20170630IRP Appendix C Technical Report.pdf

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APPENDIX C: TECHNICAL REPORT
3Effi*.INTEGRATED RESOURCE PLAN
An IDACORP Company
SAFE HARBOR STATEMENT
This document may contain forward-looking statements,
and it is important to note that the future results could
differ materially from those discussed. A full discussion
of the factors that could cause future results to differ
materially can be found in ldaho Power's filings with the
Securities and Exchange Commission.
@ Printed on recycled paper
ldaho Power Company Table of Contents
TeeLe oF CoNTENTS
IRP Advisory Council
IRP Advisory Council Meeting Schedule and Agenda.
Sales and Load Forecast Data....
Average Annual Forecast Growth Rates.........
Expected-Case Load Forecast....
Annual Summary
70th Percentile Annual Forecast Growth Rates
70tr Percentile Load Forecast....
Load and Resource Balance Data.........
Monthly Average Energy Load and Resource Balance
Monthly Average Energy Surplus/Deficit Charts ..............39
Peak-Hour Load and Resource Balance ..
i
1
I
.2
11
t2
t9
t9
Peak-Hour Surplus/Defi cit Charts
Demand-Side Resource Data
Cost Effectiveness.....
Resource Development and Evaluation
Planning Assumptions and Alternate Costs
Forecast and Cost-Effectiveness Data
Supply-Side Resource Data
..............61
..............61
.60
62
.............62
............63
.....71
Key Financial and Forecast Assumptions..............
Cost Inputs and Operating Assumptions........ ....................73
Transmission Cost Assumptions.............................74
Cost Assumptions by Supply-Side Resource Type ...........74
Levelized Cost of Energy.....................76
Peak-Hour Capacity Credit (Contribution to Peak)
Solar and Wind Resources
77
Energy Shape-Solar 77
2017 IRP Assumed Solar Capacity Factors .................77
Idaho Schedule STlOregon Schedule 85-Integration Costs for Solar and Wind Resources.T8
Solar.
7l
..77
2017 lntegrated Resource Plan-Appendix C
78
Page i
PURPA Reference Data..........
Resource Portfolio P7 .............
Renewable Energy Certificate Forecast....
Fuel Price Forecast....
Natural Gas, Coal, and Nuclear Price Forecast (nominal $/IVIMBIu)...
Existing Resource Data..........
Hydroelectric and Thermal Plant Data
Qualiffing Facility Data (PURPA) .............
Compliance with State of Oregon IRP Guidelines
Guideline I : Substantive Requirements........
Guideline 2 : Procedural Requirements ................
Guideline 3: Plan Filing, Review, and Updates.................
Guideline 4: Plan Components
......106
......106
.94
t07
110
110
148
150
t52
........108
........108
........112
........1 l4Power Purchase Agreement Data..........
Flow Modeling...........
Models......
ll5
Model Inputs
Model Results
Hydro Modeling Results (PDR580). ..............118
Portfolio Analysis, Results, and Supporting Documentation...
Portfolio Emissions.
IPC Emissions...........
COz Emission............
NOx Emission...........
.........1 15
.........1 15
.........1 16
..........148
..........148
..........148
..........148
..........149
..........149
...........150
...........15 1
Guideline
Guideline
Guideline
Guideline
Guideline
Transmission .............
Conservation .............
Demand Response..
Environmental Costs.
Direct Access Loads........
Guideline l0: Multi-state Utilities
Guideline I I : Reliability..
5:
6:
7:
8:
9:
............ I 53
............ I 56
156
............157
............157
r57
.....158
.............1 58
Table of Contents ldaho Power Company
Page ii 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Table of Contents
Guideline l2: Distributed Generation
Guideline I 3 : Resource Acquisition .............
Compliance with EV Guidelines
Guideline l: Forecast the Demand for Flexible Capacity
Guideline 2: Forecast the Supply for Flexible Capacity
Guideline 3: Evaluate Flexible Resources on a Consistent and Comparable Basis...
State Of Oregon Action Items Regarding Idaho Power's 2015 Irp
Action Item l: B2H Transmission Line..........
Action ltem 2: Gateway West Transmission Line ..................
Action Item 3: Energy Efficiency.
Action Item 4: Section 111(d)...........
Action Item 5: Shoshone Falls License Amendment.......
Action Item 6: Jim Bridger Unit 3...............
Action Item 7: Shoshone Falls Upgrades Study
Action Item 8: Jim Bridger Unit 4...............
Action Item 9: North Valmy Units 1 atd2......
Action Item l0: Shoshone Falls 2017 Upgrade
Action Item I l: Jim Bridger Units I and2......
Action ltem 12: Shoshone Falls 2019 On-Line Date.
..158
..158
..r60
..160
.......160
.......161
.......161
.......161
.......161
.......161
....162
....162
160
161
162
163
....t62
....t62
Other Issues........
...163
...163
2017 lntegrated Resource Plan-Appendix C Page iii
ldaho Power Company lntroduction
lrurnooucroN
Appendix C-Technical Appendix contains supporting data and explanatory materials used to develop
Idaho Power's 2017 Integrated Resource Plan (IRP).
The main document, the IRP, contains a full narrative of Idaho Power's resource planning process.
Additional information regarding the 2017 IRP sales and load forecast is contained in Appendix A-
Sales and Load Forecast, and details on Idaho Power's demand-side management efforts are explained
inAppendix B-Demand-Side Management 2014 Annual Report. The IRP, including the
three appendices, was filed with the Idaho and Oregon public utility commissions in June 2017.
For information or questions concerning the resource plan or the resource planning process,
contact Idaho Power:
Idaho Power-Resource Planning
1221 West Idaho Street
Boise,Idaho 83702
208-388-2623
[e-mail]
2017 lntegrated Resource Plan-Appendix C Page 1
ldaho Power Company IRP Advisory Council
IRP AovISoRY CoUNcIL
Idaho Power has involved representatives of the public in the IRP planning process since the early
1990s. This public forum is known as the IRP Advisory Council (IRPAC). The IRPAC generally meets
monthly during the development of the IRP, and the meetings are open to the public. Members of the
council include regulatory, political, environmental, and customer representatives, as well as
representatives of other public-interest groups.
Idaho Power hosted 8 IRPAC meetings, including a workshop designed to explore the potential for
distributed energy resources to defer grid investment. Idaho Power values these opportunities to
convene, and the IRPAC members and the public have made significant contributions to this plan.
Idaho Power believes working with members of the IRPAC and the public is rewarding, and the IRP is
better because of public involvement. Idaho Power and the members of the IRPAC recognize outside
perspective is valuable, but also understand that final decisions on the IRP are made by Idaho Power.
Customer Representatives
Agricultural Representative
Boise State University
Idaho National Laboratory
Micron
Simplot
Pu bl ic I nterest Representatives
Boise Metro Chamber of Commerce
Boise State University Energy Policy Institute
City of Boise
Idaho Conservation League
Idaho Legislature
Idaho Office of Energy and Mineral Resources
Idaho Sierra Club
Idaho Technology Council
Idaho Water Resource Board
Northwest Power and Conservation Council
Oil and Gas Industry Advisor
Oregon State University-Malheur Experiment Station
Snake River Alliance
University of Idaho Center for Ecohydraulics Research
Sid Erwin
Barry Burbank
Kurt Myers
Clancy Kelley
Don Sturtevant
Ray Stark
David Solan
Steve Burgos
Ben Otto
Representative Robert Anderst
John Chatburn/Scott Pugrud
Mike Heckl er / Zack Waterman/Casey Mattoon
Jay Larsen
Roger Chase
Shirley Lindstrom/Jim Yost
David Hawk
Clint Shock
Wendy Wilson/Chad Worth
Daniele Tonina
2017 lntegrated Resource Plan-Appendix C Page 1
IRP Advisory Council ldaho Power Company
Regulatory Commission Representatives
Idaho Public Utilities Commission
Public Utility Commission of Oregon
Stacey Donohue
Nadine Hanhan
IRP Advisory Council Meeting Schedule and Agenda
Meeting Dates Agenda ltems
2016
2017
2016 Thursday, September 8
2016 Thursday, October 13
2016 Thursday, November 10
I ntroductions/meeting overview
Welcome and opening remarks
IRP process explanation
Pilot projects update
Clean Power Plan update
Natural gas forecast
Review of September IRPAC meeting
T&D deferral benefit
Demand-side resources
Streamflow forecast
Hydro production forecast
Review of October IRPAC meeting
Transmission system overview
Boardman-Hemingway/Gateway West update
Load forecast
Contracl purchased power forecast
Deferral of Distribution lnvestment Workshop
Review of November IRPAC meeting
Energy efficiency potential study
Recap/review
Resource stack of IRP resources
Final load and resource balance
Resource portfolio design
Review of January IRPAC meeting
Revisit of natural gas price forecast
AURORA and portfolio analysis
NW Power and Conservation Council Regional Perspective
Flexibility analysis
500 kV transmission projects update
Overview of remaining steps
Review of March IRPAC meeting
Stochastic risk analysis results
Demand response as a resource
Resource stack costs - IRP resources
Qualitative risk analysis discussion
Closing-remaining schedule
Thursday, December 19
Thursday, January 12
2017 Thursday, March 9
2017 Thursday, April 13
Page2 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company IRP Advisory Council
Meeting Dates Agenda ltems
2017 Thursday, May 11 Action plan (2017 -2020)Hells Canyon Complex relicensing
Spring runoff and power system operations
Energy imbalance market (ElM) overview
IPC sustainability programs
Loss-of-load analysis
Closing comments
2017 lntegrated Resource Plan-Appendix C Page 3
ldaho Power Company Sales and Load Forecast Data
Snles AND Loao FonecAST Dare
Average Annual Forecast Growth Rates
2017-2022 2017-2027 2017-2036
Sales
Residential Sales
Commercial Sales
lrrigation Sales
lndustrial Sales
AdditionalFirm Sales
System Sales
TotalSales
Loads
Residential Load
Commercial Load
lrrigation Load
lndustrial Load
Additional Firm Sales
System Load Losses
System Load
Total Load
Peaks
System Peak
TotalPeak
Winter Peak
Summer Peak
Customers
Residential Customers
Commercial Customers
lrrigation Customers
lndustrial Customers
1.48%
0.87o/o
0.620/o
1.29o/o
O.94o/o
1.130/o
1.13o/o
1.48o/o
0.86%
0.620/o
1.25%
o.94%
1.12%
1.12%
1.12o/o
1.57o/o
1.57o/o
1.220/o
1.78%
2.1',\o/o
1.860/o
'l .420/o
0.50%
1.40%
0.790/o
0.59%
0.90%
1.400/o
1.04o/o
1.Mo/o
1.40o/o
0.78o/o
0.59%
0.89%
1.4Oo/o
1.03Yo
1.O4Yo
1.Mo/o
1.490/o
1.49o/o
1.05%
1.660/o
2.02o/o
1.90o/o
1.37o/o
0.65%
1.240/o
0.75o/o
0.59%
0.73%
O.760/o
o.91%
o.91%
1.22o/o
0.74%
0.58%
o.70%
o.76%
0.91Yo
0.89%
0.89%
1.36%
1.36%
0.88%
1.53%
1.78o/o
1.77o/o
1.29o/o
0.59%
2017 lntegrated Resource Plan-Appendix C Page 1
Expected-Case Load Forecast
Monthly Summaryr 112017 212017 312017 412017 512017 6n0fl 712017 812017 912017 1012017 1112017 1212017
Average Load (a[iWFsOh Porcentile
Sales and Load Forecast Data ldaho Power Company
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
814
494
2
281
113
145
671
466
3
279
111
129
592
434
I
277
106
1'18
506
430
130
263
106
120
446
429
345
268
105
135
512
462
587
292
102
169
588
499
503
289
108
172
469
467
328
286
107
140
650
460
5
279
112
126
799
499
3
278
114
144
455
444
73
289
104
113
621
503
643
285
'108
189
1,850
1,718
1,964
{,850
1,658
1,527
't,757
1,658
1,537
1,408
1,630
1,537
2,350
2,118
2,549
2,350
2,159
1 ,913
2,337
2,{59
t,796
1 ,616
1,941
{,796
1,477
1 ,316
1,604
1,477
1,631
1,505
1,733
r,63r
1,836
1,695
1,957
{,836
1,555 1,728 2,123
1,405 1,564 1,930
1,675 1,8s8 2,265
1,555 1,728 2,123
Peak Load (MWlggt Percentile
2,009 2,663 3,395System Peak (1 houo
Total Peak Load
2,408 2,279 2,018 3,566 3,213 2,767 2,072 2,264 2,517
2,408 2,279 2,018 2,009 2,663 3,395 3,566 3,213 2,767 2,072 2,264 2,517
Monthly Summaryr 112018 212018 312018 412018 512018 612018 7t2018 812018 912018 l0r20l8 1112018 1A201[.
Average Load (aMw)-soth Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
829
501
2
289
115
't48
882
471
3
288
113
131
602
438
I
285
108
120
522
467
590
300
103
17'l
634
509
647
294
110
191
478
473
330
294
109
143
661
465
5
287
114
128
813
504
3
282
'116
146
514
435
131
271
107
122
601
506
506
298
110
175
463
449
73
297
106
114
455
434
347
276
107
137
System Peak (l hour)2,454 2,315 2,053
t,581 1,756 2,155
1,428 1 ,589 1,958
1,703 1,887 2,299
1,58t 1,756 2,155
Peak Load (MWFgoh Percentile
2,037 2,701 3,453 3,630 3,269 2,818 2,100 2,292 2,5s4
r,884
1,749
1,990
1,884
1,688
1,554
1,788
r,688
1,563
1,432
1,657
1,563
2,385
2,150
2,587
2,38s
2,195
't,945
2,375
2,195
1,826
1,642
1,986
1,826
1,502
1,339
1,621
1,502
r,660
1,531
1,763
1,660
1,864
1,721
1,987
1,864
Total Peak Load 2,4il 2,315 2,053 2,037 2,701 3,453 3,630 3,269 2,818 2,100 2,292 2,59
Monthly Summaryr 1nO19 2t2O19 312019 412019 t2019 612019 712019 812019 912019 10/2019 1112019 1212019
Average Load (aMw)-sorh Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
844
505
3
294
117
150
648
513
652
298
11',|
194
470
453
74
302
107
116
695
475
3
292
115
133
612
442
I
289
109
122
523
439
132
275
109
124
464
438
350
280
108
139
533
471
595
305
104
174
614
511
510
302
111
177
487
477
332
299
110
144
672
470
5
291
115
130
823
508
3
285
117
147
System Peak (1 hour)2,497 2,347 2,OU
1,601 1,778 2,182
1,447 1,609 1,983
1,714 1,911 2,341
t,60t 1,778 2,182
Peak Load (ilWFgoth Percentile
2,062 2,735 3,505 3,692 3,322 2,861 2,122 2,316 2,572
1,912
1,776
2,O20
1,912
1,711
't,576
1 ,813
1,711
1,583
1,450
1,688
1,583
2,416
2,178
2,604
2,416
2,225
1,971
2,408
2,225
1,849
1,663
2,012
t,849
1,521
1,356
1,641
1,521
1,682
1,551
1,787
1,682
t,883
1,739
2,0O7
,l,883
Total Peak Load 2,497 2,347 2,0U 2,062 2,735 3,505 3,692 3,322 2,861 2,122 2,316 2,572
ol lhe2017 lRP, are a@unted for in the load and resour@ balance- The p€ak load fore€st doas not include the impact of sxisting or new demand response prcgrams, which are both
a@unted for in ths load and resoure balane.
Page2 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Sales and Load Forecast Data
Monthly Summaryr 112020 212020 3t2020 4t2O2O 512020 612020 712020 812020 912020 1Ol202O 11l2O2O 1212020
Average Load (aMw)-soth Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
851
510
3
297
118
151
616
444
I
292
110
122
526
442
133
278
109
125
468
441
352
283
108
140
676
473
5
294
116
131
676
462
J
285
112
129
539
475
600
308
105
175
656
517
656
301
112
196
621
515
513
305
111
179
492
481
334
302
110
146
473
456
74
305
108
117
831
512
3
287
118
149
System Peak (1 houo 2,517 2,360 2,097
1,613 't,792 2,200
1,457 1 ,622 1,999
1,727 1,939 2,346
1,613 1,792 2,200
Peak Load (MWFgOth Percentile
2,076 2,758 3,538 3,745 3,364 2,890 2,136 2,329 2,576
1,929
1,791
2,038
1,929
1,665
1,533
1,762
1,665
1,594
1,460
1,699
1,594
2,437
2,197
2,626
2,437
2,245
't,989
2,446
2,245
1,865
1,677
2,015
r,865
1,533
1,365
'1,653
r,533
r,695
1,563
1,810
1,695
't,899
1,753
2,014
1,899
Total Peak Load 2,517 2,360 2,097 2,076 2,7s8 3,538 3,745 3,364 2,890 2,136 2,329 2,576
Monthly Summaryl 112021 2t2021 3t2021 4t2O21 5t2021 812021 712021 8t2O21 9t2O21 10t2O21 11t2021 1212021
Average Load (aMW)-SOh Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
861
514
2
298
118
153
707
481
J
297
116
135
621
447
I
294
111
123
531
445
134
279
110
126
473
445
354
284
109
141
546
478
601
310
105
176
665
520
659
303
112
197
630
519
516
307
112
180
477
459
75
306
108
117
682
477
5
296
116
132
498
485
336
303
111
147
843
516
3
288
119
150
System Peak (1 houo 2,529 2,372 2,105
1,625 1,806 2,216
1,468 1,634 2,014
1,739 1,954 2,364
1,625 1,806 2,216
Peak Load (MWFgOtt' Percentile
2,087 2,780 3,570 3,797 3,406 2,917 2,149 2,343 2,596
't,946
1,807
2,066
1,946
1,738
1,601
1,84'.1
1,738
't,605
1,470
1,702
1,605
2,456
2,214
2,647
2,456
2,264
2,006
2,467
2,264
1,879
1,690
2,031
1,879
1,544
1,375
1,676
1,5M
1,708
1,575
1,814
1,708
1,918
1,771
2,034
1,918
Total Peak Load 2,529 2,372 2,105 2,087 2,780 3,570 3,797 3,406 2,917 2,149 2,343 2,596
Monthly Summaryr 'tt2022 212022 312022 412022 sl2022 612022 7t2022 8t2022 9t2022 1012022 11t2O22 1A2022
Average Load (aMw)-sorh Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
875
518
3
300
119
155
630
450
9
295
112
125
539
449
134
281
111
127
482
448
356
286
110
143
507
489
338
305
111
148
485
463
75
308
109
1 '19
856
520
3
290
120
152
718
485
3
298
117
136
556
482
605
311
106
178
678
524
663
304
113
199
643
524
519
308
113
182
692
481
5
297
117
133
1,970
1,829
2,091
t,970
1,757
1,618
1,861
1,757
1,621
1,485
1,719
1,621
2,442
2,238
2,693
2,482
2,290
2,029
2,478
2,290
1,899
1,708
2,052
1,899
1,558
1,388
'1,692
r,558
1,726
1,592
1,833
1,726
1,940
1,791
2,058
1,940
1,641 1,824 2,239
'1,483 1,650 2,034
1,756 1,973 2,388
1,641 1,824 2,239
Peak Load (MWFgoth Percentile
2,104 2,807 3,612System Peak (l hour)
Total Peak Load
2,558 2,393 2,124 3,854 3,453 2,952 2,165 2,361 2,614
2,558 2,393 2,124 2,104 2,807 3,512 3,854 3,453 2,952 2,165 2,361 2,614
ol lhe 2017 lRP, are acmunted for in the load and resource balance. The peak load fore€st does not include the impact of existing or nil demand response programs, which aro both
amunted for in the load and resource balan€.
2017 lntegrated Resource Plan-Appendix C Page 3
Sales and Load Forecast Data ldaho Power Company
Monthly Summaryr 112023 212023 312023 4t2O23 512023 612023 712023 812023 912023 1012023 1112023 1212023
Average Load (ailWls0rh Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
890
522
3
301
122
157
729
488
3
300
120
138
640
452
I
297
114
126
547
452
135
282
113
128
490
452
358
288
112
144
566
485
609
313
108
180
691
528
668
306
115
202
656
528
522
310
115
184
516
493
340
307
113
150
492
466
76
310
111
120
702
484
5
299
120
135
869
523
3
291
123
154
{,99s
1,853
2,118
1,99s
1,778
1,637
1,883
1,778
1,638
'1,501
1,737
r,638
2,509
2,262
2,722
2,509
2,3't6
2,O52
2,507
2,316
1,919
1,726
2,073
1,919
1,574
1,402
1,709
1,574
1,745
1 ,610
1,854
1,745
'1,963
1,812
2,093
r,963
1,558 1,843 2,262
1,498 1,668 2,056
1,786 1,982 2,413
1,658 1,8'l:l 2,262
Peak Load (MWFgorh Percentile
2,123 2,835 3,654System Peak (1 hour)
Total Peak Load
2,586 2,415 2,143 3,912 3,501 2,987 2,183 2,382 2,630
2,586 2,415 2,143 2,123 2,835 3,654 3,912 3,501 2,987 2,183 2,382 2,630
Monthly Summaryr 112024 212024 312024 412024 512024 612024 712024 812024 9t2024 1012024 1112024 1212024
Ayerage Load (aMlruFsoth Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
903
526
3
303
133
"t59
714
474
3
291
126
't 35
498
455
360
289
119
146
668
532
525
312
121
187
648
454
10
298
123
127
555
455
136
284
121
130
576
488
613
315
116
182
704
531
671
308
122
204
524
497
342
308
119
152
498
469
76
311
118
121
711
487
5
300
130
136
879
527
3
293
133
156
System Peak (1 hou0
Total Peak Load
2,621 2,441 2,168
1,680 1,866 2,289
1,518 1,689 2,080
1,798 2,006 2,456
1,680 t,866 2,289
Peak Load (MWF9o$ Percentile
2,145 2,867 3,699
2,026
1,881
2,141
2,026
1,742
1,604
1,844
1,742
1,660
1,52'l
1,770
1,660
2,539
2,289
2,737
2,539
2,345
2,O78
2,538
2,345
1,942
1,747
2,113
1,942
1,593
1,419
1,719
1,593
1,77O
1,633
1,881
1,770
1,991
1,838
2,122
1,991
3,974 3,554 3,025 2,206 2,410 2,653
2,621 2,441 2,168 2,145 2,867 3,699 3,974 3,554 3,025 2,206 2,410 2,653
Monthly Summaryr 112025 212025 312025 412025 512025 612025 712025 812025 9t2O25 1012025 1112025 1212025
Average Load (aMw)-sorh Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
677
537
528
313
122
188
530
501
344
310
120
153
913
530
3
305
133
160
747
494
3
303
130
141
653
457
'10
300
123
128
560
458
137
285
121
130
504
458
362
291
119
147
583
491
616
316
116
183
713
534
675
309
122
205
502
472
76
313
118
122
717
491
A
302
130
137
888
531
3
294
1U
157
System Peak (1 houo 2,635 2,454 2,177
1,691 1,880 2,305
1 ,528 1,701 2,095
1,810 2,021 2,474
1,691 1,880 2,305
Peak Load (MWFgott Percentile
2,156 2,888 3,731 4,026 3,595 3,051 2,218 2,423 2,659
2,O43
1,897
2,t59
2,043
2,559
2,307
2,758
2,559
2,365
2,096
2,577
2,365
t,957
1,760
2,114
1,957
1,603
1,429
1,730
1,603
1,783
1,644
1,904
1,783
2,007
1,853
2,',t28
2,OO7
1,817
1,674
1,925
1,817
1,671
1,530
1,781
1,671
Total Peak Load 2,635 2,4il 2,177 2,'t56 2,888 3,731 1,026 3,595 3,051 2,218 2,423 2,659
of the 2017 lRP, are acmunted for in the load and resour@ balan€. The peak load forecast does not include the impact of existing or nar demand response programs, which are both
accounted for in lhe load and resoure balane.
Page 4 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Sales and Load Forecast Data
Monthly Summaryr 112026 212026 312026 412026 5t2O26 6t2o26 7t2O26 8t2026 9t2o26 1ot2o26 11t2o26 1212026
Average Load (aMwFsoth Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
923
534
3
306
133
162
754
498
3
304
130
142
659
459
10
301
123
129
509
461
364
292
119
148
590
495
619
318
't 16
185
687
541
53'l
315
122
190
536
s05
345
311
120
154
506
475
77
314
118
123
899
535
3
296
134
158
565
461
137
287
121
131
723
538
678
311
122
207
724
495
5
303
130
138
System Peak (1 hour)2,649 2,464 2,185
1,702 1,893 2,322
1,538 1,713 2,110
1,822 2,048 2,477
't,702 1,893 2,322
Peak Load (MWFgoh Percentile
2,167 2,910 3,763 4,078 3,636 3,078 2,229 2,435 2,675
2,060
1 ,913
2,177
2,060
t,831
1,686
1,939
t,831
1,681
1,540
1,792
1,68t
2,579
2,325
2,779
2,579
2,385
2,113
2,599
2,385
1,972
1,773
2,130
1,972
1,614
1,438
1,741
1,611
1,795
1,656
1,917
1,795
2,024
1,869
2,146
2,O24
Total Peak Load 2,649 2,464 2,185 2,167 2,910 3,763 4,078 3,636 3,078 2,229 2,435 2,675
Monthly Summaryl ll2i27 212027 312027 412027 512027 6t2O27 712027 8t2O27 912027 1012027 11t2O27 1A2O27
Average Load (aMtrv)-soth Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
935
539
3
308
'133
163
763
501
3
306
130
143
666
462
10
303
123
130
516
465
366
293
119
149
ROO
498
623
319
116
186
735
542
682
312
122
209
544
509
348
313
120
156
732
498
5
305
130
140
57'.|
465
'138
288
121
132
698
546
534
316
122
192
512
479
77
316
118
124
910
538
3
297
134
160
System Peak (1 hour)2,672 2,481 2,200
1,716 1,909 2,342
1,550 1,727 2,128
1,836 2,065 2,498
1,7t6 1,909 2,342
Peak Load (MWFgoth Percentile
2,181 2,934 3,800 4,132 3,680 3,'109 2,243 2,450 2,689
2,080
1,932
2,208
2,080
1,846
1,700
1,956
r,846
1,694
1,551
1,796
r,694
2,602
2,346
2,805
2,602
2,408
2,134
2,624
2,408
1,989
1,789
2,149
1,989
1,626
1,448
1,765
1,626
1,810
1,669
1,922
1,810
2,O42
1,885
2,1 66
2,O42
Total Peak Load 2,672 2,481 2,200 2,181 2,934 3,800 4,132 3,680 3,109 2,243 2,450 2,689
Monthly Summaryr 1t2028 2t2028 3t2028 412028 5t2O28 6t2028 7t2028 8t2O28 9t2028 1Ot2028 1112028 12t2O28
Average Load (aMW)-5Oh Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
551
512
350
315
120
157
739
501
5
307
130
141
947
542
3
309
134
165
746
486
3
297
126
139
673
464
10
305
123
131
577
468
139
290
121
133
523
468
368
295
119
151
608
501
627
321
116
188
746
545
687
314
123
211
709
550
537
318
122
194
517
482
78
3't8
118
125
920
542
3
299
134
161
2,100
1,950
2,229
2,{00
1,797
1,655
1,902
1,197
1,705
1,562
1,809
1,706
2,625
2,366
2,847
2,625
2,430
2,1 53
2,630
2,430
2,005
1,803
2,1 66
2,005
1,637
1,459
1,778
1,637
1,824
1,682
1,937
1,824
2,059
1,901
2,1 95
2,059
1,728 1,924 2,361
1,562 1,741 2,146
1,862 2,069 2,518
1,728 1,924 2,361
Peak Load (MWFgoth Percentile
2,195 2,958 3,837System Peak (1 hour)
Total Peak Load
2,695 2,496 2,214 4,187 3,725 3,140 2,257 2,465 2,701
2,695 2,496 2,214 2,195 2,958 3,837 4,187 3,725 3,140 2,257 2,48s 2,701
of lhe 2017 lRP, are a@ounted for in the load and resour@ balane. The peak load fore€st does not include tha impac'l of axisting or nil demand response programs, which are both
a@unted for in the load and resourca balance.
2017 lntegrated Resource Plan-Appendix C Page 5
Sales and Load Forecast Data ldaho Power Company
Monthly Summaryr 112029 212029 312029 412029 512029 612029 712029 812029 912029 1012029 1112029 12t2O29
Average Load (aMWFSOh Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
958
547
3
311
133
166
780
507
3
309
130
145
678
467
10
306
123
132
582
471
140
292
12',1
1U
615
505
630
323
116
189
756
549
690
316
122
213
719
554
540
320
122
195
558
517
352
317
'120
158
529
471
370
297
119
152
521
485
78
320
118
126
746
505
5
308
130
142
929
546
3
301
1U
163
2,118
1,966
2,237
2,118
1,875
1,727
1,986
t,875
1,717
1,573
1,820
1,717
2,646
2,386
2,871
2,646
2,451
2,172
2,653
2,451
2,021
1,817
2,198
2,O21
1,648
1,468
1,778
1,6'18
1,837
1,694
1,951
1,837
2,075
1 ,916
2,212
2,O75
1,740 1,939 2,379
1,572 1,754 2,162
1,874 2,084 2,537
1,74 1,939 2,379
Peak Load (MWFgoth Percentile
2,207 2,981 3,871System Peak (1 hour)
Total Peak Load
2,712 2,509 2.224 4,240 3,768 3,169 2,269 2,478 2,713
2,712 2,509 2,224 2,207 2,981 3,871 4,240 3,768 3,169 2,269 2,478 2,f '.t3
Monthty Summaryr 112030 212030 3t2030 412030 5/2030 6/2030 7t2O3O 8/2030 912030 1012030 1'1t2030 1212030
Average Load (aMWFSOh Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
967
551
3
313
'133
168
683
469
10
308
123
133
585
474
141
293
121
135
534
475
373
299
119
153
622
508
634
325
116
191
765
552
694
318
122
214
728
559
543
322
122
197
563
521
354
318
120
159
787
510
3
31 1
'130
146
525
488
79
322
118
126
751
509
5
310
130
143
937
550
3
303
134
164
2,135
1,982
2,255
2,135
1,888
1,739
2,000
1,888
1,727
1,582
1,840
1,727
2,667
2,404
2,874
2,667
2,471
2,190
2,675
2,471
2,035
1,831
2,214
2,O35
1,658
1,477
1,789
1,658
1,8/E
1,705
1,963
1,8rl8
2,090
1,929
2,228
2,090
1,7 51 I,952 2,396
1,582 1,766 2,177
1,874 2,098 2,571
1,751 1,952 2,396
Peak Load (MWFgoth Percentile
2,218 3,002 3,903System Peak (1 hour)
Total Peak Load
2,730 2,522 2,235 4,292 3,809 3,195 2,280 2,489 2,722
2,730 2,522 2,235 2,218 3,002 3,903 4,292 3,809 3,195 2,280 2,489 2,722
Monthly summaryr 1t2031 212031 3t2031 4t2O31 5t2O31 6/2031 7t2O31 8t2O31 9t2O31 1Ot2031 11t2O31 12t2O31
Average Load (aMwFsoth Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
976
555
3
315
133
169
793
513
3
313
130
147
539
478
375
300
119
154
629
511
637
327
116
192
774
556
698
320
122
216
737
563
546
324
122
199
569
524
356
320
120
161
756
512
5
312
130
144
944687590
478
142
295
121
136
528
491
79
323
118
127
472
310
553
3
3(X
1U
165
't0
123
133
2,151
1,997
2,262
2,151
r,900
1,750
2,0',13
1,900
1,736
1,590
1,850
1,736
2,686
2,421
2,877
2,686
2,491
2,207
2,714
2,491
2,O49
1,843
2,200
2,O49
t,667
1,486
1,799
t,667
1,859
1,715
1,975
t,859
2,103
1,942
2,220
2,103
1,761 1,965 2,412
1,591 1,778 2,192
1,885 2100 2,588
1,761 1,965 2,412
Peak Load (MWFgoth Percentile
2,230 3,023 3,935System Peak (1 hour)
Total Peak Load
2,747 2,534 2,245 4,344 3,851 3,222 2,292 2,501 2,725
2,747 2,534 2,215 2,230 3,023 3,93s 4,3U 3,85t 3,222 2,292 2,501 2,725
of the 2017 lRP, are a@unted for in the load and resource balance. The peak load forecast does not include the impacl of existing or nsw demand response programs, which are both
accounted for in the load and rasour€ balane.
Page 6 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Sales and Load Forecast Data
Monthly Summaryi 112032 212032 312032 412032 512032 G12032 712032 812032 912032 1ot2o32 1112032 1212032
Average Load (aMw)-soth Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
983
559
3
316
133
170
770
499
3
304
126
143
543
481
377
302
119
'155
634
514
640
328
116
193
782
559
702
321
123
218
744
567
549
325
122
200
573
528
357
322
120
162
953
557
3
305
134
'166
691
474
10
311
123
134
593
481
142
296
121
137
530
495
80
325
118
128
760
516
6
314
130
144
2,165
2,O10
2,277
2,165
1,84s
1,699
1,963
t,845
1,74
1,597
1,849
1,74
2,704
2,437
2,896
2,704
2,508
2,223
2,734
2,508
2,062
1,855
2,214
2,062
1,676
1,493
1,820
1,676
1,869
't,724
't,975
1,869
2,119
1,956
2,236
2,119
1,770 1,976 2,427
1,599 1,788 2,206
1,895 2,125 2,589
1,770 1,976 2,427
Peak Load (Mw)-g0ft Percentile
2,237 3,042 3,963System Peak (1 hour)
Total Peak Load
2,755 2,544 2,248 4,394 3,890 3,245 2,301 2,511 2,737
2,755 2,54 2,24 2,237 3,042 3,963 4,394 3,890 3,245 2,301 2,511 2,737
Monthly Summaryl 112033 212033 3/2033 412033 5/2033 6/2033 712033 8/2033 9/2033 t0/2033 11t2O33 1212033
Average Load (aMWFsoth Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
994
563
3
318
134
172
696
477
10
313
124
135
597
484
143
298
121
138
548
485
379
303
119
156
642
518
644
330
117
195
792
563
706
323
123
219
754
572
552
327
122
202
806
520
3
316
131
150
580
532
360
323
120
163
534
498
80
327
119
129
766
520
6
315
130
145
963
561
3
307
134
168
2,184
2,027
2,307
2,184
1,925
1,773
2,039
,t,925
1,79
1,507
1,860
1,754
2,725
2,457
2,937
2,725
2,530
2,242
2,738
2,530
2,O78
1,869
2,231
2,078
1,686
1,502
1,831
't,686
1,882
1,736
1,989
1,882
2,136
'l,972
2,255
2,136
1,781 1,991 2,445
1,610 1,801 2,222
1,907 2,140 2,608
1,781 1,991 2,U5
Peak Load (MWFgoth Percentile
2,249 3,064 3,997System Peak ('l hour)
Total Peak Load
2,775 2,554 2,260 4,447 3,932 3,274 2,313 2,524 2,752
2,775 2,5s4 2,260 2,249 3,064 3,997 4,447 3,932 3,274 2,313 2,524 2,752
Monthly Summary, 112034 212034 3/2034 412034 512034 612034 712034 812034 912034 1Ol2O34 1112034 1212034
Average Load (aMw)-soth Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
1,007
568
319
814
524
3
318
131
'151
702
479
10
315
124
136
650
521
648
332
117
196
803
567
710
324
123
221
765
577
556
329
122
204
587
537
362
325
120
164
539
502
81
328
119
130
773
523
6
317
130
147
3
134
173
603
488
144
299
121
139
555
488
381
305
119
157
975
566
3
309
134
169
2,204
2,046
2,328
2,204
t,9lo
1,787
2,055
1,9,O
1,766
1,617
't,872
1,766
2,748
2,478
2,962
2,748
2,553
2,262
2,763
2,553
2,O94
1,884
2,248
2,O94
1,697
1,512
1,843
1,697
1,896
1,748
2,003
1,896
2,155
1,990
2,286
2,155
1,794 2,005 2,464
1,621 1,815 2,240
1,932 2,143 2,629
1,794 2,006 2,4G4
Peak Load (MWFgoth Percentile
2,263 3,088 4,034System Peak (1 hour)
Total Peak Load
2,799 2,571 2,274 4,502 3,978 3,305 2,327 2,539 2,765
2,799 2,571 2,214 2,263 3,088 4,034 4,502 3,978 3,30s 2,327 2,539 2,765
of the 2017 lRP, are amunled for in the load and resoure balane. Th€ p€ak load forecast do6s not include the impact of existing or nil demand response prcgrams, which are both
a@unted ior in the load and resour€ balancs.
2017 lntegrated Resource Plan-Appendix C Page 7
Sales and Load Forecast Data ldaho Power Company
Monthly Summaryr 112035 212035 312035 4t2O35 5/2035 6r203s 7l203s 812035 9/2035 10/2035 1ll2u35 1212035
Average Load (aMWFsOh Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
'1,019
573
3
321
134
175
823
527
3
319
131
152
709
482
10
316
124
137
608
491
145
301
122
140
658
525
652
333
117
198
777
582
559
330
122
206
594
541
364
326
120
166
780
528
6
318
131
148
561
492
384
306
120
159
814
571
715
326
123
223
544
505
81
330
119
130
987
570
3
310
134
171
System Peak (1 hour)2,820 2,585 2,286
1,806 2,021 2,481
1,632 1,829 2,258
1,946 2,160 2,650
1,806 2,021 2,484
Peak Load (MWF90h Percentile
2,276 3,112 4,072 4,s57 4,023 3,336 2,340 2,553 2,783
2,225
2,066
2,340
2,225
1,956
1,801
2,072
1,956
1,778
1,629
1,885
1,778
2,772
2,499
2,987
2,772
2,576
2,283
2,788
2,576
2,112
'1,899
2,28'.1
2,112
1,709
1,523
1,844
1,709
1,910
1,762
2,019
1,910
2,176
2,009
2,308
2,176
Total Peak Load 2,820 2,58s 2,286 2,276 3,112 4,072 4,557 4,023 3,336 234iJ 2,s53 2,783
Monthly Summaryr 112036 212036 3/2036 412036 5/2036 6/2036 712036 8/2036 9/2036 10/2036 tll2036 1212036
Average Load (afiwFsorh Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
1,034
578
3
323
134
177
805
513
3
3t0
126
148
614
495
146
302
122
141
668
530
657
335
't17
200
827
575
720
328
123
225
602
546
367
328
120
167
789
532
6
320
131
149
716
486
't0
318
124
138
568
496
386
308
120
160
549
509
82
331
119
131
1,000
575
3
311
134
173
789
587
563
332
122
208
2,24
2,087
2,364
2,248
t,905
1,755
2,017
1,905
1,791
1,641
1,909
1,791
2,798
2,522
2,997
2,798
2,602
2,305
2,835
2,602
2,130
1,916
2,287
2,130
1,722
1,534
1,857
1,722
1,926
1,776
2,046
1,926
2,197
2,028
2,319
2,',t97
I,820 2,038 2,506
1,644 1,844 2,277
1,948 2,178 2,688
't,820 2,038 2,506
Peak Load (MWFgoth Percentile
2,291 3,138 4,112System Peak (1 hour)
Total Peak Load
2,846 2,604 2,301 4,613 4,070 3,370 2,354 2,569 2,801
2,846 2,604 2,301 2,291 3,138 4,112 4,613 4,070 3,370 2,354 2,569 2,801
of the 2017 lRP, ar6 accounted for in the load and resour@ balance. The peak load forec€st des not include lhe impact of existing or nsfl demand response programs, which are botha@unted for in lhe load and resource balan@.
