200207182002 IRP Appendix.pdf

Idaho Power Company

2002 Integrated Resource Plan

Technical Appendix

Idaho Power Company
2002 Integrated Resource Plan
Technical Appendix

Table Of Contents

Sales and Load Forecast ..................................................................................................................3
Expected Load Forecast.........................................................................................................4
70th Percentile Load Forecast...............................................................................................15
Existing Resource Data..................................................................................................................27
Hydroelectric Plant Data......................................................................................................28
Thermal Plant Data ..............................................................................................................29
Surplus/Deficiency ..............................................................................................................30
50th Percentile Water – 50th Percentile Loads............................................................30
70th Percentile Water – 70th Percentile Loads............................................................33
90th Percentile Water – 70th Percentile Loads............................................................36
Electric Price Forecast .........................................................................................................39
Gas Price Forecast ...............................................................................................................42
2002 IRP 10 Year Plan Costs ..............................................................................................43
QF Project Data ...................................................................................................................44
Assumptions Used to Price Resource Alternatives ..............................................................45
Distributed Generation Report.............................................................................................47
Principle IRP Distribution List ......................................................................................................53

3

Expected Load Forecast

70th Percentile Load Forecast

SALES AND LOAD FORECASTS

4
Description: 2002 Expected Forecast

SALES & LOAD REPORT

Jan. 2002 Feb. 2002 Mar. 2002 Apr. 2002 May. 2002 Jun. 2002 Jul. 2002 Aug. 2002 Sep. 2002 Oct. 2002 Nov. 2002 Dec. 2002

Average Load (Average Megawatts)

Residential 678 620 544 462 397 395 437 428 388 421 545 678
Commercial 420 408 390 381 383 396 415 418 411 402 413 439
Irrigation 1 1 8 110 294 499 569 429 256 89 8 1
Industrial 250 253 257 257 256 257 265 265 270 276 277 277
Micron 76 76 77 76 79 83 87 88 88 88 88 86
Simplot 32 33 30 32 32 23 32 33 33 32 33 33
Weiser 7 7 6 5 5 5 6 6 5 6 6 7
Raft River Rural Electric Coop. 7 8 7 6 6 6 6 6 6 5 6 7
INEEL 29 28 26 23 22 21 21 22 20 24 28 30
Loss 152 138 123 118 130 166 198 181 148 127 136 157
FIRM LOAD 1,652 1,571 1,467 1,471 1,601 1,852 2,034 1,876 1,625 1,469 1,540 1,715

Fmc First Block 5 10 10 10 10 10 10 10 10 10 10 10
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 1 1 1 1 1 1 1 1 1 1 1
Fmc Load 5 11 11 11 11 11 11 11 11 11 11 11
SYSTEM LOAD 1,657 1,581 1,477 1,482 1,612 1,863 2,045 1,886 1,636 1,480 1,551 1,726

Firm Off-System Load 47 27 23 38 43 57 78 78 70 30 26 42
TOTAL LOAD 1,704 1,608 1,500 1,520 1,655 1,920 2,123 1,965 1,705 1,510 1,577 1,768

Peak Load (Megawatts)

FIRM PEAK LOAD 2,357 2,224 2,072 1,890 2,234 2,751 2,902 2,614 2,245 1,977 2,152 2,514

Fmc Peak 5 10 10 10 10 10 10 10 10 10 10 10
Loss 0 1 1 1 1 1 1 1 1 1 1 1
SYSTEM PEAK (1 HOUR) 2,362 2,234 2,083 1,900 2,245 2,762 2,913 2,625 2,256 1,988 2,163 2,524

Firm Off-System Peak 60 35 29 49 58 81 96 96 96 38 33 53
Loss 2 1 1 2 2 3 4 4 4 2 1 2
TOTAL PEAK LOAD 2,425 2,271 2,113 1,951 2,305 2,846 3,013 2,725 2,356 2,027 2,197 2,580

5
Description: 2002 Expected Forecast

SALES & LOAD REPORT

Jan. 2003 Feb. 2003 Mar. 2003 Apr. 2003 May. 2003 Jun. 2003 Jul. 2003 Aug. 2003 Sep. 2003 Oct. 2003 Nov. 2003 Dec. 2003

Average Load (Average Megawatts)

Residential 687 618 535 446 390 402 456 445 394 432 562 707
Commercial 440 422 400 386 394 416 443 446 426 416 430 467
Irrigation 1 1 8 115 306 519 592 447 266 92 8 1
Industrial 264 264 269 266 267 273 284 283 281 285 287 288
Micron 84 84 85 86 85 85 87 88 86 85 85 85
Simplot 32 34 30 32 32 24 33 33 33 32 33 34
Weiser 7 7 6 5 5 5 6 6 5 6 7 8
Raft River Rural Electric Coop. 7 8 7 6 6 6 6 6 6 6 6 7
INEEL 35 34 31 29 26 26 25 25 26 28 32 35
Loss 157 141 125 119 133 172 208 190 153 131 141 164
FIRM LOAD 1,715 1,611 1,495 1,490 1,644 1,927 2,140 1,969 1,676 1,514 1,591 1,795

Fmc First Block 10 10 10 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 1 1 1 0 0 0 0 0 0 0 0 0
Fmc Load 11 11 11 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 1,726 1,622 1,505 1,490 1,644 1,927 2,140 1,969 1,676 1,514 1,591 1,795

Firm Off-System Load 42 22 19 34 38 42 61 61 61 30 26 42
TOTAL LOAD 1,767 1,644 1,524 1,524 1,682 1,969 2,201 2,030 1,738 1,544 1,617 1,837

Peak Load (Megawatts)

FIRM PEAK LOAD 2,425 2,266 2,109 1,910 2,286 2,829 3,024 2,704 2,281 2,017 2,196 2,607

Fmc Peak 10 10 10 0 0 0 0 0 0 0 0 0
Loss 1 1 1 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,436 2,276 2,119 1,910 2,286 2,829 3,024 2,704 2,281 2,017 2,196 2,607

Firm Off-System Peak 53 28 23 43 48 53 78 78 78 38 33 53
Loss 2 1 1 2 2 2 3 3 3 2 1 2
TOTAL PEAK LOAD 2,491 2,306 2,143 1,955 2,336 2,884 3,105 2,785 2,362 2,056 2,230 2,662

6
Description: 2002 Expected Forecast

SALES & LOAD REPORT

Jan. 2004 Feb. 2004 Mar. 2004 Apr. 2004 May. 2004 Jun. 2004 Jul. 2004 Aug. 2004 Sep. 2004 Oct. 2004 Nov. 2004 Dec. 2004

Average Load (Average Megawatts)

Residential 723 653 568 479 425 439 485 468 417 443 562 727
Commercial 476 455 430 416 417 436 465 466 442 435 454 490
Irrigation 1 1 8 113 300 509 580 438 261 90 8 1
Industrial 276 275 277 272 273 279 291 289 288 292 294 295
Micron 86 86 87 88 88 87 89 90 88 87 87 87
Simplot 33 33 30 32 32 24 33 33 33 32 33 34
Weiser 7 7 6 5 5 5 6 6 6 6 7 8
Raft River Rural Electric Coop. 7 8 7 6 6 6 6 6 6 6 6 7
INEEL 38 35 33 31 28 28 27 27 28 30 34 37
Loss 166 149 132 126 138 178 214 195 158 135 144 170
FIRM LOAD 1,812 1,701 1,579 1,567 1,713 1,991 2,197 2,019 1,725 1,557 1,630 1,855

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 1,812 1,701 1,579 1,567 1,713 1,991 2,197 2,019 1,725 1,557 1,630 1,855

Firm Off-System Load 3 3 3 3 3 3 0 0 0 0 0 0
TOTAL LOAD 1,815 1,704 1,582 1,570 1,716 1,994 2,197 2,019 1,725 1,557 1,630 1,855

Peak Load (Megawatts)

FIRM PEAK LOAD 2,526 2,335 2,203 1,982 2,352 2,901 3,107 2,764 2,318 2,062 2,228 2,682

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,526 2,335 2,203 1,982 2,352 2,901 3,107 2,764 2,318 2,062 2,228 2,682

Firm Off-System Peak 3 3 3 3 3 3 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,529 2,338 2,206 1,985 2,355 2,904 3,107 2,764 2,318 2,062 2,228 2,682

7
Description: 2002 Expected Forecast

SALES & LOAD REPORT

Jan. 2005 Feb. 2005 Mar. 2005 Apr. 2005 May. 2005 Jun. 2005 Jul. 2005 Aug. 2005 Sep. 2005 Oct. 2005 Nov. 2005 Dec. 2005

Average Load (Average Megawatts)

Residential 756 683 590 498 451 472 523 503 446 473 599 752
Commercial 496 474 449 435 437 457 487 488 462 454 474 509
Irrigation 1 1 8 114 303 513 586 442 263 91 8 1
Industrial 282 281 283 278 279 285 297 296 294 299 301 301
Micron 89 89 90 91 91 90 92 93 91 90 90 90
Simplot 33 34 30 32 32 24 33 33 33 32 33 34
Weiser 8 7 6 5 5 6 6 6 6 6 7 8
Raft River Rural Electric Coop. 7 8 7 7 6 6 6 6 6 6 6 7
INEEL 38 37 33 31 28 28 27 27 28 30 34 37
Loss 173 155 137 130 144 185 222 203 164 141 151 175
FIRM LOAD 1,881 1,769 1,634 1,621 1,776 2,066 2,280 2,098 1,793 1,622 1,703 1,914

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 1,881 1,769 1,634 1,621 1,776 2,066 2,280 2,098 1,793 1,622 1,703 1,914

Firm Off-System Load 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL LOAD 1,881 1,769 1,634 1,621 1,776 2,066 2,280 2,098 1,793 1,622 1,703 1,914

Peak Load (Megawatts)

FIRM PEAK LOAD 2,608 2,407 2,268 2,033 2,414 2,977 3,209 2,844 2,354 2,122 2,292 2,754

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,608 2,407 2,268 2,033 2,414 2,977 3,209 2,844 2,354 2,122 2,292 2,754

Firm Off-System Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,608 2,407 2,268 2,033 2,414 2,977 3,209 2,844 2,354 2,122 2,292 2,754

8
Description: 2002 Expected Forecast

SALES & LOAD REPORT

Jan. 2006 Feb. 2006 Mar. 2006 Apr. 2006 May. 2006 Jun. 2006 Jul. 2006 Aug. 2006 Sep. 2006 Oct. 2006 Nov. 2006 Dec. 2006

Average Load (Average Megawatts)

Residential 769 695 600 507 461 485 538 518 456 482 609 765
Commercial 514 491 466 453 456 476 508 508 480 472 492 527
Irrigation 1 1 8 114 304 515 588 444 264 92 8 1
Industrial 287 287 289 284 285 291 304 302 300 305 307 307
Micron 92 92 93 94 94 93 96 97 94 93 93 94
Simplot 33 34 31 32 32 24 33 33 33 32 33 34
Weiser 8 7 6 5 5 6 6 6 6 6 7 8
Raft River Rural Electric Coop. 8 8 7 7 6 6 6 6 6 6 7 7
INEEL 38 37 33 31 28 28 27 27 28 30 34 37
Loss 177 159 140 133 147 189 228 208 168 144 155 180
FIRM LOAD 1,927 1,811 1,675 1,661 1,818 2,113 2,333 2,149 1,837 1,662 1,746 1,960

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 1,927 1,811 1,675 1,661 1,818 2,113 2,333 2,149 1,837 1,662 1,746 1,960

Firm Off-System Load 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL LOAD 1,927 1,811 1,675 1,661 1,818 2,113 2,333 2,149 1,837 1,662 1,746 1,960

Peak Load (Megawatts)

FIRM PEAK LOAD 2,658 2,448 2,316 2,070 2,462 3,037 3,286 2,904 2,388 2,160 2,328 2,809

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,658 2,448 2,316 2,070 2,462 3,037 3,286 2,904 2,388 2,160 2,328 2,809

Firm Off-System Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,658 2,448 2,316 2,070 2,462 3,037 3,286 2,904 2,388 2,160 2,328 2,809

