reinforcing the 230 kV system will increase electric reliability,adequacy, and supports system operation initiatives such as line maintenance andvegetation management.

7. Otis Orchards 230/115 kV

In response to Spokane Valley loadgrowth, Avista is adding 230/115 kVtransformation at the Otis Orchardssubstation. Area load growth hasmade it difficult to meet electricdemand with only theautotransformers at Rathdrum andBeacon. Loss of an areaautotransformer during summerloading may require that customeroutages be rotated to keep remaining230/115 kV autotransformers withintheir operating limits. At OtisOrchards, the 230 kV substation willbe constructed in the doublebreaker/double bus configuration andtwo (2) 250 MVA autotransformersinstalled to serve load in the SpokaneValley.

Beginning in February of 2003, Avista will host a series of public meetings to discussoptions for routing the 230 kV lines into Otis Orchards. Stakeholders will be asked toprovide input on how the Beacon-Rathdrum 230 kV Line can be looped into OtisOrchards and whether a portion of the Beacon-Benewah 230 kV right-of-way should beused for line routing. The process will help Avista make a routing decision that issupported by the local community.

Four public meeting workshops were held in the Otis community to discuss the need foradditional 230 kV support in the Spokane Valley area. The Company presented severalline routing options and asked attendees to comment on those proposals and or tosuggest alternate options. The option with the most community support would involverelocating the Otis Orchards substation to Boulder Park. The project team is evaluatingall of the options and will render a decision before the end of April (3/6/03).

Photo 3. Otis Orchards Substation


Page 12 of 15

8. Spokane Area 230 kV Line Upgrades

Two 230 kV lines connect BPA’s Bell substation with Avista’s Beacon substation. Sinceboth circuits are electrically equivalent, loss of one 230 kV circuit causes the adjacentcircuit to carry the additional load. To prevent line overloads, the Beacon-Bell #4 line willbe reconductored in 2004 and Beacon-Bell #5 line the following year. Again, ACSSconductor will be used to increase the line’s thermal capacity without increasing theweight or diameter of the conductor. Since conductor loading is not increased, most ofthe existing wood H-frames structures will be retained.

9. Pinecreek 230 kV Substation

The effort to reconstruct the 230 and 115 kV facilities at Pinecreek is underway. Thiswork will increase the station’s transmission line capacity and reconnect the #1 230/115kV autotransformer. The new 230 kV line positions for Benewah & Noxon will be inservice prior to construction outages on the Beacon-Rathdrum line (June 1, 2003). Theremaining construction will be finished before the end of 2003.


Page 13 of 15

Summary

The load service and West of Hatwai construction projects will add over 100 circuit milesof new 230 kV transmission line to Avista’s system and will increase the capacity ofanother 50 miles of line. Also, two new 230 kV substations will be constructed at DryCreek & Otis Orchards and three existing substations will be completely reconstructed(Pinecreek, Rathdrum and Benewah). This effort represents work at 40% of Avista’s230 kV substations. Related projects at six additional substations are necessary to meetcapacity requirements, to upgrade protective relaying, and to add a power circuit breakerat Beacon substation. In total, Avista will perform work in eleven of thirteen 230 kVsubstations or 85% of the system. This investment in our 230 kV system will not onlyincrease the capacity & reliability of our electric delivery system but will also support theregion’s transmission needs. Not since the addition of Rathdrum Substation in the late1970’s combined with the 230 kV line work at Noxon in the early 1980’s has Avistacommitted to constructing so many 230 kV facilities.

The diagram on page 2 indicates the total installed cost of the 2003-2006 230 kVupgrade projects at 85.5 million dollars. This value represents a cost forecast based onthe project scope information available at the end of 2002. Estimates for transmissionlines do not include the additional cost of extensive environmental review (e.g.Environmental Impact Statement), the cost of condemnation to secure right-of-way, orthe cost re-routing lines to avoid certain land areas. Inherently, budgeting for the totalcost of transmission facilities is problematic because of the large number of unknownfactors. As mentioned, the cost of communications and the remedial action scheme arenot available as of this printing. A comprehensive study of the Company’s 230 kVprotective relay schemes is underway and will yield a project scope & objectives within60 days. The total cost of the effort to upgrade Avista’s 230 kV infrastructure isestimated between 85 and 100 million dollars.