Page 8 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Sales and Load Forecast Data
Annual Summary
2017 20t8 20t9 2020 2021 2022 2023 2024 2025 2026
Billed Sales (lrwhFsOh Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
System Sales
Total Sales
5,'t92,299
4,076,548
1,932,624
2,451,735
945,1 67
5,284,270
4,1 23,898
1,943,945
2,524,052
961,532
5,387,516
4,161,677
1,958,945
2,560,579
972,050
5,433,174
4,191,974
't,970,715
2,586,1 1 6
979,308
5,493,900
4,224,260
1,979,560
2,601,172
982,862
5,587,539
4,256,4'.t6
1,993,436
2,614,083
990,453
5,680,823
4,288,363
2,005,655
2,629,176
1,O11,238
5,764,006
4,316,202
2,016,870
2,643,507
1,083,805
5,826,598
4,344,798
2,027,030
2,656,723
1,086,225
5,889,242
4,377,647
2,037,054
2,669,379
1,085,654
14,598,372
14,598,372
14,841,697
14,841,697
15,040,768
15,040,768
15,161,288
15,'t61,288
15,251,755
15,281,755
15,441,927
15,41,927
15,615,255
r5,6r5,255
1 5,824,391
15,824,39{
15,941 ,373
t 5,941,373
16,058,976
16,058,976
Generation Month Sales (Mwh)-sos Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
System Sales
Total Sales
Loss
5,1 99,31 6
4,O79,292
1,932,630
2,457,663
945,1 67
5,295,568
4,126,078
1,943,953
2,527,046
96 t .532
5,390,883
4,163,415
1,958,952
2,562,672
972,050
5,437,684
4,193,828
1,970,720
2,587,350
979,308
5,500,755
4,226,101
1,979,568
2,602,230
982,862
5,594,373
4,258,242
1,993,443
2,615,320
990,453
5,686,930
4,289,946
2,005,661
2,630,351
1,011,238
5,768,617
4,317,830
2,016,876
2,644,590
1,083,805
5,831,239
4,346,675
2,027,036
2,657,760
1,086,225
s,895,050
4,379,442
2,037,061
2,670,478
1,085,654
14,614,068 14,854,177 15,047,972 15,168,890 15,291,516 15,451,831 15,624,126 15,831,717 15,948,935 16,067,685
14,6t4,068
1,242,079
14,85d.,177
1,261,466
15,047,972
't,277,968
ts,t68,890
1,288,110
15,291,516
1,298,996
t5,451,831
1 ,313,309
15,624,126
1,327,880
1s,831,717
1,342,679
15,9/t8,935
1 ,353,1 86
16,067,685
1,364,020
Required Generation 15,856,147 16,115,643 16,325,941 16,457,000 16,590,511 16,765,141 16,952,006 17,174,396 17,302,121 17,431,7Os
Average Load (aUtrVFSOh Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
594
466
221
281
108
142
605
471
222
288
110
144
6'15
475
224
293
111
146
619
477
224
295
111
147
628
482
226
297
112
148
639
486
228
299
113
150
649
490
229
300
115
152
657
492
230
301
123
153
666
496
231
303
124
154
673
500
233
305
124
156
'1,810
1,844
1,94t
1,840
't,671
1,972
1,864
1,693
1,997
1,874
1,702
2,008
1,894
1,720
2,030
1,914
1,738
2,051
'I,935
1,758
2,075
1,955
't,776
2,095
1,975
1,794
2,117
1,990
1,808
2,133
1,810 1,840 1,864 1,874 1,894 1,914 1,935 1,955 1,975 1,990
Peak Load (MWF90h Percentile
3,566 3,630 3,692 3,745 3,797 3,854 3,912 3,974 4,026 4,078System Peak (1 Houo
Total Peak Load 3,566 3,630 3,G92 3,745 3,797 3,854 3,912 3,974 4,026 4,078
2017 lntegrated Resource Plan-Appendix C Page 9
Sales and Load Forecast Data ldaho Power Company
2027 2028 2029 2030 2031 2032 2033 2034 2035 2036
Billed Sales (MWhF50s Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
System Sales
Total Sales
5,967,300
4,409,099
2,050,468
2,682,789
1,086,654
6,042,091
4,436,214
2,062,925
2,698,620
1,089,273
6,107,379
4,469,871
2,074,075
2,714,704
1,087,891
6,164,550
4,500,782
2,086,1 55
2,730,194
'I,087,891
6,217 ,671
4,530,660
2,097,975
2,745,660
1,087,891
6,262,116
4,560,429
2,107,907
2,759,437
1,088,891
6,326,691
4,593,200
2,120,788
2,772,278
1,089,891
6,399,357
4,626,751
2,134,429
2,786,182
1,089,891
6,472,617
4,662,614
2,147,505
2,800,272
1,091,891
6,556,711
4,701,216
2,162,226
2,813,726
1,091,891
16,1 96,31 0
16,196,310
16,329,123
16,329,123
16,453,920
16,453,920
1 6,569,573
16,569,573
16,679,857
15,679,857
16,778,781
16,778,781
16,902,848
16,902,8/t8
17,036,61 0
17,036,610
17,174,899
17,174,899
17,325,771
17,325,771
Generation Month Sales (MWhFsOh Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
System Saleg
Total Sales
Loss
Required Generation
5,972,903
4,410,638
2,050,475
2,684,087
1,086,654
6,047,O37
4,438,137
2,062,931
2,699,938
1,089,273
6,1't1,779
4,471,632
2,074,082
2,715,974
1,087,891
6,168,711
4,s02,482
2,086,1 62
2,731,462
1,087,891
6,221,263
4,532,353
2,097,981
2,746,789
1,087,891
6,267,266
4,562,298
2,107,914
2,760,490
1,088,891
6,332,524
4,595,1 1 4
2,120,796
2,773,418
1,089,891
6,405,338
4,628,801
2,134,436
2,787,337
1,089,891
6,479,512
4,664,824
2,147,513
2,801,375
'1,091,891
6,563,740
4,703,281
2 j42,234
2,814,823
1,091,891
16,204,757 16,337,317 16,461,358 16,576,708 16,686,278 16,786,859 16,911,743 17,045,803 17,185,114 17,335,969
16,204,757
1,376,496
't6,337,3r7
1,388,365
16,461,358
1,399,639
16,576,708
1,410,019
r6,686,278
1 ,419,853
16,786,859
1,428,827
16,911,743
1,440,150
{7,0't5,803
1,452,371
17,185,114
1,464,969
17,335,969
1,478,800
17,581,253 17,725,682 17,860,997 17,986,727 18,106,130 18,215,685 18,351,893 18,498,173 18,650,084 18,814,769
Average Load (ailW)-5orh Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
LoSs
System Load
Light Load
Heavy Load
Total Load
682
503
234
306
124
157
688
505
235
307
124
158
698
510
237
310
124
160
704
514
238
312
124
161
710
s',t7
239
314
124
162
713
519
240
314
124
163
731
528
244
318
124
166
747
535
246
320
124
168
723
525
242
317
124
164
740
533
245
320
125
167
2,007
1,823
2,151
2,018
1,833
2,164
2,039
1,852
2,1 86
2,053
1,865
2,201
2,067
1,877
2,209
2,074
1,884
2,216
2,095
1,903
2,239
2,112
1 ,918
2,258
2,129
1,934
2,275
2,142
1,946
2,289
2,OO7 2,018 2,039 2,053 2,067 2,074 2,095 2,112 2,129 2,142
Peak Load (trlwFgolh Percentile
4,132 4,187 4,240 4,292 4,344 4,394 4,447 4,502 4,557 4,613System Peak (1 Hour)
Total Peak Load 4,132 4,187 4,240 4,292 43U 4,394 4,447 4,502 4,557 4,613
Page 10 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Sales and Load Forecast Data
70th Percentile Annual Forecast Growth Rates
2017-2022 2017-2027 2017-2036
Sales
Residential Sales
Commercial Sales
lrrigation Sales
lndustrial Sales
Additional Firm Sales
System Sales
TotalSales
Loads
Residential Load
Commercial Load
lrrigation Load
lndustrial Load
Additional Firm Sales
System Load Losses
System Load
Total Load
Peaks
System Peak
Total Peak
Winter Peak
Summer Peak
Customers
Residential Customers
Commercial Customers
lrrigation Customers
lndustrial Customers
1.49o/o
0.88%
0.58%
1.29o/o
o.940/o
1.13o/o
1.130/o
1.49o/o
0.88%
0.58%
1.25%
0.94%
1.12%
1.12%
1.12%
1.57%
1.57%
1.2Oo/o
1.57o/o
2.11o/o
1.86%
1.42o/o
0.50%
1.41%
0.80%
0.56%
0.90%
1.40%
1.05%
1.O5%
1.40o/o
0.80%
0.56%
0.89%
1.40o/o
1.03o/o
1.04o/o
1.04o/o
1.49%
1.49%
1.O3o/o
1.49%
2.02%
1.90%
1.37o/o
0.65%
1.240/o
0.77o/o
0.56%
O.73o/o
O.760/o
o.91%
0.91%
1.22%
0.75o/o
0.54o/o
0.7oo/o
O.760/o
O.91o/o
0.89%
0.89%
1.370/o
1.370/o
0.87%
1.37o/o
'1.78%
1.77%
1.29%
0.59%
2017 lntegrated Resource Plan-Appendix C Page 1 1
70th Percentile Load Forecast
Monthly Summaryr 112017 212017 312017 412017 512017 612017 712017 812017 912017 1Ol2O17 1112017 1A2O17
Average Load (aMWF7os Percentile
Sales and Load Forecast Data ldaho Power Company
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
845
504
2
281
113
't49
690
472
3
279
111
131
604
437
10
277
106
120
460
435
394
268
'105
142
542
471
633
292
102
177
614
504
516
289
108
't76
483
474
341
286
107
144
664
463
5
279
112
128
513
433
152
263
106
123
653
511
664
285
108
194
463
447
78
289
104
114
819
504
3
278
114
146
r,894
1,759
2,011
r,894
{,686
1,553
1,786
r,686
1,555
1,424
1,649
{,555
2,415
2,'t77
2,620
2,415
2,207
1,956
2,389
2,207
1,834
'1,650
1,982
1,834
1,495
1,332
1,624
t,49s
r,650
1,522
1,753
1,650
{,863
't,720
1,986
't,863
1,591 {,803 2,217
1 ,437 1 ,631 2,015
1,714 1,938 2,365
1,59t t,803 2,217
Peak Load (MWFgStn Percentile
2,020 2,686 3,431System Peak (1 hour) 2,441 2,358 2,067 3,586 3,248 2,781 2,091 2,307 2,611
Total Peak Load 2,U1 2,358 2,067 2,020 2,686 3,43t 3,586 3,248 2,78'.t 2,091 2,307 2,61'l
Monthly Summaryr 1n018 2t2018 3/2018 4t2018 512018 El2O18 712018 812018 9/2018 10120'18 1112018 1212018
Average Load (aitIryFTOh Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
860
510
2
289
115
't52
702
477
3
288
't 13
133
6t4
442
10
285
108
122
522
438
153
271
107
125
553
477
636
300
103
180
492
480
343
294
109
146
674
469
5
287
114
130
469
440
396
276
107
144
667
517
667
294
'110
197
627
511
519
298
110
179
471
452
78
297
106
116
833
509
3
282
116
148
System Peak (1 houo 2,487 2,393 2,101
1,617 1,831 2,250
1,461 1,657 2,045
1,742 1,969 2,400
1,617 1,831 2,250
Peak Load (MWFgsth Percentile
2,048 2,724 3,489 3,651 3,305 2,833 2,118 2,335 2,648
1,929
1,791
2,038
I,929
1,716
1,580
1,818
1,716
1,581
1,448
1,676
t,58t
2,452
2,211
2,660
2,452
2,243
1,988
2,428
2,243
1,864
1,677
2,028
t,864
1,521
1,355
'1,640
1,s21
1,679
1,548
1,783
1,679
1,891
1,745
2,015
1,891
Total Peak Load 2,487 2,393 2,101 2,04 2,724 3,489 3,651 3,305 2,833 2,118 2,335 2,648
Monthly Summaryr l/2019 2l20't9 3/2019 412019 512019 6/2019 712019 812019 912019 10/2019 1112019 12t2019
Average Load (ailwFToth Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
876
515
3
294
117
154
530
442
154
275
109
127
478
444
399
280
108
146
565
481
641
305
104
182
682
521
672
298
1't'l
200
642
516
523
302
1't'l
181
502
485
346
299
1t0
148
478
456
79
302
'l07
't17
843
513
3
285
117
150
714
481
3
292
'115
135
624
445
11
289
109
123
685
473
5
291
115
131
1,958
1 ,818
2,068
1,958
1,740
1,602
1,843
1,740
t,601
1,467
1,707
I,601
2,485
2,240
2,678
2,485
2,274
2,015
2,461
2,274
r,889
1,699
2,055
1,889
1,sn
1,372
1,661
{,5lo
1,701
1,569
1,807
1,701
1,9t0
1,764
2,036
1,9{0
1,637 t,854 2,278
1,480 1,678 2,070
1,7s3 1,993 2,444
1,637 t,854 2,278
Peak Load (MWF95h Percentile
2,073 2,758 3,540System Peak (1 hour
Total Peak Load
2,530 2,426 2,132 3,713 3,359 2,876 2,141 2,359 2,666
2,530 2,426 2,132 2,073 2,758 3,5/O 3,713 3,359 2,876 2,141 2,359 2,666
of the 201 7 lRP, are accrunted for in tha load and resour@ balan@. The peak load fore€st doss not includa the impact of sxisting or nw damand response programs, which are both
accounted for in lh6 load and Esourca balanca.
Page 12 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Sales and Load Forecast Data
Monthly Summaryr 1l2O2O 212020 3l2O2O 412020 5t202O 6t202O 712020 812020 912020 1012020 1112020 1212020
Ayerage Load (aMWF7oth Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
883
519
c
297
'118
155
628
448
11
292
110
124
481
460
79
305
108
118
695
468
3
285
112
131
534
446
155
278
109
128
483
447
401
283
108
147
571
485
645
308
105
183
690
525
676
301
112
202
650
520
526
305
111
183
507
489
348
302
110
149
690
477
5
294
116
132
851
517
3
287
118
151
1,975
1,834
2,086
1,97s
1,693
1,559
'l,792
r,693
1,613
1,477
1 ,719
t,613
2,506
2,259
2,701
2,506
2,295
2,034
2,501
2,295
1,904
I ,713
2,057
't,904
1,55r
1,382
1,673
r,55r
1,714
1,581
1,831
1,714
1,926
1,778
2,043
1,926
t,650 1,869 2,297
1,490 1,691 2,087
1,766 2,022 2,450
1,650 1,859 2,297
Peak Load (MWFgsth Percentile
2,087 2,780 3,574System Peak (1 hour)
Total Peak Load
2,550 2,438 2,146 3,766 3,402 2,904 2,154 2,373 2,671
2,550 2,438 2,146 2,087 2,780 3,574 3,766 3,402 2,904 2,1* 2,373 2,671
Monthly Summaryr 112021 2t2021 312021 412021 5t2O21 612021 712021 812021 912021 10t2021 11t2021 12t2021
Average Load (aMWFTOh Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
893
524
3
298
118
157
727
488
3
297
116
137
634
450
11
294
111
125
489
451
402
284
109
148
579
488
647
310
105
'185
701
529
679
JU5
112
203
659
525
528
307
112
185
486
463
80
306
108
119
696
481
E
296
116
133
539
449
156
275
110
129
513
493
349
303
111
150
863
521
3
288
119
153
1,993
1,850
2,115
1,993
1,768
1,628
1,872
1,768
1,624
1,488
1,722
1,624
2,527
2,278
2,723
2,527
2,316
2,052
2,524
2,316
1,920
1,727
2,074
1,920
1,562
1,392
1,696
1,562
1,727
1,593
'1,835
1,727
r,946
1,796
2,064
l,9tf6
1,652 1,883 2,31s
't,501 1,704 2,104
1,779 2,038 2,469
1,662 1,883 2,315
Peak Load (MWlg5tn Percentile
2,098 2,803 3,606System Peak (1 hour)
Total Peak Load
2,562 2,450 2,153 3,819 3,444 2,932 2,168 2,387 2,691
2,562 2,450 2,153 2,098 2,803 3,606 3,819 3,444 2,932 2,168 2,387 2,691
Monthly Summaryl 112022 212022 312022 412022 5t2O22 6t2022 712022 812022 912022 1012022 1112022 1212022
Average Load (aMw)-7oth Percentile
Residentlal
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
673
530
532
308
113
187
493
466
80
308
109
120
908
528
3
300
119
159
738
492
3
298
117
139
643
453
11
295
112
126
547
453
156
281
111
130
498
455
405
286
110
150
590
492
652
311
106
187
715
533
684
304
113
206
706
484
5
297
117
135
877
525
3
290
120
155
522
497
352
305
111
152
System Peak (1 hour) 2,591 2,472 2,173
1,678 1,902 2,338
1 ,516 1,721 2,125
1,796 2,058 2,494
1,678 1,902 2,338
Peak Load (MW)-95s Percentile
2,1',t6 2,830 3,647 3,876 3,492 2,966 2,184 2,405 2,708
2,O17
1,872
2,141
2,O17
1,787
1,645
1,892
1,787
1,640
1,502
1,739
1,640
2,554
2,303
2,771
2,5*
2,342
2,075
2,535
2,342
r,939
1,744
2,095
r,939
1,577
1,405
1,712
1,577
1,745
I ,610
1,854
1,745
1,968
1,817
2,087
t,968
Total Peak Load 2,591 2,472 2,173 2,116 2,830 3,647 3,876 3,492 2,966 2,184 2,405 2,708
of tho 2017 lRP, are aGounted for in the load and resourc€ balance. The peak load foreGst does not include the impact of existing or nil demand response programs, which are both
a@unted for in the load and resoure balane.
2017 lntegrated Resource Plan-Appendix C Page 13
Sales and Load Forecast Data ldaho Power Company
Monthiy Summaryr 112023 A2023 312023 N2O23 512023 6,12023 712023 812023 912023 1012023 1112023 1212023
Average Load (aMWF7orh Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
923
533
3
301
122
161
602
496
655
313
108
189
500
470
81
310
111
121
750
495
3
300
120
140
652
456
't'l
297
114
128
555
456
157
282
113
131
507
458
407
288
112
15'l
729
537
688
306
115
208
687
534
535
310
115
189
532
501
354
307
113
154
716
299
889
529
3
291
123
156
488
o
120
136
System Peak (1 hour) 2,619 2,493 2,192
1,695 1,922 2,363
1,532 1,739 2,147
1,826 2,066 2,520
1,695 1,922 2,363
Peak Load (Mw)-gsrh Percentile
2,134 2,858 3,690 3,934 3,541 3,002 2,202 2,426 2,725
2,043
1,896
2,1 68
2,O43
1,808
1,665
1 ,915
r,808
1,657
1 ,518
1,757
t,657
2,582
2,328
2,801
2,582
2,369
2,100
2,564
2,369
r,960
1,763
2,1't8
1,960
1,592
1,419
1,729
1,592
t,765
1,628
1,875
t,765
1,99{
1,838
2,123
1,991
Total Peak Load 2,619 2,493 2,192 2,134 2,858 3,690 3,934 3,54{ 3,002 2,202 2,426 2,725
Monthly Summaryr 112024 2t2024 3t2O24 412024 512024 612024 712024 812024 912024 10t2O24 1112024 12t2O24
Average Load (aMw)-7oth Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
936
537
3
303
'133
'163
733
481
3
291
126
137
660
458
1'.|
298
123
129
563
459
158
284
121
133
515
461
409
289
119
153
612
499
659
315
116
191
699
538
538
312
121
19'l
540
505
356
308
119
155
725 900
532
3
293
133
158
742
540
692
308
122
210
506
473
81
311
118
123
491
6
300
130
138
2,074
't,926
2,191
2,074
1,771
1,631
1,875
1,771
1,679
1,538
1,790
1,679
2,614
2,356
2,817
2,614
2,400
2,126
2,597
2,400
I,984
1,784
2,158
1,984
1,612
1,436
1,739
1,612
I,790
1,651
1,902
1,790
2,O19
1,864
2,152
2,019
1,717 I,9/r5 2,390
1,551 1,760 2,172
1,838 2,091 2.565
1,717 I,9r15 2,390
Peak Load (MW)-gsth Percentile
2,156 2,890 3,735System Peak (1 hour)
Total Peak Load
2,654 2,520 2,217 3,998 3,594 3,040 2,225 2,454 2,747
2,8il 2,520 2,217 2,156 2,890 3,73s 3,998 3,594 3,0,O 2,22s 2,4il 2,747
Monthly Summaryl 112025 212025 312025 412025 512025 612025 712025 812025 912025 1Ol2O25 1112025 1212025
Average Load (aMWFTOh Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
946
541
3
305
133
164
767
501
3
303
130
143
666
460
11
300
123
130
568
462
159
285
121
134
620
502
662
316
116
192
709
542
540
313
122
193
546
509
357
310
120
156
510
476
81
313
118
124
909
536
3
294
134
159
521
464
411
291
119
154
731
495
6
302
130
139
753
543
695
309
122
212
System Peak (1 hour) 2,668 2,533 2,226
1,728 1,959 2,408
1,562 1,773 2,189
1,850 2,106 2,584
1,728 1,959 2,408
Peak Load (MWF95$ Percentile
2,167 2,91't 3,766 4,050 3,636 3,066 2,236 2,466 2,754
2,091
1,942
2,209
2,09t
1,848
1,702
1,957
1,848
1,690
1,548
1,801
{,690
2,535
2,375
2,839
2,635
2,420
2,145
2,638
2,420
1,999
1,798
2,1 59
I,999
1,622
1,445
1,750
1,622
1,803
1,663
1,926
{,803
2,035
1,879
2,158
2,035
Total Peak Load 2,668 2,533 2,226 2,167 2,911 3,766 4,050 3,636 3,066 2,236 2,466 2,754
ol lhe2017 lRP, are a@unted for in lhe load and resource balane. The peak load fore€st does not indude the impact of existing or nafl demand response prcgrams, which are both
accounted for in the load and Esour€ balane.
Page 14 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Sales and Load Forecast Data
Monthly Summaryr 112026 212026 312026 412026 s12026 612028 7t2028 8t2o26 9t2o28 1ot2o26 11t2026 12t2o26
Average Load (aMW)-70th Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
956
545
3
306
133
166
774
505
3
304
130
144
671
463
11
301
123
131
573
465
159
287
121
135
738
499
5
303
130
'140
919
540
3
296
134
161
527
468
412
292
119
155
628
506
665
318
116
194
763
547
698
311
122
214
720
547
543
315
122
195
553
513
359
311
120
158
515
479
82
314
118
124
2,109
1,958
2,228
2,1 09
t,86r
1,714
1,971
t,86'l
1,700
1,558
1,813
1,700
2,656
2,394
2,862
2,656
2,441
2,163
2,660
2,441
2,014
1,81 1
2,176
2,014
1,633
1,455
't,761
1,633
1,815
1,674
1,939
,l,8t 5
2,052
1,895
2,177
2,O52
1,7& 1,973 2,426
1,572 ',t,786 2,205
1,863 2,135 2,588
1,740 1,973 2,426
Peak Load (MWFgsth Percentile
2,178 2,933 3,798System Peak (l hour)
Total Peak Load
2,682 2,542 2,233 4,102 3,578 3,093 2,248 2,479 2,769
2,682 2,542 2,233 2,178 2,933 3,798 4,102 3,678 3,093 2,28 2,479 2,769
Monthly Summaryl 112027 212027 312027 412027 sl2027 Gl2O27 712027 812027 912027 1012027 1112027 12t2027
Average Load (aMw)-7oth Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
968
550
3
308
133
147
784
508
J
306
130
146
679
466
11
303
123
132
579
469
160
288
121
136
534
472
415
293
119
156
776
551
703
312
122
216
561
517
361
313
120
159
520
483
82
316
118
125
930
544
3
297
134
162
638
509
669
319
116
195
732
552
547
316
122
197
746
502
6
305
130
141
2,129
1,977
2,260
2,129
1,877
1,729
1,988
1,877
'1,713
1,569
1,817
't,713
2,580
2,416
2,888
2,680
2,465
2,184
2,686
2,465
2,031
1,827
2,195
2,031
1,645
1,465
1,786
1,6tt5
r,830
1,688
1,944
1,830
2,O71
1,912
2,1 96
2,O71
1,753 1,990 2,447
1,584 1,800 2,224
1,877 2,153 2,610
1,753 1,990 2,447
Peak Load (MW)-gsth Percentile
2,192 2,957 3,836System Peak (1 hour
Total Peak Load
2,705 2,559 2,248 4,157 3,723 3,124 2,262 2,493 2,784
2,705 2,559 2,24 2,192 2,957 3,836 4,157 3,723 3,124 2,262 2,493 2,784
Monthly Summaryr 112028 A2028 312028 412028 512028 612028 712028 812028 912028 1ot2o28 11t2028 12t2028
Average Load (aMWF7orh Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
980
554
3
309
134
169
585
472
161
290
121
137
568
521
363
315
120
161
941
548
3
299
134
164
765
494
J
297
126
142
685
468
11
305
123
133
541
475
417
295
119
158
647
512
673
321
1'16
197
788
554
707
314
123
218
743
556
550
318
122
199
525
486
83
318
118
126
753
506
6
307
130
142
2,149
1,995
2,281
2,149
1,827
',l,682
1,934
1,827
1,725
1,580
1,829
1,725
2,704
2,438
2,933
2,704
2,4A8
2,205
2,692
2,488
2,O48
1,842
2,213
2,048
1,656
1,476
1,799
1,656
1,844
1,701
1,959
1,84
2,088
't,928
2,226
2,088
1,766 2,005 2,467
1 ,596 1 ,815 2,242
'1,902 2,156 2,632
1,766 2,005 2,4G7
Peak Load (MW)-gsrh Percentile
2,206 2,981 3,872System Peak (1 hour) 2,728 2,574 2,263 4,212 3,768 3,155 2,276 2,509 2,796
Total Peak Load 2,728 2,574 2,263 2,206 2,981 3,872 4,212 3,768 3,155 2,276 2,509 2,796
of the 2017 lRP, are accounted for in the load and resourc€ balance. Tha peak load fors€st doss not include the impac{ of existing or nil demand response programs, which are both
a@unted for in ths load and Esour€ balane.
2017 lntegrated Resource Plan-Appendix C Page 15
Sales and Load Forecast Data ldaho Power Company
Monthly Summaryi 112029 212029 312029 412029 512029 612029 712029 812029 912029 1012029 1112029 12t2029
Average Load (aMw)-7oth Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
991
558
3
311
133
171
691
471
11
306
123
134
548
478
419
297
119
159
656
516
676
323
116
199
760
509
6
308
130
144
800
515
3
309
130
148
591
475
162
292
121
138
799
558
711
316
122
220
754
561
553
320
122
201
575
525
365
317
't20
162
530
489
83
320
118
127
949
552
3
301
134
165
System Peak (1 hour) 2,745 2,588 2,273
1,778 2,020 2,486
1,607 1,828 2,259
1,915 2,172 2,652
1,778 2,020 2,486
Peak Load (MWFgsrh Percentile
2,218 3,004 3,906 4,265 3,811 3,183 2,288 2,521 2,807
2,167
2,012
2,290
2,167
1,906
1,756
2,O19
1,906
1,736
1,590
1,841
1,735
2,726
2,458
2,957
2,726
2,510
2,224
2,716
2,510
2,064
1,856
2,246
2,064
1,667
1,485
1,799
1,667
1,857
1,713
't,973
1,857
2,104
1,942
2,243
2,104
Total Peak Load 2,745 2,588 2,273 2,218 3,004 3,906 4,265 3,811 3,183 2,288 2,521 2,807
Monthly Summaryr 1t2O3O 2l2O3O 3/2030 rU2030 5/2030 612030 712030 8/2030 9/2030 10/2030 1112030 12l2O3O
Average Load (aMWF7oth Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
1,000
563
3
313
133
172
553
482
421
299
1't9
160
809
562
715
318
122
222
807
518
3
311
130
149
696
473
11
308
123
134
595
479
163
293
121
139
663
520
680
325
116
200
764
565
556
322
122
202
581
529
367
318
120
163
533
492
84
322
118
128
765
513
6
310
130
144
958
555
3
303
134
166
2,184
2,028
2,307
2,184
1,919
1,768
2,033
{,919
1,76
1,600
'I,861
1,7&
2,74
2,477
2,961
2,748
2,531
2,243
2,739
2,53't
2,079
1,870
2,262
2,O79
1,677
1,494
1,809
1,677
1,869
1,724
1,985
1,859
2,119
1,956
2,259
2,119
1,789 2,034 2,504
1,617 1,841 2,276
1,915 2,187 2,687
{,789 2,034 2,504
Peak Load (Mw)-gsth Percentile
2,230 3,025 3,939System Peak (1 hour)
Total Peak Load
2,763 2,601 2,284 4,317 3,853 3,210 2,299 2,533 2,817
2,763 2,601 2,284 2,230 3,025 3,939 4,317 3,853 3,210 2,299 2,533 2,817
Monthly Summaryl 112031 212031 3/2031 412031 5/2031 6/2031 712031 812031 9/2031 1012031 1112031 1212031
Average Load (aMw)-7oth Percentile
Residential
Commercial
lrrigatlon
lndustrial
Additional Firm
Loss
System Load
Light Load
HeaW Load
Total Load
1,009
567
3
315
133
173
813
522
3
313
130
150
700
476
'11
310
123
135
599
482
164
295
121
139
558
485
423
300
119
161
671
523
683
327
116
202
819
566
719
320
122
223
773
569
559
324
122
204
586
533
369
320
't20
164
537
496
84
323
118
129
517
312
965
559
3
304
134
168
770
6
130
145
2,200
2,043
2,314
2,200
t,931
1,779
2,046
1,931
1,755
1,608
1,871
1,755
2,768
2,496
2,965
2,768
2,551
2,261
2,780
2,551
2,094
1,883
2,247
2,094
1,687
1,503
1 ,819
r,687
r,880
1,7U
1,997
1,880
2,132
1,969
2,251
2,132
1,799 2,04 2,522
1,626 1 ,853 2,292
1,926 2,188 2,706
r,799 2,048 2,522
Peak Load (Mw)-gsth Percentile
2,241 3,047 3,971System Peak (1 hour)
Total Peak Load
2,780 2,613 2,294 4,370 3,896 3,237 2,311 2,545 2,820
2,780 2,613 2,294 2,241 3,047 3,971 4,370 3,896 3,237 2,311 2,545 2,820
of the 2017 lRP, are accounted for in the load and resour@ balance. The peak load fore€st does not include the impact of existing or nil demand response prcgrams, which are both
amunted for in lhe load and Esour@ balan@.
Page 16 2017 lntegrated Resource Plan-Appendix C
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
1,017
571
3
316
133
175
703
478
11
311
123
136
677
526
686
328
116
203
507
790 602
485
164
296
121
140
563
489
425
302
119
162
827
569
722
321
123
225
781
574
562
325
122
206
539
499
84
325
118
129
774
520
6
314
130
146
973
563
3
305
1U
169
591
537
371
322
120
165
3
304
126
146
ldaho Power Company Sales and Load Forecast Data
Monthly Summaryr 112032 212032 312032 4t2032 512032 6t2o32 7t2032 8t2O32 9t2032 1012032 1112032 1212032
Average Load (aMWF7oth Percentile
2,215
2,057
2,330
2,215
1,875
1,727
1,996
1,87s
1,763
1 ,615
1,870
1,763
2,787
2,512
2,985
2,787
2,570
2,277
2,800
2,570
2,107
1,895
2,261
2,107
1,69s
1,510
1,841
1,695
1,890
1,743
1,997
1,890
2,148
1,983
2,267
2,14
1,809 2,060 2,537
1,634 1 ,864 2,306
1,936 2,214 2,707
t,809 2,060 2,s37
Peak Load (MWFgsth Percentile
2,244 3,065 3,998System Peak (1 hour)
Total Peak Load
2,788 2,623 2,297 4,420 3,935 3,260 2,320 2,555 2,832
2,788 2,623 2,297 424 3,065 3,998 4,420 3,935 3,260 2,320 2,555 2,832
Monthly Summaryi 112033 212033 3/2033 412033 5/2033 6/2033 712033 812033 9/2033 10/2033 1112033 1212033
Average Load (aMWF7oth Percentile
Residential
Commercial
lnigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
1,028
576
3
318
134
176
826
528
3
316
131
152
709
481
11
313
124
137
606
488
165
298
121
141
569
492
427
303
119
163
543
502
85
327
119
130
780
524
6
315
130
147
984
567
3
307
134
170
685
530
690
330
117
205
598
542
373
323
120
167
838
573
726
323
123
227
792
579
565
327
'122
207
2,234
2,074
2,360
2,234
1,956
1,802
2,072
1,956
1,774
1,625
1,881
1,774
2,809
2,533
3,028
2,809
2,592
2,297
2,805
2,592
2,123
1,909
2,279
2,123
1,705
1 ,519
1,852
1,705
1,903
1,755
2,011
1,903
2,1 66
2,000
2,286
2,166
1,820 2,074 2,5s7
1,645 1,877 2,323
1,948 2,230 2,727
1,820 2,074 2,ss7
Peak Load (MWF95i,' Percentile
2,260 3,087 4,032System Peak (1 hour)
Total Peak Load
2,808 2,633 2,309 4,474 3,979 3,288 2,332 2,567 2,847
2,808 2,633 2,309 2,2G0 3,087 4,032 4,474 3,979 3,288 2,332 2,567 2,847
Monthly Summaryr 112034 A2O34 3t2O34 4t2o34 st2034 6t2o34 712034 8t2O34 9t2o34 1012034 1112034 12t2O34
Average Load (aMtru)-7oth Percenule
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
1,040
581
3
319
134
178
835
532
3
318
131
154
715
484
11
315
124
138
612
492
166
299
121
142
575
496
430
305
119
155
694
534
694
332
117
206
850
577
731
324
123
229
548
506
85
328
119
13'l
787
s2a
6
317
'130
148
995
572
3
309
134
172
605
546
376
325
120
168
804
583
568
329
122
209
2,2*
2,093
2,381
2,2s4
1,972
1 ,816
2,088
1,972
1,786
1,636
1,894
1,786
2,834
2,554
3,054
2,834
2,615
2,318
2,831
2,615
2,140
1,924
2,297
2,140
1,717
1,530
1,864
1,717
1,916
1,768
2,025
1,916
2,165
2,017
2,317
2,185
1,832 2,090 2,577
1,656 1,891 2,342
1,974 2,234 2,749
1,832 2,090 2,s77
Peak Load (MWFgsth Percentile
2,274 3,112 4,070System Peak (1 hour) 2,832 2,649 2,323 4,529 4,025 3,319 2,346 2,582 2,860
Total Peak Load 2,832 2,649 2,323 2,274 3,112 4,070 4,529 4,025 3,319 2,346 2,582 2,860
1 The sles and load ftre€st considar and refects th6 impacl of existing energy eficiency progEms on average lGd and peak demand. The nw energy eficiency programs, proposd as part
of the 201 7 lRP, arg accountgd fq in the load and resource b€lance. The peak load forecast does not include the impacl of existing or n* demand response prcgrams, which are both
ac@unted for h the load and resoure balane.
2017 lntegrated Resource Plan-Appendix C Page 17
Sales and Load Forecast Data ldaho Power Company
Monthly Summaryr 112035 212035 312035 412035 5/2035 6/2035 712035 8/2035 9/2035 10/2035 11t2035 1U2O35
Average Load (aMWF7oth Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
1,053
585
3
321
1U
180
844
536
3
319
131
155
721
487
11
316
124
139
617
496
167
301
122
143
582
500
432
306
120
166
703
538
698
333
117
208
862
581
735
326
123
231
815
589
572
330
122
211
612
551
378
326
120
170
552
510
86
330
119
't32
794
532
6
318
131
150
1,008
576
3
310
1U
174
2,275
2,113
2,393
2,275
1,988
1,830
2,105
t,988
1,798
1,647
1,906
't,798
1,845 2,'.t06 2,598
1,667 1,905 2,361
1,988 2,251 2,771
1,845 2,106 2,598
Peak Load (MWFg5th Percentile
2,287 3,135 4,107
2,858
2,577
3,080
2,858
2,640
2,339
2,857
2,640
2,1s7
1,940
2,331
2,157
1,728
1,540
1,865
1,728
t,931
1,781
2,O41
1,931
2,205
2,036
2,339
2,205
System Peak (1 houo
Total Peak Load
2,853 2,664 2,334 4,584 4,070 3,350 2,359 2,597 2.878
2,853 2,664 2,334 2,287 3,t35 4,107 4,584 4,070 3,350 2,359 2,597 2,878
Monthly summaryr 1t2036 a2036 3/2036 4t2036 s/2036 6/2036 7t2036 8/2036 9/2036 t0/2036 t1r2036 12t2036
Average Load (aliwFToth Percentile
Residential
Commercial
lrrigation
lndustrial
Additional Firm
Loss
System Load
Light Load
Heavy Load
Total Load
1,067
591
3
323
134
182
825
521
3
310
126
151
729
490
11
318
124
140
623
500
168
302
122
144
589
504
435
308
120
167
713
542
703
335
117
210
875
586
740
328
123
233
828
594
576
332
122
214
620
556
380
328
120
171
558
514
87
331
1t9
133
803
537
6
320
131
151
1,021
581
3
311
134
175
2,299
2,134
2,4',t7
2,299
r,936
1,783
2,049
1,936
1,811
1,659
1,931
1,811
1,859 2,123 2,620
1 ,680 1,92',t 2,381
1,990 2,269 2,A11
1,859 2,123 2,620
Peak Load (MWFgsth Percentile
2,302 3,161 4,148
2,885
2,601
3,090
2,885
2,666
2,362
2,905
2,666
2,176
1,957
2,336
2,176
1,741
1,551
1,878
1,741
1,947
1,796
2,068
't,947
2,227
2,056
2,350
2,227
System Peak (1 hour) 2,879 2,682 2,350 4,641 4,118 3,384 2,373 2,612 2,896
Total Peak Load 2,879 2,682 2,350 2,302 3,161 4,148 4,641 4,118 3,384 2,373 2,612 2,896
ol lhe 2017 lRP, are arcounted for in the load and resource balance. The peak load fore€st does not include the impact of existing or ntr demand response programs, which are both
accounted for in the load and resoure balane.