9
Description: 2002 Expected Forecast

SALES & LOAD REPORT

Jan. 2007 Feb. 2007 Mar. 2007 Apr. 2007 May. 2007 Jun. 2007 Jul. 2007 Aug. 2007 Sep. 2007 Oct. 2007 Nov. 2007 Dec. 2007

Average Load (Average Megawatts)

Residential 782 707 610 516 471 497 554 532 467 490 620 777
Commercial 532 509 484 472 474 496 528 528 499 490 510 546
Irrigation 1 1 8 114 304 515 587 443 264 92 8 1
Industrial 293 293 295 290 290 297 309 308 306 311 313 313
Micron 95 95 96 97 97 96 98 100 97 96 96 96
Simplot 33 34 31 32 32 24 33 34 34 33 34 34
Weiser 8 7 6 5 5 6 6 6 6 6 7 8
Raft River Rural Electric Coop. 8 8 7 7 6 6 6 6 6 6 7 7
INEEL 38 37 33 31 28 28 27 27 28 30 34 37
Loss 181 163 144 136 150 193 233 213 172 148 159 184
FIRM LOAD 1,971 1,853 1,714 1,700 1,859 2,158 2,383 2,197 1,878 1,701 1,787 2,004

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 1,971 1,853 1,714 1,700 1,859 2,158 2,383 2,197 1,878 1,701 1,787 2,004

Firm Off-System Load 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL LOAD 1,971 1,853 1,714 1,700 1,859 2,158 2,383 2,197 1,878 1,701 1,787 2,004

Peak Load (Megawatts)

FIRM PEAK LOAD 2,706 2,487 2,362 2,106 2,507 3,094 3,359 2,960 2,420 2,197 2,363 2,861

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,706 2,487 2,362 2,106 2,507 3,094 3,359 2,960 2,420 2,197 2,363 2,861

Firm Off-System Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,706 2,487 2,362 2,106 2,507 3,094 3,359 2,960 2,420 2,197 2,363 2,861

10

Description: 2002 Expected Forecast

SALES & LOAD REPORT

Jan. 2008 Feb. 2008 Mar. 2008 Apr. 2008 May. 2008 Jun. 2008 Jul. 2008 Aug. 2008 Sep. 2008 Oct. 2008 Nov. 2008 Dec. 2008

Average Load (Average Megawatts)

Residential 793 716 618 524 480 509 568 545 475 497 628 786
Commercial 551 527 502 490 494 516 550 549 518 508 529 565
Irrigation 1 1 8 114 304 516 588 444 265 92 8 1
Industrial 299 298 301 295 296 303 315 314 312 317 319 319
Micron 97 97 98 99 99 98 101 102 100 98 98 99
Simplot 33 33 31 33 32 24 33 34 34 33 34 34
Weiser 8 7 6 5 5 6 6 6 6 6 7 8
Raft River Rural Electric Coop. 8 8 8 7 6 7 6 6 6 6 7 8
INEEL 38 35 33 31 28 28 27 27 28 30 34 37
Loss 185 166 147 140 154 198 237 217 176 151 163 188
FIRM LOAD 2,013 1,890 1,752 1,738 1,898 2,203 2,433 2,245 1,919 1,739 1,827 2,046

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 2,013 1,890 1,752 1,738 1,898 2,203 2,433 2,245 1,919 1,739 1,827 2,046

Firm Off-System Load 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL LOAD 2,013 1,890 1,752 1,738 1,898 2,203 2,433 2,245 1,919 1,739 1,827 2,046

Peak Load (Megawatts)

FIRM PEAK LOAD 2,752 2,521 2,406 2,141 2,551 3,150 3,430 3,015 2,451 2,232 2,397 2,911

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,752 2,521 2,406 2,141 2,551 3,150 3,430 3,015 2,451 2,232 2,397 2,911

Firm Off-System Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,752 2,521 2,406 2,141 2,551 3,150 3,430 3,015 2,451 2,232 2,397 2,911

11

Description: 2002 Expected Forecast

SALES & LOAD REPORT

Jan. 2009 Feb. 2009 Mar. 2009 Apr. 2009 May. 2009 Jun. 2009 Jul. 2009 Aug. 2009 Sep. 2009 Oct. 2009 Nov. 2009 Dec. 2009

Average Load (Average Megawatts)

Residential 801 724 625 530 487 519 581 556 483 503 635 794
Commercial 570 546 520 509 513 536 571 571 537 527 548 585
Irrigation 1 1 8 114 304 515 588 443 264 92 8 1
Industrial 305 304 306 301 302 309 322 320 318 323 325 325
Micron 100 100 101 102 101 101 103 105 102 101 101 101
Simplot 33 35 31 33 33 24 34 34 34 33 34 35
Weiser 8 7 6 5 5 6 7 6 6 6 7 8
Raft River Rural Electric Coop. 8 8 8 7 6 7 6 6 6 6 7 8
INEEL 38 37 33 31 28 28 27 27 28 30 34 37
Loss 189 170 150 143 157 201 242 222 179 155 166 191
FIRM LOAD 2,053 1,931 1,789 1,774 1,937 2,246 2,480 2,291 1,958 1,775 1,865 2,085

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 2,053 1,931 1,789 1,774 1,937 2,246 2,480 2,291 1,958 1,775 1,865 2,085

Firm Off-System Load 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL LOAD 2,053 1,931 1,789 1,774 1,937 2,246 2,480 2,291 1,958 1,775 1,865 2,085

Peak Load (Megawatts)

FIRM PEAK LOAD 2,795 2,560 2,449 2,175 2,593 3,202 3,498 3,067 2,480 2,267 2,429 2,958

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,795 2,560 2,449 2,175 2,593 3,202 3,498 3,067 2,480 2,267 2,429 2,958

Firm Off-System Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,795 2,560 2,449 2,175 2,593 3,202 3,498 3,067 2,480 2,267 2,429 2,958

12

Description: 2002 Expected Forecast

SALES & LOAD REPORT

Jan. 2010 Feb. 2010 Mar. 2010 Apr. 2010 May. 2010 Jun. 2010 Jul. 2010 Aug. 2010 Sep. 2010 Oct. 2010 Nov. 2010 Dec. 2010

Average Load (Average Megawatts)

Residential 808 730 630 534 493 528 593 567 489 508 640 801
Commercial 590 564 539 529 533 557 593 592 557 546 567 605
Irrigation 1 1 8 114 304 515 588 444 264 92 8 1
Industrial 311 310 312 307 308 315 328 326 324 329 332 332
Micron 102 102 103 104 104 103 105 107 104 103 103 103
Simplot 34 35 31 33 33 24 34 34 34 33 34 35
Weiser 8 8 6 6 5 6 7 7 6 6 7 8
Raft River Rural Electric Coop. 8 9 8 7 6 7 6 6 6 6 7 8
INEEL 38 37 33 31 28 28 27 27 28 30 34 37
Loss 193 173 153 145 160 205 247 226 183 158 169 195
FIRM LOAD 2,091 1,967 1,823 1,810 1,975 2,288 2,528 2,336 1,997 1,811 1,902 2,125

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 2,091 1,967 1,823 1,810 1,975 2,288 2,528 2,336 1,997 1,811 1,902 2,125

Firm Off-System Load 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL LOAD 2,091 1,967 1,823 1,810 1,975 2,288 2,528 2,336 1,997 1,811 1,902 2,125

Peak Load (Megawatts)

FIRM PEAK LOAD 2,837 2,594 2,491 2,208 2,633 3,253 3,563 3,119 2,508 2,301 2,462 3,008

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,837 2,594 2,491 2,208 2,633 3,253 3,563 3,119 2,508 2,301 2,462 3,008

Firm Off-System Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,837 2,594 2,491 2,208 2,633 3,253 3,563 3,119 2,508 2,301 2,462 3,008

13

Description: 2002 Expected Forecast

SALES & LOAD REPORT

Jan. 2011 Feb. 2011 Mar. 2011 Apr. 2011 May. 2011 Jun. 2011 Jul. 2011 Aug. 2011 Sep. 2011 Oct. 2011 Nov. 2011 Dec. 2011

Average Load (Average Megawatts)

Residential 815 736 635 539 500 538 605 577 496 512 646 809
Commercial 610 583 558 549 554 579 616 615 577 565 587 625
Irrigation 1 1 8 114 304 516 589 444 265 92 8 1
Industrial 317 317 319 313 314 321 335 333 331 336 339 339
Micron 104 104 105 106 106 105 107 109 106 105 105 105
Simplot 34 35 31 33 33 24 34 34 34 33 34 35
Weiser 8 8 7 6 5 6 7 7 6 6 7 8
Raft River Rural Electric Coop. 8 9 8 7 7 7 6 7 6 6 7 8
INEEL 38 37 33 31 28 28 27 27 28 30 34 37
Loss 196 176 156 148 163 209 252 231 187 161 173 199
FIRM LOAD 2,130 2,004 1,860 1,847 2,014 2,333 2,578 2,385 2,037 1,848 1,941 2,166

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 2,130 2,004 1,860 1,847 2,014 2,333 2,578 2,385 2,037 1,848 1,941 2,166

Firm Off-System Load 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL LOAD 2,130 2,004 1,860 1,847 2,014 2,333 2,578 2,385 2,037 1,848 1,941 2,166

Peak Load (Megawatts)

FIRM PEAK LOAD 2,882 2,631 2,536 2,243 2,674 3,304 3,630 3,170 2,534 2,337 2,494 3,059

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,882 2,631 2,536 2,243 2,674 3,304 3,630 3,170 2,534 2,337 2,494 3,059

Firm Off-System Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,882 2,631 2,536 2,243 2,674 3,304 3,630 3,170 2,534 2,337 2,494 3,059

14

Description: 2002 Expected Forecast
SALES & LOAD REPORT

2002 2003 2004 2005 2006 2007 2008 2009 2010 2011

Average Load (Average Megawatts)

Residential 499 506 532 562 573 585 595 603 610 617
Commercial 406 424 449 468 487 506 525 545 565 585
Irrigation 190 198 193 195 196 196 196 196 196 197
Industrial 263 276 284 290 296 301 307 313 320 326
Micron 83 85 87 91 94 97 99 101 103 105
Simplot 32 32 32 32 32 32 32 33 33 33
Weiser 6 6 6 6 6 6 6 7 7 7
Raft River Rural Electric Coop. 6 6 6 7 7 7 7 7 7 7
INEEL 24 29 31 32 32 32 31 32 32 32
Loss 148 153 159 165 169 173 177 181 184 188
FIRM LOAD 1,657 1,715 1,780 1,848 1,892 1,935 1,976 2,017 2,056 2,097

Fmc First Block 10 2 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0
Loss 1 0 0 0 0 0 0 0 0 0
Fmc Load 10 3 0 0 0 0 0 0 0 0
SYSTEM LOAD 1,667 1,718 1,780 1,848 1,892 1,935 1,976 2,017 2,056 2,097

Firm Off-System Load 47 40 2 0 0 0 0 0 0 0
TOTAL LOAD 1,714 1,758 1,781 1,848 1,892 1,935 1,976 2,017 2,056 2,097

Peak Load (Megawatts)

FIRM PEAK LOAD 2,902 3,024 3,107 3,209 3,286 3,359 3,430 3,498 3,563 3,630

Fmc Peak 10 0 0 0 0 0 0 0 0 0
Loss 1 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,913 3,024 3,107 3,209 3,286 3,359 3,430 3,498 3,563 3,630

Firm Off-System Peak 96 78 0 0 0 0 0 0 0 0
Loss 4 3 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 3,013 3,105 3,107 3,209 3,286 3,359 3,430 3,498 3,563 3,630

Description: 2002 70th Percentile Forecast

SALES & LOAD REPORT

Jan. 2002 Feb. 2002 Mar. 2002 Apr. 2002 May. 2002 Jun. 2002 Jul. 2002 Aug. 2002 Sep. 2002 Oct. 2002 Nov. 2002 Dec. 2002

Average Load (Average Megawatts)

Residential 696 636 559 473 406 408 447 439 401 432 557 699
Commercial 427 414 395 385 386 399 417 422 416 406 417 446
Irrigation 1 1 17 151 341 539 592 445 272 98 9 1
Industrial 250 253 257 257 256 257 265 265 270 276 277 277
Micron 76 76 77 76 79 83 87 88 88 88 88 86
Simplot 32 33 30 32 32 23 32 33 33 32 33 33
Weiser 7 7 6 5 5 5 6 6 5 6 6 7
Raft River Rural Electric Coop. 7 8 7 6 6 6 6 6 6 5 6 7
INEEL 29 28 26 23 22 21 21 22 20 24 28 30
Loss 155 140 126 124 135 172 203 185 152 130 138 160
FIRM LOAD 1,680 1,596 1,498 1,531 1,667 1,915 2,075 1,909 1,664 1,497 1,559 1,745