Page 14 of 15

Technical Reference

ACSS Transmission Conductor

Any metal whose temperature is raised above annealing point loses its ability to supporta mechanical load. In conventional all-aluminum steel reinforced conductor (ACSR), thelower annealing temperature of the aluminum limits the overall operating temperature ofthe conductor to less than 100°C. However in aluminum conductor, steel supportedcable (ACSS), the aluminum is fully annealed and the steel inner core carries 100% ofthe mechanical load. The annealing temperature of steel is much higher than aluminumallowing ACSS to be operated in excess of 200°C (392°F). Florida Power and Light hasbeen using ACSS for a number of years to meet the increasing demand for electricitywithout increasing the number of transmission lines. ACSS wire technology is nowcommonly used throughout the utility sector to increase transmission line capacity.Avista currently uses ACSS on the 115 kV lines between Beacon and Ross Park andbetween Beacon and Ninth & Central substations.

Double Breaker-Double Bus Substation

System planning studies indicate that Avista’s transmission system does not meetWECC/NERC planning criteria for certain 230 kV bus outages or when consideringcertain “failed breaker” contingencies. Most of Avista’s 230 kV substations areconstructed with a single main bus and an auxiliary bus that can be used to isolate apower circuit breaker for maintenance. Faulted conditions on the 230 kV bus requirethat all line breakers operate to isolate the bus from the transmission system. Thisprotection philosophy does not meet planning criteria at several stations. Byconstructing a second 230 kV main bus, fault clearing of a single bus does not interruptservice to connected 230 kV lines. This configuration will be used at Rathdrum, OtisOrchards, Dry Creek, and Benewah substations.

Dual-Redundant Communication System for RAS and 230 kV Protective Relaying

System planning studies also indicate that Avista’s 230 kV system cannot withstand timedelayed clearing of 230 kV line faults. Most 230 kV transmission lines usecommunication aided relaying to ensure high speed clearing of line faults near a station.These are commonly referred to as Zone 2 faults and occur within the first 10 to 15% ofthe line’s overall length. If time delayed clearing of a Zone 2 fault causes severedisruptions in system voltage, causes voltage oscillations, or forces generation units totrip off-line, the communication path between line terminal equipment must be fullyredundant and not subject to a common mode failure. A project plan to identify the needand performance of a 230 kV communication system is currently underway.

Remedial Action Scheme

Remedial action scheme, or RAS, describes the specific application of protectiverelaying and communications hardware. Typically, RAS action trips generation or loadto mitigate a problem caused by a transmission line outage. Most transmission transfer


Page 15 of 15

paths are “stability limited” which means that WECC/NERC planning criteria is not metfor loading conditions below the thermal capacity of the line(s). Most transmission pathsthat contain multiple 500 kV lines can only be operated up to their “stability limit”. Oneway to support a transmission path rating is to ensure that generation or load is droppedso that system voltages, voltage oscillations, and system frequency are not adverselyimpacted by line outages. For example, the California-Oregon Intertie (COI, Path 66) isa stability limited path which requires that generation be dropped in the Mid-Columbiasystem when any two of the three 500 kV lines are simultaneously faulted. By quicklydecreasing generation for a double line fault, the remaining 500 kV line operates withinits rated limit. Generally, RAS schemes are managed by System Operators andadjusted so that the correct amount of generation or load is “armed to trip” for certain lineoutages.

NERC & WECC

The National Electric Reliability Council (NERC) was formed in 1962 after seventransmission interconnections were closed resulting in the largest synchronized electricsystem in the world. However, the system-wide blackouts that occurred in 1965 (NewYork) prompted federal agencies to strengthen NERC’s role in establishing minimumoperating and planning criteria for utilities. Today, membership in NERC includes allU.S. and Canadian utilities and some portions of Mexico. NERC is comprised of 10subregions including the Western Electric Coordinating Council (WECC) that spansacross most of the western United States, British Columbia, and Alberta. Like NERC,WECC has established operating and planning criteria and considers the regionaldifferences between eastern and western interconnections. For Avista, NERC andWECC operating and planning criteria form the basis of how we coordinate ourtransmission system with neighboring utilities and how we study and evaluate the needfor transmission expansion. The WoH projects and their impact to the transmissionsystem were reviewed and approved by WECC subgroups.