Page 18 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Loeo AND RESOURCE BaIeruCE DATA
Monthly Average Energy Load and Resource Balance
1t2017 2t2017 3t2017 4t2017 5t2017 6t2017 7t2017 8t2017 9t2017 10t2017 ',t1t2017 12t2017
't0
(1,894)
1
11
(1,686)
1
10
(1,555)
1
10
(1 ,591)
1
12
(1,803)
,|
14
(2,217)
1
15
(2,415)
1
15
(2,207)
1
13
(1,834)
1
10
(1,863)
12 11
(1,4s5) (1,6s0)
1'.|
(1,8s3) (1,68s) (1,554) (1,5e0) (1,802) (2,216) (2,414) (2,206) (1,834) (1,4s4) (1,64e) (1,862)
958
527
453
189
958
511
591
328
751
281
729
266
958
527
582
202
958
286
647
214
926
280
591
211
754
279
870
318
958
507
536
283
9s8
508
367
2',t2
958
277
413
223
958
281
442
198
958
284
347
182
Load Forecast-included EE
Load Forecast (7otho/o w/EE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (70m% d EE)
Existing Resources
Total Coal
Total Gas
Hydro (7oth%)-HCC
Hydro (70th%)--Other
Total Hydro (70th%)
CSPP (PURPA)
PPAs
Elkhorn Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchan ge-Retum
Total PPAS
Transmission Capacity available for
itlarket Purchases
Eristing Resource Subtotal
784
230
35
10
25
5
0
861
303
801
328
995
411
1,187
418
919
414
819
397
636
334
640
291
529
271
642
247
39
10
25
4
0
42
10
23
3
(20)
30
I
17
1
(20)
29
I
16
4
0
578
362
32
7
13
7
0
36
8
12
10
0
35
10
25
6
0
35
I
20
I
(20)
39
I
23
7
(20)
33
7
16
10
0
34
8
15
11
0
75
203
75
245
57
237
37
290
58
175
59
335
68
399
65
222
53
285
58
320
66
3'13
77
142
2,777 2,728 2,713 2,776 2,925 3,268 3,060 2,801 2,139 2,496 2,335 2,634
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0 0 0 0 0 000
2017 lntegrated Resource Plan-Appendix C Page 19
Load and Resource Balance Data ldaho Power Company
Monthly Average Energy Load and Resource Balance (continued)
1t2018 A2U8 3t2018 4t2018 512018 6n0t8 7nU8 8n0t8 9t2018 '.t0t2018 11t2018 12t2018
Load Forecast-included EE
Load Forecast (70th% w/EE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (70th% w/ EE)
Existing Resources
Total coal
Total Gas
Hydro (7oh%)-HCC
Hydro (70th%)-Other
Total Hydro (70h%)
CSPP (PURPA)
PPAs
Elkhom Valley Wnd
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie ExchangFRetum
Total PPAS
Transmission Capacity available for
Market Purchases
Exbting Resource Subtotal
21 21 20
(1,s2s) (1,716) (1,581)
444
21 24 27
(1 ,617) (1 ,831 ) (2,250)
455
28 28 24 23 21 21
(2,4s2) (2,243) (1,864) (1,521) (1,679) (1,8s1)
5 4 4 4
(1,e25) (1,712) (1,577) (1,613) (1,827) (2,245) (2,447) (2,238) (1,860) (1,516) (1,674) (1,887)
958
527
582
202
958
286
647
214
926
280
591
211
751
281
729
266
754
279
870
318
958
511
591
328
958
507
536
283
958
508
367
212
958
277
413
223
958
241
442
198
958
284
347
182
958
527
453
189
784
230
35
10
25
5
0
861
303
801
328
995
4',t1
1,187
418
919
414
819
397
578
362
32
7
13
7
0
636
334
29
I
16
4
0
640
291
529
271
642
247
35
'10
25
6
0
39
I
23
7
(20)
35
9
20
I
(20)
33
7
16
10
0
u
8
15
11
0
36
8
12
10
0
30
I
17
1
(20)
42
10
23
3
(20)
39
10
25
4
0
75 75
243
58
318
53
284
65
220
68
399
66
313
59
333
58
174
37 57
236
77
202 289 142
2,760 2,776 2,689 2,788 2,956 3,285 3,060 2,798 2,438 2,495 2,328 2,64',1
2017 IRP Resourcea
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0 0 0 0 0 0 0 0 0 0
Page 20 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Monthly Average Energy Load and Resource Balance (continued)
1t2019 2t2019 312019 4/2019 512019 612019 712019 8t2019 912019 1012019 1112019 1212019
32 31 30 31 36 40 41 41 36 ss 32 31
(1,s58) (1,740) (1,601) (1,6s7) (1,8s4) (2,278) (2,485) (2,274) (1,88e) (1,540) (1,701) (1,s10)
8888911111110988
(1,e50) (1,7321 (1,ss4) (1,629) (1,845) (2,268) (2,474) (2,264) (1,87e) (1,530) (1,6e3) (1,e02)
956
527
560
194
956
527
459
182
956
286
670
252
909
280
590
215
838
281
742
285
733
279
872
323
956
511
614
332
956
507
536
284
956
508
366
213
956
277
407
224
956
281
443
198
956
284
346
't74
Load Forecastincluded EE
Load Forecast fiotho/o WEE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (70th% w/ EE)
Existing Resources
Total Coal
Total Gas
Hydro (7oth%FHCC
Hydro (7oth%)-Other
Total Hydro (70th%)
CSPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie ExchangFRetum
Total PPAS
Transmission Capacity available for
iiarket Purchases
Exlstlng Resource Subtotal
33
16
10
0
36
8
12
10
0
755
230
1 ,195
418
946
414
34
8
15
11
0
820
397
642
293
30
I
17
1
(20)
1,O27
411
35
I
20
I
(20)
805
328
39
I
23
7
(20)
921
303
35
10
25
6
0
248
39
10
25
4
0
272
42
10
23
3
(20)
631
334
29
I
16
4
0
579
362
32
7
13
7
0
520 641
35
10
25
5
0
5737
288
58
177
59
332
6668
387
6553
293
7575
201 242
58
317 226 302 236
77
183
2,7u 2,783 2,695 2,902 2,916 3,281 3,0'18 2,796 2,434 2,496 2,325 2,633
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0 0 0 0 0 0 0 0 0 0 0 0
2017 lntegrated Resource Plan-Appendix C Page21
Load and Resource Balance Data ldaho Power Company
Monthly Average Energy Load and Resource Balance (continued)
1t2020 2n020 3t2020 4t2020 st2020 6t2020 7t2020 8t2020 9t2020 10t2020 11t2020 1a2020
46
(1,s75)
7
48
(1,693)
7
44
(1,613)
6
47
(1,650)
7
53
(1,86e)
8
54
(1,904)
8
51
(1,551)
7
47
(1,714)
7
45
(1,s26)
7
59 61 60
(2,2s7) (2,506) (2,2s5)
999
(1,e68) (1,686) (1 ,606) (1 ,643) (1 ,861) (2,288) (2.4s7) (2,286) (1,8s6) (1,543) (1,7o7) (1,s20)
841
284
346
174
841
277
406
224
u1
507
536
284
842
286
670
256
u1
527
561
194
843
280
590
215
698
28'l
742
286
633
279
874
323
841
511
615
332
u1
508
365
213
841
281
443
198
u1
527
460
't82
Load Forecast-;ncluded EE
Load Forecast Ooth% w/EE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (7Oh% w/ EE)
Existing Resources
Total Coal
Total Gas
Hydro (7ofr%FHCC
Hydro (7os%Hther
Total Hydro (70s%)
CSPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanae Exchange-Take
Clatskanie Exchange-Retum
Total PPAS
Transmission Capacity available for
ilarket Purchases
Existing Resource Subtotal
33
7
16
10
0
34
8
15
't1
0
36
8
't2
10
0
755
231
630
337
29
I
16
4
0
578
365
32
7
13
7
0
35
10
25
5
0
35
I
20
9
(20)
805
330
39
I
23
7
(20)
925
304
35
10
25
6
0
1,028
414
1,198
421
946
417
819
401
64',|
293
39
'10
25
4
0
520
272
42
10
23
3
(20)
30
I
17
,|
(20)
642
248
6553
293
75
243
75
201
58
317
68
387
5737
288
58
't76
59
331
66
301
77
182227235
2,631 2,575 2,632 2,767 2,823 3,t70 2,936 2,683 2,320 2,381 2,209 2,518
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0 0 0 0 0 0 0 0 0 0 0 0
Page22 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Monthly Average Energy Load and Resource Balance (continued)
1t2021 2/2021 3t2021 1ti2021 5t2021 6t2021 7t2021 8t2021 9n021 10t2021 11t2021 12t2021
5 5 5 6 9 't2 I 6
0
5 51212
(1,8s4) (1,686) (1,555) (1,s91) (1,803) (2,217) (2,415) (2,207) (1,834) (1,49s) (1,6s0) (1,863)
0 0 0
(1,8e4) (1,686) (1,ss4) (1,seo) (1,802) (2,216) (2,414) (2,206) (1,834) (1,4e5) (1,650) (1,862)
0
787
527
558
191
787
286
668
251
700
280
590
213
563
281
744
288
608
279
873
324
747
511
612
331
787
507
536
284
787
508
s65
212
787
277
403
22s
787
281
443
198
787
527
458
180
787
284
346
't74
Load Forecast-included EE
Load Forecast (70th% WEE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (70th% W EE)
Existing Resources
Total Coal
Total Gas
Hydro (70th%)-HCC
Hydro (7oth%)-Other
Total Hydro (70th%)
CSPP (PURPA)
PPAs
Elkhom Valley Wnd
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchan ge-Retum
Total PPAS
Transmission Capaclty ayailable for
Market Purchaseg
Existing Resource Subtotal
749
231
9'19
304
't,032
414
1,197
42',1
944
417
627
337
641
293
520
272
638
248
803
330
39
I
23
0
0
33
7
16
0
0
35
I
20
0
0
35
10
25
0
0
35
10
25
0
0
39
10
25
0
0
42
10
23
0
0
30
I
17
0
0
29
9
16
0
0
819
401
36
I
12
0
0
577
365
32
7
13
0
0
u
8
15
0
0
73
242
7156
348
5452
389
5657
445
5564
352
7l
376
69
302
70
261 285 360 234 294
2,625 2,667 2,559 2,706 2,845 3,16't 2,930 2,679 2,316 2,406 2,230 2,515
1,.,
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0 0 0 0 0 0 0 0 0 0 0 0
2017 lntegrated Resource Plan-Appendix C Page 23
Load and Resource Balance Data ldaho Power Company
Monthly Average Energy Load and Resource Balance (continued)
1t2022 2n022 3t2022 412022 5t2022 6t2022 7t2022 8t2022 912022 10t2022 1112022 '.t2t2022
Load Forecast-included EE
Load Forecast (/oth% w/EE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (70h% w/ EE)
Existing Resources
Total Coal
Total Gas
Hydro (7OIh%FHCC
Hydro (7oth%)-Other
Total Hydro (7Oh%)
CSPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAS
Transmission Capacity available for
70 70
(2,017) (1,787)
99
68
(1,640)
I
72 82
(1,678) (1,e02)
9 10
92
(2,338)
12
94
(2,s54)
12
93
(2,342)
12
82
(1,ese)
10
77
(1,577)
10
72
11,745)
I
70
(1,968)
I
(2,008) (1,778) (1,631) (1,668) (1,891) (2,326) (2,542) (2,3s0) (1,e2e) (1,567) (1,736) (1,ese)
787
527
562
197
787
286
67'l
245
684
280
590
212
603
281
725
248
650
279
873
324
787
511
601
331
787
507
535
283
787
508
s64
212
787
277
403
222
787 787
284
346
174
787
527
461
183
241
442
197
759
231
35
10
25
0
0
9'16
304
802
330
39
9
23
0
0
973
414
1,197
421
932
417
8't8
401
575
365
32
7
13
0
0
625
337
29
I
16
0
0
639
293
520
272
u4
248
35
10
25
0
0
35
I
20
0
0
33
7
16
0
0
u
8
15
0
0
36
8
12
0
0
30
9
17
0
0
42
10
23
0
0
39
10
25
0
0
70
260
69 71
375
64 55
244
57 56
357
52 54
233
74
293
73
241302352444389347
Exlstlng Resource Subtotal 2,634 2,664 2,541 2,687 2,886 3,148 2,926 2,678 2,3{3 2,403 2,230 2,521
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0 0 0 0 0 0 0 0 0 0
Page24 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Monthly Average Energy Load and Resource Balance (continued)
1t2023 2t2023 3t2023 4t2023 5t2023 6t2023 7t2023 8/2023 912023 1012023 1112023 1212023
Load Forecast-included EE
Load Forecast (70th% w/EE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (70h% w, EE)
Existing Resources
Total Coal
Total Gas
Hydro (7oth%FHCC
Hydro (7Oth%)-Other
Total Hydro (70t'%)
CSPP (PURPA)
PPAs
Elkhorn Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchan ge-Retum
Total PPAS
Transmission Capacity avaiSable for
Market Purchases
Existing Resource Subtotal
82 83 79 82 94 107 110 1'.12 96 92 84 82
(2,043) (1,808) (1,657) (1,6e5) (1,922) (2,363) (2,582) (2,36s) (1,e60) (1,5e2) (1,765) (1,ss1)
10 11 10 10 12 14 14 't4 12 12 11 11
(2,032) (1,797) (1.647) (1,685) (1,910) (2,34e) (2,568) (2,3s5) (1,e48) (1,s81) (1,755) (1,s81)
787
527
562
197
787 717 602
281
725
248
759
279
875
324
787
511
600
330
787
507
534
283
787
508
363
212
787
277
396
221
787
28',|
443
197
787
284
u7
173
787
527
4s9
183
286
670
244
280
590
211
758
231
914
304
801
330
39
I
23
0
0
973
414
1,199
421
930
417
817
401
575
365
617
337
639
293
30
9
'17
0
0
520
272
642
248
39
10
25
0
0
35
10
25
35
10
25
0
0
35
I
20
33
7
16
0
0
34
8
15
36
I
12
32
7
13
0
0
29
I
16
0
0
42
10
23
0
0
0
0
0
0
0
0
0
0
70
259
69
301
71
375
64
352
55
283
57
443
56
356
52
388
54
232
56
346
74
292
73
240
2,632 2,661 2,573 2,686 2,996 3,t45 2,924 2,675 2,304 2,401 2,229 2,517
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
0
0
0
0 0
0
0
0 0 0
0
0
0
0
0
0 0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0 0 0 0 0 0 0 0 0 0 0
2017 Integrated Resource Plan-Appendix C Page 25
Load and Resource Balance Data ldaho Power Company
Monthly Average Energy Load and Resource Balance (continued)
112024 2n024 3t2024 4t2024 5t2024 6t2024 7n024 8t2024 9t2024 10t2024 1112024 12t2024
Load Forecast-included EE
Load Forecast Ooth% w/EE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (7Sh% w, EE)
Existing Resources
Total Coal
Total Gas
Hydro (70th%)-HCC
Hydro (70th%)-other
Total Hydro (70th%)
csPP (PURPA)
PPAs
Elkhorn Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie ExchangrRetum
Total PPAS
Transmission Capacity avallable for
Market Purchases
Existlng Resource Subtotal
95 100 91 96 109 122 128 128 110 105 97 92
(1,7e0) (2,01s)
12 12
(2,074) (1,771) (1,67s) (1,717) (1,s4s) (2,3s0) (2,614) (2,400) (1,s84) (1,612)
12 13 12 12 14 16 16 16 14 '13
(2,062) (1,758) (1,668) (1,705) (1,e31) (2,375) (2,5s7) (2,383) (1,e70) (1,5s8) (1,778) (2,007)
786
527
561
196
763
286
669
241
744
280
589
2',t1
602
281
725
244
616
279
875
324
690
51 1
599
330
786
507
534
282
786
508
363
211
786
277
392
220
786
281
M3
196
786
284
346
't73
786
527
456
183
757 910
304
800
s30
973
4',14
1,199
421
33
7
16
0
0
929
417
816
401
573
365
612
337
639
293
519
272
639
248231
35
10
25
0
0
35
10
25
0
0
39
I
23
0
0
35
I
20
0
0
34
8
15
0
0
36
8
12
0
0
32
7
13
0
0
29
I
16
0
0
30
I
17
0
0
42
't0
23
0
0
39
10
25
0
0
70 69
s00
71 il
351
55 57
442
56
355
52
347
54
232
56
345
74
292
73
240258375282
2,630 2,632 2,598 2,6U 2,852 3,0/6 2,921 2,672 2,299 2,400 2,226 2,511
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0 0 0 0 0 0 0 0 0 0 0 0
Page 26 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Monthly Average Energy Load and Resource Balance (continued)
1t2025 A2025 312025 4t2025 5t2025 6t2025 7t2025 8t2025 9t2025 10t2025 11t2025 12t2025
109
(2,091)
13
110
(1,848)
13
104
(1,6e0)
12
125
(1,95s)
14
146
(2,63s)
17
't45
(2,420)
17
126
(1,sse)
15
120
(1,622)
14
110
(1,803)
13
109
(2,03s)
13
111
(1,728)
13
140
(2,408)
16
(2.07e) (1,835) (1,678) (1,716) (1,s45) (2,3s2) (2,618) (2,403) (1,s84) (1,608) (1,7s0) (2,022)
786
527
560
196
763
246
669
238
744
280
587
210
602
725
616
279
875
324
690
51'l
598
329
786
508
362
210
786
277
388
219
786
443
786
284
347
172
786
527
453
182
281
195
786
507
533
282
281
248
Load Forecast-included EE
Load Forecast (70th% w/EE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (70th% W EE)
Existing Resources
Total Coal
Total Gas
Hydro (70th%)-HCC
Hydro (7oth%)-Other
Total Hydro (7Oh%)
CSPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Retum
Total PPAS
Transmission Capacity available for
iiarket Purchases
Existing Resource Subtotal
756
231
s72
414
1, 199
421
927
417
571
365
638
290
519
269
907
304
35
10
25
0
0
35
10
25
0
0
33
7
16
0
0
35
9
20
0
0
798
330
39
9
23
0
0
814
401
36
I
12
0
0
34
8
15
0
0
30
9
17
0
0
607
337
29
I
16
0
0
32
7
13
0
0
636
245
39
10
25
0
0
42
10
23
0
0
73
239
74
292
56
345
il
230
52
385
56
354
57
440
55
280
64
351
71
374
69
300
70
259
2,630 2,629 2,595 2,6U 2,850 3,041 2,9't9 2,669 2,292 2,396 2,223 2,506
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0 0 0 0 0 0 0 0 0 0
2017 lntegrated Resource Plan-Appendix C Page27
Load and Resource Balance Data ldaho Power Company
Monthly Average Energy Load and Resource Balance (continued)
1t2026 2t2026 3t2026 4t2026 5t2026 6t2026 7t2026 8t2026 9t2026 1012026 1112026 12t2026
123 '.t23 117 125 140 157 165 162 142 132 124 122
(2,10s) (1,861) (1,700) (1,740) (1,e73) (2,426) (2,6s6) (2,441) (2,014) (1,633) (1,815) (2,052)
10 10 10 10 12 13 14 13 12 1',|10 10
(2,oes) (1,8s1) (1,6e1) (1,730) (1,e62) (2,413) (2,642) (2,428) (2,002) (1,622) (1,805) (2.042)
673 650 673
507
532
281
576
5tl
596
329
286
665
235
527
559
196
6,41
280
587
209
502
281
723
247
502
279
876
324
673
508
361
209
673
277
384
219
673
281
443
194
673
284
u7
171
673
527
449
182
Load Forecast-included EE
Load Forecast (70th% w/EE)
Adjustment for EE Potential Study Forecast
Net Load Forccast (70h% w, EE)
Existing Resources
Total Coal
Total Gas
Hydro (7o$%FHCC
Hydro (7oth%Hther
Total Hydro (70th%)
csPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchan ge-Retum
Total PPAS
Transmbsion Capacity available for
Market Purchases
Exlsting Resource Subtotal
29
9
16
0
0
42
10
23
0
0
755
228
900
301
637
288
30
I
17
39
23
602
333
570
363
32
7
13
0
0
970
408
35
o
20
796
323
1,201
417
33
7
16
0
0
925
415
813
399
36
8
12
0
0
518
265
631
241
35
10
25
0
0
35
10
25
0
0
I
34
I
15
0
0
39
10
25
0
0
0
0
0
0
0
0
69
299
70 71
373
7374
291
5654
229
52
385
56
353
57
440
55
280
64
350258 344 240
2,512 2,504 44U 2,575 2,734 2,923 2,801 2,552 2,t69 2,279 2,105 2,385
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
200 200 200 500 500 500 500 500 500 200 200 200
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
200 200 200 500 500 500 500 500 500 200 200 200
Page 28 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Monthly Average Energy Load and Resource Balance (continued)
1t2027 212027 312027 412027 5t2027 6t2027 7t2027 812027 9t2027 10t2027 11t2027 1212027
136 136 131 139 156 176 183 179 157 146 138 136
(2.12s) (1,877) (1,713) (1,7s3) (1,eso) (2,447) (2,680) (2,465) (2,031) (1,645) (1,830) (2,071)
8 8 10 11 10 8
(2,121) (1,869) (1,705) (1,745) (1,e81) (2,437) (2,670) (2,454) (2,022) (1,636) (1,822) (2,063)
I I o I
673
527
558.3
195.2
641
280
586.4
207.4
502
281
721.6
246.5
502
279
874.6
324.8
576
5l'l
594.3
328.1
673
507
530.6
280.5
673
277
379.3
217.6
673
281
443.7
193.8
673
284
346.4
170.5
673
527
443.2
181 .3
673
508
359.4
208.9
650
286
655.9
228.9
Load Forecast-included EE
Load Forecast (70th% w/EE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (70fro/6 w/ EE)
Existing Resources
Total Coal
Total Gas
Hydro (70th%)-HCC
Hydro (7Otholo)-Other
Total Hydro (70th%)
CSPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie ExchangFReturn
Total PPAS
Transmisslon Capacity available for
Market Purchases
Existing Resource Subtotal
754
224
794
323
1 ,199
417
922
4't5
811
399
597
333
637
288
517
265
624
241
885
297
35
10
25
0
0
35
10
25
0
0
968
408
35
I
20
0
0
33
7
16
0
0
39
9
23
0
0
568
363
32
7
13
0
0
30
I
17
0
0
29
I
16
0
0
36
I
12
0
0
u
I
15
0
0
42
10
23
0
0
39
10
25
0
0
73
239
56
344
545564
349
7169
299
70
257 373
57
279 438
56 52
352 384 229
74
291
2,505 2,486 2,481 2,572 2,732 2,9t9 2,798 2,549 2,164 2,279 2,104 2,378
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
200200200500500500500500500200200200
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
200 200 200 500 500 500 500 500 500 200 200 200
2017 lntegrated Resource Plan-Appendix C Page 29
Load and Resource Balance Data ldaho Power Company
Monthly Average Energy Load and Resource Balance (continued)
1t2028 2t2028 3t2028 4t2028 5t2028 6t2028 7t2028 8t2028 9t2028 10t2028 11t2028 1212028
150
(2,149)
151
(1,827)
6
144
(1,72s)
6
147
(1,766)
6
170
(2,005)
7
191
(2,467)
7
172
(2,048)
7
162
(1,6s6)
6
151
(1,844)
6
150
(2,088)
6b
200 203
(2,704) (2,488)
88
(2,143) (1,821) (1,720) (1 ,760) (1 ,eee) (2,460) (2,6s6) (2,480) (2,041) (1,650) (1,838) (2,082)
673
527
556
135
650
286
647
216
502
279
875
325
673
507
530
280
673
277
376
217
673
284
347
170
673
527
442
18"1
673
281
443
193
673
508
358
208
576
511
593
327
502
281
721
246
641
280
585
203
Load Forecast-included EE
Load Forecast (70th% WEE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (70rh% w/ EE)
Existng Resources
Total Coal
Total Gas
Hydro (7osoloFHCC
Hydro (70th%)-Other
Total Hydro (7Oh%)
CSPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Retum
Total PPAS
Transmission Capacity available for
Market Purchases
Existing Resource Subtotal
751
224
967
408
0
I
20
0
0
788
323
0
I
23
0
0
863
297
0
10
25
0
0
0
10
25
0
0
1,199
417
920
415
810
399
636
288
0
I
17
0
0
0
10
23
0
0
0
I
16
0
0
0
8
12
0
0
0
8
'15
0
0
0
7
16
0
0
566
363
0
7
13
0
0
593
333
516
265
622
241
0
10
25
0
0
34
239
33
290
26
344
25
228
20
383
20
351
22
437
2329
349
3t
372
35
299
35
257 277
2,467 2,429 2,435 2,536 2,697 2,881 2,760 2,514 2,129 2,28 2,051 2,337
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
NeYY Resource Subtotel
200200200500500500500500500200200200
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
200 200 200 500 500 500 500 500 500 200 200 200
Page 30 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Monthly Average Energy Load and Resource Balance (continued)
ll202g 212029 3no2g 41i2029 5t2029 8t2029 7t2029 8t2029 9t2029 10t2025 11t2029 12t2029
164
(2,167)
3
164
(1,e06)
3
156
(1,736)
2
162 186 208 220 221 186 177 164 163
(1,778) (2,020) (2,486) (2,726) (2,s10) (2,064) (1,667) (1,8s7) (2,104)
333333333
(2,16s) (1,e04) (1,734) (1,776) (2.017) (2,483) (2,723) (2,s06) (2,061) (1,664) (1,854) (2,101)
505
527
553
'195
447
286
637
212
481
280
584
20'l
377
281
719
244
377
279
875
324
505
507
529
280
505
277
373
216
505
28',|
443
192
505
284
346
169
505
527
441
178
505
508
357
207
432
511
592
326
Load Forecast-included EE
Load Forecast (70th% WEE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (70th% w, EE)
Existing Resources
Total Coal
Total Gas
Hydro (70h0lo!-HCC
Hydro (7os%Hther
Total Hydro (7Oh%)
CSPP (PURPA)
PPAB
Elkhorn Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Retum
Total PPAS
Transmission Capacity available for
Market Purchases
Existlng Resource Subtotal
748
216
849
286
0
10
25
0
0
785
312
1,199
403
918
402
635
277
515
252
620
228
964
391
0
I
20
0
0
589
324
0
I
16
0
0
564
355
0
7
13
0
0
808
389
0
I
12
0
0
0
10
25
0
0
0
10
23
0
0
0
I
't7
0
0
0
8
15
0
0
0
7
16
0
0
0
10
25
0
0
0
I
0
0
23
3433
290
26
343
25
226
20222329
348
3l
372
35
298
35
256 276 435
20
350 382 238
2,286 2,241 2,261 2,390 2,556 2,720 2,580 2,335 1,9/t5 2,067 1,879 2,152
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
200200200500500500500500500200200200
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
200 200 200 500 500 500 s00 500 500 200 200 200
2017 lntegrated Resource Plan-Appendix C Page 31
Load and Resource Balance Data ldaho Power Company
Monthly Average Energy Load and Resource Balance (continued)
l/2030 2t2030 312030 4t2030 512030 6/2030 7t2030 8/2030 9/2030 10t2030 11t2030 12t2030
180
(2,184)
0
180
(1,91 9)
0
170
(1,746)
0
179
(1,789)
0
242
(2,748)
0
240
(2,s31)
0
203
(2,07e)
0
192
(1,677)
0
179
(1,869)
0
178
(2,11s)
0
203 227
(2,034) (2,504)
00
(2,184) (1,s1s) (1,746) (1,78e) (2,034) (2,s04) (2,748) (2,s31) (2,07e) (1,677) (1,86s) (2,11e)
505
527
551
193
487
286
630
205
481
280
583
195
377
281
7't9
242
377
279
874
323
505
507
528
279
505
277
370
215
505
u7
505
527
440
'178
284
168
505
281
443
191
505
508
356
206
432
511
590
325
Load Forecast-included EE
Load Forecast (/oth% WEE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (70s% w, EE)
Existing Resources
Total Coal
Total Gas
Hydro (7oh%)-HCC
Hydro (7Orh%)-Other
Total Hydro (7Oh%)
CSPP (PURPA}
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Retum
Total PPAS
Transmlsslon Capacity ayailable for
Market Purchases
Erlstlng Resource Subtotal
743
213
778
309
1,197
403
916
394
515
243
618
219
0
I
23
0
0
835
283
0
10
25
0
0
0
10
25
0
0
0
I
15
0
0
0
7
16
0
0
961
391
0
I
20
0
0
562
350
0
7
13
0
0
806
383
0
I
12
0
0
584 634
270
0
9
17
0
0
317
0
9
16
0
0
0
10
25
0
0
0
't0
23
0
0
34
238
3326
343
2520222329
349
3535
255
3l
371
20
381298275 43s 349 226 289
2,278 2,223 2,250 2,388 2,5il 2,710 2,570 2,327 1,935 2,059 1,868 2,142
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
200200200500500500500s00200200200
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
200 200 200 500 500 500 500 500 500 200 200 200
Page32 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Monthly Average Energy Load and Resource Balance (continued)
1t2031 2t2031 3t2031 4t2031 5t2031 6t2031 7t2031 8t2031 9/2031 1012031 11t2031 1212031
195 195 184 195 220 247
(2,048) (2,522)
00
263
(2,768l
0
258
(2,s51)
0
193 195
(2,132)
0
220 207
(2,0s4) (1,687)
00
(2,200) (1,e31) (1,755) (1,7es)(1,880)
0 0 0
(2,200) (1,e31) (1,755) (1,7se) (2,048) (2,522) (2,768) (2,551) (2,0e4) (1,687) (1,880) (2,132)
505
527
551
't97
481
280
582
197
377
281
718
24'l
377
279
872
322
505
507
527
27A
277
214
505
281
443
'190
505
284
348
168
505
527
439
179
505
365
505
508
355
205
432
511
588
323
487
286
628
206
Load Forecast-included EE
Load Forecast (70th% w/EE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (7Oh% w, EE)
Existing Resources
Total Coal
Total Gas
Hydro (7Orhold-HCC
Hydro (7Oth%)--{ther
Total Hydro (70th%l
CSPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchan ge-Take
Clatskanie ExchangFRetum
Total PPAS
Transmission Capacity available for
ilarket Purchases
Existing Resource Subtotal
748
182
835
208
0
't0
25
0
0
779
237
958
315
633
217
6'.t7
151
805
335
0
8
12
0
0
0
I
't5
0
0
1,194
333
0
7
16
0
0
0
I
20
0
0
0
I
23
0
0
911
336
560
309
0
7
't3
0
0
579
273
0
I
16
0
0
516
172
0
10
23
0
0
0
10
25
0
0
0
I
7
0
0
0
10
25
0
0
3433
289
26
342
252329
348
31
372
35
297
35
255
22 20 20
348 380275 4U 226 237
2,252 2,147 2,180 2,308 2,481 2,66 2,520 2,282 1,88s 2,004 1,798 2,072
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
200
0
20
200500500200200500
0
20
500
0
20
500
0
20
500
0
20
200
0
20
200
0
0
0
0
0
0
0
0
0
0
0
0
220 200 200 500 500 520 520 520 520 200 200 220
2017 lntegrated Resource Plan-Appendix C Page 33
Load and Resource Balance Data ldaho Power Company
Monthly Average Energy Load and Resource Balance (continued)
112032 2t2032 3t2032 4t2032 5t2032 612032 7t2032 A2082 9t2032 10t2032 1il2032 1212032
210 216 200 212
(1,80e)
0
238
(2,060)
0
268
(2,537)
0
282
(2,787)
0
276
(2,570)
0
237
(2,107)
0
219
(1,6s5)
0
210
(1,8s0)
0
202
(2.148)
0
(2,215) (1,875) (1,763)
0 0
(2,215) (1,875) (1,763) (1,80e) (2,060) (2,537) (2.787) (2,570) (2.107) (1,6es) (1,8e0) (2,148)
505
284
v7
167
505
277
361
213
505
50E
354
204
507
278
432
51'l
585
322
487
286
620
20'l
505
527
550
196
48'l
280
580
189
377
28',|
716
237
377
279
870
321
505
525
505
281
443
190
505
527
434
178
Load Forecast-included EE
Load Forecast (70th% w/EE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (70th% w/ EE)
Existing Resources
Total Coal
Total Gas
Hydro (7oh%FHCC
Hyclro (70th%)-Other
Total Hydro (70s%)
CSPP (PURPA)
PPAs
Elkhom Valley Wind
Rafr River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Retum
Total PPAS
Transmission Capacity ayailable for
Market Purchases
Existing Resource Subtotal
746
140
822
191
769
221
1,191
325
803
329
574
267
632
210
952
296
0
I
20
0
0
0
I
23
0
0
0
10
25
0
0
0
7
16
0
0
0
10
25
0
0
558
303
907
329
0
10
25
0
0
514
172
0
10
23
0
0
616
151
0
7
13
0
0
0
I
12
0
0
0
8
15
0
0
0
I
16
0
0
0
I
17
0
0
34
237
3326
342
2520
380
2022
433
2329
348
3535
254
3t
371297 274 347 225 289
2,206 2,117 2,t53 2,284 2,469 2,634 2,511 2,274 {,873 t,996 1,796 2,071
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
200
0
40
500500200200 500
0
40
200500
0
40
500
0
40
500
0
40
200
0
40
200
0
0
0
0
0
0
0
0
0
0
240 200 200 500 500 540 540 540 540 200 200 240
Page 34 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Monthly Average Energy Load and Resource Balance (continued)
1t2033 2t2033 3/2033 4t2033 512033 612033 7t2033 812033 9/2033 1012033 1112033 1212033
225 224 215 227 257 289 301 296 253 233
(2,234) (1,9s6) (1.774) (1,820) (2,074) (2,ss7) (2,80s) (2,se2) (2.123) (1,705)
0000000000
225
(1,903)
0
226
(2,166)
0
(2,234) (1,956) (1,774) (1,820) (2,074) (2,ss7) (2,80e) (2,5e2) (2.123) (1,705) (1,e03) (2,166)
336
284
u7
336
28'.l
443
277
357
336
507
524
277
251
279
870
321
336
527
549
193
325
286
618
199
320
280
580
'187
251
281
7',t5
232
288
511
583
321
336
508
352
204
336
527
437
177
336
212 189 167
Load Forecast-included EE
Load Forecast (7oth% w/EE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (70th% w, EE)
Existing Resources
Total Coal
Total Gas
Hydro (7ofi%)-HCC
Hydro (7os%)-Other
Total Hydro (70th%)
CSPP (PURPA)
PPAS
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchang+-Take
Clatskanie Exchange-Return
Total PPAS
Transmission Capaclty avallable for
Market Purchases
Existing Resource Subtotal
743
98
818
134
767
164
't,192
276
904
284
15
632 514
122
615
103
0
10
25
0
10
25
0
0
947
23',|
0
I
20
0
I
23
't67
801
290
0
I
0
7
17
0
0
16
0
0
0
8
12
0
0
0
8
0
0
568
229
0
I
16
0
0
556
271
0
7
13
0
0
't0
25
0
0
10
23
0
0
0
0
0
0
0
0
0
33
288
25
224
20
378
20
345
22
431
23
272
29
347
35
296
35
254
31
370
26
341
34
237
1,993 t,893 1,932 2,087 2,293 z,UO 2,300 2,070 1,661 1,784 1,576 {,853
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New R$ource Subtotal
200
292
40
200
286
0
200
280
0
500
279
500
281
500
276
40
200
292
40
200
284
0
200
281
0
500
277
40
500
272
40
500
273
4000
532 486 480 781 779 816 A12 813 817 48',1 484 532
2017 lntegrated Resource Plan-Appendix C Page 35
Load and Resource Balance Data ldaho Power Company
Monthly Average Energy Load and Resource Balance (continued)
112034 2t2034 3t2034 4t2034 5t2034 612034 7t2034 8t2034 9t2034 10t2034 11t2034 1212034
Load Forecastincluded EE
Load Forecast (70th% WEE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (70s% w, EE)
Existing Resources
Total Coal
Total Gas
Hydro (7o$%FHCC
Hydro (70th%)-Other
Total Hydro (70s%)
CSPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie ExchangFRetum
Total PPAS
Transmission Capacity avallable for
Market Purchases
Existing Resource Subtotal
242
(2,254)
0
243
(1,e72)
0
229
(1,786)
0
235
(1,832)
0
270 303
(2,0s0) (2.5771
00
324 327 272 253 239 242
(2,834) (2,615) (2,140) 11,717) (1,s16) (2,185)
000000
(2,254) (1,972) (1,786) (1,832) (2,0e0) (2,577) (2,834) (2,615) (2,140) (1,717) (1,s16) (2,185)
336
527
549
193
325
286
616
198
320
280
579
186
25'l
28',|
712
221
251
279
869
321
288
511
581
320
336
507
523
276
336
508
351
203
336
277
353
211
336
281
442
188
336
284
u7
166
336
527
436
177
74',1
98
814
134
765
144
933
231
1,190
276
901
2U
800
290
554
271
564
229
631
167
513
't22
6t3
't03
0 0 0
I
0
I
0
7
16
0
0
0
8
0
8
12
0
0
0
7
0
I
16
0
0
0
I
0
10
23
0
10
25
0
0
10
25
0
10
25 23
0
20
0
0
't5
0
0
13 17
0 0
0
0
0
0
0000
35
254
35
296
3l
370
29
347
23
272
22
430
20
344
20
377
25
223
26
341
33
288
34
237
1,992 t,889 {,930 2,073 2,291 2,435 2,298 2,067 .t,655 1,782 1,576 1,851
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
200
292
40
200
286
0
200
280
500
281
0
500
279
500 500 500 500 200
28'l
0
200 200
276
40
272
40
273
40
277
40
284 292
40000
532 486 480 78'.t 779 816 812 813 817 481 484 532
Page 36 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Monthly Average Energy Load and Resource Balance (continued)
1t2035 2t2035 3/2035 4t2035 5/2035 612035 7t2035 8/2035 9/2035 10t2035 11t2035 12t2035
260
(2,275)
0
258
(1,988)
0
244
(1,7e8)
0
253
(1,845)
0
288
(2,106)
0
322
(2,s98)
0
347 347
(2,858) (2,640)
00
287 270
(2,157) (1,728)
00
254 258
(1,e31) (2,205)
00
(2,275) (1,e88) (1,7e8) (1,845) (2,106) (2,5e8) (2,858) (2,640) (2,157) (1,728) (1,e31) (2,205)
336
527
548
191
32s
286
612
197
320
280
578
185
251
281
712
215
251
279
867
321
288
51',l
580
319
336
507
522
276
336
281
443
187
336
244
348
165
336
527
435
176
336
277
348
210
336
508
350
202
Load Forecast-included EE
Load Forecast (70th% WEE)
Adjustmentfor EE Potential Study Forecast
Net Load Forecast (70th% w, EE)
Existing Resources
Total Coal
Total Gas
Hydro (70th%)-HCC
Hydro (7oth%)-Other
Total Hydro (70th%)
CSPP (PURPA)
PPAs
Elkhorn Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchan ge-Take
Clatskanie Exchange-Retum
Total PPAS
Transmission Capacity available for
Market Purchases
Existing Resource Subtotal
0
8
15
0
0
0
10
25
0
0
0
122
558
229
s52
271
898
284
927
231
738
98
0
0
17
0
0
2320
0
0
0
9
0
I
0
7
0
809
134
763 1 ,188
276
630
167
513
0
10
611
103164
0
9
23
0
't0
25
0
0
9
798
290
0
8
12
0
0
10
25
0
0
7
16
0
0
16
0
0
13
0
0000
34
236
33
287
20
377
20
344
23
271
29
346
3t35
296
35
253
22
430
25
222
26
341369
t,988 1,885 1,927 2,065 2,288 2,433 2,296 2,06s 1,648 1,782 1,574 1,849
20tZ IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
200
292
69
281277
69
500
272
69
500
276
69
279
0
500
281
0
200
286
200
280
0
500 500
273
69
500 200 200 200
292
69
284
00
561 486 480 781 779 845 841 842 846 481 484 561
2017 lntegrated Resource Plan-Appendix C Page 37
Load and Resource Balance Data ldaho Power Company
Monthly Average Energy Load and Resource Balance (continued)
1t2036 2n036 312036 4t2036 512036 612036 712036 812036 9/2036 1012036 ltr2036 12t2036
277
(2,299)
0
284
(1,936)
0
258
(1,81 1)
0
273
(1,8ss)
0
306
(2,123)
0
364
(2,666)
0
306
(2,176)
0
285
(1,741)
0
343 372
(2,620) (2,885)
00
269 266
(1,947) (2,227)
00
(2,2se) (1,e36) (1,81 1) (1,8se) (2,123) (2,620) (2,885) (2,666) (2,176) (1 ,741) (1 ,e47) (2,227)
336
527
546
185
325
286
609
197
320
280
577
184
251
281
7',to
214
336
284
347
165
336
527
435
176
336
281
443
187
336
508
349
201
336
507
521
275