Fmc First Block 5 10 10 10 10 10 10 10 10 10 10 10
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 1 1 1 1 1 1 1 1 1 1 1
Fmc Load 5 11 11 11 11 11 11 11 11 11 11 11
SYSTEM LOAD 1,685 1,606 1,509 1,542 1,677 1,926 2,085 1,919 1,675 1,508 1,569 1,756

Firm Off-System Load 47 27 23 38 43 57 78 78 70 30 26 42
TOTAL LOAD 1,732 1,633 1,531 1,580 1,721 1,983 2,163 1,998 1,744 1,538 1,596 1,797

Peak Load (Megawatts)

FIRM PEAK LOAD 2,441 2,384 2,184 1,953 2,302 2,828 2,969 2,658 2,283 2,022 2,302 2,619

Fmc Peak 5 10 10 10 10 10 10 10 10 10 10 10
Loss 0 1 1 1 1 1 1 1 1 1 1 1
SYSTEM PEAK (1 HOUR) 2,446 2,395 2,195 1,964 2,313 2,839 2,979 2,669 2,294 2,033 2,313 2,630

Firm Off-System Peak 60 35 29 49 58 81 96 96 96 38 33 53
Loss 2 1 1 2 2 3 4 4 4 2 1 2
TOTAL PEAK LOAD 2,509 2,431 2,225 2,015 2,373 2,923 3,079 2,769 2,394 2,072 2,347 2,685

Description: 2002 70th Percentile Forecast

SALES & LOAD REPORT

Jan. 2003 Feb. 2003 Mar. 2003 Apr. 2003 May. 2003 Jun. 2003 Jul. 2003 Aug. 2003 Sep. 2003 Oct. 2003 Nov. 2003 Dec. 2003

Average Load (Average Megawatts)

Residential 707 635 550 457 401 415 467 457 409 444 574 727
Commercial 447 428 404 389 397 419 446 449 431 421 434 474
Irrigation 1 1 17 155 353 560 615 463 282 102 9 1
Industrial 264 264 269 266 267 273 284 283 281 285 287 288
Micron 84 84 85 86 85 85 87 88 86 85 85 85
Simplot 32 34 30 32 32 24 33 33 33 32 33 34
Weiser 7 7 6 5 5 5 6 6 5 6 7 8
Raft Rive r Rural Electric Coop. 7 8 7 6 6 6 6 6 6 6 6 7
INEEL 35 34 31 29 26 26 25 25 26 28 32 35
Loss 160 143 127 124 138 179 213 194 157 134 143 167
FIRM LOAD 1,744 1,637 1,526 1,550 1,710 1,991 2,181 2,003 1,716 1,542 1,610 1,826

Fmc First Block 10 10 10 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 1 1 1 0 0 0 0 0 0 0 0 0
Fmc Load 11 11 11 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 1,755 1,647 1,537 1,550 1,710 1,991 2,181 2,003 1,716 1,542 1,610 1,826

Firm Off-System Load 42 22 19 34 38 42 61 61 61 30 26 42
TOTAL LOAD 1,797 1,670 1,555 1,584 1,748 2,033 2,242 2,064 1,777 1,572 1,636 1,867

Peak Load (Megawatts)

FIRM PEAK LOAD 2,511 2,429 2,223 1,973 2,355 2,908 3,092 2,750 2,320 2,062 2,348 2,714

Fmc Peak 10 10 10 0 0 0 0 0 0 0 0 0
Loss 1 1 1 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,522 2,440 2,233 1,973 2,355 2,908 3,092 2,750 2,320 2,062 2,348 2,714

Firm Off-System Peak 53 28 23 43 48 53 78 78 78 38 33 53
Loss 2 1 1 2 2 2 3 3 3 2 1 2
TOTAL PEAK LOAD 2,577 2,469 2,257 2,018 2,405 2,963 3,173 2,831 2,401 2,101 2,382 2,769

Description: 2002 70th Percentile Forecast

SALES & LOAD REPORT

Jan. 2004 Feb. 2004 Mar. 2004 Apr. 2004 May. 2004 Jun. 2004 Jul. 2004 Aug. 2004 Sep. 2004 Oct. 2004 Nov. 2004 Dec. 2004

Average Load (Average Megawatts)

Residential 743 671 584 490 436 453 497 480 431 455 574 748
Commercial 482 461 435 419 420 440 469 470 448 439 458 497
Irrigation 1 1 17 153 347 549 603 454 277 100 9 1
Industrial 276 275 277 272 273 279 291 289 288 292 294 295
Micron 86 86 87 88 88 87 89 90 88 87 87 87
Simplot 33 33 30 32 32 24 33 33 33 32 33 34
Weiser 7 7 6 5 5 5 6 6 6 6 7 8
Raft River Rural Electric Coop. 7 8 7 6 6 6 6 6 6 6 6 7
INEEL 38 35 33 31 28 28 27 27 28 30 34 37
Loss 169 152 135 131 144 185 218 199 162 138 146 173
FIRM LOAD 1,842 1,728 1,611 1,628 1,779 2,056 2,238 2,054 1,765 1,585 1,649 1,887

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 1,842 1,728 1,611 1,628 1,779 2,056 2,238 2,054 1,765 1,585 1,649 1,887

Firm Off-System Load 3 3 3 3 3 3 0 0 0 0 0 0
TOTAL LOAD 1,845 1,731 1,614 1,631 1,782 2,059 2,238 2,054 1,765 1,585 1,649 1,887

Peak Load (Megawatts)

FIRM PEAK LOAD 2,613 2,501 2,318 2,046 2,422 2,981 3,175 2,811 2,358 2,107 2,382 2,790

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,613 2,501 2,318 2,046 2,422 2,981 3,175 2,811 2,358 2,107 2,382 2,790

Firm Off-System Peak 3 3 3 3 3 3 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,616 2,504 2,321 2,049 2,425 2,984 3,175 2,811 2,358 2,107 2,382 2,790

Description: 2002 70th Percentile Forecast

SALES & LOAD REPORT

Jan. 2005 Feb. 2005 Mar. 2005 Apr. 2005 May. 2005 Jun. 2005 Jul. 2005 Aug. 2005 Sep. 2005 Oct. 2005 Nov. 2005 Dec. 2005

Average Load (Average Megawatts)

Residential 776 701 606 510 462 486 535 516 461 485 611 773
Commercial 503 480 454 438 440 461 490 491 468 459 478 516
Irrigation 1 1 17 154 350 554 608 458 279 101 9 1
Industrial 282 281 283 278 279 285 297 296 294 299 301 301
Micron 89 89 90 91 91 90 92 93 91 90 90 90
Simplot 33 34 30 32 32 24 33 33 33 32 33 34
Weiser 8 7 6 5 5 6 6 6 6 6 7 8
Raft River Rural Electric Coop. 7 8 7 7 6 6 6 6 6 6 6 7
INEEL 38 37 33 31 28 28 27 27 28 30 34 37
Loss 176 158 140 135 150 191 227 207 168 144 153 179
FIRM LOAD 1,912 1,796 1,666 1,682 1,843 2,131 2,322 2,134 1,834 1,651 1,723 1,946

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 1,912 1,796 1,666 1,682 1,843 2,131 2,322 2,134 1,834 1,651 1,723 1,946

Firm Off-System Load 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL LOAD 1,912 1,796 1,666 1,682 1,843 2,131 2,322 2,134 1,834 1,651 1,723 1,946

Peak Load (Megawatts)

FIRM PEAK LOAD 2,697 2,575 2,385 2,097 2,485 3,058 3,279 2,892 2,395 2,169 2,448 2,864

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,697 2,575 2,385 2,097 2,485 3,058 3,279 2,892 2,395 2,169 2,448 2,864

Firm Off-System Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,697 2,575 2,385 2,097 2,485 3,058 3,279 2,892 2,395 2,169 2,448 2,864

Description: 2002 70th Percentile Forecast

SALES & LOAD REPORT

Jan. 2006 Feb. 2006 Mar. 2006 Apr. 2006 May. 2006 Jun. 2006 Jul. 2006 Aug. 2006 Sep. 2006 Oct. 2006 Nov. 2006 Dec. 2006

Average Load (Average Megawatts)

Residential 790 713 616 520 473 500 551 531 472 493 622 787
Commercial 521 498 471 456 459 480 511 512 486 477 496 535
Irrigation 1 1 17 154 351 556 610 459 280 101 9 1
Industrial 287 287 289 284 285 291 304 302 300 305 307 307
Micron 92 92 93 94 94 93 96 97 94 93 93 94
Simplot 33 34 31 32 32 24 33 33 33 32 33 34
Weiser 8 7 6 5 5 6 6 6 6 6 7 8
Raft River Rural Electric Coop. 8 8 7 7 6 6 6 6 6 6 7 7
INEEL 38 37 33 31 28 28 27 27 28 30 34 37
Loss 180 162 143 139 153 196 232 212 172 147 157 183
FIRM LOAD 1,958 1,839 1,707 1,723 1,886 2,180 2,376 2,186 1,878 1,691 1,766 1,993

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 1,958 1,839 1,707 1,723 1,886 2,180 2,376 2,186 1,878 1,691 1,766 1,993

Firm Off-System Load 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL LOAD 1,958 1,839 1,707 1,723 1,886 2,180 2,376 2,186 1,878 1,691 1,766 1,993

Peak Load (Megawatts)

FIRM PEAK LOAD 2,748 2,618 2,434 2,135 2,534 3,120 3,358 2,952 2,430 2,207 2,486 2,921

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,748 2,618 2,434 2,135 2,534 3,120 3,358 2,952 2,430 2,207 2,486 2,921

Firm Off-System Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,748 2,618 2,434 2,135 2,534 3,120 3,358 2,952 2,430 2,207 2,486 2,921

Description: 2002 70th Percentile Forecast

SALES & LOAD REPORT

Jan. 2007 Feb. 2007 Mar. 2007 Apr. 2007 May. 2007 Jun. 2007 Jul. 2007 Aug. 2007 Sep. 2007 Oct. 2007 Nov. 2007 Dec. 2007

Average Load (Average Megawatts)

Residential 804 725 627 529 483 513 567 546 482 502 633 799
Commercial 540 516 489 475 478 500 532 532 505 495 515 554
Irrigation 1 1 17 154 351 556 610 459 280 101 9 1
Industrial 293 293 295 290 290 297 309 308 306 311 313 313
Micron 95 95 96 97 97 96 98 100 97 96 96 96
Simplot 33 34 31 32 32 24 33 34 34 33 34 34
Weiser 8 7 6 5 5 6 6 6 6 6 7 8
Raft River Rural Electric Coop. 8 8 7 7 6 6 6 6 6 6 7 7
INEEL 38 37 33 31 28 28 27 27 28 30 34 37
Loss 185 165 147 142 156 200 237 217 176 151 161 187
FIRM LOAD 2,003 1,881 1,748 1,762 1,927 2,225 2,427 2,234 1,920 1,731 1,808 2,037

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 2,003 1,881 1,748 1,762 1,927 2,225 2,427 2,234 1,920 1,731 1,808 2,037

Firm Off-System Load 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL LOAD 2,003 1,881 1,748 1,762 1,927 2,225 2,427 2,234 1,920 1,731 1,808 2,037

Peak Load (Megawatts)

FIRM PEAK LOAD 2,798 2,660 2,482 2,172 2,580 3,179 3,432 3,010 2,463 2,244 2,523 2,974

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,798 2,660 2,482 2,172 2,580 3,179 3,432 3,010 2,463 2,244 2,523 2,974

Firm Off-System Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,798 2,660 2,482 2,172 2,580 3,179 3,432 3,010 2,463 2,244 2,523 2,974

Description: 2002 70th Percentile Forecast

SALES & LOAD REPORT

Jan. 2008 Feb. 2008 Mar. 2008 Apr. 2008 May. 2008 Jun. 2008 Jul. 2008 Aug. 2008 Sep. 2008 Oct. 2008 Nov. 2008 Dec. 2008