ID Task Name Person Resp

0 West of Hatwai Projects1 Beacon-Rathdrum DC 230 kV Line (ER 255)

2 Transmission Line

3 Engineering

4 RFP Bid Package for Constructi

5 Evaluation & Award Contract

6 Material Acquisition

7 Construction

8 Marshalling Yards

9 Access Roads

10 Foundations

11 Structure Installation

12 Remove 230 kV Line

13 Conductor Installation

14 Energize 3-Terminal Line

15 Test & Commission

16 Rathdrum Substation

17 Engineering

18 Physical Drawings

19 Electrical Drawings


21 Construction

22 Grading/Fencing

23 Mechanical / Structural

24 Relay / Electrical

25 Communications Hardware

26 Energize 3-Terminal Line


28 Beacon Relay Upgrades

29 Protective Relay DSN



32 R-428 Auxillary Breaker

33 R-424 Rathdrum Breaker

34 R-432 Otis Orchards Breaker


36 Cabinet Relay Upgrade




40 R-322 Rathdrum Breaker


42 Pine Creek Substation 230 kV Rebuild (ER 8

43 230 kV Substation

44 Construction

45 Mechanical / Structural Ph 2 & 3



48 Cutover Noxon & Benewah Line

49 Energize Autotransformers & Au

50 Benewah Relay Upgrades

51 Material Acquistion


53 R-390 Auxillary Breaker

54 R-355 Pinecreek Breaker

55 Beacon-Bell #4 230 kV Reconductor (ER E0

56 Transmission Design


58 Line Construction

59 Beacon Relay Upgrade


61 Communication DSN



64 Install Comm Hardware

65 R-429 Bell #4 Breaker

11%

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Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov DecQtr 1, 2003 Qtr 2, 2003 Qtr 3, 2003 Qtr 4, 2003 Qtr 1, 2004 Qtr 2, 2004 Qtr 3, 2004 Qtr 4, 2004

Critical

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West of Hatwai Schedule - Last Updated Tue 4/15/03

Page 1 Printed on Tue 4/15/03

Project: West of Hatwai ProjectsDate: Tue 4/15/03


66 Beacon-Bell #5 230 kV Reconductor (ERE07




70 Beacon Relay Upgrade





75 Install Comm Hardware

76 R-420 Bell #5 Breaker

77 Dry Creek Substation (ER271)


79 Engineering

80 Final Project Diagram

81 Relay Protection Plan

82 Substation Automation DSN

83 RFP Bid Package Release

84 Bid Evaluation & Award Contrac

85 Permitting

86 EMTP Study





91 Construction

92 Grading/Fencing


94 Electrical / Relay

95 Install Communication Hardware

96 Cutover 3- 230 kV Lines


98 Landscaping

99 L/C Area Fiber Optic Study

100 Dry Creek- North Lewiston 230 kV Line

101 Thermal Uprate Study

102 Structure Modifications

103 Hatwai - Lolo 230 kV Line Reconductor



106 Structure Reinforcement


108 Hatwai - N. Lewiston 230 kV Line Recon



111 Structure Reinforcement


113 North Lewiston - Pound Lane 115 kV Lo

114 Engineering

115 Construction

116 Lolo Substation Hatwai Breaker & 230 k

117 Engineering






123 Construction





128 North Lewiston Relay Upgrade




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Project Summary

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Deadline







134 R-413 Dry Creek Breaker


136 North Lewiston Spare Auto Transforme







143 Boulder 230 kV Substation (ER 948)


145 Engineering


147 Relay Protection DSN


149 Pre Application Permitting Meeti

150 Release RFP Bid Package

151 Bid Evaluation & Award Contrac

152 Permitting



155 Communications DSN


157 Construction

158 Grading/Fencing





163 Landscaping

164 Boulder 230 kV Loop

165 Public Process

166 Announce Route Decision

167 Preliminary Engineering

168 Right of Way Acquisition


170 Final Design

171 Construction


173 Benewah - Shawnee 230 kV Line (ER 594)

174 Benewah Substation

175 Engineering


177 Permitting

178 EMTP Study







185 Construction

186 Grading/Fencing



189 Communications Install


191 Shawnee Substation

192 Engineering






0%

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198 Construction




202 Moscow Relay Upgrade






208 R-373 Benewah Breaker

209 Transmission Line

210 Engineering

211 RFP Bid Package

212 Evaluation & Award Contract

213 Preliminary Route Alternatives

214 Preliminary Survey and Mapping

215 Conceptual Design

216 Detail Survey & Mapping

217 Final Design

218 Release Construction Bid Pck

219 Bid Evaluation & Award Constru


221 Public Process

222 Information Packet

223 Identify Stakeholders

224 Notification of Key Stakeholders

225 Announce Project

226 Public Meetings

227 Announce Routing

228 Environmental & Permitting

229 Preliminary Agency Meetings

230 SEPA & Permit Appl

231 EA/EIS

232 Final Permits

233 R/W Acquisition

234 First Owner Contact

235 Prep Easment Documents

236 R/W Negotiation

237 Condemnation - Need & Necess

238 Condemnation Valuation

239 Construction Access Plan

240 Construction

241 Marshalling Yards

242 Access Roads

243 Foundations

244 Structure Installation



247 NW-Westside 115 Reconductor (ER249)




251 Nez Perce Substation Capacitors (actual sta

252 Engineering

253 EMTP Study




257 Construction




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Rolled Up Baseline


Rolled Up Milestone

External Tasks

Project Summary

External Milestone

Deadline