251
279
868
320
288
511
s78
318
336
277
343
209
Load Forecast-included EE
Load Forecast (7oth% MEE)
Adjustment for EE Potential Study Forecast
Net Load Forecast (70th% w/ EE)
Existing Resources
Total Coal
Total Gas
Hydro (7Oth%)-HCC
Hydro (70th%)-Other
Total Hydro (70th%)
CSPP (PURPA)
PPAs
Elkhom Valley Wnd
Rafl River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAS
Transmission Capacity available for
Market Purchasos
Exlsting Resource Subtotal
731
98
806
134
0
761
154
1,188
276
629
167
17
5't2
0
10
611
't03122
550
271
896
2U
924
23'l
796
290
0
8
12
0
0
552
229
0
9
16
0
00
0
10
25
0
0
10
25
0
20
0
0
I
23
0
0
0
7
0
I
13
0
0
0
8
15
0
0
0
7
16
0
0
0
9
0
0
0
10
25
0
0
23
0
0
26
u'l
20
375
29
346
3t
368
35
295
35
252
23
270
22
429
20
343
33
287
34
236
25
222
{,980 1,88t 1,924 2,063 2,287 2,430 2,293 2,051 1,642 1,781 t,573 {,8rt8
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engines
New Resource Subtotal
0
200
292
99
200
286
0
200
2AO
500
241 244
0
500
273
99
500
276
99
500
279
0
500
272
99
500
277
99
200
281
0
200 200
292
990
591 486 480 781 779 875 871 872 876 481 484 591
Page 38 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Monthly Average Energy Surplus/Deficit Gharts
Average energy monthly surpluses and deficits with IRP DSM and existing resources
1,400
1,300
1,200
1,'100
1,000
900
800
700
600
500
=
400
=G 300
200
'100
0
(1 00)
(200)
(300 )
(400)
(s00 )
(600)
(700)
c
Average energy monthly surpluses and deficits with IRP DSM, existing resources, and IRP Resources
1,400
1,300
1,2@
1,1 00
1,000
900
800
700
600
500
400
300
200
100
0
(1 00)
(200)
(300)
(400)
(500 )
(600)
(700)
oNc
o
o
@
co
Nco
NNc
oNco
@Nco
Nco
Nco
@Nco
NNco
Eco
o
o
3
coco
N
coco
o
co
oNcG
N
co
@
c
o
co
oNco
Nco
NNco
@N
o
N
o
Nco
Nco
NNc co
Nco
@Nco co
3cocG
3coc
N
o
2017 lntegrated Resource Plan-Appendix C Page 39
Load and Resource Balance Data ldaho Power Company
Peak-Hour Load and Resource Balance
112017 212017 3n0l7 4t2017 5t2017 6n0l7 7t2017 8t2017 9t2017 10t2017 11t2017 12t2017
(2,44s) (2,367) (2,078) (2,032) (2,702) (3,444) (3,605) (3,266) (2,801) (2,105) (2,315) (2,620)
I 11 12 16 13 18 18 20 15 I 9
(2,441) (2,3s8) (2,067) (2,020) (2,686) (3,431) (3,s86) (3,248) (2.781) (2,0s1) (2,307) (2,611)
0
1
390 0 0
't,020
716
950
190
1,020
716
900
195
1,020
716
950
172
1,O20
716
1,000
301
1,020
716
850
203
1,020
716
1,050
291
1,O20
716
800
208
1,020
716
750
197
I
'l
0000 390 0 0337
(2,440) (2,357) (2,066) (2,01e) (2,685) (3,040) (3,1ss) (2,s10) (2,780) (2,0e0) (2,307) (2,611)
1,O20
716
1,000
285
't,o20
716
750
215
't,o20
716
900
189
,020
716
650
185
Load Forccast (95tho/6 wrno DSll)
Load Forecast-included EE
Load Forecast (95th% w/DSM and EE)
Adjustment for EE Potential Study Forecasl
Existing Oemand Response
Peak-Hour Forecast WDSM and EE
Existing Resources
Total Coal
Total Gas
Hydro (90th%)-HCC
Hydro (90s%)--Other
Total Hydro (90s%)
CSPP (PURPA}
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAS
Transmission Capacfi Available for
Market Purchases
Existing Resource Subtotal
1,140
66
5
1,095
69
1,122
152
1,053
194
1,341
234
1,301
311
1,2A5
314
1,008
307
965
210
947
174
5
I
17
1
(20)
1,089
68
5
10
25
4
0
835
'151
10
25
5
0
10
25
6
5 5
8
15
11
0
5
7
13
7
0
5
I
23
7
(20)
5
I
20
9
0(20)
5
I
16
4
0
5
I
12
10
0
5
7
16
10
5
10
23
3
(20)0
21
237
32
335
38
399
38
222
2323
320
4645
203 245 285
35
313
34
175
't2
290
43
182
3,190 3,190 3,354 3,291 3,511 3,785 3,684 3,420 3,120 3,160 2,979 3,fl9
2017 IRP Resourcea
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Resource Subtotal
Monthly Deficit
0
0
0
0
0
0
0
0
0
0
0 0
000
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
Page 40 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Peak-Hour Load and Resource Balance (continued)
112018 212018 312018 412018 5t2018 6/2018 7t2018 8t2018 912018 10t2018 11t2018 12t2018
(2,44e)
I
(2,441)
1
0
(2,367) (2,078) (2,032)
I 11 12
(2,358) (2,067) (2,020)
111
000
(2,702)
16
(2,686)
1
0
(3,444)
13
(3,431)
1
390
(3,605)
18
(3,586)
I
390
(s,266)
18
(3,248)
1
337
(2,801)
20
(2,781)
1
0
(2,1 0s)
15
(2,091)
1
0
(2,315) (2,620)
8 o
(2,61 1)
1
0
(2,s07)
1
0
(2,440) (2,3s7) (2,066) (2,01s) (2,685) (3,040) (3,1s5) (2,e1 0) (2,780) (2,0e0) (2,307) (2,61 1)
1,020
716
950
190
1,020
716
900
195
1,020
716
950
172
1,020
716
850
203
1,020
716
1,050
291
't,020
716
800
208
1,020
716
750
215
1,020
716
750
197
1,020
716
650
185
1,020
716
900
189
1,020 1,020
716 716
1,000 1 ,000
301 285
Load Forecast (95th% w/no DSM)
Load Forecast-included EE
Load Forecast (95th% WDSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forecast w/DSIl,l and EE
Existing Resources
Total Coal
Total Gas
Hydro (9oh%)-HCC
Hydro (90th%)-Other
Total Hydro (90th%)
CSPP (PURPA)
PPAs
Elkhorn Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAS
Transmission Capacity Available for
Market Purchases
Existing Resource Subtotal
5
10
25
5
0
5
16
10
0
5
9
16
4
0
'1,140
66
1,095
69
1j22
152
1,053
194
1,341
234
1,301
311
1,285
314
1,008
307
965
210
947
174
835
151
5
10
23
3
(20)
1,089
68
5
10
25
6
0
5
o
23
55
9
I
17
(20)
I
20
(20)
5
8
15
11
0
5
8
12
10
0
5
7
13
7
0
5
10
25
4
0
7
(20)
45
202
46
243
23
318
2112
289
34
174
32
333
3538
399
3823
284
43
182220313236
3,187 3,188 3,351 3,291 3,s75 3,790 3,684 3,418 3,120 3,160 2,973 3,117
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Resource Subtotal
Monthly Deficit
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0 0 0 0 0 0 0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
000
0
0
0
0
2017 lntegrated Resource Plan-Appendix C Page 41
Load and Resource Balance Data ldaho Power Company
Peak-Hour Load and Resource Balance (continued)
1t20tg 2t2019 3/2019 4t2019 s/2019 612019 7t2019 8/2019 9/2019 10t2019 11t2019 12t2019
(2,561 )
31
(2,s30)
8
0
(2.458)
32
(2,426)
I
0
't2
390
12
390
't2
337
(2,
(2,07s)
I
0
I 64)
31
132)
8
0
(2,107) (2,7s8) (3,s85) (3,760) (3,405) (2,s16) (2,1821 (2,3s1 ) (2,6se)
34 40 45 47 46 40 41 31 32
(2 (2,758) (3,540) (3,713) (3,35e) Q,e76) (2,141) (2,35e) (2,666)
11
0
11 11
0 0 0
o
0
(2,521) (2,417) (2,124) (2,06s) (2,747) (3,1se) (3,s10) (3,010) (2,86s) (2,130) (2,351) (2,658)
1,O20
716
950
181
1,O20
716
900
186
1,020
716
950
172
1,020
716
850
204
1,020
716
1,000
309
'1,020
716
1,000
285
1,020
716
1,050
301
't,020
7't6
800
209
1,O20
716
750
216
1,O20
716
750
't 98
1,O20
716
650
177
1,020
716
900
177
Load Forecast (95s% wrno DSM)
Load Forecastincluded EE
Load Forecast (95th% WDSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forecast wrDSM and EE
Existing Resources
Total Coal
Total Gas
Hydro (90th%)-HCC
Hydro (9Oth%)--Other
Total Hydro (90t%)
CSPP (PURPA)
PPAB
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAS
Transmission Capacity Available for
Market Purchases
Existlng Resource Subtotal
5
7
16
10
0
5
8
12
10
0
1,131
66
1,086
69
1,122
'152
't,054
194
1,351
234
1,309
311
't,285
314
'1,009
307
966
210
948
177
827
153
't,077
68
5
10
25
6
0
5
10
25
5
0
5
I
20
I
(20)
5
9
23
7
(20)
5
8
15
11
0
5
7
13
7
0
5
I
16
4
0
5
10
25
4
0
5
10
23
3
(20)
5
I
17
1
(20)
2112
288
34
177
32
332
35
302
38
387
3823
293
2346
242
45
201 317 226 236
€
183
3,179 3,178 3,350 3,300 3,584 3,781 3,673 3,417 3,123 3,t6t 2,572 3,109
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Rosource Subtotal
Monthly Deficit
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
Page42 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Peak-Hour Load and Resource Balance (continued)
1t2020 2t2020 3t2020 4t12020 5t2020 6t2020 7no20 8t2020 9t2020 10t2020 fin020 1212020
(2,5e8) (2,487) (2,1e2) (2,136) (2,840) (3,641) (3,836) (3,46e) (2,s62) (2,215) (2,420) (2,720)
49 46 50 67 70 58 60 48
(2,(3,574) (3,766) (3,402) (2,904) (2,154) (2,373) (2,67
7 7 10
390
10
(2,sso)
4948
(2,087\46)(2,,438)(2
6759
780)
I
0
7
0
7
0 0
10
337
1)
7
0
7
0
9
0
8
00390
(2,s43) (2,431) (2,13e) (2,080) (2,772) (3,174) (3,366) (3,05s) (2,8s6) (2,14s) (2,366) (2,664)
889
716
950
181
889
716
1,000
308
889
716
1,000
285
889
716
900
't 80
889
716
950
172
889
716
850
205
889
716
1,050
300
889
716
800
209
889
716
750
215
889
716
900
't78
889
716
750
198
889
716
650
177
Load Forecast (95rh% wlno DSil)
Load Forecastincluded EE
Load Forecast (95e% w/DSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forocast W/DSM and EE
Existing Resources
Total Coal
Total Gas
Hydro (9o$%)-HCC
Hydro (90h%)-Other
Total Hydro (90th%)
csPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPA8
Transmbsion Capacity Available for
Market Purchases
Existing Resource Subtotal
1,131
66
1,080
69
't,122
154
1,055
195
1,350
236
1,308
316
1,285
319
1,009
312
965
213
827
153
1,078
68
948
177
5
10
25
5
0 0
5
7
13
7
0
5
I
16
4
5
7
16
10
0
5
10
25
6
0
5
I
20
9
(20)
5
9
23
7
(20)
5
I
15
11
0
5
8
12
10
0
5
I
17
1
(20)
5
10
23
3
(20)
5
10
25
4
0
43
314
21
366
34
308
3235
433
38
359
23
425
2346
374
45
332
38
518
12
4',t9448463
3,179 3,173 3,353 3,303 3,587 3,785 3,676 3,421 3,124 3,161 2,971 3,108
2017 IRP Resourcea
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Resource Subtotal
Monthly Deficit
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
2017 lntegrated Resource Plan-Appendix C Page 43
Load and Resource Balance Data ldaho Power Company
Peak-Hour Load and Resource Balance (continued)
1t2021 2t2021 312021 412021 5t2021 6t2021 7n021 8t2021 9t2021 10t2021 11t2021 12t2021
(2,624)
61
(2,562)
8
0
(2,513)
63
(2,450)
I
0
(2,212)
58
(2,1 s3)
8
0
(2,161)
63
(2,0s8)
8
0
(2,877)
74
(2,803)
10
0
(3,6s1)
86
(3,606)
11
390
(3,908)
90
(3,81e)
12
390
(3,529)
85
(3,444)
11
337
(3,004)
72
(2,932)
10
0
(2,243)
76
(2,1 68)
10
0
(2,448)
61
(2,387)
8
0
(2,754)
63
(2,6e1)
8
0
(2,ss4) (2,442) (2j4s) (2,090) (2,7s3) (3,205) (3,417) (3,0e6) (2,922) (2,1s7) (2,37s) (2,683)
835
716
950
175
835
716
900
183
835
716
950
173
835
716
1,050
299
835
850
7'.t6
205
835
716
1,000
307
835
716
1,000
285
835
716
800
209
835
7',t6
750
215
835
716
750
198
835
716
650
177
835
716
900
175
Load Forecast (951h% w/no DSM)
Load Forecastincluded EE
Load Forecast (95th% WDSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forecast dDSM and EE
Existing Resources
Total Coal
Total Gas
Hydro (90th%)-HCC
Hydro (9Oth%)--.other
Total Hydro (golh%)
CSPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAS
Transmission Capacity Available for
Market Purchases
Existing Resource Subtotal
1,125
66
't,083
69
't,123
154
1,055
196
948
177
1,075
68
1,349 1 ,307 't ,285 1 ,009 965 827
't 53
5
10
23
0
0
5
10
25
0
5
9
16
0
0
236 316 319 312 213
5
9
23
0
0
5
10
25
0
0
5
10
25
0
5
I
20
0
5
8
12
0
0
5
7
16
0
E
8
15
0
0
5
7
3
0
5
I
7
0
000
39
374
38
425
3l30
366
25
521
25
492
27
576
3436
507
40
433
40
392
28
417484 479
3,174 3,175 3,371 3,320 3,580 3,777 3,67t 3,417 3,124 3,185 2,993 3,{08
20l7lRP Resourres
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Resource Subtotal
Monthly Deficit
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
Page 44 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Peak-Hour Load and Resource Balance (continued)
1t2022 212022 3t2022 4t2022 5t2022 6t2022 7t2022 8t2022 9t2022 10t2022 11t2022 12t2022
(2,666)
75
(2,5s1)
10
0
(2,548)
76
(2,472)
10
0
(2,244)
71
(2,173)
9
0
(2,1e1)
76
(2,116)
10
0
13
390
't4
390
13
337
(2,s1s) (3,7s0) (3,s85) (3,5e5) (3,0s3) (2,275) (2,47s) (2,785)
87 91 74
I
0
76
(2,830) (3,647) (3,876) (3,4s2) (2,s66) (2,184) (2,405) (2,708)
11
89 103 109 103
11 12
0 0
"t0
0 0
(2,582) 12,462) (2,164) (2,106) (2,818) (3,244) (3,472) (3,142) (2,95s) (2,172) (2,3ss) (2,699)
835
716
950
183
835
716
900
147
835
716
950
172
835
7',t6
850
205
835
716
1,050
300
835
716
't,000
304
835
716
1,000
284
835
716
800
207
835
716
750
214
835
716
750
197
835
7't6
650
177
835
716
900
183
Load Forecast (95h% w/no DSM)
Load Forecast-included EE
Load Forecast (95th% w/DSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forecast wrDSM and EE
Existing Resources
Total Coal
Total Gas
Hydro (90th%)-HCC
Hydro (gos%Hther
Total Hydro (90o%)
csPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAS
Transmission Capacity Available for
Market Purchases
Eristing Resource Subtotal
1,133 1,087 1,122 1,055 1,350
69 154 196 236
1,304
316
1,2U
319
1,007
312
964
213
947
177
827
153
1,083
68
5
7
16
0
0
5
9
20
0
5
9
23
0
5
10
25
0
66
5
10
25
0
00
5
I
't5
0
0
5
7
13
0
0
5
I
12
0
0
5
I
17
0
0
5
I
16
0
0
5
10
25
0
0
5
't0
23
0
0
40
391 506 484
28
416 478 373
3,{8t 3,179 3,370 3,320 3,580 3,773 3,667 3,4t6 3,122 3,184 2,992 3,114
3938
424
3130
365
25
521
25
489
27
575
343640
433
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Resource Subtotal
ilonthly Deficit
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
2017 lntegrated Resource Plan-Appendix C Page 45
Load and Resource Balance Data ldaho Power Company
Peak-Hour Load and Resource Balance (continued)
1n023 2nO23 3nO23 1J2023 5n023 6t2023 7t2023 8t2023 9n023 10t2023 11t2023 12i2023
(2,707) (2,582) (2,275) (2,222) (2,s61) (3,80e) (4,064) (3,661) (3,103) (2,306) (2,511), (2,814)
88 89 86 89
(2,61e) (2,4e3) (2,1e2) (2,134) (2,858) (3,6e0) (3,s34) (3,s41) (3,002) (2,202) (2,4261 (2,725)
1'.|11 11 11 13
104
(2,608) (2,482) (2,181) (2,122) (2,845) (3,284) (s,528) (3,188) (2,e8e) (2,18e) (2,415) (2,713)
88 103 120 129 120 101
15
390
16
390
15
337
13 13 11 1',|
0 0 0 0 0 0 0 0 0
835
716
950
182
835
716
900
187
835
716
950
172
835
716
850
205
835
7',t6
1,050
299
835
716
1,000
303
835
716
1,000
284
835
7',t6
800
207
835
716
750
214
835
716
750
197
835
716
650
176
835
716
900
183
Load Forecast (95th% w/no DSM)
Load Forecast-included EE
Load Forecast (95th% w/DSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forecast W/DSM and EE
Existing Resources
Total Coal
Total Gas
Hydro (90th%)-HCC
Hydro (9Oth%)-Other
Total Hydro (90h%)
CSPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAS
Transmis8ion Capacity Avallable fror
llrarket Purchases
Existing Resource Subtotal
5
7
16
0
0
5
I
15
0
0
5
I
12
0
0
5
10
23
0
0
5
10
25
0
0
1,132
66
5
1,O87
69
1,122
154
1,055
196
1,349
236
't,303
316
1,284
319
1,007
312
964
213
947
177
826
153
't,083
68
0
't0
25
0
0
5
10
25
0
2023
5
I
5
I
0
0
0
0
5
7
't3
0
0
5
I
16
5
9
17
0
0
0
0
3938
423
3l30
364
25
520
25
488
27
574
3436
506
40,O
390
28
415432484 477 372
3,179 3,178 3,370 3,3{9 3,578 3,771 3,666 3,415 3,120 3,182 2,990 3,113
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Resource Subtotal
Monthly Deficit
0 0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0 0
00
0
0
0
0
0
0
0
0
0
0
0 0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0 0
0
0
00
0
Page 46 2017 lntegrated Resource Plan-Appendix C
Idaho Power Company Load and Resource Balance Data
Peak-Hour Load and Resource Balance (continued)
1n024 212024 3t2021 41202/ 5t2024 61202{ 7t2024 8t2024 9t2021 10t2021 1il2024 12J2024
(2,755)
101
(2,654)
13
0
(2,621)
'101
(2,520)
13
0
(2,312)
95
(2,217)
12
0
(2,257)
100
(2,1 56)
13
0
(3,007)
117
(2,8e0)
15
0
(3,871)
136
(3,735)
17
390
(4,147)
149
(3,ss8)
19
390
(3,731)
137
(3,ss4)
17
337
(3,1 55)
116
(3,040)
15
0
(2,342)
't't7
(2,22s)
't5
0
(2,552)
98
(2,454)
12
0
(2,84e)
102
(2,747)
13
0
(2,641) (2,s07) (2,205) (2,144) (2,87s) (3,328) (3,s8e) (3,240) (3,025) (2,210) (2,442) (2,735)
835
716
950
182
835
716
900
181
835
716
950
172
835
716
850
205
835
716
1,050
299
835
716
1,000
302
835
7'.t6
1,000
283
835
716
800
206
835
716
750
213
835
718
750
196
835
716
900
182
835
716
650
175
Load Forecast (956% w/no DSM)
Load Forecastincluded EE
Load Forecast (95b% WDSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forecast wrDsil and EE
Existing Resources
Total Coal
Total Gas
Hydro (9oth%)-HCC
Hydro (9oth%)-Other
Total Hydro (90h%)
csPP (PURPA)
PPAs
Elkhom Valley Wnd
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAS
Transmlsslon Capacity Avallable forilartet Purthasea
Exbtang R$ource Subtotat
1,'.t32 't,08't 1,122 1,055 1,349 1,302 1,283 1,006
69 154 236 316 319 312
963
213
825
153
946
177
5
I
17
0
0
1,082
68
5
't0
25
0
0
196
5
9
20
0
0
5
I
23
0
0
5
10
25
0
0
66
5
10
25
0
0
5
7
6
0
5
I
15
0
0
5
E
12
0
0
5
7
13
0
0
5
s
6
0
5
10
23
0
39
372
38
423
3'l
476
25252tv36
506
4
431
&
389 483 573 487 519
30
364
3,{78 3,171 3,369 3,318 3,577 3,769 3,665 3,4t3 3,120 3,18' 2,990 3,112
28
414
20{7 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
l{aw R$ource Subtota!
ilonthly Deflclt
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
2017 lntegrated Resource Plan-Appendix C Page47
Load and Resource Balance Data ldaho Power Company
Peak-Hour Load and Resource Balance (continued)
u2025 212025 3t2025 4t2025 st202s 612025 7n025 8t2025 9t2025 10t2025 11t2025 12t2025
(2,783)
115
(2,668)
13
0
(2,648)
115
(2,s33)
t3
0
(2,333)
108
(2,226)
13
0
(2,281)
114
(2,167)
13
0
(3,043)
132
(2,911)
15
0
(3,920)
153
(3,766)
18
390
(4,221)
't72
(4,0s0)
20
390
(3,7s1)
156
(3,636)
't8
337
(3,1 98)
132
(3,066)
15
0
(2,368)
131
(2,236)
15
0
(2,577),
110
(2,466)
13
0
(2,86s)
115
(2,754)
13
0
(2,655) (2,519) (2,213) (2,154) (2,8s6) (3,359) (3,640) (3,281) (3,051) (2,221) (2,4541 (2,741)
835
716
950
't81
835
716
900
186
835
716
850
204
835
716
1,050
298
835
7't6
1,000
30'l
835
716
1,000
283
835
7'16
750
212
835
716
750
195
835
7',t6
650
175
835
716
900
181
835
7',t6
800
206
835
716
950
171
Load Forecast (95s% w/no DSlll)
Load Forecast-included EE
Load Forecast (95th% w/DSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forecast wrDSM and EE
Existing Resources
Total Coal
Total Gas
Hydro (90th%)-HCC
Hydro (90th%)-Other
Total Hydro (90th%)
CSPP (PURPA)
PPAs
Elkhorn Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAs
Transmiseion Capacity Available for
llarket Purchases
Existing Resource Subtotal
5
10
25
0
0
5
I
12
0
0
5
I
16
0
0
1,131
66
1,086
69
1,12',1
154
1,054
196
1,348
236
1,301
316
1,283
319
1,006
312
962
213
945
176
825
153
5
10
23
0
0
1,081
68
555555
7
16
0
0
0
0
5
I
17
0
0
5
7
't3
0
0
10
25
I
20
I
23
I
15
0
0
10
25
0
0
0
0
0
0
40
390
36
505
28
412
25
486
25
517
39
371
38
423
3l
476
30
362
27
571
34
483
40
431
3,178 3,t76 3,368 3,3t8 3,574 3,766 3,663 3,411 3,117 3,180 2,989 3,110
2017 lR? Re8ources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Resource Subtotal
Monthly Deficit
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
00
Page 48 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Peak-Hour Load and Resource Balance (continued)
1t2026 2t2026 3t2026 4t2026 5n026 6t2026 7t2026 8t2026 9t2026 10t2026 11t2026 12t2026
Load Forecast (95th% wrno DSM)
Load Forecastincluded EE
Load Forecast (95th% dDSM and EE)
Ad,ustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forecast wrDSM and EE
Existing Resources
Total Coal
Total Gas
Hydro (go$%FHCC
Hydro (90h%!-Other
Total Hydro (9Oh%)
CSPP (PURPA)
PPAs
Elkhorn Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAS
Transmission Capacity Avallable for
Market Purchases
Existing Resource Subtotal
(2,814)
133
(2,682)
11
0
(2,674)
131
(2,5421
11
0
(2,357)
124
(2,233)
10
0
(2,308)
130
(2,178)
11
0
(3,082)
149
(2,933)
12
0
(3,972)
174
(3,7s8)
't4
390
(4,301)
199
(4,102)
16
390
(3,856)
178
(s,678)
15
337
(3,24s)
152
(3,0s3)
13
0
(2,3e6)
148
(2,248)
12
0
(2,604\
125
(2,479)
10
0
(2,e01)
13't
(2,769)
11
0
(2,671) (2,531) (2,223) (2,167) (2,e20) (3,3e4) (3,6s5) (3,326) (3,080) (2,236) (2,46s) (2,75s)
703
716
950
18'l
703
716
900
185
703
716
950
171
703
7',t6
850
2M
703
716
1,050
294
703
716
1,000
300
703
716
1,000
282
703
716
800
205
703
716
750
211
703
716
750
'195
703
716
650
't74
703
716
900
't 81
1,131
66
1,085
68
1,121
153
1,054 1,348
236
1,300
316
1,282
318
1,005
312
961
212
945
176
824
't52
1,081
68195
5
10
25
0
0
5
10
25
0
0
5 5 5
7
16
0
0
5
8
15
0
0
5
8
't2
0
0
5
7
13
0
0
5
I
16
0
0
5
I
17
0
0
5
10
23
0
0
5
I
23
I
20
0
10
25
0
0 0 0
40
52'.1
40
562
36
636
34
613
28
543
27
703
25
616
25
648
30
492
31
607
38
554
39
503
3,176 3,174 3,365 3,316 3,573 3,764 3,66t 3,4t0 3,114 3,177 2,987 3,t t0
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Resource Subtotal
Monthly Deficit
200 200 200 500 500 s00 500 s00 500 200 200 200
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
200 200 200 500 500 500 500 500 500 200 200 200
0 0 0 0 0 0 0 0 0 0 0 0
2017 lntegrated Resource Plan-Appendix C Page 49
Load and Resource Balance Data ldaho Power Company
Peak-Hour Load and Resource Balance (continued)
1t2027 2t2027 3t'.t2027 4t2027 512027 612027 7t2027 8t2027 9t2027 1012027 1112027 12t2027
(2,8s4) (2,706) (2,387) (2,338) (3,123) (4,02s) (4,s83) (3,e23) (3,2e5) (2,426) (2,633) (2,e31)
149 147 139 146 166 194 227 201 172 164 139 147
(2,705) (2,sss) (2,248) (2,1e2) (2,957) (3,836) (4,157) (3,723) (3,124) (2,262) (2,4e3) (2,784)
8 10 118 oI
0
o
0 0 0 0 390
't3
390
12
337
10 10
0 0
8
0 0
(2,6e6) (2,551) (2,240) (2,184) (2,e47\ (3,434) (3,753) (3,374) (3,114) (2,252) (2,485) (2,776)
703
716
950
180
703
716
900
185
703
716
950
170
703
716
850
2U
703
716
1,000
298
703
716
1,000
282
703
716
800
205
703
7'.|6
750
210
703
716
650
174
703
716
900
181
703
716
1,050
296
703
716
750
194
Load Forecast (95th% w/no DSM)
Load Forecast-included EE
Load Forecast (95u% WOSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forccast WDSM and EE
Existing Resources
Total Coal
Total Gas
Hydro (90th%)-HCC
Hydro (gos%)-Other
Total Hydro (9Oh%)
CSPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchang+-Take
Clatskanie Exchange-Return
Total PPAS
Transmission Capacity Available for
Market Purchases
Existing Resource Subtotal
1,130
65
1J20
153
1,085
68
't,054
195
1,346
236
1,298
316
1,282
318
1,005
312
960
212
944
176
824
152
1,081
68
5
10
25
0
0
5
8
12
0
0
5
I
16
0
0
5
10
25
0
0
5
7
16
0
0
5
10
23
0
0
2023
5
o
5
I
0
0
0
0
5
7
13
0
0
5
8
15
0
0
5
I
17
0
0
5
10
25
0
0
39
502
38
554
3t
607
3025
647
27
701
28
542
36/m
562
/t{l
520
34
612
25
615636 492
3,174 3,173 3,365 3,314 3,570 3,76t 3,659 3,408 3,113 3,177 2,986 3,109
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Resource Subtotal
Monthly Defieit
200 200
0
0
200
0
200 500
0
0
500
0
500
0
0
500
0
200
0
0
200
0
500 500 500 500
0
200 200
200 200
0
0
0
0
0
0
500
0
500
0
200
0
0
0
0
0
0
0
0
0
0
200
0 00 0 0
Page 50 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Peak-Hour Load and Resource Balance (continued)
1t2028 A2028 312028 4t2028 5t2028 6t2028 7t2028 812028 912028 10t2028 1112028 1212028
(2,8e4) (2,737) (2,417) (2,368) (3,165) (4,085) (4,467) (3,9s1) (3,346) (2,4s5) (2,661) (2,s57)
166 163 155 161 '183 213 255 223 192 179 153 162
(2,728) (2,574) (2,263) (2,206) (2,s81) (3,872) (4,212) (3,768) (3,155) (2,276) (2,50s) (2,796)
6 7 10
390
o 7 67
0
8b
0
6
o
6
0 0 0 390 337 0 0 0
(2,721) (2,568) (2,257) (2,200) (2,e74) (3,474) (3,812) (3,422) (3,147) (2,26s) (2,s03) (2,78e)
703
716
950
180
703
716
900
179
703
7't6
950
't70
703
716
850
2U
703
716
1,050
295
703
716
1,000
296
703
716
1,000
281
703
716
800
204
703
716
750
209
703
716
750
193
703
716
650
173
703
716
900
181
Load Forecast (95rh% w,no DSM)
Load Forecastincluded EE
Load Forecast (95s% w/DSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forecast WDSM and EE
Exasting Resources
Total Coal
Total Gas
Hydro (goth%FHCC
Hydro (gos%Hther
Total Hydro (90th%)
CSPP (PURPA)
PPAs
Elkhorn Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAS
Transmlsslon Capacity Available for
Market Purchases
Existing Re3ource Subtotal
1,130
65
1,079
68
1,120
153
1,054
195
1,345
236
1,296
316
't,281
318
1,004
312
959
212
943 823
152
1,081
68
0
10
176
0
10
25
0
0 0
7
0
I
0
o
0
8
15
0
0
0
I
12
0
0
0
7
13
0
0
0
I
16
0
0
0
I
17
0
0
0
0
23
0
0
10
25
0
10
23
0
25
0
16
0
20
0
0000
3433
553
25
491
2023
540
2935
562
35
520
3l
635 612
22
700
20
614 646
26
607 502
3,t69 3,163 3,358 3,309 3,562 3,753 3,653 3,401 3,106 3,171 2,979 3,104
ji'i;'i1 ;1.r,, ' ,.,;,i. ,..'l,r
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Re3ource Subtotal
Monthly Deflclt
200 200 500 500 500 500 500 500200
0
0
200
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
500
0
500
0
500
0
0
500
0
0
0
200
0
0
200
0
200 200
200 200500
0
200
0
200 500
0000 0
2017 lntegrated Resource Plan-Appendix C Page 51
Load and Resource Balance Data ldaho Power Company
Peak-Hour Load and Resource Balance (continued)
1n029 2t2029 312029 4t2029 5t2029 6t2029 7t2029 8t2029 9t2029 10t2029 11t2029 12t2029
(2,s2s) (2,767) (2,444I (2,3s6) (3,205) (4,13e) (4,551) (4,058) (3,3s7) (2,483) (2,688) (2,s85)
184 175 172 178 201 233 286 247 2'.t3 195 167 178
(2,745) (2,588) (2,273) (2,218) (3,004) (3,s06) (4,265) (3,811) (3,183) (2,288) (2,521) (2,807)
3 3 3 4 34
0
3
0 0
3
0 0 390 390 337
3
0
5 3
0
3
0 0
(2,742) (2,s8s) (2,270) (2,21s) (3,001) (3,513) (3,870) (3,470) (3,180) (2,285) (2,519) (2,805)
527
716
950
179
527
716
900
184
527
716
950
169
527
716
850
203
527
716
1,050
293
527
716
1,000
295
527
716
1,000
281
527
7't6
800
203
527
716
750
208
527
716
750
192
527
716
650
172
527
7',t6
900
180
Load Forecast (95tr% wrno Dsill)
Load Forecastincluded EE
Load Forecast (9$h% WDSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forecaet W,DSM and EE
Existing Resources
Total Coal
Total Gas
Hydro (goh%)-HCC
Hydro (9Oth%)-Other
Total Hydro (90th%)
CSPP (PURPA)
PPAg
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Tota! PPA3
Transmission Capacity Available for
Market Purchases
Existing Resource Subtotal
1,129
63
1,084
66
1,1 19
151
1,053
193
1,343
233
1,295
313
1,281
316
1,003
309
942
173
1,080
65
958
209
0
o
16
0
0
0
10
25
0
0
422
149
0
't0
23
0
0
0
7
16
0
0
0
o
20
0
0
0
9
23
0
0
0
10
25
0
0
0
't0
25
0
0
0
I
17
0
0
0
7
13
0
0
0
8
12
0
0
0
8
15
0
0
35
519 635
29
611 539 613 489
33
553
26
606
2520
645
2022
698
233t35
561
34
501
2,989 2,988 3,180 3,129 3,381 3,s7r 3,473 3,221 2,924 2,991 2,800 2,924
2017 IRP Resourcea
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Reaource Subtotal
llonthly Deficit
0
0
200
200
200200200500500500500500500200200
200200500
000000
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
200
0
500
0
500
0
0
0
0
0
0
200
0
200
0
500
0
500
0
Page 52 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Peak-Hour Load and Resource Balance (continued)
112030 ?i'2030 312030 412030 512030 612030 7t2030 812030 912030 10t2030 11t2030 1a2$o
(2,s6s)
203
(2,763)
0
0
(2,797)
197
(2,601)
0
0
(2,473)
189
(2,284)
0
0
(2,425)
196
(2,230)
0
0
(3,245)
220
(3,025)
0
0
(4,1e2)
253
(3,e3e)
0
390
(4,636)
318
14,317)
0
390
(4,125)
272
(3,853)
0
337
(3,447)
237
(3,210)
0
0
(2,s11)
21',|
(2,2se)
0
0
(2,715)
182
(2,s33)
0
0
(3,012)
195
(2,817)
0
0
(2,763) (2,601) (2,284) (2,230) (3,025) (3,s4e) (3,e27) (3,516) (3,210) (2,2ee) (2,533) (2,817)
527
7'.t6
950
179
527
716
900
183
527
716
1,000
280
527
716
950
169
527
716
850
203
527
716
1,050
293
527
716
1,000
294
527
716
650
172
527
716
750
207
527
7't6
800
203
527
716
750
192
527
716
900
175
Load Forecast (95th% dno DSM)
Load Forecast-included EE
Load Forecast (gStho/o w/DSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Foreca3t W/DSM and EE
Existing Resources
Total Coal
Total Gas
Hyclro (90th%)-HCC
H ydro (90tho/o)--Other
Total Hydro (90th%)
CSPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Retu rn
Total PPAS
Transmission Capacity Available for
Market Purchases
Existing Resource Subtotal
0
I
15
0
0
0
8
12
0
0
0
10
23
0
0
0
10
25
0
0
1,129
63
't,083
65
0
1,1 19
151
1,053
't 93
1,343
233
't,294
311
1,280
314
1,00s
307
957
207
942
171
822
148
1,079
63
0 00
I
23
0
0
9
0
7
16
0
0
0
7
13
0
0
0
9
16
0
0
20
0
00
10
25
0
't0
25
0
0
I
17
0
00
35
518
34
501
33
552
26
606
25
489
20
444
20
612
22
698
23
538
3l
634
35
561
29
612
2,988 2,987 3,178 3,130 3,380 3,568 3,410 3,218 2,922 2,988 2,797 2,921
.l I .. ,. : rll, i,. rl
2017 IRP Resourceg
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocatng Gas Engine
New Resource Subtotal
Monthly Deflclt
200
0
0
200
0
500
0
0
500
0
200 200
500
500
0
0
500
0
500 500 500 500 200 200 200
0
0
0
0
0
00
500
0
0
500 200
0
500
0
0
0
0
0
0 0
0
0
200200
0
200200
0
2017 lntegrated Resource Plan-Appendix C Page 53
Load and Resource Balance Data ldaho Power Company
Peak-Hour Load and Resource Balance (continued)
112031 A2031 3t2031 4t2031 5t2031 6/2031 7t2031 8t2031 9/2031 10t2031 11t2031 12t2031
(3,001) (2.827) (2,501) (2,454) (3,285) (4,244) (4,723) (4,1e3) (3,4e7) (2,s38) (2,741) (3,031)
222 214 207 213 238 274 353 297 261 227 196 211
(2,780) (2,61s) (2,2s4) (2,241) (3,047) (3,e71) (4,370) (3,8e6) (3,237) (2,311) (2.545) (2,820)
0 0 0
390
0
337
0 0
0 0
0
0
0 00
390
0 0
000 0
(2,7801 (2,613) (2,2s4) (2.241) (3,047) (s,581) (3,s80) (3,55s) (3,237) (2,311) (2,545) (2,820)
527
716
950
179
527
716
900
183
527
716
950
169
527
7',t6
850
203
527
716
1,000
292
527
716
1,000
279
527
716
800
202
527
716
750
191
527
7'.t6
650
171
527
716
900
179
527
7'.t6
1,050
292
527
716
750
206
Load Forecast (95th% w,no DSM)
Load Forecast-ncluded EE
Load Forecast (95th% w/DSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forecast wrDsill and EE
Existing Resources
Total Coal
Totat Gas
Hydro (goh%)-HCC
Hydro (90th%)--Other
Total Hydro (90th%)
CSPP (PURPA)
PPAs
Elkhorn Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAS
Transmission Capaclty Available for
Market Purchases
Existlng Resource Subtotal
1,129
58
1,1 19
141
1,083
55
1,053
183
1,342
222
1,292
302
1,279
305
1,002
298
956
198
941
162
82'.1
137
1,079
53
0
I
0
0
0
10
25
0
10
25
0
0
0
I
12
0
0
0
I
'16
0
0
0
10
23
0
0
0
I
2023
0
7
16
0
0
0
0
0
I
17
0
0
0
7
13
0
0
0
I
15
0
0
0
10
25
0
0
0
0
u
500
33
552
26
605
25
489
20
643
22
697
23
538
3l35
560
35 29
611
20
611518635
2,983 2,976 3,t69 3,1t9 3,368 3,556 3,459 3,207 2,91'.t 2,977 2,786 2,910
20{7 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Resource Subtotal
Monthly Deficit
200 200 200 500 500 500 500 500 500 200 200
0
36
236
36
536
36
536
36
536
36
536
0
200
0
200
0
0
200
0
0
36
236 200
0
200
00
0
0
0
0
0
0
0
0
500
0
500
0
0
0 00 0
0
0 000
Page 54 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Peak-Hour Load and Resource Balance (continued)
1t2032 2t2032 3t2032 4t2032 512032 6t2032 7t2032 8t2032 912032 1012032 1112032 1212032
Load Forecast (951h% wrno DSm)
Load Forecast-included EE
Load Forecast (95s% w/DSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forecast wrDSM and EE
Existing Resources
Total Coal
Total Gas
Hydro (90th%)-HCC
Hydro (9Oth%)-Other
Total Hydro (90s%)
csPP (PURPA)
PPAs
Elkhorn Valley Wind
Rafr River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAS
Transmission Capaclty Available for
Market Purchases
Existing Resource Subtotal
(3,02e)
240
(2,788)
0
0
(2,853)
231
(2,623\
0
0
(2,522)
225
(2,2e7)
0
0
(2,479)
230
(2,248)
0
0
(3,321)
256
(3,065)
0
0
(4,2e1)
293
(3,ee8)
0
390
(4,807)
387
(4,420)
0
390
(4,2s8)
323
(3,s35)
0
337
(3,s45)
285
(3,260)
0
0
(2,562)
242
(2,320)
0
0
(2,765)
210
(2,s55)
0
0
(3,059)
227
(2,832)
0
0
(2,788) (2,623) (2.2e7) (2,248) (3,06s) (3,608) (4,030) (3,5s8) (3,260) (2,320) (2,555) (2,832)
527
7'16
950
179
527
7'.t6
900
't77
527
716
950
169
527
716
850
202
527
716
1,050
291
527
716
1,000
290
527 527
716
800
201
527
716
750
205
527
716
750
190
527
716
650
170
527
716
900
179
716
1,000
279
'1,'129 1,077
53
1,119
138
1,052
180
't,341
221
1,290
301
1,279
303
1,001
297
955
197
940
161
820
137
'1,079
5350
0
10
25
0
0
0
10
25
0
0
0 0
7
16
0
0
0 0
8
12
0
0
0 0
I
16
0
0
0
I
17
0
0
0
10
23
0
0
0
10
25
I
23
I
20
8
15
7
13
0
0
0
0
0 0
0 0 0
35
517
35
560
3l
634
29
611
23
537
22
696
20
610
20
643
25
488
26
605
33
552
34
500
2,974 2,968 3,165 3,1t5 3,354 3,552 3,456 3,205 2,908 2,975 2,785 2,909
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Resource Subtotal
Monthly Deficit
200 200 200 500 500
00000
720000
272 200 200 500 500
500
0
72
572
500 500 500 200 200 200
0 0 0 0
0
0 0
72
572
(2)
72
572
72
572
0 72
272200200
0 0 0 0 0 0 0 0 0
Note: Remaining monthly deficit amounts for July 2032, July 2035, and July 2036 are below de minimis amounts and occur near the end of
the planning perlod leaving adequate time to adjust in future planning periods.