Average Load (Average Megawatts)

Residential 814 735 635 537 492 525 582 559 491 510 641 809
Commercial 559 534 507 494 497 520 553 553 524 513 534 573
Irrigation 1 1 17 154 351 556 611 459 280 101 9 1
Industrial 299 298 301 295 296 303 315 314 312 317 319 319
Micron 97 97 98 99 99 98 101 102 100 98 98 99
Simplot 33 33 31 33 32 24 33 34 34 33 34 34
Weiser 8 7 6 5 5 6 6 6 6 6 7 8
Raft River Rural Electric Coop. 8 8 8 7 6 7 6 6 6 6 7 8
INEEL 38 35 33 31 28 28 27 27 28 30 34 37
Loss 189 169 150 145 160 204 242 221 180 154 165 191
FIRM LOAD 2,045 1,918 1,786 1,800 1,968 2,271 2,477 2,283 1,961 1,769 1,848 2,079

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 2,045 1,918 1,786 1,800 1,968 2,271 2,477 2,283 1,961 1,769 1,848 2,079

Firm Off-System Load 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL LOAD 2,045 1,918 1,786 1,800 1,968 2,271 2,477 2,283 1,961 1,769 1,848 2,079

Peak Load (Megawatts)

FIRM PEAK LOAD 2,845 2,696 2,528 2,207 2,624 3,235 3,504 3,065 2,494 2,280 2,559 3,026

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,845 2,696 2,528 2,207 2,624 3,235 3,504 3,065 2,494 2,280 2,559 3,026

Firm Off-System Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,845 2,696 2,528 2,207 2,624 3,235 3,504 3,065 2,494 2,280 2,559 3,026

Description: 2002 70th Percentile Forecast

SALES & LOAD REPORT

Jan. 2009 Feb. 2009 Mar. 2009 Apr. 2009 May. 2009 Jun. 2009 Jul. 2009 Aug. 2009 Sep. 2009 Oct. 2009 Nov. 2009 Dec. 2009

Average Load (Average Megawatts)

Residential 823 743 642 543 500 537 595 571 500 516 649 817
Commercial 578 553 526 513 517 541 575 575 544 532 553 593
Irrigation 1 1 17 154 351 556 610 459 280 101 9 1
Industrial 305 304 306 301 302 309 322 320 318 323 325 325
Micron 100 100 101 102 101 101 103 105 102 101 101 101
Simplot 33 35 31 33 33 24 34 34 34 33 34 35
Weiser 8 7 6 5 5 6 7 6 6 6 7 8
Raft River Rural Electric Coop. 8 8 8 7 6 7 6 6 6 6 7 8
INEEL 38 37 33 31 28 28 27 27 28 30 34 37
Loss 192 172 153 148 163 208 247 226 184 158 168 195
FIRM LOAD 2,086 1,960 1,823 1,837 2,007 2,314 2,526 2,330 2,001 1,806 1,887 2,120

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 2,086 1,960 1,823 1,837 2,007 2,314 2,526 2,330 2,001 1,806 1,887 2,120

Firm Off-System Load 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL LOAD 2,086 1,960 1,823 1,837 2,007 2,314 2,526 2,330 2,001 1,806 1,887 2,120

Peak Load (Megawatts)

FIRM PEAK LOAD 2,889 2,737 2,572 2,241 2,667 3,289 3,573 3,119 2,524 2,315 2,594 3,075

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,889 2,737 2,572 2,241 2,667 3,289 3,573 3,119 2,524 2,315 2,594 3,075

Firm Off-System Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,889 2,737 2,572 2,241 2,667 3,289 3,573 3,119 2,524 2,315 2,594 3,075

Description: 2002 70th Percentile Forecast

SALES & LOAD REPORT

Jan. 2010 Feb. 2010 Mar. 2010 Apr. 2010 May. 2010 Jun. 2010 Jul. 2010 Aug. 2010 Sep. 2010 Oct. 2010 Nov. 2010 Dec. 2010

Average Load (Average Megawatts)

Residential 830 749 647 548 507 546 607 582 507 521 654 824
Commercial 598 571 544 532 537 562 597 596 564 551 572 613
Irrigation 1 1 17 154 351 556 610 459 280 101 9 1
Industrial 311 310 312 307 308 315 328 326 324 329 332 332
Micron 102 102 103 104 104 103 105 107 104 103 103 103
Simplot 34 35 31 33 33 24 34 34 34 33 34 35
Weiser 8 8 6 6 5 6 7 7 6 6 7 8
Raft River Rural Electric Coop. 8 9 8 7 6 7 6 6 6 6 7 8
INEEL 38 37 33 31 28 28 27 27 28 30 34 37
Loss 196 176 156 151 166 212 252 231 188 161 172 199
FIRM LOAD 2,124 1,996 1,858 1,873 2,045 2,358 2,573 2,376 2,040 1,841 1,924 2,160

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 2,124 1,996 1,858 1,873 2,045 2,358 2,573 2,376 2,040 1,841 1,924 2,160

Firm Off-System Load 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL LOAD 2,124 1,996 1,858 1,873 2,045 2,358 2,573 2,376 2,040 1,841 1,924 2,160

Peak Load (Megawatts)

FIRM PEAK LOAD 2,932 2,774 2,615 2,275 2,709 3,341 3,640 3,171 2,552 2,350 2,627 3,125

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,932 2,774 2,615 2,275 2,709 3,341 3,640 3,171 2,552 2,350 2,627 3,125

Firm Off-System Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,932 2,774 2,615 2,275 2,709 3,341 3,640 3,171 2,552 2,350 2,627 3,125

Description: 2002 70th Percentile Forecast

SALES & LOAD REPORT

Jan. 2011 Feb. 2011 Mar. 2011 Apr. 2011 May. 2011 Jun. 2011 Jul. 2011 Aug. 2011 Sep. 2011 Oct. 2011 Nov. 2011 Dec. 2011

Average Load (Average Megawatts)

Residential 838 756 653 554 514 556 620 594 514 526 660 832
Commercial 618 591 563 553 558 583 620 619 584 571 592 633
Irrigation 1 1 17 155 352 557 611 460 280 101 9 1
Industrial 317 317 319 313 314 321 335 333 331 336 339 339
Micron 104 104 105 106 106 105 107 109 106 105 105 105
Simplot 34 35 31 33 33 24 34 34 34 33 34 35
Weiser 8 8 7 6 5 6 7 7 6 6 7 8
Raft River Rural Electric Coop. 8 9 8 7 7 7 6 7 6 6 7 8
INEEL 38 37 33 31 28 28 27 27 28 30 34 37
Loss 200 179 159 154 170 216 257 235 191 164 175 203
FIRM LOAD 2,164 2,034 1,895 1,911 2,085 2,404 2,624 2,425 2,082 1,879 1,963 2,202

Fmc First Block 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
Fmc Load 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM LOAD 2,164 2,034 1,895 1,911 2,085 2,404 2,624 2,425 2,082 1,879 1,963 2,202

Firm Off-System Load 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL LOAD 2,164 2,034 1,895 1,911 2,085 2,404 2,624 2,425 2,082 1,879 1,963 2,202

Peak Load (Megawatts)

FIRM PEAK LOAD 2,977 2,812 2,660 2,310 2,751 3,394 3,707 3,223 2,579 2,386 2,663 3,179

Fmc Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,977 2,812 2,660 2,310 2,751 3,394 3,707 3,223 2,579 2,386 2,663 3,179

Firm Off-System Peak 0 0 0 0 0 0 0 0 0 0 0 0
Loss 0 0 0 0 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 2,977 2,812 2,660 2,310 2,751 3,394 3,707 3,223 2,579 2,386 2,663 3,179

Description: 2002 70th Percentile Forecast
SALES & LOAD REPORT

2002 2003 2004 2005 2006 2007 2008 2009 2010 2011

Average Load (Average Megawatts)

Residential 512 520 547 577 589 601 611 619 627 634
Commercial 411 428 453 473 492 511 530 550 570 591
Irrigation 207 214 210 212 213 213 212 213 213 213
Industrial 263 276 284 290 296 301 307 313 320 326
Micron 83 85 87 91 94 97 99 101 103 105
Simplot 32 32 32 32 32 32 32 33 33 33
Weiser 6 6 6 6 6 6 6 7 7 7
Raft Rive r Rural Electric Coop.6 6 6 7 7 7 7 7 7 7
INEEL 24 29 31 32 32 32 31 32 32 32
Loss 152 157 163 169 173 177 181 185 188 192
FIRM LOAD 1,696 1,754 1,819 1,888 1,933 1,976 2,018 2,059 2,099 2,140

Fmc First Block 10 2 0 0 0 0 0 0 0 0
Fmc Second Block 0 0 0 0 0 0 0 0 0 0
Loss 1 0 0 0 0 0 0 0 0 0
Fmc Load 10 3 0 0 0 0 0 0 0 0
SYSTEM LOAD 1,706 1,757 1,819 1,888 1,933 1,976 2,018 2,059 2,099 2,140

Firm Off-System Load 47 40 2 0 0 0 0 0 0 0
TOTAL LOAD 1,753 1,797 1,821 1,888 1,933 1,976 2,018 2,059 2,099 2,140

Peak Load (Megawatts)

FIRM PEAK LOAD 2,969 3,092 3,175 3,279 3,358 3,432 3,504 3,573 3,640 3,707

Fmc Peak 10 0 0 0 0 0 0 0 0 0
Loss 1 0 0 0 0 0 0 0 0 0
SYSTEM PEAK (1 HOUR) 2,979 3,092 3,175 3,279 3,358 3,432 3,504 3,573 3,640 3,707

Firm Off-System Peak 96 78 0 0 0 0 0 0 0 0
Loss 4 3 0 0 0 0 0 0 0 0
TOTAL PEAK LOAD 3,079 3,173 3,175 3,279 3,358 3,432 3,504 3,573 3,640 3,707

26

LEFT BLANK INTENTIONALLY

27

Hydroelectric Plant Data

Thermal Plant Data

Surplus/Deficiency
50th Percentile Water – 50th Percentile Loads
70th Percentile Water – 70th Percentile Loads
90th Percentile Water – 70th Percentile Loads

Electric Price Forecast

Gas Price Forecast

2002 IRP 10 Year Plan Costs

QF Project Data

Assumptions Used to Price Resource Alternatives

Distributed Generation Report

EXISTING RESOURCE DATA

28
Existing Resources
Hydroelectric Plant Data
Plant Name Nameplate Capacity
Total Nameplate
Capacity FERC License
By Unit (Megawatts) Expiration Date

American Falls 92.34 2025
Units 1-3 30.78
Bliss 75.00 Annual
Units 1-3 25.00
Brownlee 585.40 2005
Units 1-4 90.10
Unit 5 225.00
Cascade 12.42 2031
Units 1-2 6.21
Oxbow 190.00 2005
Units 1-4 47.50
Hells Canyon 391.50 2005
Units 1-3 130.50
Malad 21.77 2004
Upper 8.27
Lower 13.50
Milner 59.45 2038
Unit 1 46.55
Unit 2 12.07
Unit 3 0.83
C.J. Strike 82.80 2000
Units 1-3 27.60
Swan Falls 25.00 2010
Units 1-2 12.50
Twin Falls 52.74 2040
Unit 1 8.44
Unit 2 44.30
Upper Salmon 34.50 Annual
Units 1-2 9.00
Units 3-4 8.25
Lower Salmon 60.00 Annual
Units 1-4 15.00
Shoshone Falls 12.50 Annual
Unit 1 0.60
Unit 2 0.40
Unit 3 11.50
Clear Lake 2.50 NA
Unit 1 2.50
Thousand Springs 8.80 NA
Units 1-2 1.00
Unit 3 6.80

29
Existing Resources
Thermal Plant Data

Plant Name
Total Plant
Capacity (MW)
Maximum Dependable Capacity (MDC)
By Unit
Jim Bridger* 703
Unit 1 177
Unit 2 177
Unit 3 177
Unit 4 173
Boardman* 55
Unit 1 55
North Valmy* 261
Unit 1 127
Unit 2 134