2017 lntegrated Resource Plan-Appendix C Page 55
Load and Resource Balance Data ldaho Power Company
Peak-Hour Load and Resource Balance (continued)
t/2033 2t2033 3/2033 4t2033 5t2033 612033 7t2033 8/2033 912033 10t2033 11t2033 12t2033
Load Forecast (95s% wrno DSM)
Load Forecastincluded EE
Load Forecast (95th% w/DSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Foreca3t dDSM and EE
Existing Resources
Total Coal
Total Gas
Hydro (90th%)-HCC
Hydro (9Oth%)-Other
Total Hydro (9Oh%)
csPP (PURPA)
PPAs
Elkhorn Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAS
Transmlsslon Capacity Available for
Market Purchases
Exbting Resource Subtotal
(3,066)
258
(2,808)
0
0
(2,87e)
247
(2,6s3)
0
0
(2,ss0)
242
(2,30e)
0
0
(2,s07)
247
(2,260)
0
0
(3,359)
272
(3,087)
0
0
(4,343)
311
(4,032)
0
390
(4,8s4)
421
(4,474)
0
390
(4,325)
347
(3,979)
0
337
(3,ss6)
308
(3,288)
0
0
(2,587)
255
(2,332)
0
0
(2,7eo)
222
(2,567)
0
0
(3,08e)
242
(2,847)
0
0
(2,808)(2,633) (2,30e) (2,260) (3,087) (3,642) (4,084) (3,642) (3,288)(2,332) (2,567) (2,847)
352
716
950
178
352
716
900
182
352
716
950
168
352
716
850
200
352
716
1,050
290
352
716
1,000
289
352
716
1,000
278
352
716
800
200
352
716
750
204
352
716
750
189
352
7'.t6
650
170
352
716
900
178
1,128 1,082 1,'t 18 1,050 1,340
212
't,289
292
1,278
295
1,000
288
954
188
939
152
820
124
1,078
4441
0
10
25
0
0
44 130 171
0
10
25
0
0
9
23
0
0
o
20
0
0
7
16
0
0
0
8
15
0
0
0
8
12
0
0
0
7
13
0
0
0
I
6
0
0
I
17
0
0
0
10
23
0
0
10
25
0
0 0 0
35 35
559
3t 29
610
23
535
22
694
20 20
64't
25 26
604
33
551
34
500517633608487
2,789 2,787 2,979 2,928 3,177 3,364 3,269 3,017 2,721 2,789 2,598 2,724
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Resource Subtotal
ilonthly Deffcit
200
300
72
572
0
200
300
0
500
0
200
300
0
500
0
500
300
0
800
0
500 500
300
72
872
0
500
300
72
872
0
500
300
72
872
0
500
300
72
872
0
200
300
0
500
0
200
300
0
500
0
200
300
72
572
0
300
0
800
0
Page 56 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Peak-Hour Load and Resource Balance (continued)
1n034 2nOU 312034 412031 512034 Et2034 7t2034 812034 9t2034 10t2034 11t2034 12t2031
(3,108) (2,s12) (2,582) (2,s37) (3,400) (4,3e8) (4,s85) (4,se6) (3,6s2) (2,613) (2,816) (3,117)
276 262 259 263 288 328 455 37'.|,332 267 2U 257
(2,(3,112) (4,070) (4,s2e) (4,02s) (3,31e) (2,346) (2,s82) (2,860)
0 0 0 0
64e)
0
0
(2,
0
274)
0
0
(2,323)(2,832)
(2,832) (2,64e) (2,323) (2,274) (3,112) (3,680) (4,13s) (3,688) (3,31e) (2,346) (2,582) (2,860)
0
0
00
0
0
0 0 390 390 337 0 0
0
0
352
716
950
177
352
716
900
181
352
716
950
168
352
716
850
200
352
716
1,050
289
352
716
1,000
286
352
716
1,000
278
352
7',t6
800
200
352
716
750
188
352
716
650
169
352
716
900
177
352
716
750
202
Load Forecast (95th% w/no DSitl)
Load Forecast-;ncluded EE
Load Forecast (95h% W/DSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forecast wrDsli and EE
Existing Resources
Total Coal
Total Gas
Hydro (90thYd-HCC
Hydro (90tho/o)-Other
Total Hydro (90th%)
CSPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPAS
Transmission Capacity Avallable for
Market Purchases
Exbting Resource Subtotal
1.127 1 ,081 '.t ,118
41 44 130
1,050
171
1,339
212
1,286
292
1,278
295
1,000
288
938
152
819
128
1,077
44
952
188
0
9
16
0
0
0
8
12
0
0
0
10
25
0
0
0
10
25
0
0
9
23
0
0
I
0
7
16
0
0
0
8
15
0
0
0
I
17
0
0
0
7
13
0
0
0
10
23
0
0
0
20
0
10
25
0
00
u
500
33
551
252020
607
22
693
35
559
35
517
31
633
29
610
23
535 640 486
26
604
2,787 2,786 2,979 2,928 3,t76 3,360 3,267 3,016 2,719 2,788 2,598 2,723
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Resource Subtotal
Monthly Deficlt
200
300
0
500
0
500
300
0
800
0
200 200 500
300 300
72
872
(0)
500
300
72
872
0
500 500 500 200 200 200
300
72
572
0
0000
300
0
500
0
300
72
572
300
72
872
300
0
500
0
300
0
500
0
300
72
872
0
2017 lntegrated Resource Plan-Appendix C Page 57
Load and Resource Balance Data ldaho Power Company
Peak-Hour Load and Resource Balance (continued)
1n035 2t2035 3/2035 4t2035 512035 6/2035 7n035 812035 912035 1012035 1112035 12J2035
(3,147) (2,e42) (2,611) (2,s66) (3,440) (4,4ss) (5,076) (4,466) (3,707) (2,638) (2,843) (3,14e)
294 278 276 280 305 345 492 396 357 280 246 272
(3,(4,107) (4,s84) (4,070) (3,350) (2
0
390
0
390 337
(2,s97)(2,287)(2,334)(2,8s3),664)
0
0
(2 359)
0
0
0
35)
0
0
878)
0
0
(2,
0
0
0
0
0
0
0
0
0
0
878)(2,(2,5s7)3s9)(2,(2,85s) (2,664) (2,334) (2,287) (s,135) (3,717) (4,194) (3,733) (3,350)
352
716
950
176
352
716
900
181
352
716
950
167
352
716
850
200
352
716
1,050
287
352
716
1,000
2U
352
716
1,000
277
352
716
800
199
352
716
750
201
352
716
750
188
s52
716
650
168
352
716
900
177
Load Forecast (95th% wrno DSM)
Load Forecast-included EE
Load Forecast (95s% WDSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forccast wrDSM and EE
Existing Resources
Total Coal
Total Gas
Hydro (90th%)-HCC
Hydro (90h%)--Other
Total Hydro (90fr%)
CSPP (PURPA)
PPAs
Elkhom Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Return
Total PPA8
TranBmi$ion Capacity Available for
Market Purchases
Existing R*ource Subtotal
1,126
41
1,081
44
1,117
130
1,050
171
1,337
212
1,284
292
1,277
295
999
288
951
188
938
152
8't8
128
1,077
44
0
I
20
0
0
0
9
23
0
0
0
10
25
0
0
0
10
25
0
0
0
8
12
0
0
0
8
15
0
0
0
7
16
0
0
0
7
13
0
0
0
10
23
0
0
0
I
17
0
0
0
I
16
0
0
0
10
25
0
0
35
516 632 693 485 499
2,786 2,786 2,977 2,927 3,173 3,358 3,267 3,015 2,716 2,787 2,596 2,721
3433
550
28
604
2520
640
20
607
2223
534
29
609
3{35
559
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Resource Subtotal
Monthly Deficit
200
300
126
626
0
200
300
0
500
0
200
300
0
500
0
500
300
0
800
0
500
300
126
926
0
500
300
't26
926
0
500
300
126
926
0
200
300
0
500
0
200
300
126
626
0
200
300
0
500
0
500
300
0
800
0
500
300
126
926
(2)
Note: Remaining monthly deficit amounts for July 2032, July 2035, and July 2036 are below de minimis amounts and occur near the end of
the planning period leaving adequate time to adjust in future planning periods.
Page 58 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Load and Resource Balance Data
Peak-Hour Load and Resource Balance (continued)
1t2036 2t2036 3/2036 4t2036 5/2036 6/2036 7t2036 8/2036 9/2036 t0r2036 11t2036 12t2036
(3,1e3) (2,s78\ (2,646) (2,see) (3,484) (4.512) (5,172) (4,541) (3,76s) (2,666) (2,871)(3,1 83)
288
(2,8e6)
0
0
314 295 296 298 323 364 531 423 384 293 259
(2,87s) (2,682)(2,350)
0
0
(2,302) (3,161) (4,148) (4,641) (4,118) (3,s84) (2,373) (2,612)
0 0 0
390
0 00
0 0
0
0
0 0
00 390 337 0 0
(2,87e) (2,682) (2,350) (2.302) (3,161) (3,758) (4,251) (3,781) (3,384) (2,373) (2,612) (2,8e6)
352
716
950
175
352
716
1,000
282
352
716
1,000
276
352
716
900
175
352
716
950
166
352
716
850
200
352
716
1,050
286
352
716
800
198
352
716
750
200
352
716
750
187
352
716
650
167
352
716
900
176
Load Forecast (95th% w/no DSM)
Load Forecast-included EE
Load Forecast (95s% WDSM and EE)
Adjustment for EE Potential Study Forecast
Existing Demand Response
Peak-Hour Forecast WDSM and EE
Existing Resources
Total Coal
Total Gas
Hydro (9Otho/o)-HCC
Hydro (90th%)-Other
Total Hydro (90th%)
csPP (PURPA)
PPAs
Elkhorn Valley Wind
Raft River Geothermal
Neal Hot Springs Geothermal
Clatskanie Exchange-Take
Clatskanie Exchange-Retu rn
Total PPAS
Transmission Capacity Available for
Market Purchases
Existing Resource Subtotal
1,125
41
0
1,075
44
0
1,1 16
130
1,050
171
1,336
212
1,282
292
1,276
295
998
288
950
188
937
152
817
128
1,076
44
0
10
25
0
0
'10
25
0
0
I
23
0
0
0
7
16
0
0
I
0
8
15
0
0
0
8
12
0
0
0
7
13
0
0
0
I
't6
0
I
17
0
0
0
10
23
0
0
0
10
25
0
0
20
0
0
0
00
515
3l
631 692 638 604 499
2,784 2,779 2,976 2,927 3,170 3,355 3,255 3,012 2,715 2,786 2,595 2,721
3433
550
2625
485
2020
606
2223
533
29
609
35
558
35
2017 IRP Resources
2026 Boardman to Hemingway Transmission
2033 Combined Cycle Combustion Turbine
2030s Reciprocating Gas Engine
New Resource Subtotal
Monthly Deficit
200
300
180
680
0
500
300
180
980
0
500
300
180
980
0
200
300
0
500
0
0
500
0
200
300
0
500
0
200 500 500
300 300 300
500
300
'180
980
(6)
500
300
180
980
0
200
300
180
680
0
200
300
0
500
00
800800
00
Note: Remaining monthly deficit amounts for July 2032, July 2035, and July 2036 are below de minimis amounts and occur near the end of
the planning period leaving adequate time to adjust in future planning periods.
2017 lntegrated Resource Plan-Appendix C Page 59
ldaho Power Company Demand-Side Resource Data
DerueruD-SrDE ResouRcE Dere
Cost Effectiveness
Idaho Power considers cost-effectiveness to be the primary screening tool prior to demand-side
management (DSM) program implementation. Idaho Power's goal is for all programs to have
benefit/cost (B/C) ratios greater than one for the total resource cost (TRC) test, utility cost (UC) test, and
participant cost test (PCT) at the program and measure level where appropriate. Each cost-effectiveness
test provides a different perspective, and Idaho Power believes each test provides value when evaluating
program performance. If a specific measure or program is found to be not cost-effective from each of the
three tests. For resource planning Idaho Power primarily uses the total resource cost (TRC) test and the
utility cost (UC) tests to determine the cost-effective energy efficiency for inclusion in the IRP.
Each energy efficiency program and individual program measures are reviewed annually as part of
preparation of an annual report that is submitted to both the Idaho Public Utilities Commission and
Public Utilities Commission of Oregon. More information on Idaho Power's programs and cost-
effectiveness is included in the Demand-Side Management 2016 Annual Reporr and its Supplement l:
C o s t- Effe ctiv ene s s, (idahopower.com/EnergyEfhciency/reports. cfm).
Incorporated into the cost-effectiveness analysis are inputs from various sources that represent the most
current and reliable information available. Measure savings, measure life, and participant cost
assumptions for prescriptive programs are usually sourced from the Regional Technical Forum (RTF),
which is the regional advisory group and technical arm of the Northwest Power and Conservation
Council G\fPCC). For custom and non-prescriptive programs, annual energy savings can be derived from
program evaluations, engineering estimates, or regionally deemed values. Participant costs for
non-prescriptive programs are often actual costs from customer-submitted information. Other inputs
used in the cost-effectiveness models are obtained from the IRP process, including the financial
assumptions along with the value of DSM alternative costs.
For the 2017 IRP, non-energy related benefits (NEB) were included in the cost-effectiveness analysis of
the program forecasts. NEB include savings from water savings, defened maintenance and operational
costs, avoided supplemental fuels, and other quantifiable benefits. NEB values from the2016 portfolio
of programs was used in the calculation of cost-effectiveness at the sector level. For a complete list of
NEB and sources that Idaho Power currently uses for its program cost-effectiveness, see Demand-Side
Monogement 2016 Annual Reporr and its Supplement I: Cost-Effectiveness,
(idahopower. com/EnergyEfhciency/reports. cfm).
The cost-effective analysis methods used at Idaho Power are consistent with published methods and
standard practices. Idaho Power relies on the Electric Power Research Institute End Use Technical
Assessment Guide (TAG) Understanding Cost-Effectiveness of Energt Effictency Programs, and the
California Standard Practice Manual for the cost-effectiveness methodology. As defined in the TAG
and Califurnia Standard Proctice Manual, the TRC and UC tests are most like supply-side cost analysis
and provide a useful basis to compare demand-side and supply-side resources.
2017 lntegrated Resource Plan-Appendix C Page 61
Demand-Side Resource Data ldaho Power Company
Resource Development and Evaluation
When developing energy effrciency programs, Idaho Power uses data and experiences from other
companies in the region, or throughout the country, where applicable, to help identifu specific program
parameters. This is accomplished through discussions with other utilities' progftrm managers and
researchers. Idaho Power also uses electric industry research organizations, such as E Source, the
Consortium for Energy Efficiency (CEE), American Council for an Energy-Effrcient Economy
(ACEEE), and the Association of Energy Service Professionals (AESP), to identifu similar programs
and their results.
A11 programs are included in an ongoing evaluation schedule where a third-party consultant verifies the
claimed savings from the program. Programs are also evaluated to review the program processes to
assess the effectiveness of the program delivery. If an evaluation determines that savings are less than
claimed or that there is potential for improvement in delivery of the program, then changes can be made
based on the recofirmendations. Recent evaluations from the 2016 program year can be found in the
Demand-Side Management 2016 Annual Report and its Supplement 2: Evaluations,
(idahopower. com/EnergyEffi ciency/reports. cfm).
Planning Assumptions and Alternate Costs
All financial assumptions used in the cost-effectiveness analysis for energy efficiency resources
included in the 2017 IRP are consistent with the financial assumptions made for supply-side resources,
including the discount rate and cost escalation rates. The IRP is also the source of the DSM alternative
costs, which is the basis for estimating the value of energy savings and demand reduction resulting from
the DSM programs. The DSM alternative energy costs are based on either IRP forecast of fuel costs of a
natural gas peaking unit for peak summer hours or future energy prices as determined by the
AURORAxmp@ Electric Market Model. The avoided capacity resource for peak summer hours is based
on a 170 MW natural gas-fired, simple-cycle combustion turbine (SCCT) 35-year levelized cost.
The AURORAxmp@ model is an electricity forecasting tool that simulates hourly economic dispatch of
supply-side resources considering demand-side, and transmission resources. Idaho Power's planning
model forecasts electric market prices throughout southem Idaho and theWestern Electricity
Coordinating Council (WECC) region. Idaho Power modeled hourly, marginal electricity costs for the
years 2017 through 2036 to estimate the potential system benefit of avoiding future cost production
energy. An initial run of DSM Alternative costs is estimated during the preliminary analysis phase of the
IRP process. The preliminary runs combined updated planning assumptions including load and natural
gas price forecasts run using the preferred resource portfolio from the 2015 IRP. After the selection of
the preferred portfolio a final run of marginal prices will be run which, once acknowledged, become the
DSM altemative energy prices for energy efficiency valuation until the next IRP analysis is completed
and acknowledged.
To simpliff cost-effectiveness calculations, the DSM altemative costs are averaged and placed into
five pricing categories. The resulting pricing categories include the following:
Page 62 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Demand-Side Resource Data
o Summer On-Peak (SONPFAverage of Idaho Power variable energy and operating costs of a
170 MW SCCT, which is the marginal resource for peak hour load deficits during summertime
heavy load hours
o Summer Mid-Peak (SMP)-Average of heavy load prices from June to August (excluding the
SONP hours)
o Summer Off-Peak (SOFPFAverage of light load prices from June to August
o Non-Summer Mid-Peak (NSMP)-Average of heavy load prices in January through May and
September through December
o Non-Summer Off-Peak (NSOFPfAverage of light load prices in January through May and
September through December
The SONP is treated differently than the other four pricing periods when valuing energy efficiency.
The estimated levelized capacity cost of a new SCCT is $122 per kWYear over a 35-year period.
The $122 per kWYear avoided capacity value is spread across the annual SONP hours to value the
energy efficiency savings occurring during the hours.
Forecast and Cost-Effectiveness Data
Table DSM-l lists the financial assumptions used for the cost-effectiveness analysis.
Table DSM-I. IRP financia! assumptions
DSM Analysis Assumptions
Avoided 35-Year Levelized Capacity Costs
SCCT
Financia! Assumptions
Weighted average cost of capital (2016 year ending affer tax)
Financial escalation factor
Transmission Losses
Non-summer secondary losses
Summer peak loss
$122R\Nlyear
6.74%
2.1Oo/o
9.60%
9.70%
2017 lnlegrated Resource Plan-Appendix C Page 63
Demand-Side Resource Data ldaho Power Company
Table DSM-2 shows the planning results of averaging forward energy prices over the 2}-year
planning period.
Table DSM-2. DSM alternate costs by pricing period
Year
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
$48.14
$53.96
$54.40
$55.s9
$57.00
$57.70
$58.80
$61.08
$63.75
$66.15
$68.26
$71.36
$73.79
$75.69
$77.07
$78.34
$78.88
$78.79
$77.22
$75.80
$29.55
$31.32
$32.35
$32.56
$33.08
$33.04
$34.20
$35.90
$36.67
$38.74
$41.86
$45.2',1
$46.30
$48.53
$50.56
$51.91
$52.02
$52.71
$51.71
$51.20
$26.33
$28.28
$29.33
$30.53
$30.94
$31.59
$33.75
$35.82
$36.46
$38.40
$41.04
$44.09
$44.94
$47.23
$48.01
$48.94
$48.16
$47.92
$46.89
$45.74
$28.28
$29.94
$30.75
$30.75
$30.75
$30.60
$32.99
$34.52
$35.53
$37.98
$41.18
$44.4
$47.07
$49.11
$51.00
$52.49
$53.35
$53.80
$53.08
$51.83
$26.47
$27.92
$28.81
$28.99
$29.05
$28.35
$31.92
$33.55
$34.19
$36.43
$39.35
$42.35
$44.23
$46.31
$48.22
$49.82
$50.36
$51.02
$50.46
$49.59
Annual
Average2
$42.76
$44.64
$45.48
$45.73
$45.96
$45.74
$48.29
$49.90
$50.87
$53.21
$56.19
$59.28
$61.38
$63.45
$65.24
$66.69
$67.23
$67.67
$66.90
$65.80
1 Estimated average annual variable operations and management costs of a 170 MW capacity SCCT
2Annual average across all hours includes 35 year levelized capacity value of a 170 IVIW SCCT.
Page 64 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Demand-Side Resource Data
Tables DSM-3 and DSM-4 shows the distribution of the three summer and two non-summer pricing
periods across the hours and days of the week and for holidays.
Table DSM-3. DSM alternate cost summer pricing periods (June 1-August 31)
Hour Sunday Monday Tuesday Wednesday Thursday Friday Saturday Holiday
1
2
3
4
5
6
7
8
I
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
2017 lntegrated Resource Plan-Appendix C Page 65
Demand-Side Resource Data ldaho Power Company
Table DSM-4. DSM alternate cost non-summer pricing periods (September 1-May 31)
Hour Sunday Monday Tuesday Wednesday Thursday Friday Saturday Holiday
1
2
3
4
5
6
7
8
I
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSMP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
NSOFP
Page 66 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Demand-Side Resource Data
Tables DSM-5 lists the 2}-year cumulative forecasted of average energy (aMW) by customer class and
total on-peak reduction potential (MW).
Table DSM-S. Gumulative existing energy efficiency forecast 2017-2036
(aMW w/transmisslon /osses and peak contibutions [MW])
Year Residentia!
Com mercial/l ndustrial/
Special Contracts lrrigation Total On Peak (MW)
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2
3
5
6
8
I
11
12
14
15
17
19
20
22
23
25
26
28
29
31
2
6
10
12
14
16
18
21
24
27
31
34
38
42
46
50
54
58
62
66
I
19
29
40
51
63
75
86
98
105
112
120
't26
133
'140
146
154
162
169
175
13
28
44
59
73
89
104
120
135
147
160
173
184
196
208
220
234
247
261
273
20
40
60
80
102
123
146
168
192
216
240
265
290
316
343
370
397
425
454
483
2017 lntegrated Resource Plan-Appendix C Page 67
Demand-Side Resource Data ldaho Power Company
Table DSM-6 details the 20-year estimated utility or program administrator costs of the achievable
potential energy efficiency forecast by customer class.
Table DSM-6. Energy Efficiency Total Utility (Program Administrator) Gosts 2017-2036 ($000s)
Year Residential
Com mercial/lndustria!/
Special Contracts Irrigation Total
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
20-Year NPV
$3,828
$5,718
$6,821
$3,907
$3,998
$3,840
$4,323
$5,690
$6,546
$8,1 83
$8,832
$9,297
$9,736
$11,500
$11,490
$11,983
$12,696
$13,278
$13,954
$14,616
$12,199
$13,638
$14,977
$15,785
$16,350
$17,482
$18,094
$18,174
$18,123
$11,837
$12,546
$12,886
$11,140
$12,028
$11,627
$12,178
$14,815
$14,982
$14,828
$12,726
$1,868
$1,916
$1,957
$1,999
$2,032
$2,087
$2,126
$2,167
$2,207
$2,251
$2,328
$2,36s
$2,395
$2,472
$2,517
$2,572
$2,627
$2,684
$2,741
$2,800
$17,896
$21,273
$23,754
$21,691
$22,380
$23,410
$24,544
$26,031
$26,877
$22,271
$23,706
$24,548
$23,272
$26,001
$25,635
$26,733
$30,1 38
$30,943
$31,523
$30,142
$78,908 $157,520 $23,828 $260,255
Page 68 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Demand-Side Resource Data
Table DSM-7 details the 20-year estimated total resource costs of the achievable potential energy
efficiency forecast by customer class.
Table DSM-7. Energy Efficiency Total Resource Gosts 2017-2036 ($000s)
Year Residentia!
Com mercial/! ndustria!/
Special Gontracts !rrigation Total
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
20-Year NPV
$8,015
$12,137
$14,548
$8,242
$8,331
$7,887
$8,731
$11,338
$12,891
$15,995
$17,132
$17,896
$18,614
$21,884
$21,758
$22,584
$23,821
$24,816
$25,990
$27,144
$23,432
$26,196
$28,767
$30,320
$31,405
$33,579
$34,754
$34,909
$34,811
$22,736
$24,098
$24,751
$21,398
$23,103
$22,333
$23,392
$28,456
$28,776
$28,482
$24,443
$6,428
$6,594
$6,733
$6,877
$6,990
$7,180
$7,316
$7,454
$7,595
$7,745
$8,008
$8,138
$8,240
$8,507
$8,661
$8,848
$9,038
$9,233
$9,431
$9,634
$37,874
$214,926
$50,048
$45,439
$46,727
$48,647
$50,801
$53,701
$55,296
$46,475
$49,238
$50,784
$48,253
$53,493
$52,753
$54,824
$61,315
$62,825
$63,903
$61,221
$155,425 $302,559 $81,981 $539,954
2017 lntegrated Resource Plan-Appendix C Page 69
Demand-Side Resource Data ldaho Power Company
Table DSM-8 shows the cost-effectiveness analysis and levelized cost of saved energy for achievable
potential energy efficiency by sector through the IRP planning period.
Table DSM-8. Total Energy Efficiency Benefits 2017-2036 ($000s)
Year Residential
Com mercial/lndustria!/
Special Contracts !rrigation Total
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
20-Year NPV
$15,350
$22,620
$25,730
$13,491
$12,535
$10,887
$10,996
$13,068
$13,625
$15,557
$15,384
$14,873
$14,345
$15,667
$14,495
$14,017
$13,760
$13,368
$13,038
$12,675
$40,747
$43,1 35
$44,722
$44,331
$43,O77
$43,208
$41,986
$39,472
$36,775
$22,459
$22,268
$21,412
$17,333
$17,508
$15,844
$15,555
$17,738
$15,940
$13,930
$10,483
$9,459
$9,265
$8,988
$8,668
$8,281
$8,001
$7,673
$7,313
$6,950
$6,613
$6,387
$6,071
$5,7s1
$5,548
$5,283
$5,057
$4,842
$4,643
$4,447
$4,260
$65,555
$75,020
$79,40
$66,490
$63,894
$62,096
$60,655
$59,853
$57,350
$44,629
$44,038
$42,356
$37,428
$38,723
$35,622
$34,629
$36,340
$33,950
$31,415
$27,418
$295,479 $567,923 $133,497 $996,900
DSM-9. Tota I energy efficiency cost-effectiveness summary
2036 Load
Reduction
(aM\rV)
Utility Costs
($000s)
(20-Year NPV)
Resource
Costs ($000s)
(20-Year NPV)
Total Benefits
($000s)
(20-Year NPV)
TRC:
BenefiU
Cost Ratio
TRC Levelized
Costs
(cents/kWh)
Residential
lndustriaUCommerciaU
Special Contract
lrrigation
Total
$78,908 $155,425 $295,47966
't76
31
273
1.9 6.7
$157,520
$23,828
$260,255
$302,5s9
$81,981
$539,964
$567,923
$133,498
$996,900
1.9
1.6
't.8
3.9
6.7
4.8
Page 70 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
Supplv-Sroe ResouRcE Dnrn
Key Financial and Forecast Assumptions
Financing Cap Structure and Cost
Composition
Debt
Preferred
Common
Total
Cost
Debt
Preferred
Common
Average Weighted Cost
100.00%
7.860/o
Financial Assumptions and Factors
50.04o/o
0.00%
49.960/o
5.73o/o
0.00%
10.00%
Plant operating (book) life
Discount rate (weighted average cost of capitall)
Composite tax rate
Deferred rate
General O&M escalation rate
Emission adder escalation rate
Annual property tax rate (% of investment)
Property tax escalation rate
Annual insurance premiums (% of investment)
lnsurance escalation rate
AFUDC rate (annual)
Expected Life of the Asset
6.74o/o
39.100/o
35.00%
2.10o/o
3.00o/o
0.29%
3.00%
O.31Yo
2.OO%
7.720/o
1 lncorporates tax effec{s.
Emission lntensity Rate (lbs per MMBtu by technology)
COz
Smallframe SCCT
Large frame SCCT
CCCT'txl
Reciprocating engines
Pulverized coal
125
118
119
119
2',to
2017 lntegrated Resource Plan-Appendix C Page71
Supply-Side Resource Data ldaho Power Company
Fuel Forecast Base Case (Nominal, $ per MMBtu)
Year Natural Gas Nuclear
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
2040
2041
2042
2043
2044
2045
2046
$2.75
$3.28
$3.28
$3.35
$3.45
$3.47
$3.53
$3.71
$3.92
$4.10
$4.26
$4.51
$4.70
$4.83
$4.91
$4.98
$4.98
$4.91
$4.70
$4.51
$4.53
$4.56
$4.59
$4.62
$4.64
$4.67
$4.70
$4.73
$4.76
$4.78
$0.57
$0.58
$0.59
$0.60
$0.61
$0.63
$0.64
$0.65
$0.67
$0.68
$0.70
$0.71
$0.73
$0.74
$0.76
$0.77
$0.79
$0.81
$0.81
$0.82
$0.82
$0.83
$0.83
$0.84
$0.84
$0.85
$0.85
$0.86
$0.87
$0.87
Page72 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
Cost lnputs and Operating Assumptions
(All costs in 2017 dollars)
Plant PlantCapital Transmission($lxw;t's Capital $/kW
Total Total
lnvestment
$/kw
Fixed
o&M
$/kw3
Variable
o&M
$/kw
Heat
Rate
Btu/kWhSupply-Side Resources
Capital
$/kw
Capacity
(Mw)
Other
$/MWh
Economic
Life
Biomass lndirect-Anaerobic Digester (35 MW
Boardman to Hemingway (250 MW
Canal Drop Hydro (1 MW
CCCT (1x1) F Class (300 MW
CCCT (2xl) F Class (550 M\ /)
cHP (35 MW
Demand Response-Additional (25 MW
Geothermal (30 MW
Reciprocating Gas Engine (18.8 MW
SCCT-Frame F Class (170 lvlvv)
Small Modular Nuclear (50 MW
Solar Pv-Rooftop C&l (1 lt W)
Solar Pv-Rooftop Residential (0.005 MW)
Solar Pv-Utility Scale 1-Axis Tracking (30 MVV)
Storage-lce Thermal Storage (10 MW
Storag+-Li Battery Residential (10 MW
Storage-Pumped-Hydro (300 MW
Storage-V Flow Battery (10l^rt)
Storage-Zn Battery (10 MW
Wnd (100 M\rV)
35
350
1
300
550
at
25
35
18
't70
50
1
0
30
10
10
300
10
10
100
6,522
0
3,753
1,246
1,150
2,2',t3
0
4,675
775
878
6,1 26
2,925
2,400
1,375
2,000
3,114
2,352
3,736
2,010
1,475
144
734
70
98
109
35
0
144
112
117
663
0
0
144
0
0
183
0
0
117
$6,666
$734
$3,823
$'1,344
$1,259
$2,248
$0
$4,819
$887
$995
$6,789
$2,925
$2,400
$1 ,519
$2,000
$3,1 14
$2,535
$3,736
$2,01 0
$1,592
$7,1 33
$734
$4,550
$1,574
$1,474
$2,406
$0
$5,342
$945
$1,060
$10,279
$s,040
$2,495
$1,579
$2,039
$3,175
$3,017
$3,809
$2,049
$1,700
3
0
2
I
1
4
51
18
,|
1
8
1
2
1
3
4
4
b
3
3
16
0
0
0
3
0
0
0
0
0
0
14,500
0
0
6,714
6,700
6,060
0
0
8,370
1 0,300
1 1,493
0
0
0
0
0
0
0
0
0
30
55
75
30
30
40
20
25
40
35
40
25
25
25
20
10
50
10
10
25
0
7
11
2
0
0
0
0
0
0
0
0
0
5
0
5
0
0
0
0
16
0
1
0
0
0
0
rPlant costs include engineering development costs, generating and ancillary equipment purchase, and installation costs, as well as balance of plant construction.
2 Total lnvestment includes capital costs and AFUDC.
3 Fixed O&M excludes property taxes and insurance (separately calculated within the levelized resource cost analysis)
2017 lntegrated Resource Plan-Appendix C Page 73
Supply-Side Resource Data ldaho Power Company
Transmission Cost Assumptions
Cost Assumptions by Supply-Side Resource Type
Capacity
(MW Rating)
Overnight
Transmission
Capital CosUkWl Cost Assumptions Notes
Local lnterconnection
Assumptions
Backbone Transmission
Assumptions
Biomass lndirect--*naerobic Digester
35 $144 Assume distribution feeder
locations in the Magic Valley;
displaces equivalent MW of
portfolio resources in same region.
Geothermal (binary-cycle)-ldaho
35 $144 Assume Raft River area location; Requires s-mile 138-kV line to
displaces equivalent MW of portfolio nearby station with new t 38-kV
resour@s in same region. substation line terminal bay.
Hydro--Canal Drop (Seasonal)
1 $70 Assume Magic Valley location Assume 4 miles of distribution
connecling to 46-kV sub- rebuild at $ 1 50 thousand per mile
transmission or local feeder. plus $1 00 thousand in
substation upgrades.
Natural GaS-SCCT Frame F Class (ldaho Power's peaker plants use this technology)
170 $1 17 Assume Mountain Home location; Assume 2 mi of 230 kV line
displaces equivalent lvlw of required to connect to
portfolio resources in same region. nearby station.
Natural Gas-Reciprocating Gas Engine Wartsila 34SG
18 $112 Assume Mountain Home location; lnterconnecting at RTSN
displacesequivalentlvlwof 230-kVstation.
portfolio resources in same region.
Natural GaS-CCCT (1x1) F Class with Duct Firing
300 $98 Assume Mountain Home location; Assume 2 miles of 230-kV line
displaces equivalent MW of required to connect to
portfolio resources in same region. nearby station.
Natural Gas-CCCT (2xl) F Class
550 $109
Assume $3.5 million of distribution
feeder upgrades and $1.167
million in substation upgrades.
Assigns Pro-Rata share for
transmission upgrades identified
for east-of-Boise resources.
Natural Gas--Combined Heat and Power (CHP)
35 $35
Build new facility south of Boise
(assume Simco Road area).
Assumed location in
Treasure Valley.
New 230-kV switching station with
a22-mile;230-kV line to Boise
Bench Substation and wrap
230-kV DNPR-HRBD line into
new station.
Assigns Pro-Rata share for
transmission upgrades identifi ed
for east-of-Boase resources.
No backbone upgrades required
Assigns Pro-Rata share for
transmission upgrades identified
for east-of-Boise resources.
Assigns Pro-Rata share for
transmission upgrades identified
for easlof-Boise resources.
Assigns Pro-Rata share for
transmission upgrades identifi ed
for east-of-Boise resources.
Rebuild RTSN-DRAM 230 kV line,
BOBN-DRAM 230 kV line,
MCRN-BOBN 138 kV line,
and replace BOMT-SWPO
wave trap.
Nuclear-Small Modular Reactor (SMR)
50 $663 Assume tie into ANTS 230-kV
transmission substation;
displaces equivalent lvw of
portfolio resources east of Boise.
Assume 1 mile tap to existing
1 38-kV line and new 1 38-kV
source substation.
Two 2-mile, 138-kV lines to
interconnect to Antelope
Substation. New 138-kV terminal
atANTS.
No backbone upgrades required.
New parallel 55-mile, 230-kV line
from Antelope to Brady
Substation. New 230-kV terminal
at Brady Substation.
Assigns Pro-Rata share for
transmission upgrades identifi ed
for east-of-Boise resour@s.
Pumped Storage-new upper reservoir and generation/pumping plant, pump water from existing lower reservoir to new upper reservoir and run water through
new power plant)
300 $1 83 Assume Anderson Ranch 1 I mi 230-kV line to connect Assigns Pro-Rata share for
location; displaces equivalent MW to RTSN. transmission upgrades identified
ofportfolio resources in same foreast-of-Boise resources.
region.
Page74 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
Capacity
(MW Rating)
Overnight
Transmission
Capital CosUkW Cost Assumptions Notes
Local lnterconnection
Assumptions
Backbone Transmission
Assumptions
Solar Pv-Utility Scale 1-Axis Tracking
30 $144
Wnd-ldaho
100 $1 17
Assume Magic Valley location;
displaces equivalent lvIW of
portfolio resources in same region.
Assume 1 mile 230 kV line and
associated stations equipment.
Assigns Pro-Rata share for
transmission upgrades identified
for east-of-Boise resou rces.
Assigns Pro-Rata share for
transmission upgrades identified
for east-of-Boise resources.
Assume location within 5 miles of
Midpoint Substation; displaces
equivalent MW of portfolio
resources in same region.
Assume 5 mi of 230-kV
transmission from MPSN to
project site.
2017 lntegrated Resource Plan-Appendix C Page 75
Supply-Side Resource Data ldaho Power Company
Levelized Cost of Energy
3o-Year Levelized Cost of Energy (at stated capacity factors)
Cost of
Net of Tax
CrediUsteam
sales/lntegration,
Transmission
Revenue
Capacity
Factor
Total
Cost per
MWhSupplyside Resources Capital
Non-Fuel
o&Ml
WholesaleFuel Energy
Biomass lndirect-Anaerobic Digester (35 MW
Boardman to Hemingway (250 MW
Canal Drop Hydro (1 MW
CCCT (1x1) F Class (300 MW)
CCCT (2x1) F Class (550 MW)
cHP (35 MW
Demand Response-Additional (25 MW
Geothermal (30 lvw
Reciprocating Gas Engine (18.8 MW)
SCCT-Frame F Class (170 tvIVV)
Small Modular Nuclear (50 lvIW)
Solar Pv-Rooftop C&l (1 MW
Solar Pv-Rooftop Residential (0.005 MW
Solar Pv-Utility Scale 1-Axis Tracking (30 MW)
Storage-lce Thermal Storage (10 MW
Storage-Li Battery Residential (10 MW
Storage-Pumped-Hydro (300 MW
Storage-V Flow Battery (10 [A /)
Storage-Zn Battery (10 MW
Wind (100 MW
$98
$18
$140
$26
$25
$33
$o
$64
$41
$118
$124
$1 53
$126
$62
$595
$400
$1 58
$1,679
$51 6
$64
$35
$3
$25
$6
$7
$20
$706
$47
$18
$36
$31
$2s
$26
$12
$1 47
$60
$57
$317
$92
$24
$0
-$9
$0
$0
$0
-$6
$0
$0
$0
$0
$0
$1
$1
$1
$0
$0
$o
$0
$o
$22
$1 33
$39
$1 65
$s9
$5s
$71
$706
$11 1
$94
$1 97
$163
$179
$1 53
$74
$742
$460
$214
$1,996
$608
$11 1
85o/o
33%
33%
70%
70o/o
80o/o
1o/o
88o/o
25o/o
10o/o
9Oo/o
21o/o
21%
27o/o
4o/o
14o/o
20o/o
4%
7o/o
28o/o
$o
$0
$0
$28
$28
$25
$0
$0
$35
$43
$8
$0
$0
$0
$0
$0
$0
$0
$0
$0
$0
$28
$0
$o
$0
$0
$0
$o
$0
$0
$o
$0
$0
$0
$0
$0
$0
$0
$0
$0
1 Non Fuel O&M includes flxed and variable costs, property taxes.
Supply-Side Resources
3o-Year Levelized Capacity (fixed) Cost per kWMonth
Costof Non-FuelCapital O&M
Net of Tax Crediusteam
sales/lntegration/
Fuel Transmission Revenue Total Cost per kW
Biomass lndirect-Anaerobic Digester (35 MW
Boardman to Hemingway (250 MW)
Canal Drop Hydro (1 MW
CCCT (1x1) F Class (300 MW)
CCCT (2x1) F Class (550 MW
cHP (35 MW
Demand Response--Additional (25 M\ /)
Geothermal (30 iArU)
Reciprocating Gas Engine (18.8 MW)
SCCT-Frame F Class (170 MW
Small Modular Nuclear (50 lvTW
Solar Pv-Rooftop C&l (1 lvlw
Solar Pv-Rooftop Residential (0.005 MW)
Solar Pv-Utility Scale 1-Axis Tracking (30 telvu
Storage-lce Thermal Storage (10 MW)
Storage-Li Battery Residential (10 M\tO
Storage-Pumped-Hydro (300 MW)
Storage-V Flow Battery (10 MW
Storage-Zn Battery (10 MW)
Wnd (100 M\rV)
$61
$5
$34
$13
$13
$19
$0
$41
$7
$9
$81
$24
$19
$12
$17
$41
$23
$49
$26
$13
$9
$1
$6
$3
$2
$7
$5
$26
$2
$2
$18
$4
$4
$2
$4
$6
$8
$9
$5
$5
$0
$0
$0
$o
$0
$0
$o
$0
$0
$0
$0
$0
$0
$0
$o
$o
$0
$o
$0
$0
$0
-$2
$o
$o
$o
$0
$0
$0
$0
$0
$o
$0
$o
$0
$0
$o
$o
$0
$0
$o
$70
$4
$40
$16
$14
$26
$5
$67
$9
$10
$1 00
$27
$23
$14
$22
$47
$31
$58
$31
$18
Page 76 2017 lnlegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
Peak-Hour Gapacity Credit (Contribution to Peak)
Solar and Wind Resources
Peak hour capacity credit (contribution to peak) for new IRP intermittent generation resources
New IRP intermittent generation-Peak hour capacity credit
Resource Peak Hour Capacity Credit
PV solar south orientation
PV solar southwest orientation
PV solar single-axis tracking
Wind
28.4o/o
45.4o/o
51 .3o/o
5.0o/o
Energy Shape-Solar
2017 IRPASS umed Solar Capacity Factors
Total nameplate: 298.3 ttIW
Total annual capacity lador:27o/o
Hour Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
12:00 AM
1:00 AM
2:00 AM
3:00 AM
4:00 AM
5:00AM
6:00 AM
7:00 AM
8:00 AM
9:00 AM
'10:00 AM
11:00 AM
12:00 PM
1:00 PM
2:00 PM
3:00 PM
4:00 PM
5:00 PM
6:00 PM
7:00 PM
8:00 PM
9:00 PM
10:00 PM
11:00 PM
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.6
29.6
90.7
143.8
151.7
148.3
149.0
146.5
153.6
146.3
93.2
't 6.1
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.4
16.2
47.9
108.'l
'173.4
197.9
199.3
'196.4
199.9
1 93.1
190.2
158.0
108.3
49.5
2.3
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.1
16.6
66.4
142.9
197.6
219.0
228.1
225.6
228.6
230.1
210.6
199.3
180.4
107.2
30.5
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
8.4
47.7
126.5
203.1
228.2
240.8
243.9
249.1
239.4
242.6
222.8
214.9
189.3
147.1
69.8
2.6
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
15.9
69.8
154.3
229.6
259.5
262.4
272.8
267.5
263.5
254.4
2U.5
213.8
196.6
157.8
96.8
17.9
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
9.7
57.7
138.3
225.O
252.5
26s.0
260.3
258.1
266.2
264.8
242.9
246.2
221.7
177.8
10t.6
14.4
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.4
32.9
104.9
194.1
253.0
258.0
263.8
256.0
250.9
249.4
250.2
243.5
222.9
145.7
53.7
1.3
0.0
0.0
0.0
0.0
8.7
57.7
144.8
226.2
236.4
235.3
232.5
232.1
226.1
225.0
220.7
178.6
73.3
3.1
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.3
25.0
84.5
163.0
196.7
196.9
't92.2
184.1
't87.5
't78.4
162.2
82.2
6.3
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
2.4
29.6
65.5
109.9
130.3
129.9
120.1
117.0
111.4
a1.7
28.1
9.3
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
6.5
34.9
73.0
87.1
84.0
92.4
94.0
93.0
88.2
35.4
o.4
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
7.3
37.2
79.5
91.4
88.5
89.4
96.6
87.4
62.0
2.7
0.0
0.0
0.0
0.0
0.0
0.0
0.0
2017 lntegrated Resource Plan-Appendix C Page77
Supply-Side Resource Data ldaho Power Company
Jan Feb iiar Apr May Jun Jul Aug Sep Oct Nov Dec
Average
MWh per Day
Days in Month
MWh per Month
MWh for year
Average
28.7
688.9
31
21,355
702,875
28.7
52.9
1269.3
28
35,541
76.7
1841 .0
31
57,070
95.1
2282.9
30
68,488
111.7
2680.3
31
83,088
't23.6
2967.1
30
89,013
125.9
3022.4
31
93,695
't15.9
2781.0
31
86,211
95.9
2300.6
30
69,019
69.1
1659.3
31
51,438
39.0
935.2
30
28,O57
26.7
641.9
31
19,898
52.9 76.7 95.1 111.7 123.6 125.9 115.9 95.9 69.1 39.0 26.7
ldaho Schedule 87/Oregon Schedule 8S-lntegration Costs for
Solar and Wind Resources
SoIar
O-100 MW Solar Capacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates*
Non Levelized
OnJine Year
2016
2017
2018
2019
2020
2021
0.04
0.04
0.04
0.05
0.05
0.05
Gontract year Non-Levelized Rates*
0.04
0.04
0.04
0.04
0.04
0.04
0.04
0.04
0.04
0.04
0.04
0.05
0.05
0.05
0.05
0.05
0.05
0.05
0.05
0.05
0.06
0.06
0.06
0.06
0.06
0.06
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
2040
2041
'$/[,TWh
Page 78 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
101-200 MW Solar Capacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates*
Non Levelized
OnJine Year
2016
2017
2018
2019
2020
2021
0.19
0.20
o.20
0.21
0.21
0.22
0.16
0.17
0.17
0.18
0.18
0.18
0.19
0.19
0.20
0.20
0.20
0.21
0.2'l
0.22
0.22
0.23
0.23
0.24
o.24
o.25
o.25
0.26
0.27
0.27
o.28
o.28
Contract year
2016
20't7
20't8
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
2040
2041
Non-Levelized Rates
'$/iin rh
2017 lntegrated Resource Plan-Appendix C Page 79
Supply-Side Resource Data ldaho Power Company
201-300 MW Solar Gapacity Penetration Level
Levelized
2O-Year Contract Term
Levelized Rates*
0.41
o.42
0.43
o.44
0.44
0.45
Non Levelized
Online Year
2016
20't7
2018
2019
2020
2021
Contract year
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
2040
2041
Non-Levelized Rates
0.34
0.35
0.36
0.37
0.38
0.38
0.39
0.40
0.41
0.42
0.43
0.44
0.45
0.46
0.47
0.48
0.49
0.50
0.51
0.52
0.53
0.54
0.56
0.57
0.58
0.59
-$/l\Jl\ /h
Page 80 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
301-400 MW Solar Capacity Penetration Level
Levelized
Z0-Year Contract Term
Levelized Rates*
0.64
0.65
0.67
0.68
0.70
o.71
Non Levelized
OnJine Year Contract year
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
2040
2041
Non-Levelized Rates
2016
20't7
2018
2019
2020
2021
0.54
0.55
0.56
0.57
0.59
0.60
0.61
0.63
0.64
0.66
0.67
0.68
0.70
o.71
0.73
o.75
0.76
0.78
0.80
0.81
0.83
0.85
0.87
0.89
0.91
0.93
'$/MWh
2017 lntegrated Resource Plan-Appendix C Page 81
Supply-Side Resource Data ldaho Power Company
401-500 MW Solar Capacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates*
Non Levelized
Online Year
2016
2017
2018
2019
2020
2021
0.84
0.86
0.88
0.90
0.92
0.94
0.71
0.73
0.75
0.76
0.78
0.80
0.81
0.83
0.85
0.87
0.89
0.91
0.93
0.95
0.97
0.99
1.01
1.03
1.06
1.08
1.10
1.',t3
1.15
1.18
1.20
1.23
Contract year
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
2040
2041
Non-Levelized Rates
'$/MWh
Page 82 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
501-600 MW Solar Capacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates"
Non Levelized
OnJine Year Contract year
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
2040
2041
Non-Levelized Rates
0.86
0.87
0.89
0.91
0.93
0.95
0.97
1.00
1.02
1.04
1.06
1.09
1.11
1.13
1.'16
1.19
1.21
1.24
1.26
1.29
1.32
1.35
1.38
1.41
1.44
1.47
2016
2017
2018
2019
2020
2021
1.01
1.03
1.06
1.08
1.10
1.13
,$/MWh
2017 lntegrated Resource Plan-Appendix C Page 83
Supply-Side Resource Data ldaho Power Company
601-700 MW Solar Capacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates*
Non Levelized
On-!ine Year Contract year
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
2040
2041
Non-Levelized Rates
0.95
o.97
0.99
1.01
1.03
1.06
1.08
1.10
1.13
1.15
1.18
1.20
1.23
1.26
1.29
1.31
1.34
1.37
1.40
1.43
1.46
1.50
1.53
1.56
1.60
1.63
2016
2017
2018
2019
2020
2021
1.12
1.15
1.17
1.20
1.22
1.25
-$/MWh
Page 84 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
701-800 MW Solar Capacity Penetration Level**
Levelized
20-Year Gontract Term
Levelized Rates*
Non Levelized
OnJine Year Contract year
2016
2017
20'18
2019
2020
202',1
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
203/.