Evander Andrews 90

Salmon Diesel 5

* Idaho Power Share

30
IRP 2002
50th Percentile Water, 50th Percentile Loads, Sales & Load Forecasted Loads

(aMW)

2002 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1704)(1603)(1495)(1515)(1650)(1915)(2118)(1959)(1700)(1505)(1572)(1762)
CSPP
Contracts (100)(100)(50)
Remaining Load (1751)(1649)(1425)(1421)(1523)(1774)(1809)(1700)(1564)(1417)(1514)(1758)

Thermal
Hydro
Spring Plants
Garnet 0
Danskin
Total Generation

Surplus/Deficiency

2003 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1762)(1639)(1519)(1524)(1682)(1969)(2201)(2030)(1738)(1544)(1617)(1837)
CSPP
Contracts (50)(50)
Remaining Load (1759)(1635)(1449)(1430)(1555)(1828)(1992)(1825)(1618)(1456)(1559)(1783)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation

Surplus/Deficiency

2004 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1815)(1704)(1582)(1570)(1716)(1994)(2197)(2019)(1725)(1557)(1630)(1855)
CSPP
Contracts
Remaining Load (1762)(1650)(1512)(1476)(1589)(1863)(2063)(1889)(1605)(1469)(1572)(1801)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation

Surplus/Deficiency

2005 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1881)(1769)(1634)(1621)(1776)(2066)(2280)(2098)(1793)(1622)(1703)(1914)
CSPP
Contracts
Remaining Load (1828)(1715)(1564)(1527)(1649)(1935)(2146)(1968)(1673)(1534)(1645)(1860)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation

Surplus/Deficiency 66

31
2006 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1927)(1811)(1675)(1661)(1818)(2113)(2333)(2149)(1837)(1662)(1746)(1960)
CSPP
Contracts
Remaining Load (1874)(1757)(1605)(1567)(1691)(1982)(2199)(2019)(1717)(1574)(1688)(1906)

Thermal
Hydro
Spring Plants 30
Garnet
Danskin
Total Generation

Surplus/Def iciency (38)

2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1971)(1853)(1714)(1700)(1859)(2158)(2383)(2197)(1878)(1701)(1787)(2004)
CSPP
Contracts
Remaining Load (1918)(1799)(1644)(1606)(1732)(2027)(2249)(2067)(1758)(1613)(1729)(1950)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation

Surplus/Deficiency (36)(55)

2008 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (2013)(1890)(1752)(1738)(1898)(2203)(2433)(2245)(1919)(1739)(1827)(2046)
CSPP
Contracts
Remaining Load (1960)(1836)(1682)(1644)(1771)(2072)(2299)(2115)(1799)(1651)(1769)(1992)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation

Surplus/Deficiency (28)(76)

2009 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (2053)(1931)(1789)(1775)(1937)(2246)(2480)(2291)(1958)(1775)(1866)(2085)
CSPP
Contracts
Remaining Load (2000)(1877)(1719)(1681)(1810)(2115)(2346)(2161)(1838)(1687)(1808)(2031)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation 20

Surplus/Deficiency (75)(115)(34)

32
2010 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (2091)(1967)(1823)(1810)(1975)(2288)(2528)(2336)(1997)(1811)(1902)(2125)
CSPP
Contracts
Remaining Load (2038)(1913)(1753)(1716)(1848)(2157)(2394)(2206)(1877)(1723)(1844)(2071)

Thermal
Hydro
Spring Plants
Garnet 1
Danskin
Total Generation

Surplus/Deficiency (123)(151)(74)

2011 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (2130)(2004)(1860)(1847)(2014)(2333)(2578)(2385)(2037)(1848)(1941)(2166)
CSPP
Contracts
Remaining Load (2077)(1950)(1790)(1753)(1887)(2202)(2444)(2255)(1917)(1760)(1883)(2112)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation 1917

Surplus/Deficiency (178)(30)(190)(115)

33
IRP 2002
70th Percentile Water, 70th Percentile Loads, Sales & Load Forecasted Loads

(aMW)

2002 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1732)(1628)(1526)(1574)(1716)(1978)(2158)(1993)(1739)(1533)(1591)(1792)
CSPP
Contracts (100)(100)(50)
Remaining Load (1779)(1674)(1456)(1480)(1589)(1837)(1849)(1734)(1603)(1445)(1533)(1788)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation

Surplus/Deficiency (10)

2003 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1791)(1665)(1550)(1584)(1748)(2033)(2242)(2064)(1777)(1572)(1636)(1867)
CSPP 54
Contracts (50)(50)
Remaining Load (1788)(1661)(1480)(1490)(1621)(1892)(2033)(1859)(1657)(1484)(1578)(1813)

Thermal 875
Hydro
Spring Plants
Garnet
Danskin 2
Total Generation

Surplus/Deficiency (35)

2004 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1845)(1731)(1614)(1631)(1783)(2059)(2238)(2054)(1765)(1585)(1649)(1887)
CSPP
Contracts
Remaining Load (1792)(1677)(1544)(1537)(1656)(1928)(2104)(1924)(1645)(1497)(1591)(1833)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation

Surplus/Deficiency (61)(45)(56)

2005 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1912)(1796)(1666)(1682)(1843)(2131)(2322)(2134)(1834)(1651)(1723)(1946)
CSPP
Contracts
Remaining Load (1859)(1742)(1596)(1588)(1716)(2000)(2188)(2004)(1714)(1563)(1665)(1892)

Thermal
Hydro 11
Spring Plants
Garnet
Danskin
Total Generation 18

Surplus/Deficiency (6)(37)(103)

34
2006 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1958)(1839)(1707)(1723)(1886)(2180)(2376)(2186)(1878)(1691)(1766)(1993)
CSPP 8
Contracts
Remaining Load (1905)(1785)(1637)(1629)(1759)(2049)(2242)(2056)(1758)(1603)(1708)(1939)

Thermal
Hydro 101
Spring Plants
Garnet
Danskin
Total Generation 2177

Surplus/Deficiency (55)(45)(5)(80)(145)

2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (2003)(1881)(1748)(1762)(1927)(2225)(2427)(2234)(1920)(1731)(1808)(2037)
CSPP
Contracts
Remaining Load (1950)(1827)(1678)(1668)(1800)(2094)(2293)(2104)(1800)(1643)(1750)(1983)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation

Surplus/Deficiency (72)(96)(26)(38)(122)(162)

2008 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (2045)(1918)(1786)(1800)(1968)(2271)(2477)(2283)(1961)(1769)(1848)(2079)
CSPP
Contracts 0
Remaining Load (1992)(1864)(1716)(1706)(1841)(2140)(2343)(2153)(1841)(1681)(1790)(2025)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation 20

Surplus/Deficiency (118)(141)(63)(79)(162)(102)

2009 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (2086)(1960)(1823)(1837)(2007)(2314)(2526)(2330)(2001)(1806)(1887)(2120)
CSPP
Contracts
Remaining Load (2033)(1906)(1753)(1743)(1880)(2183)(2392)(2200)(1881)(1718)(1829)(2066)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation

Surplus/Deficiency (73)(190)(22)(119)(25)(201)(143)

35
2010 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (2124)(1996)(1858)(1873)(2045)(2358)(2573)(2376)(2040)(1841)(1924)(2160)
CSPP
Contracts
Remaining Load (2071)(1942)(1788)(1779)(1918)(2227)(2439)(2246)(1920)(1753)(1866)(2106)

Thermal
Hydro
Spring Plants 3
Garnet
Danskin
Total Generation

Surplus/Deficiency (8)(20)(117)(237)(68)(158)(77)(238)(183)

2011 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (2164)(2034)(1895)(1911)(2085)(2404)(2624)(2425)(2082)(1879)(1963)(2202)
CSPP
Contracts
Remaining Load (2111)(1980)(1825)(1817)(1958)(2273)(2490)(2295)(1962)(1791)(1905)(2148)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation

Surplus/Deficiency (45)(60)(163)(293)(111)(200)(115)(277)(225)

36
IRP 2002
90th Percentile Water, 70 Percentile Loads, Sales & Load Forecasted Loads

(aMW)

2002 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1732)(1628)(1526)(1574)(1716)(1978)(2158)(1993)(1739)(1533)(1591)(1792)
CSPP 7
Contracts (100)(100)(50)
Remaining Load (1779)(1674)(1456)(1480)(1589)(1837)(1849)(1734)(1603)(1445)(1533)(1788)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation

Surplus/Deficiency (164)(101)

2003 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1791)(1665)(1550)(1584)(1748)(2033)(2242)(2064)(1777)(1572)(1636)(1867)
CSPP
Contracts (50)(50)
Remaining Load (1788)(1661)(1480)(1490)(1621)(1892)(2033)(1859)(1657)(1484)(1578)(1813)

Thermal
Hydro
Spring Plants 3
Garnet
Danskin
Total Generation

Surplus/Deficiency (118)(221)(112)(116)(126)

2004 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1845)(1731)(1614)(1631)(1783)(2059)(2238)(2054)(1765)(1585)(1649)(1887)
CSPP
Contracts
Remaining Load (1792)(1677)(1544)(1537)(1656)(1928)(2104)(1924)(1645)(1497)(1591)(1833)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation 1

Surplus/Deficiency (135)(301)(180)(3)(104)(146)

2005 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1912)(1796)(1666)(1682)(1843)(2131)(2322)(2134)(1834)(1651)(1723)(1946)
CSPP
Contracts
Remaining Load (1859)(1742)(1596)(1588)(1716)(2000)(2188)(2004)(1714)(1563)(1665)(1892)

Thermal
Hydro
Spring Plants
Garnet 0
Danskin
Total Generation

Surplus/Deficiency (40)(56)(51)(247)(127)(72)(173)(51)(194)

37
2006 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (1958)(1839)(1707)(1723)(1886)(2180)(2376)(2186)(1878)(1691)(1766)(1993)
CSPP
Contracts
Remaining Load (1905)(1785)(1637)(1629)(1759)(2049)(2242)(2056)(1758)(1603)(1708)(1939)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation

Surplus/Deficiency (81)(97)(94)(296)(181)(118)(217)(34)(94)(236)

2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (2003)(1881)(1748)(1762)(1927)(2225)(2427)(2234)(1920)(1731)(1808)(2037)
CSPP
Contracts 0
Remaining Load (1950)(1827)(1678)(1668)(1800)(2094)(2293)(2104)(1800)(1643)(1750)(1983)

Thermal
Hydro 883
Spring Plants
Garnet
Danskin
Total Generation 1

Surplus/Deficiency (14)(199)(139)(135)(313)(232)(139)(259)(74)(136)(253)

2008 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (2045)(1918)(1786)(1800)(1968)(2271)(2477)(2283)(1961)(1769)(1848)(2079)
CSPP
Contracts
Remaining Load (1992)(1864)(1716)(1706)(1841)(2140)(2343)(2153)(1841)(1681)(1790)(2025)

Thermal
Hydro
Spring Plants
Garnet 1
Danskin
Total Generation

Surplus/Deficiency (103)(237)(177)(176)(359)(277)(176)(300)(112)(176)(193)

2009 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (2086)(1960)(1823)(1837)(2007)(2314)(2526)(2330)(2001)(1806)(1887)(2120)
CSPP
Contracts 0
Remaining Load (2033)(1906)(1753)(1743)(1880)(2183)(2392)(2200)(1881)(1718)(1829)(2066)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation 156

Surplus/Deficiency (196)(198)(211)(215)(314)(326)(214)(340)(149)(215)(234)

38
2010 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (2124)(1996)(1858)(1873)(2045)(2358)(2573)(2376)(2040)(1841)(1924)(2160)
CSPP
Contracts
Remaining Load (2071)(1942)(1788)(1779)(1918)(2227)(2439)(2246)(1920)(1753)(1866)(2106)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation

Surplus/Deficiency (30)(240)(233)(250)(253)(358)(373)(257)(379)(184)(252)(274)

2011 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load (2164)(2034)(1895)(1911)(2085)(2404)(2624)(2425)(2082)(1879)(1963)(2202)
CSPP
Contracts 0
Remaining Load (2111)(1980)(1825)(1817)(1958)(2273)(2490)(2295)(1962)(1791)(1905)(2148)

Thermal
Hydro
Spring Plants
Garnet
Danskin
Total Generation 154

Surplus/Deficiency (70)(278)(270)(288)(293)(404)(429)(300)(421)(222)(291)(316)

39
Expected Electric Price Forecast
Mid C Prices

Month HLH LLH Average Source
Jan-02 19.60 17.38 18.62 Dow Jones Index
Feb-02 20.89 19.45 20.27 Dow Jones Index
Mar-02 34.22 31.32 32.94 Dow Jones + Balance of Month
Apr-02 27.75 23.25 25.85 Forward- Market Price as of March 15, 2002
May-02 23.75 17.25 20.88 Forward- Market Price as of March 15, 2002
Jun-02 26.50 20.50 23.83 Forward- Market Price as of March 15, 2002
Jul-02 33.00 24.00 29.03 Forward- Market Price as of March 15, 2002
Aug-02 41.25 30.00 36.53 Forward- Market Price as of March 15, 2002
Sep-02 36.00 29.00 32.73 Forward- Market Price as of March 15, 2002
Oct-02 34.00 30.50 32.53 Forward- Market Price as of March 15, 2002
Nov-02 33.50 28.50 31.28 Forward- Market Price as of March 15, 2002
Dec-02 37.50 31.75 34.84 Forward- Market Price as of March 15, 2002
Jan-03 39.00 31.25 35.58 Forward- Market Price as of March 15, 2002
Feb-03 36.00 29.25 33.11 Forward- Market Price as of March 15, 2002
Mar-03 33.00 27.25 30.47 Forward- Market Price as of March 15, 2002
Apr-03 23.75 19.23 21.84 Forward- Market Price as of March 15, 2002
May-03 21.50 17.41 19.70 Forward- Market Price as of March 15, 2002
Jun-03 24.75 20.04 22.66 Forward- Market Price as of March 15, 2002
Jul-03 37.00 29.96 33.90 Forward- Market Price as of March 15, 2002
Aug-03 43.25 35.02 39.80 Forward- Market Price as of March 15, 2002
Sep-03 37.25 30.16 33.94 Forward- Market Price as of March 15, 2002
Oct-03 38.50 31.17 35.43 Forward- Market Price as of March 15, 2002
Nov-03 37.50 30.36 34.33 Forward- Market Price as of March 15, 2002
Dec-03 41.00 33.20 37.39 Forward- Market Price as of March 15, 2002
Jan-04 39.68 32.43 36.48 Forward- Market Price as of March 15, 2002
Feb-04 36.63 29.93 33.76 Forward- Market Price as of March 15, 2002
Mar-04 33.58 27.44 30.87 Forward- Market Price as of March 15, 2002
Apr-04 24.16 19.75 22.30 Forward- Market Price as of March 15, 2002
May-04 21.88 17.88 20.11 Forward- Market Price as of March 15, 2002
Jun-04 25.18 20.58 23.14 Forward- Market Price as of March 15, 2002
Jul-04 37.65 30.77 34.61 Forward- Market Price as of March 15, 2002
Aug-04 44.00 35.96 40.63 Forward- Market Price as of March 15, 2002
Sep-04 37.90 30.97 34.67 Forward- Market Price as of March 15, 2002
Oct-04 39.17 32.01 36.17 Forward- Market Price as of March 15, 2002
Nov-04 38.15 31.18 35.06 Forward- Market Price as of March 15, 2002
Dec-04 41.72 34.09 38.19 Forward- Market Price as of March 15, 2002
Jan-05 40.53 33.28 37.33 Forward- Market Price as of March 15, 2002
Feb-05 37.41 30.72 34.55 Forward- Market Price as of March 15, 2002
Mar-05 34.30 28.16 31.59 Forward- Market Price as of March 15, 2002
Apr-05 24.68 20.27 22.82 Forward- Market Price as of March 15, 2002
May-05 22.34 18.35 20.58 Forward- Market Price as of March 15, 2002
Jun-05 25.72 21.12 23.68 Forward- Market Price as of March 15, 2002
Jul-05 38.45 31.57 35.42 Forward- Market Price as of March 15, 2002
Aug-05 44.95 36.91 41.58 Forward- Market Price as of March 15, 2002

40
Month HLH LLH Average Source
Sep-05 38.71 31.79 35.48 Forward- Market Price as of March 15, 2002
Oct-05 40.01 32.85 37.01 Forward- Market Price as of March 15, 2002
Nov-05 38.97 32.00 35.87 Forward- Market Price as of March 15, 2002
Dec-05 42.61 34.99 39.09 Forward- Market Price as of March 15, 2002
Jan-06 41.67 34.13 38.34 Forward- Market Price as of March 15, 2002
Feb-06 38.46 31.51 35.48 Forward- Market Price as of March 15, 2002
Mar-06 35.26 28.88 32.45 Forward- Market Price as of March 15, 2002
Apr-06 25.37 20.78 23.44 Forward- Market Price as of March 15, 2002
May-06 22.97 18.82 21.14 Forward- Market Price as of March 15, 2002
Jun-06 26.44 21.66 24.32 Forward- Market Price as of March 15, 2002
Jul-06 39.53 32.38 36.38 Forward- Market Price as of March 15, 2002
Aug-06 46.21 37.85 42.70 Forward- Market Price as of March 15, 2002
Sep-06 39.80 32.60 36.44 Forward- Market Price as of March 15, 2002
Oct-06 41.13 33.69 38.01 Forward- Market Price as of March 15, 2002
Nov-06 40.06 32.82 36.84 Forward- Market Price as of March 15, 2002
Dec-06 43.80 35.88 40.14 Forward- Market Price as of March 15, 2002
Jan-07 38.38 32.20 35.68 AURORA Base Case Price Forecast V 6.1.3
Feb-07 32.31 29.38 31.03 AURORA Base Case Price Forecast V 6.1.3
Mar-07 31.28 27.52 29.63 AURORA Base Case Price Forecast V 6.1.3
Apr-07 33.88 26.55 30.68 AURORA Base Case Price Forecast V 6.1.3
May-07 32.02 26.11 29.44 AURORA Base Case Price Forecast V 6.1.3
Jun-07 36.48 29.64 33.49 AURORA Base Case Price Forecast V 6.1.3
Jul-07 46.65 37.76 42.76 AURORA Base Case Price Forecast V 6.1.3
Aug-07 121.70 39.07 85.55 AURORA Base Case Price Forecast V 6.1.3
Sep-07 48.78 37.59 43.88 AURORA Base Case Price Forecast V 6.1.3
Oct-07 41.24 32.38 37.36 AURORA Base Case Price Forecast V 6.1.3
Nov-07 40.71 33.27 37.46 AURORA Base Case Price Forecast V 6.1.3
Dec-07 41.06 33.87 37.91 AURORA Base Case Price Forecast V 6.1.3
Jan-08 39.01 33.61 36.65 AURORA Base Case Price Forecast V 6.1.3
Feb-08 33.10 30.87 32.12 AURORA Base Case Price Forecast V 6.1.3
Mar-08 34.56 29.38 32.30 AURORA Base Case Price Forecast V 6.1.3
Apr-08 32.55 27.17 30.19 AURORA Base Case Price Forecast V 6.1.3
May-08 33.74 27.40 30.97 AURORA Base Case Price Forecast V 6.1.3
Jun-08 43.39 31.96 38.39 AURORA Base Case Price Forecast V 6.1.3
Jul-08 46.90 38.24 43.11 AURORA Base Case Price Forecast V 6.1.3
Aug-08 129.65 40.27 90.55 AURORA Base Case Price Forecast V 6.1.3
Sep-08 61.05 37.83 50.89 AURORA Base Case Price Forecast V 6.1.3
Oct-08 43.45 34.30 39.45 AURORA Base Case Price Forecast V 6.1.3
Nov-08 43.88 36.99 40.87 AURORA Base Case Price Forecast V 6.1.3
Dec-08 41.70 35.87 39.15 AURORA Base Case Price Forecast V 6.1.3
Jan-09 40.09 35.53 38.09 AURORA Base Case Price Forecast V 6.1.3
Feb-09 34.94 32.16 33.72 AURORA Base Case Price Forecast V 6.1.3
Mar-09 36.06 30.32 33.55 AURORA Base Case Price Forecast V 6.1.3
Apr-09 32.78 28.77 31.03 AURORA Base Case Price Forecast V 6.1.3
May-09 34.56 28.16 31.76 AURORA Base Case Price Forecast V 6.1.3
Jun-09 41.64 32.04 37.44 AURORA Base Case Price Forecast V 6.1.3
Jul-09 47.93 38.35 43.74 AURORA Base Case Price Forecast V 6.1.3

41
Month HLH LLH Average Source
Aug-09 140.80 42.94 97.99 AURORA Base Case Price Forecast V 6.1.3
Sep-09 51.16 39.51 46.07 AURORA Base Case Price Forecast V 6.1.3
Oct-09 41.77 36.80 39.59 AURORA Base Case Price Forecast V 6.1.3
Nov-09 46.13 38.34 42.72 AURORA Base Case Price Forecast V 6.1.3
Dec-09 43.44 36.69 40.49 AURORA Base Case Price Forecast V 6.1.3
Jan-10 42.33 37.61 40.26 AURORA Base Case Price Forecast V 6.1.3
Feb-10 35.19 33.20 34.32 AURORA Base Case Price Forecast V 6.1.3
Mar-10 36.01 31.71 34.13 AURORA Base Case Price Forecast V 6.1.3
Apr-10 33.93 31.01 32.65 AURORA Base Case Price Forecast V 6.1.3
May-10 38.66 29.87 34.81 AURORA Base Case Price Forecast V 6.1.3
Jun-10 41.47 31.76 37.22 AURORA Base Case Price Forecast V 6.1.3
Jul-10 50.06 39.46 45.42 AURORA Base Case Price Forecast V 6.1.3
Aug-10 146.23 44.22 101.60 AURORA Base Case Price Forecast V 6.1.3
Sep-10 65.85 40.70 54.85 AURORA Base Case Price Forecast V 6.1.3
Oct-10 44.71 38.49 41.99 AURORA Base Case Price Forecast V 6.1.3
Nov-10 44.72 38.98 42.21 AURORA Base Case Price Forecast V 6.1.3
Dec-10 44.11 39.48 42.08 AURORA Base Case Price Forecast V 6.1.3
Jan-11 44.59 39.94 42.55 AURORA Base Case Price Forecast V 6.1.3
Feb-11 37.50 35.26 36.52 AURORA Base Case Price Forecast V 6.1.3
Mar-11 35.72 33.19 34.62 AURORA Base Case Price Forecast V 6.1.3
Apr-11 34.69 31.74 33.40 AURORA Base Case Price Forecast V 6.1.3
May-11 39.79 31.63 36.22 AURORA Base Case Price Forecast V 6.1.3
Jun-11 43.58 33.37 39.11 AURORA Base Case Price Forecast V 6.1.3
Jul-11 53.71 41.90 48.54 AURORA Base Case Price Forecast V 6.1.3
Aug-11 149.10 43.47 102.89 AURORA Base Case Price Forecast V 6.1.3
Sep-11 82.08 42.90 64.94 AURORA Base Case Price Forecast V 6.1.3
Oct-11 46.52 40.78 44.01 AURORA Base Case Price Forecast V 6.1.3
Nov-11 45.51 40.01 43.11 AURORA Base Case Price Forecast V 6.1.3
Dec-11 46.61 40.80 44.07 AURORA Base Case Price Forecast V 6.1.3

Note: Prices used for the high and low price scenarios were 65% and 200% of the expected price.