2035
2036
2037
2038
2039
2040
2041
Non-Levelized Rates
0.99
1.01
1.03
1.06
1.08
1.10
1.13
1.15
1.18
1.20
1.23
1.26
1.28
1.31
1.U
1.37
1.40
't.43
1.46
1.49
1.53
1.56
1.60
1.63
1.67
1.70
2016
20't7
2018
2019
2020
2021
1.17
1.20
1.22
1.25
1.28
1.30
-$/II/TWh
2017 lntegrated Resource Plan-Appendix C Page 85
Supply-Side Resource Data ldaho Power Company
801-900 MW Solar Capacity Penetration Level"*
Levelized
20-Year Contract Term
Levelized Rates*
Non Levelized
OnJine Year Contract year
2016
2017
20't8
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
2040
2041
Non-Levelized Rates
20'16
2017
20't8
2019
2020
2021
1.16
1.19
1.21
1.24
1.27
1.30
0.98
1.00
1.03
1.05
1.O7
1.09
1.12
1.14
1.17
1.19
1.22
1.25
1.28
1.30
1.33
1.36
1.39
1.42
1.45
1.48
1.52
1.55
1.59
1.62
1.66
1.69
-$/tvlwh
Page 86 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
901-1,000 MW Solar Capacity Penetration Level"*
Levelized
20-Year Contract Term
Levelized Rates*
Non Levelized
On-line Year Contract year Non-Levelized Rates
0.94
0.96
0.99
1.01
1.03
1.05
1.08
1.10
1.12
1.15
1.17
1.20
1.23
1.25
't.28
1.31
1.34
't.37
1.40
1.43
'1.46
1.49
1.52
1.56
1.59
1.63
2016
2017
2018
2019
2020
2021
1.12
1.',!4
1.17
1.19
1.22
1.25
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
2040
2041
-$/lvl\ /h
2017 lntegrated Resource Plan-Appendix C Page 87
Supply-Side Resource Data ldaho Power Company
1,001-1,100 MW Solar Capacity Penetration Level**
Levelized Non Levelized
On{ine Year
20-Year Contract Term
Levelized Rates*Non-Levelized RatesContract year
2016
2017
2018
2019
2020
2021.
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
203/,
2035
2036
2037
2038
2039
2040
2041
2016
2017
2018
2019
2020
2021
1.06
1.08
1.11
1.13
1.16
1.18
0.90
0.92
0.94
0.96
0.98
1.00
1.02
1.04
1.07
1.09
1.11
1.14
1.16
1.19
1.22
't.24
't.27
1.30
1.33
1.36
1.39
1.42
1.45
1.48
1.51
1.54
-$/[,lVVh
Page 88 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
1,1 01 -1,200 MW Solar Capacity Penetration Level*'
Levelized Non Levelized
On-line Year
2016
2017
2018
2019
2020
2021
2O-Year Contract Term
Levelized Rates*Contract year
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
2040
2041
Non-Levelized Rates
0.87
0.89
0.91
0.93
0.95
0.97
0.99
1.01
1.04
1.06
1.08
't.11
1.13
1.16
1.18
1.2',1
1.23
1.26
1.29
1.32
1.35
1.37
1.41
1.44
1.47
1.50
1.03
1.05
1.08
1.10
1.12
1.15
.$/MWh
2017 lntegrated Resource Plan-Appendix C Page 89
Supply-Side Resource Data ldaho Power Company
1,201-1,300 MW Solar Capacity Penetration Level"*
Levelized Non Levelized
On-tine Year
20-Year Contract Term
Levelized Rates*Contract year
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
2040
204',|
Non-Levelized Rates
2016
2017
2018
20't9
2020
2021
1.07
1.09
1.12
1.14
1.17
1.19
0.90
o.92
0.94
0.97
0.99
1.O1
1.03
1.05
1.08
1.10
1.12
1.15
1.17
1.20
1.23
1.25
1.28
1.31
1.34
1.37
1.40
1.43
1.46
1.49
't.52
1.56
"$/[/twh
Page 90 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
1,301-1,400 MW Solar Capacity Penetration Level**
Levelized Non Levelized
Online Year
2016
2017
2018
20't9
2020
2021
20-Year Contract Term
Levelized Rates"Non-Levelized RatesContract year
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
2040
2041
1.24
1.27
1.30
1.33
1.36
1.39
1.05
1.07
1.10
1.12
1.15
1.17
1.20
1.22
1.25
1.28
1.31
1.33
1.36
1.39
1.42
1.46
1.49
1.52
1.55
'1.59
1.62
1.66
1.70
1.73
1.77
1.81
-$/[a /h
2017 lntegrated Resource Plan-Appendix C Page 91
Supply-Side Resource Data ldaho Power Company
1,401-1,500 MW Solar Capacity Penetration Level**
Levelized Non Levelized
OnJine Year
2016
2017
2018
2019
2020
202'.1
20-Year Contract Term
Levelized Rates*Non-Levelized Rates
1.36
1.39
1.42
1.46
1.49
1.52
1.55
1.59
1.62
1.66
1.70
1.73
1_77
1.81
1.85
1.89
1.93
1.97
2.02
2.06
2.1',l
2.15
2.20
2.25
2.30
2.35
Contract year
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
20/,O
204',|
1.61
1.65
1.69
1.72
't.76
1.80
'$/lrvvh
Page 92 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
1,501-1,600 MW Solar Capacity Penetration Level""
Levelized Non Levelized
On-line Year
20-Year Contract Term
Levelized Rates"
2.26
2.31
2.36
2.41
2.47
2.52
Contract year Non-Levelized Rates
1.91
1.95
2.00
2.O4
2.09
2.13
2.18
2.23
2.28
2.33
2.38
2.43
2.48
2.54
2.59
2.65
2.71
2.77
2.83
2.89
2.95
3.O2
3.09
3.15
3.22
3.29
2016
2017
2018
2019
2020
2021
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
203',1
2032
2033
2034
2035
2036
2037
2038
2039
2040
2041
-$/wlWh
2017 lntegrated Resource Plan-Appendix C Page 93
Supply-Side Resource Data ldaho Power Company
Wind
0-100 MWWind Gapacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates*
Non Levelized
OnJine Year
2014
2015
20't6
2017
201 8
20't9
0.27
o.27
o.28
0.29
0.30
0.31
Contract year Non-Levelized Rates
0.21
o.22
o.23
0.23
0.24
o.25
0.25
o.26
0.27
0.28
0.29
o.29
0.30
0.31
o.32
0.33
0.34
0.35
0.36
0.37
0.38
0.40
o.41
o.42
0.43
0.45
20't4
2015
2016
2017
2018
20't9
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
-$/MWh
Page 94 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
101-200 MW Wind Capacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates*
Non Levelized
OnJine Year Contract year
2014
2015
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
Non-Levelized Rates
0.98
1.00
1.04
1.07
1.10
1.13
1.16
1.20
1.24
1.27
1.31
1.35
1.39
1.43
1.48
1.52
1.57
1.61
1.66
1.71
1.76
1.81
1.87
1.93
1.98
2.04
2014
2015
2016
2017
2018
2019
1.22
1.25
1.29
1.33
't.37
1.41
-$/MWh
2017 lntegrated Resource Plan-Appendix C Page 95
Supply-Side Resource Data ldaho Power Company
201-300 MW Wind Gapacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates*
2.78
2.87
2.95
3.04
3.13
3.23
Non Levelized
On-line Year Contract year
2014
2015
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
203',!
2032
2033
2034
2035
2036
2037
2038
2039
Non-Levelized Rates
2.23
2.30
2.37
2.4
2.51
2.59
2.67
2.75
2.83
2.92
3.00
3.09
3.19
3.28
3.38
3.48
3.59
3.69
3.80
3.92
4.04
4.16
4.28
4.41
4.54
4.68
2014
2015
2016
2017
2018
2019
-$/tlVVh
Page 96 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
301-400 MW Wind Capacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates*
4.95
5.'10
5.26
5.41
5.58
5.74
Non Levelized
OnJine Year Contract year
2014
2015
20't6
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
Non-Levelized Rates
3.98
4.10
4.22
4.35
4.48
4.61
4.75
4.89
5.04
5.19
5.34
5.51
5.67
5.84
6.02
6.20
6.38
6.57
6.77
6.97
7.18
7.40
7.62
7.85
8.08
8.33
2014
2015
2016
2017
2018
2019
*$/M\ruh
2017 lntegrated Resource Plan-Appendix C Page 97
Supply-Side Resource Data ldaho Power Company
401-500 MW Wind Capacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates"
7.71
7.95
8.18
8.43
8.68
8.94
Non Levelized
Online Year
2014
2015
2016
2017
20't8
2019
Contract year
2014
2015
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
Non-Levelized Rates
6.19
6.38
6.57
6.77
6.97
7.18
7.39
7.62
7.84
8.08
8.32
8.57
8.83
9.09
9.37
9.65
9.94
10.23
10.54
10.86
11.18
1',t.52
11.86
12.22
12.59
12.96
-$/MWh
Page 98 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
501{00 MW Wind Capacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates*
Non Levelized
Online Year
2014
2015
2016
2017
2018
2019
11.05
11.38
11.72
12.07
12.43
12.81
Contract year
2014
2015
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
203/'
2035
2036
2037
2038
2039
Non-Levelized Rates
8.87
9.13
9.41
9.69
9.98
10.28
10.59
10.91
11.23
11.57
't1.92
12.28
12.64
't3.02
13.41
13.82
14.23
14.66
15.'t 0
15.55
16.02
16.50
16.99
17.50
18.03
18.57
.$/MWh
2017 lntegrated Resource Plan-Appendix C Page 99
Supply-Side Resource Data ldaho Power Company
601-700 MW Wind Capacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates*
Non Levelized
OnJine Year Contract year Non-Levelized Rates
2014
2015
2016
2017
2018
2019
14.94
15.39
15.85
16.33
16.82
17.32
2014
2015
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
11.99
12.35
12.72
13.'10
13.50
13.90
14.32
14.75
15.19
15.65
16.12
16.60
17.10
17.61
18.14
18.68
19.24
19.82
20.42
21.O3
21.66
22.31
22.98
23.67
24.38
25.11
'$/MWh
Page 100 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
701-800 MW Wind Capacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates*
Non Levelized
OnJine Year
2014
2015
2016
2017
2018
2019
19.38
19.96
20.56
21.17
21.81
22.46
Gontract year
2014
2015
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
Non-Levelized Rates
15.55
16.O2
16.50
17.00
17.51
18.03
18.57
19.13
19.70
20.29
20.90
21.53
22.18
22.84
23.53
24.23
24.96
25.71
26.48
27.27
28.09
28.93
29.80
30.70
31.62
32.57
"$/l\a /h
2017 lntegrated Resource Plan-Appendix C Page 101
Supply-Side Resource Data ldaho Power Company
801-900 MW Wind Capacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates*
24.34
25.07
25.83
26.60
27.40
28.22
Non Levelized
OnJine Year Conkact year
2014
2015
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
Non-Levelized Rates
19.54
20.13
20.73
2',t.35
z',t.99
22.65
23.33
24.03
24.75
25.50
26.26
27.05
27.86
28.70
29.56
30.44
31.36
32.30
33.27
u.26
35.29
36.35
37.44
38.56
39.72
40.91
2014
20't5
2016
2017
2018
2019
.$/Ntwh
Page 102 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
901-1,000 MWWind Capacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates*
29.82
30.72
31.64
32.59
33.57
34.57
Non Levelized
OnJine Year Contract year
2014
20't5
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
Non-Levelized Rates
23.94
24.66
25.40
26.16
26.94
27.75
28.59
29.44
30.33
31.24
32.17
33.14
u.13
35.16
36.21
37.30
38.42
39.57
40.76
41.98
43.24
44.54
45.87
47.25
48.66
50.12
2014
2015
2016
2017
2018
2019
'$/tvtwh
2017 lntegrated Resource Plan-Appendix C Page 103
Supply-Side Resource Data ldaho Power Company
1,001-1,100 MW Wind Capacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates"
35.81
36.88
37.99
39.13
40.30
41.51
Non Levelized
OnJine Year Contract year
2014
2015
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
Non-Levelized Rates
28.74
29.60
30.49
31.41
32.35
33.32
34.32
35.35
36.41
37.50
38.63
39.78
40.98
42.21
43.47
44.78
46.12
47.5',1
48.93
50.40
51.91
53.47
55.07
56.72
58.43
60.18
2014
2015
2016
2017
2018
2019
'$/lr\ruh
Page 104 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
1,101-1,200 MW Wind Capacity Penetration Level
Levelized
20-Year Contract Term
Levelized Rates*
42.27
43.54
44.85
46.19
47.58
49.01
Non Levelized
OnJine Year Contract year
2014
2015
2016
20't7
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
203/.
2035
2036
2037
2038
2039
Non-Levelized Rates
33.93
34.95
36.00
37.08
38.1 I
39.34
40.52
41.73
42.98
44.27
45.60
46.97
48.38
49.83
51.33
52.87
il.45
56.09
57.77
59.50
61.29
63.12
65.02
66.97
68.98
71.05
2014
2015
2016
2017
2018
2019
*$/tvlwh
2017 lntegrated Resource Plan-Appendix C Page 105
Supply-Side Resource Data ldaho Power Company
PURPA Reference Data
The following information is provided for PURPA reference purposes.
1. Preferred portfolio: Portfolio P7
Resource Portfolio P7
Date Resource lnstalled Capacity Peak-Hour Capacity (MW)
2026 B2H 500,200" 500
2031 Reciprocating engines 36 36
2032 Reciprocating engines 36 36
2033 Combined-cycle combustion turbine (1xl) 300 300
2035 Reciprocating engines 54 54
2036 Reciprocating engines 54 54
Total 980 980
*April-Sep, Oct-Mar transfer capacity
2. Deficiency period under preferred portfolio
1't capacity deficit : (34) MW July 2026
l't energy deficit: (143) MW July 2029
3. Intermittent generation integration costs
See integration cost schedule included inAppendix C-Technical Appendix, section ldaho
Schedule 87/Oregon Schedule 81-Integration Costsfor Solar and Wind Resources.
Page 106 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Supply-Side Resource Data
Renewable Energy Certificate Forecast
Year Nominal ($/MWh)
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
4.59
4.86
4.91
5.23
5.55
5.92
6.29
6.67
7.O5
7.46
7.85
8.25
8.67
9.08
9.51
9.95
10.40
10.85
11.32
11.79
2017 lntegrated Resource Plan-Appendix C Page 107
Fuel Price Forecast ldaho Power Company
Fuel Pnrce FonecAST
Natura! Gas, Coal, and Nuclear Price Forecast (nominal $/MMBtu)
Year
!daho Citygate
Natural Gas Generic Coal Nuclear
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
$2.75
$3.28
$3.28
$3.35
$3.45
$3.47
$3.53
$3.71
$3.92
$4.10
$4.26
$4.51
$4.70
$4.83
$4.91
$4.98
$4.98
$4.91
$4.70
$4.51
$2.46
$2.55
$2.64
$2.74
$2.85
$2.94
$3.04
$3.14
$3.25
$3.34
$3.46
$3.57
$3.67
$3.79
$3.90
$4.02
$4.13
$4.27
$4.39
$4.51
$0.57
$0.58
$0.59
$0.60
$0.61
$0.63
$0.64
$0.65
$0.67
$0.68
$0.70
$0.71
$0.73
$0.74
$0.76
$0.77
$0.79
$0.81
$0.82
$0.84
2017lRP Fuel Price Forecast
$0.00
$5.00
$4.00
E
.E
Eoz $3.00l
=
$2.00
$1 .00
$0.00 20't7 2018 20't9 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036
-
Natlralcas
-Generic
coal
-Nuclear
Page 108 2017 lnlegrated Resource Plan-Appendix C
ldaho Power Company Fuel Price Forecast
$15
$14
$13
$12
$11
$10
=Fg$s
=a$s
$7
$6
$5
$4
$3
$2
$1
$0
EIA Henry Hub Spot Price Forecasts (Nominal Dollars)
-/;I
-f
Fg
-2,-2
-,4.
-2O1O
EIA Forecast
-2011
EIA Forecast
-2012
EIA Forecast (2013 IRP)*2013 EIA Forecast
-2014
EtA Forecast (2015 tRP)
-2015
EIA Forecast
-2016
EIA Forecast (2017 IRP)
2017 201A 2019 2020 2021 2022 2023 2024 2025 2026 2027 202A 2029 2030 2031 2032 2033 203/. 2035 2036
2017 lntegrated Resource Plan-Appendix C Page 109
Existing Resource Data ldaho Power Company
ExIsnruG RESoURcE Dere
Hydroelectric and Thermal Plant Data
Hydroelectric Power Plans
Nameplate
kvA kw Normal Rating klltF Emergency Rating kWs
American Falls
Bliss
Brownlee
Cascade
C.J. Strike
Clear Lake
Hells Canyon
Lower Salmon
Malad-Lower
Malad-Upper
Milner
Oxbow
Shoshone Falls
Swan Falls
Thousand Springs
Twin Falls
Upper Salmon ?"
Upper Salmon "B"
102,600
86,250
650,444
13,800
90,000
3,125
435,000
70,000
15,500
9,650
62,890
211,112
14,900
28,600
11,000
56,1 75
18,000
18,000
92,340
75,038
585,400
't2,420
82,800
2,5001
391,500
60,000
13,500
8,270
59,448
190,000
12,5001
27,',t70
8,8001
52,897
18,000
16,500
92,340
75,000
585,400
12,420
82,800
2,420
391,500
60,000
13,500
8,270
59,448
190,000
12,s00
24,1703
6,3802
52,561
18,000
'16,500
1 06,'t 90
84,860
678,040
14,280
95,420
2,430
2149,580
69,140
13,500
8,400
61,880
2',t8,520
12,500
24,170
6,380
54,170
18,000
16,560
Total Hydro 1,897,046 1,709,083
1 A power factor rating of 0.8 is assumed on four units (Clear Lake, Shoshone Falls unit 2, and Thousand Springs units 1 and 2) with a total kVA rating of
6,125 kVA on which the nameplate rating is assumed.
2 The two smaller units, 1 and 2, have nameplate ratings of 1.25 MVA and 1 MW have been taken out of service due to reduced flows from the springs and
penstock integrity.
3 The Swan Falls units have been limited to 24,170 kW as a result of vibration issues.
a Normal Rating is the normal kW output of the facility with all units on-line. This rating includes all equipment limitations and may be different than the nameplate
rating. To operate at the Normal Rating, approprlate water and ambient conditions must exist and the FERC license requirements permit.
s The Emergency Rating is defined as the maximum kW output of the facility with all units on-line. The Emergency Rating is based on manufacturer guidelines,
ANSI standards, and limited by auxiliary equipment ratings. To operate at the Emergency Rating, appropriate water conditions must exist and the FERC license
requirements permit.
6 The Shoshone Falls Unit #2 is out of service due to an exciter conditlon.
Page 110 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Thermal, Natural Gas, and Diesel Power Plans
Generator Nameplate Rating
Gross kVA Gross kW
Net Dependable Capability (NDC)6'7
kW Summer kW Winter kW
Bridger (ldaho Power share)
Boardman (ldaho Power share)
Valmy (ldaho Power share)
Total Thermal
Bennett Mountain
Evander Andrews Unit #1
Evander Andrews Unit #2
Evander Andrews Unit #3
Langley Gulch CT
Langley Gulch ST
Total Natural Gas
Salmon Diesel
Total IPC Generation
8't1,053
67,600
315,000
770,500
64,199
283,500
707,667
57,550
260,000
707,667
58,050
260,000
1,193,653
192,000
199,000
51,000
51,000
220,000
154,650
1,118,199
172,800
1 79,1 00
45,900
45,900
187,000
131,452
164,'t59
170,955
45,405
45,066
176,880
122,765
867,650
6,250
762,152
5,000 5,500
3,964,599 3,594,434
I Ratings for coal-fired generators are provided by ldaho Poweas thermal partners who operate these plants.
2 Net Dependable Capacity (NDC) is defined in the NERC Generating Availability Data System (GADS) as Gross Dependable Capacity (GDC) less the unit capacity
utilized for that unit's station service or auxiliaries. GDC is the Gross Maximum Capacity (GMC) modified for seasonal limitations over a specified period. The GDC
and Maximum Dependable Capacity (MDC) used in previous GADS reports are the same in intent and purpose. GMC is the maximum capacity a unit can sustain
over a specified period when not restricted by seasonal or other de-ratings.
3 Evander Andrews Power Plant is also known to ldaho Power as Danskin Power Plant (DNPR).
a Performance test numbers provided by the contractor corrected for the following rating conditions: 90.0 Deg. F, Relative Humidity 20%, Barometric pressure
13.378 psia, Duct Bumers ON. Performance numbers were obtained from the Siemens report EC-12087, Thermal performance test results of SGT6-5000F GAs
turbine in fuel gas at Langley Gulch, New Plymouth, lD for IPC (Unit # 1-Shop Order Number GT378521)
2017 lntegrated Resource Plan-Appendix C Page 111
Existing Resource Data ldaho Power Company
Qualifying Facility Data (PURPA)
Cogeneration and Smal! Power Productaon Projects
Status as of April 1, 2017 .
Project MW
Hydro Projects
Arena Drop 0.45 Sep-2010
Baker City Hydro 0.24 Sep-2015
Barber Dam 3.70 Apr-1989
Birch Creek 0.05 Nov-'1984
Black Canyon #3 0.14 Apr-'1984
Black Canyon Bliss Hydro 0.03 Nov-2014
Blind Canyon 1.63 Dec-20'14
Box Canyon 0.36 Feb-1984
Briggs Creek 0.60 Oct-1985
Bypass 9.96 Jun-1988
Canyon Springs 0.13 Oct-1984
Cedar Draw 'l .55 Jun-1984
Clark Canyon Hydroelectric 7.55 Jun-2017
Clear Springs Trout 0.52 Nov-'1983
Crystal Springs 2.44 Apr-1986
Curry Cattle Company 0.22 Jun-1983
Dietrich Drop 4.50 Aug-1988
Eightmile Hydro Project 0.36 Od-2014
Elk Creek 2.OO May-'1986
Falls River 9.10 Aug-1993
Fargo Drop Hydroelectric 1.27 Apr-2013
Faulkner Ranch 0.87 Aug-1987
Fisheries Dev. 0.26 Jul-1990
Geo-Bon #2 0.93 Nov-1986
Hailey Cspp 0.06 Jun-1985
Hazelton A 8.10 Mar-2011
Hazelton B 7.60 May-1993
Head of U Canal Project 1.28 May-2015
Horseshoe Bend Hydro 9.50 Sep-1995
Jim Knight 0.34 Jun-'1985
Kasel &Witherspoon 0.90 Mar-1984
Koyle Small Hydro 1.25 Apr-1984
Lateral #'10 2.06 May-'t985
Lemoyne 0.08 Jun-'1985
Little Wood River Ranch ll 1 .25 Jun-2015
Total Hydro Nameplate Rating 155.32 MW
Contract
On-line Date End Date
Sep-2030
Sep-2030
Apr-2024
Nov-201 9
Apr-2019
Oct-2035
Dec-2034
Feb-201 9
od-2020
Jun-2023
As
Jun-201 9
Estimated
Nov-201 8
Apr-2021
Jun-20'18
Au9-2023
Oct-2034
May-2021
Au9-2028
Apr-2033
Aug-2022
Jul-2040
Nov-2021
Jun-2020
Mar-2026
May-2028
Jun-2035
Sep-2030
Jun-2020
Mar-2019
Apr-2019
May-2020
Jun-2020
Oct-2035
Project
Liftle Wood Rvr Res
Liftlewood/Arkoosh
Low Line Canal
Low Line Midway Hydro
Lowline #2
Magic Reservoir
Malad River
Marco Ranches
Mile 28
Mill Creek Hydroelectric
Mitchell Bufte
Mora Drop Small Hydro Fac
Mud CreeUS&S
Mud CreekMhite
North Gooding Main
Owyhee Dam Cspp
Pigeon Cove
Pristine Springs #1
Pristine Springs #3
Reynolds lnigation
Rock Creek #1
Rock Creek #2
Sagebrush
Sahko Hydro
Schaffner
Shingle Creek
Shoshone #2
Shoshone Cspp
Snake River Pottery
Snedigar
Tiber Dam
Trout-Co
Tunnel #'l
White Water Ranch
Wilson Lake Hydro
Contract
ItllW OnJine Date End Date
2.85
0.87
7.97
2.50
2.79
9.07
0.62
1.20
1.50
0.80
2.09
1.85
o.52
0.2'l
1.30
5.00
1.89
0.13
o.20
0.26
2.05
1.90
0.43
0.50
0.53
0.22
0.58
0.37
0.07
0.54
7.50
0.24
7.00
0.16
8.40
Feb-'1985
Aug-l986
May-1985
Aug-2007
Apr-1988
Jun-1 989
May-1984
Aug-1985
Jun-1 994
Oct-201 1
May-1989
Sep-2006
Feb-1 982
Jan-1 986
Oct-2016
Aug-1985
Oct-1984
May-2005
May-2005
May-1986
Sep-1983
Apr-1989
Sep-l985
Feb-201 1
Aug-1986
Aug-1 983
May-1996
Jun-1982
Nov-1984
Jan-1 985
Jun-2004
Dec-1986
Jun-1 993
Aug-1985
May-1993
Feb-2020
Aug-2021
May-2020
Aug-2027
Apr-2023
Jun-2024
May-2019
Aug-2020
Jun-2029
Jun-2017
Dec-2033
Sep-2026
Jan-2017
Jan-202'l
Oct-2036
May-2033
Oct-2019
May-2015
May-2015
May-202'l
Sep-20 1 8
Apr-2024
Sep-2020
Feb-2021
Aug-2021
Aug-2017
May-2031
Feb-20'17
Nov-2019
Jan-2020
Jun-2024
Dec-2021
Feb-2035
Aug-2020
May-2028
Thermal Projects MW On-line Date
Simplot Pocatello Cogen 15.90 Mar-20'13
TASCfNampa Natural Gas 2 Sep-2003
TASCG-Twin Falls Natural Gas 3 Aug-2001
Total Thermal Nameplate Rating 20.90 MW
End Date
Feb-2016
As Delivered
As Delivered
Page 112 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Contract
MW Online Date End Date
Aug-2020
May-2034
May-2020
Jan-2029
Jan-2032
Apr-2029
Mar-2037
Mar-2037
Estimated
Dec-2036
Oct-2036
Nov-2036
Jan-2036
Estimated
Mar-2037
Dec-2008
Mar-20'17
Feb-201 1
Dec-20'10
Mar-2009
Dec-2012
Dec-2012
Mar-2017
Sep-2005
Feb-201 1
Dec-2012
Dec-20'12
Feb-2006
Dec-2008
Mar-2017
Dec-201 1
Dec-2028
Mar-2037
Feb-2031
Dec-2030
Mar2029
Dec-2032
Dec-2032
Mar-2037
Sep-2025
Feb-2031
Dec-2032
Dec-2032
Feb-2026
Dec-2028
Mar-2037
Dec-2031
Project
Hidden Hollow Landfill Gas
Pocatello Waste
Rock Creek Dairy
SISW LFGE
Tamarack CSPP
Murphy Flat Power, LLC
Open Range Solar Center, LLC
Orchard Ranch Solar, LLC
Railroad Solar Center, LLC
Simco Solar, LLC
Thunderegg Solar Center, LLC
Vale Air Solar Center, LLC
Vale 1 Solar
Contract
tUW On-line Date End DateProject
Biomass Projects
86 Anaerobic Digester 2.28 Aug-2010
Bannock County Landfill 3.20 May-2014
Bettencourt Dry Creek BioFac{or1 2.25 May-2010
Big Sky West Dairy Digester 1.50 Jan-2009
Double A Digester Projecl 4.50 Jan-2012
Fighting Creek Landfill 3.06 Apr-2014
Total Biomass Nameplate Rating 34.45 MW
Solar Projects
American Falls Solar ll, LLC 20.00 Mar-2017
American Falls Solar, LLC 40.00 Mar-2017
Brush Solar 2.75 Oct-20'19
Grand View PV Solar Two 80.00 Dec-2016
Grove Solar Center, LLC 6.00 Oct-2016
Hyline Solar Center, LLC 9.00 Nov-2016
lD Solar 1 40.00 Aug-2016
Morgan Solar 3.00 Oct-2019
Mt. Home Solar 1, LLC 20.00 Mar-2017
Total Solar Nameplate Rating 298.25 MW
Wind Projects
Bennett Creek Wind Farm 21.00
Benson Creek Windfarm 10.00
Burley Butte Wind Park 2'1.30
Camp Reed Wind Park 22.50
Cassia Wind Farm LLC 10.50
Cold Springs Windfarm 23.00
Desert Meadow Windfarm 23.00
Durbin Creek Windfarm 10.00
Fossil Gulch Wind 10.50
Golden Valley Wind Park 12.00
Hammett Hill Windfarm 23.00
High Mesa Wind Project 40.00
Horseshoe Bend Wind 9.00
Hot Springs Wind Farm 21 .OO
Jett Creek Windfarm 10.00
Lime Wind Energy 3.00
Total Wind Nameplate Rating 626.92 MW
3.20
0.46
4.00
5.00
5.00
Jan-2007
Dec-1 985
Aug-20'12
Oct-20'18
Jun-1 983
Jan-2027
Dec-2020
Aug-2027
Estimated
Jun-201 8
Mainline Windfarm
Milner Dam Wind
Oregon Trail Wind Park
Payne's Ferry Wind Park
Pilgrim Stage Station Wind Park
Prospeclor Windfarm
Rockland Wind Farm
Ryegrass Windfarm
Salmon Falls Wind
Sawtooth Wind Project
Thousand Springs Wind Park
Tuana Gulch Wind Park
Tuana Springs Expansion
Two Ponds Windfarm
Willow Spring Windfarm
Yahoo Creek Wind Park
20.00
20.00
10.00
4.50
20.00
10.00
10.00
3.00
Mar-2017
Mar-2017
Oct-20'16
Dec-2016
Mar-2017
Nov-2016
Nov-2016
Oct-2019
Mar-2037
Mar-2037
Oct-2036
Dec-2036
Mar-2037
Nov-2036
Nov-2036
Estimated
Dec-2032
Feb-203'l
Jan-2031
Dec-2030
Jan-2031
Mar-2037
Dec-2036
Dec-2032
Apr-2031
Nov-2031
Jan-2031
Jan-2031
May-2030
Dec-2O32
Mar-2037
Dec-2030
23.00
19.92
't3.50
21.00
10.50
10.00
80.00
23.00
22.00
22.00
12.00
10.50
35.70
23.00
10.00
21.O0
Dec-2012
Feb-201 1
Jan-2011
Dec-2010
Jan-2011
Mar-2017
Dec-201 1
Dec-2012
Apr-2O11
Nov-201 1
Jan-2011
Jan-20'11
May-2010
Dec-2012
Mar-2017
Dec-2010
Total Nameplate Rating 1,135.84 MW
The above is a summary of the Nameplate rating for the CSPP projects under contract with ldaho Power as of April 1,2017.ln the case of CSPP poects,
Nameplate rating of the actual generation units is not an a@urate or reasonable estimate of the actual energy these poects will deliver to ldaho Power.
Historical generation information, resour@ specific industry standard capacity factors, and other known and measurable operating characteristics are accounted
for in determining a reasonable estimate of the energy these poects will produce.
2017 lntegrated Resource Plan-Appendix C Page 113
Existing Resource Data ldaho Power Company
Power Purchase Agreement Data
ldaho Power Company Power Purchase Agreements Status as of April 1,2017
Contract
Project MW On-Line Date End Date
Wind projects
Elkhorn Wind Project
Totalwind nameplate MW rating
Geotherma! Projects
Raft River Unit 1
Neal Hot Springs
Total geothermal nameplate MW rating
Total nameplate MW rating
101 December2007
101
April2008
November 2012
December2O2T
April2033
November 2037
13
22
35
136
2.
Above is a summary of the nameplate ratings for the Power Purchase Agreements under contract with ldaho Power. Nameplate ratings of the actual
generation units are not an accurate or reasonable estimate of the actual energy these projects will deliver to ldaho Power. Historical generation
information, resour@-specific industry standard capacity factors, and other known and measurable operating characteristics are ac@unted for in
determining a reasonable estimate of the energy the projecls will produce.
Not included in the above table is the energy exchange agreement between ldaho Power and the Clatskanie PUD. Under the exchange, ldaho Power
receives energy from the 18-lvfw power plant atArrowrock Dam on the Boise River and retums to Clatskanie PUD energy of an equivalent value
delivered seasonally. The agreement began in January 201 0 and extends through 2020. ldaho Power retains the right to renew the agreement through
2025.
Page 114 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Flow Modeling
Models
Idaho Power uses two primary models for forecasting future flows for the IRP. The Snake River
Planning Model (SRPM) is used to forecast surface water flows and the Enhanced Snake Plain Aquifer
Model (ESPAM) is used to forecast the impact of various aquifer management practices implemented on
the Eastern Snake Plain Aquifer (ESPA). The SRPM was updated in late 2012to include hydrologic
conditions for years 1928 through 2009. ESPAM was also updated with the release of ESPAM 2.1
in late 2012. Beginning with the 2009 IRP, Idaho Power began running the SRPM and ESPAM as a
combined modeling system. The combined model seeks to maximize diversions for aquifer recharge
and system conversions without creating additional model inigation shortages over a modeled
reference condition.
Model lnputs
The inputs for the 2017 IRP were derived from management practices outlined in an agreement between
the Surface Water Coalition and Idaho Groundwater Appropriators (IGWA). The agreement set out
specific targets for several management practices that include aquifer recharge, system conversions,
and a total reduction in ground water diversions of 240,000 acre feet (acft). The 2017 IRP modeling also
recognized ongoing declines in specific reaches and additional surface water from weather
modifi cation activities.
Recharge modeled for the 2017 IRP included new recharge diversions that have the capability of
completely drying the Snake River below Milner Dam during the winter months. These diversions can
have a significant impact to flows downstream of Milner Dam. Recharge diversions increased from
2017 and peaked at close to 249,000 acft in IRP year 2022.In IRP year 2022, approximately 67,000 acft
of recharge occurs above American Falls Reservoir and 182,000 acft is diverted at Milner Dam.
Recharge diversions are held steady until 2031 when declines in reach gains reduce the amount of water
available for recharge operations.
System conversion projects involve the conversion of ground water supplied irrigated land to surface
supplied inigated land. The number of acres modeled and potential water savings was based on data
provided by the Idaho Department of Water Resources. The current model assumes a total of
16,687 acres of converted land on the ESPA with a total water savings of 2.0 acre-ft or water per acre of
irrigated land (acre-ff/acre). Diversions for conversion projects peak at approximately 33,000 acft.
Diversions for conversion projects generally decline after 202I as declines in reach gains reduces water
availability for diversion.
The model accounted for a240,000 acft decreases in ground water pumping from the Eastern Snake
Plain Aquifer (ESPA). The decreases were spread evenly over ground water inigated lands that are
subject to the agreement between the Surface Water Coalition and the IGWA. This reduction in ground
water diversions resulted in increased reach gains throughout much of the mid-Snake River.
2017 lntegrated Resource Plan-Appendix C Page 115
Existing Resource Data ldaho Power Company
The goal of the Surface Water Coalition agreement was to provide additional water to those entities
diverting Snake River water from Minidoka Dam to Milner Dam. To simulate this delivery of additional
water, a new diversion was added to the model. This diversion is not delivered to a specific entrty in the
model but is designed to simulate additional surface water diversions at Milner. The amount of this
diversion was calculated to ensure that surface water diverters would receive water amounting to the
25 percent exceedance of diversions for years 1995 -2009. These additional diversions were not
allowed if either storage water or natural flow were not available in excess of existing modeled
diversions. Water was not available in all years to fill these diversions.
Future reach declines were determined using a variety of statistical analyses. Trend data indicate reach
gains into American Falls Reservoir and from Milner Dam to Lower Salmon Falls Dam demonstrated a
statistically significant decline for the period of 1986 to 2015. On average, reach gains into American
Falls Reservoir declined 29 cubic feet per second per year. Reach gains from Milner Dam to Lower
Salmon Falls Dam declined on average 28 cubic feet per second per year. Declines in these two reaches
met strict, predefined criteria, and were therefore included as inputs into the model.
Weather modification was added to the model at different levels of development. For IRP years2017
through 2019, weather modification was increased to reflect projected levels of fully built-out programs
in Eastem Idaho, the Wood River Valley and the Boise Basin. Beyond IRP year 2019, weather
modification levels in these three basins were held constant through the rest of the IRP forecast period.
The level of weather modification was held constant at the current level in the Payette River Basin
throughout the IRP forecast period.
Model Resu/ts
The combined model allows for the ability to include future management activities, and the resulting
reach gains from those management activities into Idaho Power's 2017 IRP. Management activities,
such as recharge and system conversions, do not significantly change the total annual volume of water
expected to flow through the Hells Canyon Complex, but instead change the timing and location of
reach gains within the system. Other future management activities, such as weather modification and a
decrease in ground water pumping do directly impact the annual volume of water expected through the
Hells Canyon Complex as well as the timing and location of gains within the system.