42

Gas Price Forecast

Nominal $/mmbtu

2002 2.69
2003 3.39
2004 3.45
2005 3.51
2006 3.57
2007 3.63
2008 3.68
2009 3.74
2010 3.81
2011 3.91

43

2002 IRP 10 Year Plan Costs

10 Year Plan Costs With Market Sales: 5.6% Discount Rate
Low Market Prices Expected Market Prices High Market Prices
Strategy 1 $31,999,253 $49,229,620 $98,459,240
Strategy 2 $79,456,289 $101,072,050 $162,831,366
Strategy 3 $208,587,998 $140,230,963 -$272,811,915
Strategy 4 $145,619,109 $130,714,824 -$20,512,487

10 Year Plan Costs With Market Sales: 7.6% Discount Rate
Low Market Prices Expected Market Prices High Market Prices
Strategy 1 $27,936,943 $42,979,912 $85,959,825
Strategy 2 $75,644,665 $94,338,488 $147,749,414
Strategy 3 $207,678,969 $146,112,156 -$218,981,709
Strategy 4 $142,704,029 $128,644,724 -$6,293,827

10 Year Plan Costs With Market Sales: 9.6% Discount Rate
Low Market Prices Expected Market Prices High Market Prices
Strategy 1 $24,437,975 $37,596,885 $75,193,770
Strategy 2 $71,625,714 $87,824,936 $134,108,430
Strategy 3 $204,822,860 $149,288,850 -$173,919,061
Strategy 4 $138,833,679 $125,603,224 $5,060,697

44
Idaho Power Company
Qualifying Facilities
Cogeneration and Small Power Production Projects Online as of December 31, 2001
Project
Contract
On-line Date
Contract
End Date Project
Contract
On-line Date
Contract
End Date
Hydro Projects
Barber Dam Apr-1989 Apr-2024 Low Line Canal May-1985 May-2020
Birch Creek Nov-1984 Oct-2019 Lowline #2 Apr-1988 Apr-2023
Black Canyon #3 Apr-1984 Apr-2019 Magic Reservoir Jun-1989 May-2024
Blind Canyon Feb-1995 Feb-2015 Malad River May-1984 Apr-2019
Box Canyon Feb-1984 Feb-2019 Marco Ranches Aug-1985 Jul-2020
Briggs Creek Oct-1985 Oct-2020 Mile 28 Jun-1994 May-2029
Bypass Jun-1988 Jun-2023 Mitchell Butte May-1989 Dec-2023
Canyon Springs Oct-1984 Sep-2004 Mud Creek/S & S Mar-1982 Mar-2017
Cedar Draw Jun-1984 May-2019 Mud Creek/White Jan-1986 Jan-2021
Clear Springs Trout Nov-1983 Nov-2018 Owyhee Dam Cspp Apr-1984 Apr-2014
Crystal Springs Apr-1986 Mar-2021 Pigeon Cove Oct-1984 Oct-2019
Curry Cattle Company Jun-1983 Jun-2018 Pristine Springs Mar-1995 Mar-2005
Dietrich Drop Aug-1988 Aug-2023 Reynolds Irrigation May-1986 May-2021
Elk Creek May-1986 May-2021 Rim View Non Firm
Falls River Aug-1993 Aug-2028 Rock Creek #1 Sep-1983 Jan-2018
Faulkner Ranch Aug-1987 Aug-2022 Rock Creek #2 Apr-1989 Apr-2024
Fisheries Dev. Non Firm Sagebrush Sep-1985 Aug-2020
Geo-Bon #2 Nov-1986 Nov-2021 Schaffner Aug-1986 Aug-2021
Hailey Cspp Jun-1985 Jun-2020 Shingle Creek Aug-1983 Jul-2018
Hazelton A Jun-1990 Jun-2010 Shoshone #2 May-1996 Apr-2031
Hazelton B May-1993 May-2028 Shoshone Cspp Jun-1982 Jun-2017
Horseshoe Bend Sep-1995 Sep-2030 Snake River Pottery Nov-1984 Nov-2019
Jim Knight Jun-1985 Jun-2020 Snedigar Jan-1985 Dec-2019
Kasel & Witherspoon Mar-1984 Mar-2019 Sunshine Power # 2 Non Firm
Koyle Small Hydro Apr-1984 Apr-2019 Trout-Co Dec-1986 Nov-2021
Lateral # 10 May-1985 May-2020 Tunnel #1 Jun-1993 Dec-2027
Lemoyne Jun-1985 Jun-2020 White Water Ranch Aug-1985 Jul-2020
Little Wood Rvr Res Feb-1985 Feb-2020 Wilson Lake Hydro May-1993 May-2028
Littlewood / Arkoosh Aug-1986 Aug-2021
Total Hydro Average Annual Mw 56.41
Thermal Projects
Magic Valley Nov-1996 Nov-2016
Magic West Dec-1996 Dec-2016
Pocatello Waste Dec-1985 Dec-2020
Simplot Pocatello Feb-1991 Dec-2001
Tamarack Cspp Jun-1983 May-2018
Tasco - Nampa Oct-1998 Sep-2003
Tasco - Twin Falls Aug-2001 Jul-2006
Vaagen Brothers Sep-1995 Sep-2010
West Boise Waste Dec-1991 Dec-2006
Total Thermal Average Annual Mw 36.69
Total Average Annual Mw 93.10

45

Assumptions Used to Price Resource Alternatives

Capacity - Levelized $/kW/month
Non Fuel
Generic Location Capacity O&M Fuel Total
Conventional CT (160 MW) 3.44 0.99 0.00 4.42
Advanced CT (120 MW) 4.80 1.39 0.00 6.19
Conventional Gas/Oil CC (250 MW) 4.79 2.11 0.00 6.90
Wind (50 MW) 10.31 3.65 0.00 13.95
Scrubbed Coal (400 MW) 12.16 3.55 0.00 15.71
Integrated Coal Gasification CC (428 MW) 14.54 4.77 0.00 19.31
Fuel Cells (10 MW) 21.93 3.38 0.00 25.31
Geothermal (50 MW) 18.97 9.28 0.00 28.25
Solar Thermal (100 MW) 26.64 7.41 0.00 34.04
Photovoltaic (5 MW) 38.82 4.12 0.00 42.95

Idaho Location Capacity O&M Fuel Total
Idaho - Conventional CT - V64.3 (61.2 MW) 6.45 1.25 0.00 7.69
Idaho - Advanced CT - LM 6000 (2ea) (78.52 MW) 8.39 1.40 0.00 9.79
Idaho - Conventional V64.3 CC (88.6 MW) 9.00 1.71 0.00 10.71
Shoshone Falls Upgrade (64 MW) 10.33 0.84 0.00 11.17
Idaho Wind (10 MW) 10.31 3.03 0.00 13.34
Valmy Unit 3 (130 MW) 12.16 3.51 0.00 15.67
Boardman Unit 2 (56 MW) 13.41 3.61 0.00 17.02
Danskin CC Expansion - Incremental (38.96 MW) 18.01 1.97 0.00 19.98

Energy - Levelized $/MWH
Non Fuel
Generic Location Capacity O&M Fuel Total
Scrubbed Coal (400 MW) 20.82 10.60 12.18 43.60
Integrated Coal Gasification CC (428 MW) 24.90 9.24 10.21 44.35
Geothermal (50 MW) 29.87 14.61 0.00 44.48
Conventional Gas/Oil CC (250 MW) 8.19 4.31 32.25 44.75
Advanced CT (120 MW) 8.22 2.52 38.18 48.92
Conventional CT (160 MW) 5.88 0.59 48.17 54.65
Wind (50 MW) 44.12 15.61 0.00 59.73
Fuel Cells (10 MW) 37.56 8.56 24.32 70.43
Solar Thermal (100 MW) 86.87 24.16 0.00 111.03
Photovoltaic (5 MW) 189.93 20.17 0.00 210.10

Idaho Location Capacity O&M Fuel Total
Shoshone Falls Upgrade (64 MW) 30.10 2.45 0.00 32.56
Valmy Unit 3 (130 MW) 18.84 9.89 12.48 41.21
Danskin CC Expansion - Incremental (38.96 MW) 15.09 6.45 20.40 41.93
Boardman Unit 2 (56 MW) 21.84 10.33 13.54 45.71
Idaho - Conventional V64.3 CC (88.6 MW) 13.55 9.29 31.05 53.89
Idaho - Advanced CT - LM 6000 (2ea) (78.52 MW) 19.49 8.25 39.03 66.78
Idaho - Conventional CT - V64.3 (61.2 MW) 14.97 7.90 45.77 68.65
Idaho Wind (10 MW) 61.39 18.05 0.00 79.43

46
Assumptions Used to Price Resource Alternatives
(continued)

Operating Assumptions
Investment Capacity Fixed O&M Variable Heat
Generic Location $/Kw Factor $/Kw O&M $/MWh Rate
Conventional CT (160 MW) $348 80.0% 6.45 0.10 11,380
Advanced CT (120 MW) $486 80.0% 9.16 0.10 9,020
Conventional Gas/Oil CC (250 MW) $468 80.0% 15.61 0.52 7,618
Wind (50 MW) $1,008 32.0% 25.54 0.00 NA
Scrubbed Coal (400 MW) $1,148 80.0% 23.41 3.38 9,386
Integrated Coal Gasification CC (428 MW) $1,373 80.0% 32.67 0.80 7,869
Fuel Cells (10 MW) $2,145 80.0% 14.98 2.08 5,744
Geothermal (50 MW) $1,791 87.0% 70.07 0.00 NA
Solar Thermal (100 MW) $2,605 42.0% 47.87 0.00 NA
Photovoltaic (5 MW) $3,931 28.0% 9.85 0.00 NA

Investment Capacity Fixed O&M Variable Heat
Idaho Location $/Kw Factor $/Kw O&M $/MWh Rate
Idaho - Conventional CT - V64.3 (61.2 MW) $653 59.0% 6.67 3.75 10,813
Idaho - Advanced CT - LM 6000 (2ea) (78.52 MW) $850 59.0% 6.67 3.75 9,221
Idaho - Conventional V64.3 CC (88.6 MW) $880 91.0% 9.03 5.03 7,335
Shoshone Falls Upgrade (64 MW) $1,010 47.0% 0.33 0.00 NA
Idaho Wind (10 MW) $1,008 23.0% 20.00 0.00 NA
Valmy Unit 3 (130 MW) $1,148 88.4% 23.03 3.33 9,087
Boardman Unit 2 (56 MW) $1,266 84.1% 23.03 3.33 9,087
Danskin CC Expansion - Incremental (38.96 MW) $1,559 91.0% 4.80 1.14 NA

Financing Assumptions Fuel Assumptions
Weighted Cost of Capital Cost per MMBTU
Operating Life - Years Year Coal Gas
Composite Tax Rate 1 1.12 2.69
Property Tax Rate 2 1.11 3.39
Insurance Rate 3 1.12 3.45
O&M Esc Rate 4 1.13 3.51
After Tax Discount Rate 5 1.14 3.57
6 1.15 3.63
7 1.17 3.68
8 1.18 3.74
9 1.20 3.81
10 1.21 3.91
Average Increase in Years 11 - 30
1.80% 2.62%

47
Report to the Oregon Public Utility Commission
Distributed Generation 2001

This report is prepared in response to Oregon Public Utility Commission Order LC 27.
Order LC 27 acknowledged Idaho Power Company’s 2000 Integrated Resource Plan with a
requirement that the Company file a report concerning the role distributed generation (DG) could
play in Idaho Power’s future resource portfolio.

Idaho Power Company currently purchases approximately 100 average megawatts of
energy generated by 68 different cogeneration and small power producers (CSPP). These CSPP
projects are small (20 kW to 9 MW) and are distributed throughout the Idaho Power Company
service territory. Therefore, the existing CSPP projects as well as new CSPP projects would
qualify as DG projects. In response to recent news of higher wholesale electric prices, the
Company has received numerous inquiries from potential developers requesting information
concerning the appropriate interconnection processes and the various contract options available
for new DG projects.

Solar, wind, small hydro, wood waste, methane (animal waste, landfill gas, waste water
treatment plants), and geothermal are some of the various fuel sources that are being considered
by various distributed generation plant developers.

In negotiating a contract with a potential developer of distributed generation, Idaho Power
Company adheres to Federal and State regulations and considers the benefits of the project's
physical location, dependability, flexibility and any other characteristics that may influence the
value of the energy to the Idaho Power Company system.

New Distributed Generation Projects

In 2001, the Company signed four new contracts with small generation projects and continued
discussions with numerous other potential DG projects.

· Under provisions in contracts for two of the new projects, the project generates electricity
for its own use and any excess generation is sold to Idaho Power Company. These
projects qualify as Cogeneration projects under the current PURPA laws because the
prime mover of the generation process (steam) is also being used in another industrial
process.

· The other two projects are small (less then 25 kWh) which allows net-metering treatment
under the current Idaho Power Company, Idaho Schedule 86, Option B, offset against
retail sales.