Overall inflow to Brownlee Reservoir increases from IRP year 2017 through 2018. These increases are a
response to increased weather modification in the Upper Snake, Wood and Boise River Basins and
increased reach gains resulting from a decrease in pumping on the ESPA. Flows peak in 2018 with the
50 percent exceedance flows into Brownlee Reservoir at just over I1.72 million acre-ff/year.In2036,
those flows have declined to approximately 11.3 million acre-ftlyear. For the April through July volume
the peak occurs in202l with a volume of 5.32 million acre-ftlyear.By 2036 the April through
July inflow to Brownlee decreases to 5.17 million acre-ft/year. The decline in inflow to Brownlee
Reservoir after 2018 is likely due to the increased diversions for recharge, particularly winter time
diversions that reduce flow at Milner Dam to zero. April through July volumes continue to increase as
new reach gains from recharge and a decline in ground water pumping yield at springs tributary to the
Snake River. However, there is a long-term decrease in Snake River flows which is attributable to
Page 1 16 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
declining flows into American Falls and the Milner to Lower Salmon Falls reach. These long-term
declines eventually overwhelm any new reach gains from management practices on the ESPA.
2017 Model Parameters
Managed Recharge (acft/yr)Reach Declines (acfUyr)
Total
AmericanFalls Below Milnerlnflows lnflows
IRP
Year
2017
201 8
201 I
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
Above
American Falls
700
4,900
36,379
39,309
39,310
67,427
67,427
67,427
67,427
67,427
67,427
67,427
67,427
67,427
65,871
65,871
65,871
65,871
65,871
65,871
Below American
Falls
56,444
70,748
144,079
143,957
167,259
181 ,352
181,352
181,352
181 ,352
181,352
'181,352
181 ,352
181 ,352
181,352
176,055
176,055
176,055
176,055
176,055
176,055
57,',144
75,648
180,459
183,266
206,568
248,779
248,779
248,779
248,779
248,779
248,779
248,779
248,779
248,779
241p26
241,926
241,926
241,926
241,926
241,926
167,000
187,700
208,500
229,300
250,100
270,900
291,900
312,800
333,400
354,300
375,500
396,1 00
417,OOO
437,900
458,600
479,600
s00,600
521,300
542,200
562,900
161 ,700
181 ,900
201,400
222,400
242,600
263,1 00
283,000
303,200
323,300
343,900
364,000
384,200
404,400
424,600
444,600
465,000
485,1 00
505,300
525,600
545,300
Weather
Modification
(acft/yr)
System
Conversions
(Ac)
CREP
(Ac)
888,301
990,779
1,031,541
1,031,541
1,031,541
1,031,541
1,031,541
1,03't,54'l
1,031,541
't,031,541
't,031 ,541
1,03't,541
1,031,541
1,031,541
1,031,541
't,031,541
1,031,541
1,031,541
1,031,541
'1,031,541
16,700
16,700
16,376
16,574
16,700
16,490
't6,490
16,490
't6,490
16,490
16,490
16,490
16,490
16,490
16,238
16,238
't6,238
16,238
16,238
16,238
240,000
240,000
240,000
240,000
240,000
240,000
240,000
240,000
240,000
240,000
240,000
240,000
240,000
240,000
240,000
240,000
240,000
240,000
240,000
240,000
2017 lntegrated Resource Plan-Appendix C Page 117
Existing Resource Data ldaho Power Company
Hydro Modeling Results (PDR580)
Average Megawatt (aMW) soth Percentile Water, 50th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
UpperSalmon l&2
Upper Salmon 3&4
Type
HCC-
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
112017
308.0
1 26.9
249.6
22.6
6.2
47.3
61.5
1.5
1.9
1 1.3
32.9
34.9
12.0
19.8
35.1
6.5
19.2
17.7
2t2017
348.1
150.0
298.0
24.1
6.3
47.3
62.6
1.5
1.9
11.4
32.9
36.0
12.0
20.1
36.0
b.b
19.2
17.7
3t2017
344.5
1 56.1
315.2
24.4
6.1
42.0
56.0
2.5
1.8
12.2
27.9
20.3
12.0
18.2
22.6
7.0
18.0
16.6
4t2017
453.3
199.5
408.1
56.2
6.1
55.4
69.9
^o
1.8
12.3
38.5
42.8
12.0
22.6
45.5
7.2
1 9.1
17.7
5t2017
399.4
163.7
338.4
84.4
6.1
48.0
61.1
5.4
1.8
13.4
33.7
31.1
12.0
19.9
32.0
7.5
17.6
17.7
6t2017
415.5
168.7
340.6
92.5
5.9
41.8
51.2
1 1.6
1.7
12.0
28.1
15.4
12.0
16.8
20.1
7.0
18.0
16.2
712017
251 .3
106.8
211.7
86.7
5.9
35.5
37.2
10.4
1.7
12.1
23.1
6.4
12.0
13.0
10.7
6.9
14.1
13.3
812017
162.5
74.4
'146.3
oo. J
6.1
287
31.8
13.3
1.8
12.4
16.2
6.9
11.2
7.0
9.0
8.9
9t2017
221.4
1 00.1
195.5
42.4
6.2
37.4
44.4
8.8
1.8
13.0
23.7
6.7
15.0
7.2
14.5
tJ.o
10t2017
184.0
85.1
1 68.1
13.6
6.3
34.2
48.5
1.9
1.9
13.0
24.5
15.9
7.0
15.0
14.0
11t2017
144.7
66.2
132.2
6.2
36.5
47.7
1.4
1.9
1 1.5
22.8
9.7
15.8
5.9
6.4
13.6
12.9
12t2017
240.8
102.2
202.8
10.2
6.2
40.8
51.5
1.4
1.9
11.4
26.3
14.7
12.0
17.0
17.4
6.4
16.5
15.3
aMW
289.5
125.0
250.5
43.6
6_1
41.6
52.0
5.5
1.8
12.2
27.6
16.8
10.5
17 .1
'18.8
6.9
16.2
1 5.1
HCC Total
ROR Total
Total
684.5
330.3
'1,014.8
796.1
335.6
1,131.7
81s.8
287.7
1,103.5
1,060.9
413.0
1,473.9
901.5
391.6
1,293.1
924.8
350.4
1,275.2
s69.8
288.9
858.7
383.2
219.5
602.7
516.9
235.1
752.0
437.2
206.0
643.2
343.1
192.4
535.5
545.8
249.4
795.2
66s.0
291.7
956.6
'HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
o.z
36.8
47.7
1.4
1.9
1 1.5
22.7
6.9
11.1
7.0
8.9
9.0
6.7
15.1
7.2
13.6
14.5
6.3
16.0
7.0
14.0
15.0
9.6
15.9
5.9
6.4
12.8
13.6
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2018
299.6
124.0
244.0
24.3
6.2
47.4
61.7
1.5
1.9
11.3
33.3
36.5
12.0
19.8
36.9
6.5
17.7
19.1
2t2018
350.8
151.4
300.6
24.8
o.J
47.6
63.3
1.5
1.9
11.4
33.5
36.4
12.0
20.2
36.3
6.6
17.7
1 9.1
3/2018
344.3
156.7
316.3
25.4
6.1
42.5
567
2.5
1.8
12.2
28.2
22.6
12.0
18.5
24.3
7.0
16.8
18.2
4t2018
455.2
201.8
412.7
59.7
o. I
56.0
72.5
5.9
1.8
12.3
39.4
45.1
12.0
23.1
47.8
7.2
17.7
'19.0
5t2018
402.9
165.2
341.3
85.7
6.1
49.2
62.8
5.4
1.8
13.4
35.2
35.0
12.0
20.3
35.3
7.5
17.7
17.6
6t2018
420.5
170.7
344.5
94.1
(o
42.4
52.6
11.6
1.7
12.0
29.0
18.2
12.0
17.2
21.8
7.0
16.2
18.7
7t2018
252.O
107.1
212.2
86.9
(o
35.7
372
10.4
1.7
12.1
23.2
6.4
12.0
13.0
10.7
6.9
13.3
14.2
8/2018
162 6
74.5
146.5
66.5
6.1
28.5
31.8
13.3
1.8
12.4
16.2
9t2018
221.9
100.3
196.0
42.5
6.2
37.5
45.0
8.8
1.8
13.0
23.6
10t2018
184.2
85.3
168.3
13.6
6.3
38.3
48.6
1.9
1.9
13.0
24.5
11t2018
144.8
66.3
132.4
12t2018
245.5
104.2
206.8
14.5
6.2
42.6
53.5
1.4
1.9
11.4
29.1
23.7
12.0
176
25.3
6.4
17.2
18.7
aMW
290.4
125.6
251.8
44.8
6.1
42.0
52.8
5.5
1.8
12.2
28.2
18.7
10.5
17.3
20.4
6.9
15.3
16.4
HCC Total
ROR Total
Total
667.6
335.0
1,003.6
802.8
338.6
'l,141.4
817.3
294.9
1,112.2
1,069.7
425.6
1,495.3
909.3
404.9
1,314.2
935.7
360.5
1,296.2
571.3
289.s
860.8
383.6
219.4
603.0
518.1
235.5
753.6
437.8
206.3
64/.1
343.5
192.s
536.0
556.5
281.s
838.0
657.8
298.8
966.5
'HCC=Hells Canyon Complex, *ROR= Run of River
Page 118 2017 lntegrated Resource Plan-Appendix C
Hydro Modeling Results (PDR580) (continued)
ldaho Power Company Existing Resource Data
Average Megawatt (aMW) 50th Percentile Water, 50th PercenUle Load
Resource
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
6.9
11.2
6.7
15.1
6.3
16.0
6.2
36.3
47.1
1.4
1.9
1 1.5
22.4
8.5
15.6
4.7
6.4
12.6
13.3
28.0
18.2
10.4
17.3
20.0
6.9
15.2
16.3
Type
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2019
257.4
123.1
242.2
24.4
6.2
46.9
61.4
1.5
1.9
11.3
32.8
35.0
12.0
19.6
35.6
6.5
17.7
19.2
2t2019
349.1
150.7
299.1
25.O
6.3
47.7
63.1
1.5
1.9
11.4
33.1
35.0
,t2.0
20.2
35.5
6.6
17.7
19_1
3/20t9
343.4
156.3
315.5
22.5
6.1
40.5
53.9
2.5
1.8
12.2
26.0
15.2
12.0
17.7
18.6
7.0
15.4
16.5
4t2019
454.0
201.2
411.5
60.5
6.1
56.2
71.3
5.9
1.8
12.3
39.5
44.9
12.O
23.1
47.4
7.2
17.7
19.0
5t2019
405.5
166.2
343.3
86.6
6.'l
50.1
62.9
5.4
1.8
13.4
35.5
35.7
12.0
20.4
35.9
7.5
17.7
17.6
612019
422.9
171 .7
3/,6.4
95.2
EO
43.4
54.4
't 1.6
1.7
,t2.o
29.3
21.2
12.O
17.7
24.0
7.0
16.2
18.9
7t2019
252.2
107.2
212.4
87.'l
5.9
35.7
37.3
10.4
't.7
12.1
23.2
6.4
12.0
13.0
10.7
6.9
13.4
14.2
8t2019
't62.7
74.5
146.6
66.6
6.t
28.6
3'1.9
13.3
1.8
12.4
16_3
7.0
8.9
9.0
912019
221.6
100.2
195.6
42.6
6.2
37.5
45.0
8.8
1.8
13.0
23.6
10t2019
184.7
85.5
168.7
13.6
6.3
38.3
48.7
1.9
.1.9
13.0
24.5
1112019
't44.5
66.1
132.0
12t2019
243.7
103.4
205.2
15.9
6.2
43.2
54.3
1.4
1.9
1't.4
29.6
25.3
12.0
17 _8
27.0
6.4
17.5
19.1
aMW
290.1
125.5
251.5
45.0
6.1
42.0
52.6
5.5
1.8
7.2
13.5
14.4
7.0
14.0
15.0
HCC Total
ROR Total
Total
662.7
33{.9
994.6
798.9
336.r
1,135.0
815.2
268.0
r,083.2
r,066.7
424.9
1,491.6
9t5.0
408.5
1,323.5
94{.0
370.6
1,3{ 1.6
571.8
289.9
861.7
383.8
219.9
603.7
517.3
235.4
752.7
438.9
206.4
6tt5.3
342.6
188.0
530.6
552.3
289.0
841.3
667.2
285.2
952.4
'HCC=Hells Canyon Complex, "ROR= Run of River
Average Megawatt (aMW) 50th Percentile Water, soth Percentile Load
Resource
American Falls
1,000 Springs
BIiSS
C.J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
6.9
11.1
7.O
9.0
8.9
6.7
't 5.0
7.2
14.4
't 3.5
6.3
16.0
7.O
14.9
14.0
8.8
15.6
5.2
6.4
13.3
12.6
Type
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2020
257.8
123.3
242.6
24.5
6.2
47.0
61.6
1.5
1.9
11.3
32.9
35.3
12.0
19.6
35.8
6.5
't9.2
17.7
a2020
338.0
145.9
289.7
24.4
6.3
46.2
61.0
1.4
1.9
11.4
32.2
34.3
1 1.6
19.5
34.7
6.6
18.4
17.1
3t2020
u3.4
156.3
315.5
22.3
6.1
40.5
53.8
2.5
1.8
12.2
25.9
15.2
12.0
17.7
18.6
7.O
16.5
15.3
4t2020
454.2
201.2
411.7
60.7
6.1
56.3
71.4
5.9
1.8
12.3
39.6
45.0
12.O
23.1
47.5
7.2
19.0
17.7
512020
405.7
'166.4
343.5
86.6
6.1
50.2
63.1
5.4
1.8
,13.4
35.6
35.8
12.0
20.4
35.9
7.5
't7.6
't7.7
6t2020
422.7
171_6
346.2
95.2
5.9
43.4
54.4
11.6
1.7
12.0
29.3
21.2
12.0
17.8
24.0
7.0
18.9
16.2
7t2020
252.1
147.1
212.3
87.1
5.9
35.7
37.3
10.4
't.7
12.1
23.2
6.4
12.0
13.0
10.7
6.9
14.2
13.3
8t2020
162.5
74.4
146.4
66.6
6.1
28.5
31.8
13.3
1.8
12.4
16.2
9t2020
221.2
100.0
195.3
42.6
6.2
37.4
44.8
8.8
1.8
13.0
23.5
10t2020
184.7
85.4
168.6
13.6
6.3
38.3
48.7
1.9
1.9
13.0
24.5
11t2020
144.4
56.1
131 .9
6.2
36.3
47.1
't.4
1.9
1 1.5
22.4
12t2020
243.7
103.4
205.3
16.1
6.2
43.3
54.5
1.4
1.9
11.4
29.7
25.6
12.0
17.9
27.3
6.4
19.2
17.6
aMW
289.2
125.1
250.7
45.0
6.1
41.9
52.5
5.5
1.8
12.2
27.9
18.2
10.4
17.2
20.o
6.9
16.2
15.1
HCC Total
ROR Total
Total
663.7
332.9
996.6
773.8
327.'.|
t,{00.6
815.2
267.5
1,082.7
1,067.t
425.8
1,492.7
915.7
,O9.0
1,324.6
940.5
370.7
1,311.2
571.5
289.8
861.3
383.3
219.5
602.8
516.4
234.9
751.3
tli,8.7
206.3
545.0
342.4
188.8
531.2
552.4
290.5
842.9
665.0
296.9
96r.9
*Hcc=Hells Canyon Complex, *ROR= Run of River
2017 lntegrated Resource Plan-Appendix C Page 119
Existing Resource Data ldaho Power Company
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
BIiSS
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
6.9
11.1
6.7
15.0
7.0
9.0
8.9
7.2
14.3
'13.4
6.3
'16.0
7.0
14.9
13.9
8.2
'15.6
4.5
6.4
13.3
12.6
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t202'.1
296.8
122.9
241.8
24.6
6.2
46.7
61.2
1.5
1.9
11.3
32.6
34.4
12.0
19.5
35.1
6.5
19.2
177
212021
348.7
150.5
298.8
25.2
6.3
47.6
62.9
1.5
1.9
11.4
32.9
34.5
12.0
20.2
35.1
6.6
19 1
177
3t2021
343.9
156 5
315.9
22.3
6.1
40.4
53.5
2.5
1.8
12.2
25.7
14.2
12.0
17.6
1 8.1
7.0
to J
'15'l
4t2021
454.9
201 .5
412.3
60.3
6.1
56.3
71.5
5.9
1.8
12.3
39.7
45.2
12.0
23.1
47.7
7.2
19.0
17.7
st2021
406.0
166.6
343.8
86.6
6.1
50.4
63.3
5.4
1.8
13.4
35.8
35.7
12.0
20.4
359
7.5
17.6
177
6t202',1
422.7
171.6
346.1
95.2
5.9
43.3
54.5
11.6
1.7
12.0
29.3
21.1
12.0
17.8
240
7.0
18.9
16.2
7t2021
252.1
107.1
212.3
87.1
5.9
35.7
37.3
10.4
1.7
12.1
23.2
6.4
12.0
13.0
10.7
6.9
14.2
133
8t2021
162.4
74.4
146.3
66.6
6.1
28.5
31.8
13.3
1.8
12.4
16.2
9t2021
216.4
99.6
195.4
42.6
6.2
37.3
44.7
8.8
1.8
13.0
23.4
10t2021
184.8
85.4
168.6
13.6
o.J
38.2
48.6
't.9
1.9
13.0
24.4
11t2021
144.6
66.1
132.1
6.2
36.1
46.9
1.4
1.9
1 1.5
22.3
12t2021
242.5
102.9
204.3
15.9
6.2
43.0
54.1
1.4
1.9
11.4
29.5
24.8
12.0
17.8
26.5
6.4
19.0
17.4
aMW
289.6
125.4
251.5
45.0
6.1
42.0
52.5
5.5
1.8
12.2
27.9
18.0
10.3
17.3
19.8
6.9
16.2
1 5.1
HCC Total
ROR Total
Total
66t.s
330.3
991.8
798.0
334.9
1,132.9
8't6.3
2G4.9
1,O81.2
1,068.7
425.8
'1,494.5
916.4
409.5
1,325.9
940.4
370.6
1,31 1.0
571.5
289.8
851.3
383.1
2't9.5
602.6
5't 1.3
234.4
745.6
438.8
205.9
64/-.7
342.8
187.0
529.8
549.7
287.3
837.0
665.5
296.6
963.2
-HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
7.0
8.9
8.8
7.0
14.8
13.9
Type
HCC.
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2022
298.8
123.7
243.4
24.6
62
47.2
61.3
'1.5
1.9
'l'1.3
33.0
35.7
12.0
19.7
36.2
6.5
19.2
17.7
2t2022
351 2
151 .5
300.8
o.J
48.1
63.4
1.5
'1.9
11.4
33.4
36.5
12.0
20.3
36.7
6.6
1 9.1
17.7
3t2022
343.5
156.3
315.5
22.7
ot
40.8
54.4
2.5
1.8
12.2
26.3
16.0
12.0
17.9
19.3
7.0
16.8
15.6
4t2022
441.1
195.4
400.1
578
o. I
52.7
67.1
(o
1.8
12.3
36.5
42.0
12.0
21.6
41 .1
7.2
1 9.1
17.7
st2022
407.1
167.0
344.5
86.7
6.1
50.4
63.1
5.4
1.8
13.4
35.8
35.6
12.0
20.4
35.8
7.5
17.6
17.7
6t2022
422.4
171.5
345.9
95.2
5.9
43.3
53.6
1 1.6
1.7
12.0
29.3
21.3
12.0
17.5
24.1
7.0
18.9
16.2
7t2022
251.8
107.0
212.1
87.1
5.9
35.6
37.2
10.4
1.7
12.1
23.1
6.4
12.0
13.0
10.7
6.9
14.1
13.3
8t2022
162.2
74.3
1 46.1
66.5
6.1
28.4
31.7
13.3
1.8
12.4
16.1
6.9
11.1
9t2022
215.7
99.2
194.7
42.5
6.2
5l z
44.5
8.8
1.8
13.0
23.3
6.7
14.9
10t2022
184.8
85.4
168.5
13.6
oc
38.1
48.5
1.9
1.9
13.0
24.3
1'.1t2022
144.7
66.2
132 2
6.2
36.2
47.0
1.4
1.9
1 1.5
22.4
12t2022
244.0
103.6
205.6
16.4
6.2
43.6
55.3
1.4
'1.9
11.4
30.0
26.4
12.0
1 8.1
28.0
6.4
19.2
17.7
aMW
288.9
125.1
250.8
44.9
6.1
41.8
52.3
5.5
1.8
12.2
278
183
10.4
17.2
19.8
6.9
16.3
15.2
7.2
14.2
13.3
6.3
15.9
9.4
15.6
5.7
6.4
13.4
12.6
HCC Total
ROR Total
Total
66s.9
333.9
999.8
803.5
340.6
1,14/.1
815.4
271.5
1,086.9
t,036.6
400.9
1,437.5
918.5
409.2
1,327.8
939.8
369.7
1,309.5
570.9
289.4
860.3
382.6
218.9
601.5
509.5
233.6
743.1
.(}8.7
205.4
64/-.'.|
3l(,.r
189.8
532.9
553.2
294.0
847.2
664.8
296.4
961.2
*HCC=Hells Canyon Complex, *ROR= Run of River
Page 120 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource
Brownle€
Oxbo$,
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Skike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
HCC'
HGC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2023
298.6
123.6
243.2
24.6
o.t
47.2
61.3
1.5
19
1 1.3
33.0
35.8
12.0
19.7
36.2
6.5
19.2
17.7
2t2023
350.6
151 .3
300.4
25.7
6.3
48.0
63.4
1.5
1.9
11 .4
33.4
36.4
12.0
20.3
36.7
6.6
19.1
17.7
3t2023
343.4
156.2
315,3
22.7
6.1
40.8
54.3
2.5
1.8
12.2
26.3
15.9
12.0
17.8
19.3
7.0
16.7
15.5
4t2023
440.8
195.3
399.7
57.9
6.1
52.7
67.1
5.9
1.8
12.3
36.5
42.3
12.0
21.6
41.2
7.2
1 9.1
17.7
5t2023
407.4
167.1
344.8
86.7
6.1
50.4
63.1
5.4
1.8
13.4
35.8
35.6
12.0
20.4
35.7
7.5
17.6
17.7
6t2023
422.0
171.3
345.7
95.2
5.9
43.2
53.4
11.6
1.7
12.0
29.2
21.2
12.0
17.5
24.0
7.0
18.9
16.2
7t2023
251.5
106.9
211.8
87.1
5.9
35.5
37.1
'10.4
1.7
12.1
23.0
6.4
12.0
13.0
10.7
6.9
14.1
13.2
8t2023
161 .8
74.1
145.8
66.5
6.'r
24.3
31.5
13.3
1.8
12.4
16.0
9t2023
214.7
98.7
'193.7
42.5
6.2
37.0
44.3
8.8
1.8
'13.0
23.1
10t2023
184.8
85.4
'168.5
13.6
6.3
38.0
48.3
1.9
1.9
13.0
24.2
11t2023
144.6
66.1
132.1
6.2
36.2
46.8
1.4
1.9
1 1.5
22.4
12t2023
243.7
103.5
205.3
16.4
6.2
43.5
55.1
1.4
1.9
11_4
29.9
26.4
12.0
18.1
27.9
6.4
19.2
17.7
aMW
288.7
125.0
250.5
44.9
6.1
41.7
52.1
5.5
1.8
12.2
27.7
18.3
10.4
17.2
19.8
6.9
16.2
15.2
6.9
11.1
6.7
14.9
6.3
15.9
9.4
15.6
5.7
6.4
'13.3
12.6
7.0
8.8
8.8
7.0
14.7
13.8
7.2
14.1
I C_Z
HCC Total
ROR Total
Total
665.4
334.0
999.4
802.3
340.4
1.142.7
814.9
271.0
1.085.9
1,035.8
401.4
1 ,437.2
919.3
409.1
1,328.4
939.0
369.1
1 .308.1
570.2
289 0
859.2
381.7
218.4
600.1
507.1
232.8
739.8
438.7
204.8
643.5
342.8
189.5
532.3
552.5
293.5
846.0
664.1
296.1
960.2
.HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource
Brownlee
Oxbou,
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
7.0
8.8
8.7
7.2
14.O
1 3.1
7.0
14.6
13.7
Type
HCC'
HCC .
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2024
298.3
123.5
243.0
24.6
6.2
47.1
61.2
1.5
1.9
1 1.3
32.9
35.7
12.0
19.7
36.2
6.5
19.2
17.7
212024
337.4
145.6
289.1
24.4
6.3
46.3
61.1
1.4
1.9
11.4
32.2
34.7
't 1.6
19.6
35.0
6.6
18.4
17 .1
3t2024
343.1
156.0
315.0
22.7
6.1
40.7
54.2
2.5
1.8
12.2
26.2
'15.8
12.0
17.8
19.2
7.0
16.7
15.5
412024
440.6
195.2
399.6
s7.5
6.1
52.6
67.1
EO
1.8
123
36.4
42.5
12.0
21.6
41.3
7.2
19.1
17.7
5t2024
407.3
167.1
344.7
86.6
6.1
50.4
o5.t
5.4
1.8
13.4
35.8
35.4
12.0
20.4
JC.b
7.5
17.6
17 .7
6t2024
421.5
171 .1
345.2
95.0
5.9
43.0
53.2
1 1.6
1.7
12.0
29.1
21.0
12.0
17.4
23.8
7.0
'18.8
16.2
7t2024
251.2
106.7
211.5
87.0
5.9
35.5
37.0
10.4
1.7
12.1
23.0
6.4
12.0
12.9
10.7
6.9
14.0
13.2
8t2024
161.4
73.9
145.4
66.5
6.1
282
31.4
13.3
1.8
12.4
15.9
6.9
1 1.0
9t2024
213.2
070
192.1
42.4
6.2
36.9
44.1
8.8
1.8
13.0
23.0
6.7
148
10t2024
'184.9
85.3
168.3
13.6
6.3
37.9
48.2
1.9
1.9
13.0
24.1
6.3
15.8
11t2024
144.6
66.1
131 .9
12t2024
243.8
103.5
205.4
16.2
6.2
43.4
54.7
1.4
1.9
11.4
29.8
26.0
12.0
17.9
27.5
6.4
19.2
177
aMW
287.3
124.3
249 3
44.7
6.1
41.5
51.8
5.5
1.8
12.2
276
18.1
10.4
17.0
'19.5
6.9
16.1
15.1
6.2
36.1
46.7
1.4
1.9
11.5
22.3
8.9
15.6
5.3
6.4
13.3
12.6
HCC Total
ROR Total
Total
664.8
333.6
998.4
772.O
328.0
1,100.1
814.1
270.5
1,084.6
1,03s.4
401.1
1,436.5
9r9.2
408.8
1,328.0
937.8
367.8
r,305.6
569.4
288.6
858.0
380.7
217.9
598.6
503.1
232.0
735.1
438.5
204.2
642.7
342.6
't88.3
530.9
552.7
291.7
444.4
660.9
294.4
955.2
'HCC=Hells Canyon Complex, "ROR= Run of Rivtr
2017 lntegrated Resource Plan-Appendix C Page 121
Existing Resource Data ldaho Power Company
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 50th Percentile water, 50th Percentile Load
Resource
Brownlee
O:6ow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
Type
HCC.
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2025
297.9
123.3
242.7
24.6
6.2
47.0
61.0
1.5
1.9
11.3
32.6
35.7
12.0
19.6
36.2
6.5
19.2
17 .7
2t2025
348.8
150.5
298.9
25.2
6.3
47.6
63.2
1.5
1.9
11.4
33.0
35.8
12.0
20.3
36.2
6.6
19. 't
17.7
3t202s
342.7
155.9
314.7
22.6
6.1
40.6
54.1
2.5
1.8
12.2
26.0
15.7
12.0
17.8
19.1
7.0
16.6
15.4
4t202s
440.5
195.2
399.6
56.7
6.1
52.5
67.0
5.9
1.8
12.3
36.3
42.5
12.0
21.6
41.4
7.2
19.1
17.7
5t2025
407.0
166.9
344.5
86.6
6.1
50.3
63.1
5.4
1.8
13.4
35.7
35.2
12.0
20.4
35.4
7.5
17.6
17.7
6t2025
420.8
170.8
344.7
94.8
5.9
42.8
53.0
'1 1.6
1.7
12.0
29.0
20.7
12.0
17.3
zc_o
7.0
18.7
16.2
7t2025
250.8
106.6
211.2
86.9
5.9
35.4
36.8
10.4
1.7
12.1
22.9
6.4
12.0
12.9
10.7
6.9
13.9
1 3.1
8t2025
161 .0
73.7
145.1
66.4
6.1
28.1
31.2
13.3
1.8
12.4
15.8
6.9
11.0
7.0
8.7
8.6
9t2025
211.9
97,2
190.8
42.3
6.2
36.7
43.9
8.8
1.8
13.0
22.8
6.7
14.7
7.2
13.8
13.0
'10t2025
184.8
85.1
168.'1
13.5
b.J
37.8
47.8
1.9
1.9
13.0
24.0
6.3
15.8
7.0
14.5
13.6
1112025
144.9
66.2
132.2
12t2025
243.5
103.4
205.1
15.8
6.2
43.1
54.3
1.4
1.9
11 .4
29.6
25.3
12.0
17.8
27.0
6.4
19. 1
'17.5
aMW
287.9
't24.6
249.8
44.6
6.1
41.5
51.8
5.5
1,8
12.2
27.5
18.1
10.4
17 .1
19.6
6.9
16.1
1 5.1
6.2
36.1
46.5
1.4
1.9
1 1.5
22.2
8.8
15.5
5.2
6.4
13.2
12.5
HCC Total
ROR Total
Total
663.9
332.9
996.8
798.2
337.8
1,136.0
813.3
259.5
1,082.9
1,035.3
400.1
1,435.4
918.3
408.1
1,326.4
936.3
366.4
1,302.7
568.6
287.9
856.5
379.8
217.2
597.0
499.9
230.9
730.8
438.0
203.3
641.3
343.3
187.5
s30.8
552.0
288.8
840.8
662.2
294.2
956.4
'HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 50th Percentile Water, 50rh Percentile Load
Resource
Bro,vnlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
BIiSS
C J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
7.0
8.6
8.6
7.0
14.4
13.5
6.7
14.7
7.2
13.7
12.9
8.8
15.4
5.2
6.4
13.2
12.5
Type
HCC-
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2026
297 3
123.1
242.2
23.9
o.l
46.9
60.8
1.5
1.9
1 1.3
32.3
34.9
12.0
'19.6
35.1
6.5
19.2
2t2026
348.2
150.3
298.4
252
6.3
47.1
62.9
1.5
1.9
11.4
32.9
35.8
12.0
20.1
36.2
6.6
19. 1
17.7
3t2026
342.3
155.7
314.4
22.5
6.1
40.4
53.8
2.5
1.8
12.2
25.9
15.6
12.0
17.7
18.9
7.0
16.5
15.3
4t2026
440.0
195.0
399.1
56.7
6.1
52.4
66.3
5.9
1.8
12.3
36.2
42.5
12.0
21.4
41.4
7.2
19.1
17.7
5t2026
407.1
1 66.9
344.6
86.5
6.1
50.3
63.1
5.4
1.8
13.4
35.7
35.0
12.0
20.4
35.2
7.5
17.6
17.7
6t2026
420.1
170.5
344.2
94.7
5.9
42.5
52.7
I 1.6
1.7
12.0
28.9
20.4
12.0
17.3
23.3
7.0
to.o
16.2
7t2026
250.4
106.4
210.9
86.9
5.9
35.3
36.7
10.4
1.7
12.1
22.8
6.4
12.0
12.8
10.7
6.9
13.9
13. 1
8t2026
160.6
73.5
144.7
664
6.1
27.9
31 .1
13.3
1.8
12.4
15.7
9t2026
210.0
96.2
188.8
42.3
6.2
36.5
43.6
8.8
1.8
13.0
22.7
10t2026
1 85.1
85.2
1 68.1
13.5
o.J
37.6
47.6
1.9
1.9
13.0
23.8
11t2026
145.0
66.2
132.2
6.2
36.0
46.3
1.4
1.9
11.5
22.2
12t2026
243.4
103.3
205.0
15.3
6.2
42.7
53.9
1.4
1.9
1't.4
29.2
24.5
12.0
17.7
26.0
6.4
18.8
17.3
aMW
287.5
124.4
249.4
44.5
6.1
41.3
51.6
5.5
1.8
12.2
27.4
17.9
10.4
17.0
19.3
6.9
16.1
'15.0
6.9
10.9
6.3
15.7
HCC Total
ROR Total
Total
662.6
329.7
992.3
796.9
336.7
1,133.6
812.4
268.3
1,080.7
1,034.1
399.0
1,433.1
918.7
407.6
1,326.3
934.8
364.9
1,299.7
567.7
287.5
855.2
378.8
216.6
595.4
494.9
230.1
724.9
€8.4
202.4
640.8
343.4
187.1
530.5
551.7
284.7
836.4
661.2
292.9
954.1
"HCC=Hells Canyon Complex, *'ROR= Run of River
Page 122 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 50th Percentile Water, 50rh Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
Type
HCC-
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2027
296.7
122.8
241.7
23.6
6.2
46.7
60.6
1.5
1.9
1 1.3
32.2
34.5
12.0
19.5
34.6
6.5
19.2
17 .7
2t2027
347.4
149.9
297.7
25.1
6.3
47.0
62.1
1.5
1.9
11.4
32.8
35.7
12.0
20.0
36.1
b.b
19.2
17.7
3t2027
342.1
155.6
314.1
22.1
6.1
40.2
53.5
2.5
1.8
12.2
25.8
15.4
12.0
17.6
18.8
7.0
16.4
15.2
4t2027
439.9
194.8
398.9
56.6
6.1
52.3
66.1
EO
1.8
12.3
JO. I
425
12.0
21.3
41.3
7.2
19.1
17.7
512027
407.3
167.0
344.7
86.4
6.1
50.2
63.1
5.4
'1.8
13.4
35.6
34.7
12.0
20.4
35.0
7.5
17.6
17 .7
6t2027
419.6
170.3
343.8
94.6
5.9
423
52.3
1 1.6
1.7
12.0
28.6
20.1
12.0
17.2
23.7
70
18.4
162
7t2027
249.9
106.2
210.5
86.9
(o
35.2
36.5
10.4
1.7
12.'l
22.7
6.4
12.0
12.8
10.7
69
13.8
13.0
8t2027
160.1
73.3
144.3
66.3
6.1
27.8
30.9
'13.3
1.8
12.4
15.5
7.0
8.5
8.5
9t2027
208.6
95.4
187.4
42.2
6.2
36.3
43.3
8.8
1.8
13.0
22.5
10t2027
1 85.1
85.0
167.8
13.5
6.3
37.5
47.4
'1.9
1.9
13.0
23.7
11t2027
145.4
66.4
132.5
6.2
35.9
46.2
1.4
1.9
11.5
22.1
't2t2027
241.7
102.6
203.6
14.8
6.2
42.4
53.5
1.4
1.9
11 .4
28.7
23.0
12.0
17.6
24.7
6.4
18.3
16.9
aMW
287.0
124.1
248.9
44.3
6.1
41.2
51.3
5.5
1.8
12.2
27.2
17 .7
10.4
16.9
19.2
6.9
16.0
14.9
6.9
10.8
6.7
14.6
o.J
15.7
7.2
13.6
12.8
7.0
14.3
13.5
8.8
15.4
5.2
6.4
13.1
12.4
HCG Total
ROR Total
Total
66'1.2
327.9
989.r
795.0
335.4
1,130.4
81'1.8
266.7
1,078.5
1,033.6
398.3
1,43't .9
918.9
406.8
1,32s.7
933.7
363.7
1,297.4
s66.6
286.9
853.5
377.7
215.7
593.4
491.4
229.O
720.3
437.9
201.9
639.8
34/,.3
186.6
530.9
547.9
279.2
827.1
660.0
291.5
95r.5
'HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource
Browrlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
BIiSS
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon '1&2
Upper Salmon 3&4
Type
HCC-
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2028
296.0
122.6
241.2
23.3
6.2
46.6
60.4
1.5
1.9
11.3
32.1
34.0
12.0
19.5
34.3
6.5
19.2
17.7
2t2028
334.6
144.3
286.7
24.1
6.3
45.2
59.8
1.4
1.9
11.4
31.3
34.3
11.6
19.2
34.8
6.6
18.5
17 .1
3t2028
341.9
155.4
J IJ O
21.7
6.1
39.7
53.3
25
1.8
12.2
25.4
15.0
12.0
17.5
18.2
7.0
16.1
14.9
4t2028
439.6
194.6
398.4
566
6.1
52.2
65.9
50
1.8
12.3
36.0
42.5
12.0
21.3
41.3
7.2
19. 1
17.7
s12028
407.7
167.1
345.1
86.3
6.1
50.1
63.0
5.4
1.8
13.4
35.5
34.5
12.0
20.4
34.8
7.5
17.6
17.7
6t2028
4'18.8
170.0
343.2
94.5
5.9
42.1
52.0
'l 1.6
1.7
12.0
28.5
'19.3
12.0
17.1
23.5
7.0
18.3
16.2
7t2028
249.4
106.0
210.1
869
5.9
350
36.4
10.4
1.7
12.1
22.6
6.4
12.O
12.8
10.7
6.9
13.7
129
8t2028
159.6
73.1
143.8
ooJ
6.1
277
30.7
13.3
1.8
12.4
15.4
6.9
108
1012028
184.9
84.9
167.5
13.5
6.3
37.3
47.2
1.9
1.9
13.0
23.5
6.3
15.6
't'12028
145.2
662
132.3
12t2028
240.4
102 0
202.5
14.2
62
41.9
53.1
1.4
'1.9
11 .4
28.1
21.5
12.0
17.5
23.3
6.4
17.8
16.5
aMW
285.4
123.4
247.5
44.1
6.1
40.8
50.9
5.5
1.8
12.2
26.9
17.3
10.4
16.8
18.8
6.9
15.8
14.4
9t2028
207.2
947
185.9
42.1
6.2
36 1
43.0
8.8
1.8
'13.0
22.3
6.7
14.5
7.0
8.4
a4
7.2
'13.5
127
7.0
14.2
134
ot
35.8
46.1
1.4
1.9
1 1.5
22.0
8.8
15.3
5.2
6.4
13.1
12.4
HCC Total
ROR Total
Total
659.8
326.4
986.2
765.6
323.5
1,089.1
81 1.1
263.5
1,074.6
1,032.6
397.9
1,430.5
919.9
406.0
1,325.9
932.0
361.8
1,293.8
565.5
286.3
8s1.8
376.5
215.1
s9't.6
487.8
227.9
71s.6
437.3
201.0
638.3
343.7
186.2
s29.9
544.9
273.2
818.1
656.4
289.1
945.4
'HCC=Hells Canyon Complex, *ROR= Run of River
2017 lntegrated Resource Plan-Appendix C Page 123
Modeling Results (PDR580) (continued)
Existing Resource Data ldaho Power Company
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource
Brownlee
O$ow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
6.2
35.5
46.0
1.4
1.9
1 1.5
21.9
6.9
10.7
7.0
8.3
8.3
6.7
14.4
7.2
13.3
12.6
6.3
15.5
7.0
14.1
13.3
8.8
15.3
5.2
6.4
12.9
12.3
Type
HCC-
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2029
295.5
122.3
240.8
22.9
o.z
46.4
60.2
1.5
1.9
11.3
31.9
33.5
12.0
19.4
34.0
6.5
19.2
17.7
2t2029
344.4
148.5
294.9
24.9
o.J
46.7
61.7
1.5
1.9
11 .4
32.3
35.4
12.0
19.9
35.9
6.6
19.2
17.7
3t2029
341.4
154.7
312.5
21.3
6.1
39.2
53.1
2.5
1.8
12.2
25.0
14.4
12.0
17.3
17.6
7.0
15.8
14.7
4t2029
440.0
193.8
396.9
56.4
6.1
52.0
65.7
5.9
1.8
12.3
35.9
42.4
12.0
21.2
41.2
7.2
1 9.1
17.7
5t2029
411.9
168.8
348.2
86.3
6.1
500
63.0
5.4
1.8
't3.4
35.4
34.2
12.0
20.4
34.6
7.5
17.6
17.7
6t2029
417.9
169.7
342.5
94.5
5.9
42.0
51.6
11.6
1.7
12.0
28.3
19.0
12.0
17.0
23.3
7.0
18. 1
16.2
7t2029
249.0
105.8
209.7
86.8
AO
34.9
36.2
10.4
1.7
12.1
22.5
6.4
12.0
12.7
10.7
AO
13.6
12.4
8t2029
159.2
72.8
143.4
oo. I
6.1
27.5
30.5
13.3
1.8
12.4
15.3
9t2029
205.8
93.9
I 84.5
42.0
6.2
35.9
42.7
8.8
1.8
13.0
22.2
10t2029
185.0
84.9
167.5
13.4
6.3
37.2
47.0
1.9
1.9
13.0
23.4
11t2029
145.0
66.1
132.O
12t2029
238.8
10'l .3
201.1
13.7
6.2
41.1
52.6
1.4
1.9
11 .4
27.4
19.3
12.0
17.4
21.7
6.4
17.3
16.0
aMw
286.2
123.5
247.8
44.0
6.1
40.7
50.9
55
'1.8
12.2
26.8
17 .1
'10.4
16.8
18.7
6.9
15.7
14.8
HCC Total
ROR Total
Total
658.6
324.5
983.1
787.8
333.4
1,121.2
808.6
260.1
1,068.7
1,030.7
396.9
1,427.6
928.8
405.3
1,334.1
930.1
350.3
1,290.4
564.5
285.5
850.0
375.4
214.1
589.5
484.1
226.8
710.9
437.4
200.2
637.6
343.1
185.4
528.5
541.2
265.8
807.0
557.5
288.2
945.7
'HCC=Hells Canyon Complex, -ROR= Run of River
Average Megawatt (aMW) 50rh Percentile Water, 50th Percentile Load
Resource
Bmwnlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
UpperSalmon 1&2
Upper Salmon 3&4
Type
HCC',
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2030
295.1
122.2
240.5
22.7
6.2
46.2
EOO
1.5
1.9
1 1.3
31.8
33.2
12.0
19.3
33.9
6.5
19.2
17.7
2t2030
343.8
148.2
294.4
24.8
6.3
465
61.5
IA
1.9
11.4
32.1
35.3
12.0
19.8
35.8
6.6
19.2
17.7
3/2030
341.0
154.6
312.1
21.1
6.1
38.9
528
2.5
'1.8
12.2
24.9
14.1
12.0
17.2
't7.5
7.0
15.7
14.6
4t2030
439.6
193.7
396.5
56.3
6.1
51.4
65.5
50
1.8
12.3
35.8
42.2
12.0
21.2
41.1
7.2
19.1
17.7
s/2030
411 .7
168.7
348.1
86.2
6.1
49.9
62.9
5.4
1.8
13.4
35.3
33.9
12.0
20.3
34.3
7.5
17.6
17.7
6/2030
417.0
169.3
341.8
94.5
5.9
41.8
51.3
1 1.6
1.7
12.O
28.1
18.7
12.0
16.9
23.1
70
18.0
16.2
7t2030
244.5
105.6
209.3
86.9
5.9
34.8
36.0
10.4
1.7
12.1
22.3
6.4
12.0
12.7
10.7
6.9
13.5
12.8
8/2030
158.7
72.6
143.0
66.0
6.'t
27.4
303
13.3
1.8
12.4
15.2
7.0
8.2
4.2
9/2030
204.2
93.2
182.8
41.9
6.2
35.8
42.5
8.8
1.8
13.0
22.O
7.2
13.2
12.5
10/2030
185.5
85.0
167.7
13.4
6.3
37.0
46.8
1.9
1.9
13.0
23.3
7.0
14.0
132
'11t2030
144.7
66.0
131 .8
6.2
35.3
45.6
1.4
1.9
1 1.5
21.5
'12t2030
238.5
101.2
200.9
13.0
6.2
40.3
51.7
1.4
'1.9
11.4
26.6
17.3
12.0
17.1
19.9
6.4
16.7
15.5
aMW
285.7
123.4
247.4
43.9
6.1
40.4
50.6
5.5
1.8
12.2
26.6
16.8
10.4
16.7
18.4
6.9
15.6
14.7
6.9
10.7
6.7
14.3
b.J
15.5
8.5
15.4
4.8
6.4
12.6
12.O
HCC Total
ROR Total
Total
657.8
323.2
981.0
786.4
332.4
1,1 1 8.8
807.7
258.5
1,066.2
1,029.8
39s.6
1,425.4
928.4
404.2
1,332.6
928.1
358.9
1,287.0
563.4
285.0
448.4
374.3
2',t3.4
587.7
480.1
225.9
706.0
438.2
199.5
637.7
342.5
183.2
525.7
540.6
257.4
798.0
656.4
286.4
942.9
'HCC=Hells Canyon Complex, *ROR= Run of River
Page 124 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 50th Percentile Water, 50th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
'1,000 Springs
BIiSS
C.J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
7.0
8.'r
8.2
7.2
1 3.1
12.4
7.0
13.9
13.'1
Type
HCC.