Wind Generation

In October of 2001, Idaho Power and the Idaho Department of Water Resources hosted a
conference on wind generation. The conference addressed the economics of wind generation
and the potential for new sites in Idaho. While Idaho Power supports development of localized

48
wind generation, there are issues that must be addressed in order to make wind generation a
reality within the Idaho Power Company service territory:

Non Firm Energy - Wind units can only generate energy when an adequate level of wind
occurs. As a result of wind not being an ever-present fuel, wind generation is considered a
“Non Firm” energy source. This necessarily reduces the economic value of wind
generation as a generation supply resource.

Economics - Based upon the cost of the current technology coupled with the current
relatively low market value of non firm energy and the relatively low retail energy rates
being charged by Idaho Power Company it is difficult for wind generation within the Idaho
Power Company service territory to achieve the levels of economic return required by
project developers.

Environment - Many groups advocate wind generation and other generation methods
(Solar, etc) as being the right thing to do in respect to our environment, energy
independence, renewable resource, and economic base for the local economy. Idaho
Power Company believes that a cooperative effort from governmental agencies, utilities
and the public is needed for wind generation to become a reality within the Idaho Power
Company service territory.

Anaerobic Digesters

Anaerobic digestion is the process of increasing the methane production which naturally
occurs in the decay of animal waste. This methane can then be captured and used as fuel in
either internal combustion engines or turbines to produce energy. Typically these projects would
be less than 1 MW and, due to the rural and/or remote location of the dairy or feed lot, potential
operation sites are widely disbursed throughout the Idaho Power Company service territory.

Interest in this technology is primarily being driven by the fact that many communities are
aggressively seeking regulation of dairy and feed lot odors. The anaerobic digester process as
well as producing methane, also is one method of significantly reducing the odors from these
operations.

Various dairymen and cattle feeders and their organizations have contacted Idaho Power
Company in regard to contracting for the sale of energy to Idaho Power Company. In response,
Idaho Power Company has met with various dairyman and cattle organizations explaining the
interconnection process and energy contract options. At this time, numerous projects are in
various stages of research and discussions with Idaho Power Company. No anaerobic digester
generation projects are on-line at this time. However Idaho Power Company will continue to work
with potential anaerobic digester projects.

Solar

Idaho Power Company continues to receive inquires from developers and homeowners
proposing to install small photovoltaic solar generation systems. In general, the proposals are for
relatively small (less then 25 kW) homeowner type systems. As described below, Idaho Power
Company has recently filed applications of proposed new and revised tariffs to simplify the
process of installing and interconnecting these small generation units in the Idaho Power
Company service territory.

49

Small Hydro Generation

Cleary the most popular form of DG development within the Idaho Power Company service
territory has been small hydro projects both in the past as well as new proposals. The majority of
the current DG projects with the Idaho Power Company service territory are small hydro projects.
Many of the existing projects continue to upgrade equipment and increase capacity to maximize
the energy output from their particular projects.

Idaho Power Company continues to receive numerous inquires for new proposed small
hydro projects and works with every one of these proposals within current Federal and State
regulations.

Wood Waste

Idaho Power Company currently has 2 wood waste generation projects under contract. As
the timber industry is the prime source of the fuel supply, the development of these projects is
directly related to the activity within the timber industry. Along with the current downturn in the
timber industry in the Northwest we have also seen a downturn in the development of new wood
waste generation projects within the region. In fact, Boise Cascade in Emmett, Idaho has shut
down its wood waste cogeneration facility.

In spite of the general downturn in the timber products industry, Idaho Power Company
has recently completed a contract amendment with one of the existing wood waste cogeneration
projects to increase generation. Due to changes in operations at this particular location,
additional fuel will be available for energy generation as well as new more efficient equipment is
being installed which will result in an increase in generation.

In addition, Idaho Power Company continues to receive inquires from existing wood waste
generation units, currently not under contract with Idaho Power Company, researching contract
options. A few inquiries from proposed new projects have also been received and discussed with
the proposed developers.

Recent Applications Affecting Distributed Generation Filed in Idaho

In November 2001, Idaho Power filed three applications with the Idaho Public Utilities
Commission affecting future distributed generation. The Company proposed a new Net Metering
Tariff (Schedule 84), revisions to the current Non Firm Energy purchase schedule (Schedule 86),
and Interconnections to Non Utility Generation (Schedule 72).

New Net Metering Tariff (IPUC Schedule 84)

The proposed Schedule 84 is designed to make it simpler and less expensive for
customers to install and interconnect small (less then 25 kW) generation units on the Idaho
Power Company system.

In the application, Idaho Power proposed that this tariff be available to residential and
small commercial customers who own and/or operate a generation facility that is fueled by solar,
wind, biomass, hydro, or fuel cell technology, is rated at 25 kW of nameplate capacity or less, and
is interconnected to the customer's individual electric system on the customer’s side of the meter.

50

Revisions to Non Firm Energy Purchase Schedule (IPUC Schedule 86)

The provisions for net metering within this schedule were removed (now addressed in the
new Schedule 84). In addition to this change, Idaho Power Company is proposing to limit the
application of this schedule to facilities smaller than 1 MW. Other changes and additions were
also proposed to simplify and clarify the interconnection requirements to the Idaho Power
Company system. No changes were proposed that would compromise the safety or reliability of
the Idaho Power Company system.

Revisions to Schedule Regulating Interconnections to Non Utility Generation (IPUC
Schedule 72)

Throughout this schedule changes and additions were made to simplify, clarify and
potentially reduce the cost of interconnecting distributed generation projects to the Idaho Power
Company System. Interconnection requirements have been established for various sizes and
types of generation units. In some cases, the customer is required to own more of the
interconnection equipment then in the past and/or the customer is given a choice as to what
equipment they will own vs. Idaho Power Company ownership. In all cases, Idaho Power
Company maintains ownership of the equipment necessary to ensure the generation
interconnection is safe and reliable.

The Company is still awaiting a ruling on these applications. When they are approved in
Idaho, the Company will make the necessary filing with this Commission to make the Oregon and
Idaho net metering process as uniform as possible.

Going Forward

It is likely that cogeneration and small power production projects will continue to be the
primary source of distributed generation for Idaho Power Company for the near term. CSPP
energy continues to play a material role in the scheduling of current Idaho Power Company
energy resources and the planning of future Idaho Power Company resource requirements.

Idaho Power Company recognizes that distributed generation projects can provide benefits
within our system and will seek to capture these benefits for our customers via purchase power
agreements. Idaho Power Company recognizes that not all projects provide benefits to the same
degree. Therefore, the contracting process must remain flexible to reflect benefits of distributed
generation that will vary as a result of a project’s location and other value that can be placed on
the energy deliveries.

In addition, Idaho Power Company also recognizes that “negative load” caused by
interconnections to the Company’s system can create uncertainty and volatility in load
characteristics that must be carefully managed to avoid adverse effects on the Company’s
system.

By simplifying and clarifying the interconnection processes, by holding public forums, and
by carefully evaluating every proposed distributed generation project, the Company believes it
can continue to integrate DG projects in an economical and responsible manner.

51
The Company is currently preparing its 2002 Integrated Resource plan and will further
address the role of distributed generation in that planning document.

52

LEFT BLANK INTENTIONALLY

53

Principal Distribution List

54
IDAHO POWER COMPANY
2002 INTEGRATED RESOURCE PLAN
PRINCIPAL DISTRIBUTION LIST

Association of Idaho Cities
Ms. Debbie Bloom
Director of Technical Services
3314 Grace
Boise, ID 83703

Catamount Glenns Ferry Corporation
Ms. Dreama Brower
71 Allen Street
Building A
Ruland, VT 05701-4570

Indeck Idaho Management, Inc.
Mr. Mike Jones
General Manager
P.O. Box 96
Rupert, ID 83350

Astaris
Mr. Kirk Dahling
Box 4111
Pocatello, ID 83205

IACI
Mr. Brent Olmstad
P.O. Box 389
Boise, ID 83701

Dr. Greg Nelson
Idaho Farm Bureau Federation
P.O. Box 167
Boise, ID 83701-0167

Idaho Community Action Network
Ms. Leeann Hall
1311 W. Jefferson St.
Boise, ID 83702

Idaho Consumer Affairs
Mr. Wendell Phillippi
615 S. Phillips
Boise, ID 83705

Idaho Department of Water Resources
Mr. Robert Hoppie
1301 N. Orchard
Boise, ID 83706

Idaho Public Utilities Commission
Mr. Randy Lobb
P.O. Box 83720
Boise, ID 83720-0074

Idaho Public Utilities Commission
Mr. Rick Sterling
P.O. Box 83720
Boise, ID 83720-0074

Idaho Rivers United
Ms. Sarah Eddie
P.O. Box 633
Boise, ID 83701

Idaho State Department of Commerce
Mr. Alan Porter
700 W. State Street
Boise, ID 83720

Idaho State University
Mr. John Novosel
Fiscal Officer, Physical Plant
P.O. Box 8137
Pocatello, ID 83209-8137

Idaho Irrigation Pumpers Association
Lynn Tominaga
P.O. Box 2624
Boise, ID 83701-2624

Idaho Water User Association
Norman Semanko
410 South Orchard
Boise, ID 83705

55
IDAHO POWER COMPANY
2002 INTEGRATED RESOURCE PLAN
PRINCIPAL DISTRIBUTION LIST

Intermountain Gas Company
Mr. Mike McGrath
555 S. Cole Rd.
Boise, ID 83709

J.R. Simplot Company
Mr. David Hawk
999 Main Street, P.O. Box 27
Boise, ID 83707

Mr. Bernie Meyers
Bechtel BWX Technologies Idaho, LLC
P.O. Box 1625
Idaho Falls, ID 83415-3750

Micron Technology Inc.
Mr. Allen Perman
Engineering Supervisor
2805 E. Columbia Rd.
Boise, ID 83706

Micron Technology Inc.
Mr. Steve Stout
V.P. Facilities
2805 E. Columbia Rd.
Boise, ID 83706

Northwest Power Planning Council
Ms. Shirley Lindstrom
Power Planning Division
450 West State – 3rd Floor
Boise, ID 83720-0062

Northwest Power Planning Council
Mr. Jeff King
Power Planning Division
851 SW 6th Ave, Suite 1100
Portland, OR 97204-1348

Pete Richardson
Richardson & O’Leary
99 East Main – Ste. 200
P.O. Box 1849
Eagle, ID 83616

Oregon Public Utility Commission
Mr. Jack Breen
550 Capitol N.E.
Salem, OR 97310-1380

Oregon Public Utility Commission
Mr. Bill McNamee
550 Capitol Street NE
Salem, OR 97310-1380

Owyhee Irrigation District
Mr. John Ross
17 South 1st Street
Nyssa, OR 97913

Rosebud Enterprises, Inc.
Mr. Owen Orndorff
1087 West River Street
Suite 200
Boise, ID 83702

Northwest Energy Coalition
Ms. Nancy Hirsh
219 1st Ave South, Suite 100
Seattle, WA 98104

Law & Water Fund of the Rockies
Mr. William Eddie
P.O. Box 1612
Boise, ID 83701

Raft River Electric Cooperative
Mr. Bud Tracy
P.O. Box 617
Malta, ID 83342

Idaho Retail Association
Ms. Pam Eaton
1109 W. Main St, Suite 210
Boise, ID 83702-5642

56

IDAHO POWER COMPANY
2002 INTEGRATED RESOURCE PLAN
PRINCIPAL DISTRIBUTION LIST

Mr. Ronald Williams
P.O. Box 2128
Boise, ID 83701

Racine, Olson, Nye, Budge & Bailey
Mr. Randy Budge
P.O. Box 1391
Pocatello, ID 83204-1391

Idaho Governor’s Office
Mr. James Yost
P. O. Box 83720
Boise, ID 83720-0034

Boise State University
Mr. Larry Blake
Facilities Operation Maintenance
1910 University Drive
Boise, ID 83725

Idaho Conservation League
Mr. Rick Johnson
P.O. Box 844
Boise, ID 83701

Mr. Perry Swisher
8660 Oakmont Dr.
Boise, ID 83704

United Vision for Idaho
Mr. Jim Hansen
P.O. Box 2181
Boise, ID 83701

Citizens for Responsible Land Use
Ms. Jonna Weber
P.O. Box 192
Middleton, ID 86344