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2031
294.7
122.0
240.1
22.6
6.2
46.0
59.7
1.5
1.9
1 1.3
31.6
33.0
12.0
19.3
33.8
6.5
19.2
17.7
2t2031
343.1
147.9
293.8
24.7
6.3
46.4
61.3
1.5
1.9
11 .4
32.0
35.1
12.0
19.7
35.7
66
19.2
17.7
3t2031
342.7
155.3
313.6
21.0
6.1
387
52.3
2.5
1.8
12.2
24.9
14.0
12.0
17.2
17.3
7.0
15.6
14.6
4t2031
439.2
193.5
396.2
56.2
6.1
51.0
65.3
5.9
1.8
I Z.C
35.4
40.4
12.0
21.1
39.6
7.2
19.1
17.7
s/2031
411.3
168.5
347.8
86.1
6.1
49.8
62.8
5.4
1.8
13.4
35.2
33.6
12.0
20.3
34.0
7.5
17.6
17.7
6/2031
415.6
168.8
340.7
94.3
5.9
41.8
51.0
11.6
1.7
12.0
27.9
18.4
12.0
16.8
22.9
7.0
17.8
16.2
7t2031
248.0
105.4
208.9
86.8
5.9
34.7
35.9
10.4
1.7
12.1
22.2
6.4
12.0
12.7
10.7
6.9
13.5
12.7
8t2031
158.2
72.4
142.5
66.0
6. 1
27.2
30.2
13.3
1.8
12.4
15.0
6.9
10.6
9t2031
202.5
92.2
181 .1
41.8
6.2
35.6
42.2
8.8
1.8
13.0
21.4
1012031
''r85.4
84.8
167.4
13.4
6.3
36.9
46.5
1.9
1.9
13.0
23.1
11t2031
144.8
66.0
131.7
6.2
35.1
45.0
1.4
1.9
11.5
21.5
't2t2031
238.2
101 .0
200.6
11.7
6.2
39.3
50.4
1.4
1.9
11.4
25.7
14.9
12.0
16.7
17.8
6.4
16.0
14.9
aMW
285.3
123.2
247.0
43.7
6.'r
40.2
50.2
5.5
1.8
12.2
26.4
16.3
10.5
16.6
18. 1
6.9
15.5
14.6
6.7
14.3
6.3
15.4
9.5
15.2
5.8
6.4
12.7
12.0
HCC Total
ROR Total
Total
656.8
322.2
979.0
784.8
331.5
1,1 16.3
81 1.6
257.3
1,068.9
't,028.9
391.1
1,420.0
927.5
403.2
1,330.7
925.1
357.4
1,282.5
562.3
284.5
846.8
373.1
212.7
585.8
475.8
224.9
700.7
437.6
198.6
636.2
342.5
184.3
526.8
s39.8
246.7
786.5
655.5
284.s
940.0
'HCC=Hells Canyon Complex, -ROR= Run of River
Average Megawatt (aMW) 50th Percentile Water, 50rh Percentile Load
Resource
Brcwnlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 'l&2
Upper Salmon 3&4
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2032
294.3
121.9
239.8
22.5
6.2
45.9
59.4
1.5
1.9
11.3
31.5
32.8
12.O
19.2
33.7
6.5
19.2
17.7
2t2032
330.5
142.5
283.1
23.8
6.3
44.6
58.9
1.4
1.9
11 .4
30.7
11.6
19.0
34.3
6.6
18.5
17.1
3t2032
342.3
J IJ.Z
20.8
6.1
38.6
51.8
2.5
1.8
12.2
24.7
13.9
12.0
17 .1
17 .1
7.0
15.5
14.5
4t2032
438.7
193.3
395.8
56.0
61
50.9
65.0
5.9
1.8
12.3
35.2
39.3
12.0
21.1
38.5
7.2
19.1
17.7
5t2032
410.9
168.4
347.5
86.0
6.1
49.7
62.8
5.4
1.8
13.4
35.1
33.3
12.0
20.3
33.8
7.5
17.6
17.7
6t2032
414.5
168.3
339.8
94.2
5.9
41.8
50.7
11.6
1.7
12.0
27.7
18.2
12.0
16.7
22.5
7.0
't7.7
16.2
7t2032
247.5
105.2
208.5
86.8
EO
34.5
35.7
10.4
1.7
12.1
22.1
6.4
12.0
12.6
10.7
6.9
'13 4
12.6
8t2032
157.6
72.1
142 0
65.9
6.1
27.1
30.0
13.3
1.8
12.4
14.9
9t2032
200.5
91.2
179.1
41.7
6.2
35.4
42.0
8.8
1.8
13.0
21.6
10t2032
185.9
84.9
167.6
135
o.c
36.8
46.3
1.9
1.9
13.0
23.O
11t2032
145.2
66.1
132.O
12t2032
236.8
100.4
199.4
10.5
6.2
38.4
49.2
1.4
1.9
11.4
24.9
12.6
12.0
16.2
15.9
6.4
15.4
144
aMW
283.7
122.4
245 6
43.5
6.1
aoo
49.7
5.5
'1.8
12.2
26.1
15.8
10.4
16.5
17.7
6.9
15.3
14.4
7.0
8.0
8.1
6.2
34.9
44.9
1.4
1.9
11 .5
21.3
9.5
15.2
5.8
6.4
12.5
1 1.9
6.9
10.5
6.7
14.2
6.3
15.4
7.2
12.9
12.3
7.O
13.8
13.0
HCC Total
ROR Total
Total
656.0
321.2
977.2
756.1
319.8
1,075.9
810.6
255.7
1,066.3
1,027.8
388.r
1,4'15.9
926.7
402.4
1,329.1
922.6
3s6.0
1,278.6
56'1.2
283.7
8t14.9
371.7
211.9
583.6
470.8
223.A
694.6
438.4
t98.1
636.s
343.3
183.s
s26.8
536.6
236.8
773.4
551.8
281.7
933.6
"HCC=Hells Canyon Complex, '*ROR= Run of River
2017 lntegrated Resource Plan-Appendix C Page 125
Existing Resource Data ldaho Power Company
Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 50th Percentile Water,50th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
Type
HCC.
HCC
HCC
ROR
ROR"
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2033
293.9
121.7
239.5
22.3
6.2
45.7
59.'1
1.5
1.9
1 1.3
31.4
32.7
12.0
1 9.1
33.6
6.5
19.2
17.7
2t2033
341 .6
147.3
292.6
24.5
6.3
46.0
60.1
1.5
1.9
11 .4
31.7
34.8
12.0
19.4
35.4
6.6
19.2
17.7
3/2033
341.7
154.9
312.8
20.7
6.1
38.5
51.4
2.5
1.8
12.2
24.5
13.5
12.0
16.9
16.9
7.0
15.4
14.4
4t2033
438.3
1 93.1
395.4
54.1
6.1
50.7
64.1
^o
1.8
12.3
35.1
39.1
12.0
20.8
38.4
7.2
19.1
17.7
5/2033
410.4
168.2
347.1
85.9
6.1
49.6
62.7
5.4
1.8
13.4
35.0
32.9
12.0
20.3
33.5
7.5
17.6
17.7
6/2033
413.7
168.0
339.2
94.0
5.9
41.8
50.4
1 1.6
1.7
12.0
27.5
17.7
'12.0
16.4
21.4
7.0
17.5
16.2
7t2033
247.0
105.0
208.1
86.7
(o
34.4
35.5
10.4
1.7
12.1
22.0
6.4
12.0
12.5
10.7
6.9
13.3
12.6
8/2033
157 .1
71.9
141.6
65.8
6.1
26.9
29.8
13.3
1.8
12.4
14.8
6.9
10.5
7.0
7.9
8.0
9/2033
1 99.1
90.5
177.7
41.6
o.z
35.2
41.7
8.8
1.8
13.0
21.5
6.7
14.1
12.8
12.1
10/2033
186.1
84.9
167.6
13.2
6.3
36.6
46.1
1.9
1.9
13.0
22.8
6.3
15.3
7.0
13.6
12.9
1112033
145.0
66.0
131 .8
12t2033
235.6
99.9
198.4
9.1
6.2
374
47.8
1.4
1.9
11.4
24.0
10.8
12.0
15.8
13.7
6.4
14.7
13.8
aMW
284.1
122.6
246.0
43.2
6.1
39.8
49.5
5.5
1.8
12.2
26.0
15.7
10.5
16.4
17.5
6.9
15.2
14.4
o.2
34.8
44.8
1.4
1.9
11 .5
21.2
o(
15.2
5.8
6.4
12.4
1 1.8
HCC Total
ROR Total
Total
655.1
320.1
975.2
781.5
328.5
1,110.0
809.4
2s3.9
1,053.3
1,026.8
384.4
1,411 .2
925.6
401.3
1,326.9
920.9
3s3.2
1,274.1
s60.1
283.0
843.1
370.6
211.1
581.7
467.2
222.7
689.9
438.6
196.8
635.4
342.8
183.0
525.8
s33.9
226.4
760.3
652.7
280.4
933.1
'HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawaft (aMW) 50th Percentile Water, 50th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
69
10.4
7.0
7.8
7.9
6.7
14_1
7.2
12.7
12.0
6.3
15.2
7.0
13.5
12.8
9.4
15.1
5.7
6.4
't2.4
11.8
Type
HCC.
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2034
293.2
121.4
239.0
22.2
o.2
45.5
58.9
1.5
1.9
11.3
31.3
32.6
12.0
19.0
33.5
6.5
19.2
17.7
2t2034
340.9
147.0
292.0
24.4
6.3
45.8
59.9
1.5
1.9
11.4
31.5
34.6
12.0
19.4
35.2
6.6
19.2
17.7
3t2034
341.1
154.6
312.2
20.5
6.1
38.4
51 .1
2.5
'1.8
12.2
24.3
13.3
12.0
16.8
16.4
7.0
15.2
14.2
4t2034
437.8
192.9
395.0
53.8
6.1
50.5
63.2
5.9
1.8
I Z.C
35.0
38.9
12.0
20.3
38.2
7.2
1 9.1
17.7
5t2034
409.9
168.0
346.7
85.7
6.1
49.5
62.6
5.4
1.8
13.4
34.9
32.6
12.0
20.3
33.4
7.5
176
17.7
6/2034
412.8
167.7
338.5
93.8
5.9
41.8
50.1
1 1.6
1.7
12.0
27.3
17.2
12.0
16.4
21.3
7.0
17.4
16.1
7t2034
246.5
104.8
207.7
86.7
5.9
34.3
35.4
10.4
1.7
12.1
21.9
6.4
12.0
12.5
10.7
6.9
13.2
12.5
8t2034
156.6
71.6
141.2
65.7
6.1
26.8
29.6
13.3
1.8
12.4
14.7
9t2034
197.2
89.4
175.7
41.5
6.2
35.0
41.5
8.8
1.8
13.0
21.3
10t2034
186.7
85.0
167.8
13.2
b.5
36.4
45.8
1.9
1.9
13.0
22.6
11t2034
145.1
66.0
131 .8
6.2
34.6
44.6
't.4
1.9
1 1.5
21.2
12t2034
234.4
99.4
197.4
7.7
6.2
36.6
46.9
1.4
1.9
11 .4
23.7
8.7
12.0
15.6
11.6
6.4
14.5
13.6
aMW
283.5
122.3
245.4
42.9
61
39.6
49.1
5.5
1.8
12.2
25.8
15.4
10.4
16.3
't7.2
6.9
15.2
14.3
HCC Total
ROR Total
Total
653.6
3r9.2
972.8
779.9
327.4
'1,107.3
807.9
251.9
1,059.8
1,02s.7
382.0
1,407.7
924.5
400.4
1,324.9
919.0
35{.7
1,270.7
559.0
282.5
841.5
369.4
210.3
579.7
462.3
221.8
684.1
439.5
19s.8
63s.3
342.9
't82.3
525.2
531.2
218.2
749.4
6s1.2
278.6
929.9
*HCC=Hells Canyon Complex, "ROR= Run of River
Page 126 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Modeling Results (PDR580) (continued)
Average Megawatt (alrw) 50th Percentile Water, 50th Percentile Load
Resource
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2035
292.4
121.1
238.3
22.0
6.2
45.3
58.6
1.5
'1.9
11.s
31.2
32.5
12.0
18.9
33.4
6.5
19.2
17.7
2t2035
340.1
146.7
29',t.4
24.2
6.3
45.6
59.6
1.5
1.9
't't.4
31.3
34.4
't2.0
19.3
35.0
6.6
19.2
17.7
31203s
340.4
1U.3
311.6
20.0
6.1
38.0
50.8
2.5
'1.8
12.2
24.1
12.8
12.0
16.5
15.7
7.O
15.1
14.1
4t2035
437.2
't 92.6
394.4
53.7
6.1
49.8
62.6
5.9
1.8
12.3
34.7
37.7
12.0
20.1
37.2
7.2
19.1
17.7
5/2035
408.0
167.2
345.1
85.6
6.'l
49.4
62.5
5.4
1.8
13.4
34.8
32.3
12.0
20.2
33.2
7.5
17.6
17.7
6/2035
411.9
167.3
337.9
93.6
5.9
41.6
49.8
11.6
1.7
't2.0
27.3
16.8
12.0
16.3
21.1
7.0
17.3
16.0
7t2035
246.1
104.6
207.3
86.7
5.9
34.2
35.2
10.4
1.7
12.1
21.8
6.4
12.0
12.4
't0.7
6.9
13.1
12.4
8/2035
156.2
71.4
140.7
65.7
6.1
26.6
29.4
13.3
1.8
12.4
14.5
6.9
10.4
7.O
7.7
7.A
9/2035
195.0
88.3
173.5
41.4
6.2
34.8
41.3
8.8
1.8
13.0
21.1
6.7
14.1
7.2
12.5
11.9
l0/2035
't87.0
85.0
167.8
't3.2
6.3
36.1
45.6
'1.9
1.9
't 3.0
22.5
6.3
15.4
7.O
13.4
12.7
11t2035
145.7
66.2
132.2
6.2
34.4
44.1
1.4
1.9
't't.5
21.1
9.4
15.1
5.7
6.4
12.3
11.7
12t203s
233.2
98.9
196.4
6.2
6.2
36.3
46.3
1.4
1.9
11.4
24.7
6.5
12.0
'15.6
10.4
6.4
14.5
13.6
amW
282.8
122.0
244.7
42_7
6.1
39.3
48.8
5.5
1.8
12.2
25.7
15.0
10.4
16.2
'16.9
6.9
15.1
14.3
HCC Total
ROR Total
Total
651.8
318.1
969.9
778.2
326.0
1,104.2
806.3
24a.8
1,055.1
1,024.2
377.9
1,402.1
920.2
399.4
1,319.6
917.1
350.1
1,267.2
558.0
281.8
839.8
368.3
209.5
577.8
456.7
220.8
677.s
439.8
195.2
G35.0
34c.1
181.3
525.4
528.5
212.4
740.9
649.4
276.8
926.2
'HCC=Hells Canyon Complex, *ROR= Run of River
Average lregawatt (aMf,U 50th Percentile Water, 50th Percentile Load
Resource
American Falls
1,000 Springs
Bliss
C.J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
t/2036
291.5
120.7
237.6
21.7
6.2
45.1
58.3
1.5
1.9
1 1.3
31.0
32.1
12.0
18.9
33.1
6.5
19.2
17.7
a2036
326.6
140.9
279.8
23.3
6.3
43.9
57.2
1.4
1.9
11.4
30.1
33.0
11.6
18.4
33.7
6.6
18.5
17.1
3/2036
339.6
1s3.8
310.7
19.8
6.1
37.8
50.5
2.5
1.8
12.2
23.9
12.3
12.0
16.4
15.3
7.0
't4.9
14.0
4t2036
437.',|
192.3
393.8
5s.5
6.1
49.6
62.3
5.9
1.8
12.3
34.4
36.9
12.0
20.1
36.4
7.2
19.1
17.7
5/2036
407.1
r 66.8
344.4
84.4
6.1
49.2
62.4
5.4
1.8
13.4
33.9
30.3
12.0
20.2
31.6
7.5
17.6
17.7
612036
411.0
167.0
337.2
93.3
5.9
41.1
49.5
11.6
1.7
12.0
26.9
16.5
12.0
16.2
20.5
7.0
't7.o
15.8
7t2036
245.6
104.3
206.9
86.7
5.9
34.0
35.1
10.4
1.7
12.1
2',t.7
6.4
12.O
12.4
't0.7
6.9
13.0
12.3
8/2036
155.6
71.2
140.2
65.7
6.1
26.5
29.2
'13.3
1.8
12.4
14.4
6.9
10.3
7.O
7.6
7.7
9/2036
193.9
87.7
172.3
41.3
6.2
34.6
41.',|
8.8
1.8
13.0
20.9
6.7
14.O
7.2
't2.4
1 1.8
't0/2036
187.2
85.0
167.7
13.',|
6.3
35.9
45.4
1.9
1.9
13.0
22.3
6.3
15.3
7.O
13.3
12.6
11t2036
145.7
66.2
132.1
6.2
34.3
44.0
1.4
1.9
11.5
20.8
9.4
't 5.1
5.7
6.4
12.'l
1 1.6
12t2036
233.2
98.9
196.4
6.2
36.3
46.1
1.4
1.9
11.4
23.7
6.1
12.0
15.6
10.4
6.4
14.5
13.6
aMW
281.2
121.2
243.3
41.9
6.1
39.0
48.4
5.5
1.8
12.2
25.3
14.5
10.4
16. 1
16.4
6.9
14.9
14.1
HCC Total
ROR Total
Total
649.8
3{6.4
966.2
747.3
314.5
{,061.8
804.1
2t16.6
1,050.7
1,023.2
375.3
r,398.5
918.2
393.4
1,31t.6
91s.2
3{r.'l
1,262.3
556.8
281.2
838.0
367.0
208.8
575.8
/t53.9
219.8
673.6
/l:}9.9
194.2
634.1
34J.O
180.5
524.5
528.5
205.6
734.1
645.7
273-6
9{9.3
'HCC=Hells Canyon Complex, "ROR= Run of River
2017 lntegrated Resource Plan-Appendix C Page 127
Existing Resource Data ldaho Power Company
Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2017
257.2
108.9
215.6
2t2017
286.1
121.3
239.8
5.5
6.3
37.4
49.4
1.4
1.9
11 .4
23.0
6.1
12.0
16.0
9.8
b.b
14.1
13.3
3t2017
251.4
111.6
227.7
11.2
6.1
s5.9
47.7
1.3
1.8
12.2
21.9
J_b
12.0
15.8
8.1
7.0
13.4
12.6
4t2017
3'19.5
135.3
274.O
38.4
6.1
38.5
51.6
1.2
1.8
12.3
24.5
11 .4
12.0
17 .1
14.3
7.2
15.4
14.4
5t2017
385.2
159.8
324.5
73.8
6.1
41.5
49.1
2.1
1.8
13.4
27.8
14.4
12.0
16.2
17.8
7.5
17 .7
16.6
6t2017
258.9
108.8
223.1
90.9
5.9
38.9
44.7
7.1
1.7
12.0
27.0
14.7
12.0
15. 1
18.2
7.0
17.1
15.8
7t2017
237.4
100.5
198.2
87.2
(o
35.0
35.6
7.4
1.7
12.1
22.6
6.4
12.0
126
10.7
6.9
13.8
13.0
8t2017
155.6
71.1
139.8
63.0
6.1
27.9
30.8
12.0
'1.8
12.4
15 8
9t2017
175.9
80.0
156.9
35.9
6.2
36.7
43.6
7.3
1.8
13.0
23.1
10t2017
1 90.1
84.7
167.0
10.3
6.3
aaa
47.0
1.5
1.9
13.0
23.8
11t2017
148.0
66.4
132.2
6.2
35.2
45.4
1.3
1.9
1 1.5
22.2
12t2017
200.6
84.6
167.8
6.2
35.4
45.4
1.4
.1.9
11.4
22.2
1.8
9.9
15.3
6.2
6.4
13.3
12.6
aMW
238.8
102.7
205.5
34.7
6.1
JO.J
44.8
3.8
'1.8
12.2
23.'l
5.3
10.1
15.0
8.2
6.9
14.1
13.3
6.2
36.4
47.4
1.5
1.9
1 1.3
22.8
4.8
12.0
15.5
8.9
6.5
13.8
13.0
6.9
10.8
7.3
15.3
3.8
6.4
13.2
12.5
6.7
147
6.3
15.6
7.0
8.7
8.6
7.0
14.4
13.6
7.2
14.1
13.2
HCC Total
ROR Total
Total
581.7
201.9
783.6
647.2
214.2
861.4
590.7
210.7
801.4
728.8
266.2
995.0
869.5
317.7
1,187 .2
590.8
328.2
919.0
536.1
282.8
818.9
366.5
211.7
578.2
412.7
223.s
636.2
441.8
197.9
639.7
346.6
182.3
528.9
453.0
189.4
642.4
547.1
235.5
782.7
*HCC=Hells Canyon Complex, "ROR= Run of River
Average Megawatt (aMW) 70th Percentilo Water, 70th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
7.0
14.5
13.6
6.4
'13. 1
12.4
6.2
35.3
45.2
1.3
1.9
11.5
22.1
6.6
15.3
6.2
35.3
45.5
1.4
1.9
1'.1.4
22.2
9.4
15.2
5.7
6.4
13.3
12.6
Type
HCC.
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2018
249.6
106.1
210.2
62
36.4
47.5
1.4
1.9
11.3
22.8
4.3
12.0
15.5
8.8
6.5
13.8
13.0
2t2018
296.3
125.6
248.2
11.0
6.3
38.6
50.3
1.4
1.9
11.4
25.3
'13.3
12.0
16.2
16.0
b.b
15.9
14.8
3t2018
252.8
112.3
229.0
13.I
o. I
Jb- /
48.2
1.3
1.8
12.2
22.6
5.0
12.0
15.8
9.2
7.0
13.9
1 3.1
4t2018
324.7
137.6
278.4
40.8
6.1
41.6
52.8
1.2
1.8
12.3
25.6
13.6
12.0
17.4
16.8
7.2
16.3
1 5.1
5/2018
384.9
159.8
324.4
73.8
6.1
42.0
49.5
2.1
1.8
13.4
28.2
15.4
12.0
16.5
18. 1
7.5
17.7
16.8
6/2018
264.9
111.4
228.0
9'1.4
5.9
39.1
45.2
7.1
1.7
12.0
27.2
15.4
12.0
15.3
18.7
7.0
17.2
16.0
7t2018
237.0
100.4
197.9
87.2
5.9
35.'l
35.7
7.4
1.7
12.1
22.7
6.4
12.0
12.7
10.7
6.9
13.8
13.0
8t20't8
1 55.1
70.9
139.3
63.7
6.1
27.9
3'1.0
12.0
1.8
12.4
15.8
6.9
10.8
7.0
8.7
8.6
9/2018
176.1
80.0
157.0
36.3
6.2
JO6
43.6
7.3
1.8
13.0
23.1
6.7
14.7
't012018
189.9
84.7
166.9
10.3
OJ
J/ J
47.1
1.5
1.9
13.0
23.9
6.3
15.6
11t20',t8
147.7
66.3
132.0
12t2018
205.0
86.4
171.4
aMW
289.5
125.0
250.5
43.6
6.'r
41.6
52.0
5.5
1.8
12.2
27.6
16.8
10.5
17 .1
18.8
6.9
16.2
15.1
7.2
14.1
13.2
HCC Total
ROR Total
Total
565.9
201.3
767.2
670.'t
241.0
911.1
594.1
218.9
813.0
740.7
280.6
1,021.3
869.1
320.8
1,'t 89.9
604.3
331.3
93s.6
535.3
283.2
818.s
36s.3
212.6
577.9
413.1
224.0
637.1
4{1.5
't98.2
639.7
346.0
177.4
523.4
462.8
't86.5
649.3
66s.0
29't.7
956.6
'HCC=Hells Canyon Complex, '*ROR= Run of River
Page 128 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource
Brownlee
O)6o,i,
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
7.0
8.7
8.7
7.0
14.5
13.6
6.4
12.8
12.2
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2019
247.0
1 05.1
208.1
6.2
36.0
46.6
1.4
1.9
11.3
22.2
2.6
11.2
15.3
7.3
6.5
13.4
12.6
2t2019
296.0
125.5
248.0
14.2
6.3
38.9
51.5
1.4
1.9
11 .4
25.9
16.1
12.0
16.4
17.8
6.6
16.3
15.2
312019
250.8
1 1'1 .5
227.4
t? o
6.1
36.8
47.6
1.3
1.8
12.2
22.2
J.O
12.0
15.7
8.3
7.0
13.6
12.8
4t2019
325.1
137.8
278.9
40.0
6.1
41.5
53.4
1.2
'1.8
12.3
26.2
15.3
12.0
17.6
18.2
7.2
16.7
15.5
5/2019
386.3
1 60.3
325.5
73.9
6.1
42.3
50.3
2.1
1.8
13.4
28.4
15.4
12.0
16.7
18.2
7.5
17.7
17.0
6t2019
269.2
113.2
231 .5
91.5
5.9
39.1
45.3
7.1
1.7
12.0
27.2
15.4
12.0
15.4
18.9
7.0
17.2
16.0
7t2019
237.3
100.5
198 2
87.5
5.9
35.1
35.8
7.4
1.7
12.1
22.7
6.4
12.0
127
10.7
6.9
13.8
13.0
8/2019
155.2
70.9
139.5
64.0
6.1
27.9
31.0
12.0
1.8
12.4
15.8
6.9
10.9
9/2019
173.8
78.8
154.6
36.7
6.2
36.8
43.6
7.3
1.8
13.0
23.1
6.7
14.6
t0/20t9
191 .0
84.9
167.4
'10.4
o.J
37.3
47.1
1.5
1.9
13.0
23.9
6.3
15.6
't'U20,t9
147.7
66.2
131 .9
6.2
34.7
44.8
1.3
1.9
1 1.5
21.7
5.4
15.2
't2t2019
203.3
85.7
170.0
6.2
34.7
45.1
1.4
1.9
11.4
21.7
8.3
15.3
4.5
6.4
12.9
12.2
aMW
240.2
103.4
206.8
36.0
6.1
36.8
45.2
3.8
1.8
12.2
23.4
6.2
9.7
1 5.1
8.7
6.9
14.3
13.5
7.2
14.0
13.2
HCC Total
ROR Total
Total
560.2
194.4
754.6
669.s
251.9
921.4
589.7
21s.O
804.7
741.8
285.0
1,026.8
872.1
322.7
1,194.8
613.9
331.8
945.7
536.0
283.6
819.6
365.6
213.',|
578.7
407.2
224.2
631.4
443.3
198.3
641.6
345.8
174.2
520.0
459.0
't82.O
641.0
550.3
239.7
790.0
'HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 7oth Percentile Water, 7oth Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
HCC-
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2020
247.2
105.1
208.2
2t2020
296.0
125.5
248.0
14.8
O,J
39.3
51.5
1.4
1.9
11 .4
26.0
17.3
12.0
16.5
18.8
6.6
16.4
15.3
3t2020
250.8
111 5
227.5
13.9
6.1
36.9
47.7
1.3
1.8
12.2
22.2
50
12.0
15.8
8.3
7.0
13.6
128
4t2020
325.2
137.9
279.0
40.3
6.1
41.6
53.5
1.2
1.8
I Z.C
26.3
15.5
12.0
17.6
18.4
7.2
16.8
15.6
5t2020
387.4
160.8
326.3
73.9
6.1
42.4
50.5
2.1
1.8
13.4
28.4
15.4
12.0
16.8
18.2
7.5
17.7
17.0
6t2020
269.5
1 13.3
231 .8
91.5
5.9
39.1
45.2
7.1
1.7
12.0
27.1
15.4
12.0
15.4
19.2
7.0
17.2
15.9
7t2020
237.1
100.4
1 98.1
87.5
AO
35.1
35.8
7.4
1.7
12.1
22.7
6.4
12.0
12.7
10.7
6.9
13.8
13.0
8t2020
155.0
70.8
139.3
64.0
6.1
)ao
31.0
12.0
1.8
12.4
15.8
6.9
10.8
9t2020
173.5
78.6
154.3
36.7
6.2
36.7
43.4
1.8
'13.0
23.0
6.7
14.6
,1ot2020
190.9
84.9
167.3
10.4
o.c
37.3
47.O
1.5
1.9
13.0
23.8
o.c
15.6
11t2020
147.6
66.2
131 .8
12t2020
203.9
86.0
170.5
aMW
240.3
103.4
206.8
36.1
6.1
36.8
45.2
3.8
1.8
12.2
23.4
6.4
9.7
1 5.1
88
6.9
14.3
13.5
oz
36.0
46.6
1.4
1.9
11.3
22.2
2.6
11.2
15.3
7.3
6.5
13.4
12.6
6.2
34.6
44.8
1.3
1.9
1 1.5
21.7
5.4
15.2
o_l
34.7
45.1
1.4
1.9
11.4
21.7
8.3
15.3
4.5
6.4
12.9
12.2
7.0
8.7
8.6
7.2
13.9
1 3.1
7.0
14.4
13.6
6.4
12.8
12.1
HCC Total
ROR Total
Total
560.5
194.4
754.9
669.s
255.5
925.0
589.8
21s.3
80s.1
742.1
286.2
1,028.3
874.5
323.'.|
1,197.6
614.6
331.8
946.4
535.6
283.6
a19.2
365.1
212.9
578.0
406.4
223.6
829.9
443.1
198.0
641.1
345.6
174.O
5't9.6
460.4
182.0
642.4
550.6
240.0
790.6
'HCC=Hells Canyon Complex, *ROR= Run of River
2017 lntegrated Resource Plan-Appendix C Page 129
Existing Resource Data ldaho Power Company
Hydro Modeling Results (PDR580) (continued)
Average Megawaft (aMW) 70th Percentile Water, 70th Percentile Load
Resource
Brownlee
Oxbow
Hells Ganyon
Americen Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
Type
HCC-
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2021
246.1
104.7
207.3
2t2021
295.1
125.2
247.3
15.0
b.J
39.0
51.1
1.4
1.9
11.4
25.3
16.2
12.0
16.3
17.9
6.6
15.9
14.8
3t2021
250.9
111.6
227.6
t2 0
6.1
Jbb
47.5
1.3
1.8
12.2
22.0
3.5
11.4
15.7
7.4
7.0
13.4
12.7
4t2021
326.1
138.3
279.7
40.8
6.1
41.8
53.8
1.2
1.8
12.3
26.4
15.6
12.0
17.7
18.5
7.2
16.9
15.7
5t2021
386.7
160.5
325.9
739
6.1
42.5
50.6
2.1
'1.8
13.4
28.6
15.4
12.0
16.8
18.2
7.5
17.7
17 .1
6t202'.|
268.5
112.9
231.0
91.5
5.9
39.1
45.2
7.1
1.7
12.0
27.1
15.4
12.0
15.3
18.9
7.0
17.2
15.9
7t2021
237.1
100.4
''t98.1
87.5
5.9
35.1
35.8
7.4
1.7
12.1
22.7
6.4
12.0
12.7
10.7
6.9
13.8
13.0
8t2021
154.9
70.8
139.2
63.9
6.1
27.9
30.9
12.0
1.8
12.4
15.7
69
10.8
7.0
8.6
8.6
9t2021
172.2
78.1
I 53.1
36.6
6.2
36.6
43.3
7.3
1.8
13.0
22.9
6.7
14.6
72
13.9
13.1
10t2021
191.1
84.9
167.3
10.4
6.3
37.2
46.9
1.5
1.9
13.0
23.8
6.3
15.5
70
14.4
13.5
11t2021
147.8
66.2
131 .9
12t2021
202.8
85.5
169.6
aMW
239.9
103.3
206.5
36.1
6.1
36.7
45.1
3.8
1.8
12.2
23.3
6.2
9.6
15.1
8.5
6.9
14.2
13.4
6.2
35.8
46.3
1.4
1.9
11.3
22.0
1.7
1 0.1
15.4
o.J
6.5
13.2
12.5
6.2
34.6
44.7
1.3
1.9
11.5
21.6
5.4
15.2
6.4
12.7
12.1
6.2
34.4
45.0
1.4
1.9
11.4
21.4
7.9
15.2
4.2
6.4
12.6
12.0
HCC Total
ROR Total
Total
ss8.,l
190.5
748.6
667.6
251.1
918.7
590.r
212.6
802.7
744.1
287.8
1,031.9
873.1
323.6
1,196.7
612.4
331.4
943.8
535.6
283.6
8'.t9.2
364.9
212.s
577.4
403.4
223.2
626.s
4/3.3
197.6
640.9
345.9
173.7
519.6
457.9
r80.0
637.9
549.7
239.0
788.7
'HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource
Brownlee
Oxbonr
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
Type
HCC.
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2022
247.9
105.4
208.8
2t2022
296.4
125.7
248.4
12.0
6.3
39.2
51.6
1.4
.1.9
11 .4
25.3
'13.5
12.0
16.7
16.4
6.6
15.9
14.8
3t2022
251.0
111.6
227.6
13.7
6.1
36.3
47.4
1.3
1.8
12.2
22.1
3.4
11.2
15.7
7.3
7.0
13.5
12.8
4t2022
317.6
134.8
272.9
38.0
6.1
37.2
50.9
1.2
1.8
12.3
22.9
5.1
12.0
16.9
8.8
7.2
14.2
13.4
5t2022
386.9
160.6
325.9
74.3
6.1
42.3
50.7
2.1
1.8
13.4
28.6
15.4
12.0
16.9
18.2
7.5
17.7
17.2
6t2022
253.3
110.7
226.7
91.5
5.9
39.0
45.1
7.1
1.7
12.0
27.0
15.4
12.0
15.3
18.9
7.0
17.2
15.9
7t2022
236.9
100.3
197.9
87.4
5.9
35.0
35.7
7.4
1.7
12.1
zzo
6.4
12.0
12.7
10.7
6.9
13.7
12.9
8t2022
154.7
70.7
't 38.9
63.9
o. I
278
30.8
12.0
1.8
12.4
15.6
9t2022
172.1
77.5
153.0
30.2
6.2
36.5
43.1
7.3
1.8
13.0
22.7
10t2022
190.7
84.7
167.0
10.3
o.J
37.2
46.8
1.5
1.9
13.0
23.7
11t2022
148.0
66.3
132.1
6.2
34.7
44.6
1.3
1.9
1 1.5
21.6
12t2022
204.0
86.0
170.7
6.2
34.9
45.3
1.4
1.9
11 .4
21.8
aMW
239.1
102.9
205.8
35.6
6.1
36.4
44.9
3.8
'1.8
12.2
23.0
5.2
9.7
1 5.1
7.7
6.9
14.0
13.3
o_z
JO. I
469
1.4
1.9
11.3
22.4
3.2
11.7
15.4
7.7
6.5
13.5
12.7
6.9
10.8
7.O
8.6
8.5
6.7
14.5
7.2
13.8
13.0
6.3
15.5
7.0
14.3
13.4
5.4
15.2
6.4
12.7
12.1
8.7
15.3
4.9
6.4
13.0
12.3
HCC Total
ROR Total
Total
562.1
196.8
758.9
670.5
245.O
915.5
590.2
211.9
802.1
725.3
248.O
973.3
873.4
324.'.|
1,197.4
600.7
331.1
931.8
535.'l
283.0
818.1
364.3
212.1
576.4
403.0
222.0
624.9
&2.4
197.1
639.5
346.4
173.7
520.1
460.7
't83.s
64/.2
5,7.8
235.7
783.5
"HCC=Hells Canyon Complex, *ROR= Run of River
Page '130 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Hydro Modeling Results (PDR580) (continued)
Average Megawaft (aMW) 70th Percentile Water, 70th Percentile Load
Resource
Brownlee
O$ow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
Type
HCC-
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2023
247.7
105.3
208.6
6.2
36.1
46.8
1.4
'1.9
tl.c
22.3
3.2
11.7
15.4
7.7
6.5
13.5
12.7
2t2023
296.1
125.6
248.0
11.6
6.3
39.3
51.4
1.4
1.9
't1.4
25.4
13.0
12.0
16.8
16.4
6.6
16.0
14.9
3t2023
250 8
111 .4
227.4
13.7
6.1
36.2
473
1.3
1.8
12.2
22.0
3.3
11.2
15.7
7.3
7.0
13.5
12.7
4t2023
317.6
134.7
272.7
38.4
6.1
5t.2
51.0
1.2
1.8
12.3
22.9
5.0
12.0
16.9
8.7
7.2
14.2
13.3
st2023
387.5
160.8
326.4
74.3
6.1
42.4
50.7
2.1
1.8
13.4
28.7
15.4
12.0
16.9
18.2
7.5
17.7
17.2
6t2023
262.9
1 10.5
226.4
91.5
5.9
38.9
45.0
7.1
1.7
12.0
26.9
15.4
12.0
15.2
18.9
7.0
17 .1
15.8
7t2023
236.6
100.2
197.6
87.4
AO
35.0
35.6
7.4
1.7
12.1
22.5
6.4
12.0
12.6
10.7
6.9
13.7
12.9
812023
154.3
70.5
138.6
63.9
6.1
27.7
30.7
12.0
'1.8
12.4
15.5
6.9
10.7
7.0
8.5
8.5
9t2023
167.1
77.3
151 .5
36.1
6.2
36.3
42.9
t.3
1.8
13.0
22.6
6.7
14.5
7.2
'13.7
12.9
10t2023
190.8
84.7
167.0
10.3
o_J
37.1
46.7
1.5
1.9
13.0
23.6
O,J
'15.5
7.0
14.2
13.4
11t2023
1 48.3
66.4
132.3
12t2023
203.1
85.7
1 69.9
aMW
238.6
102.8
205.5
35.6
6.1
50.5
44.8
3.8
1.8
12.2
23.0
5.1
9.7
15.1
7.7
6.9
14.0
13.2
o.z
34.6
44.5
1.3
1.9
11 .5
21.5
5.4
15.2
6.4
12.7
12.0
6.2
34.8
45.2
1.4
1.9
11 .4
21.7
8.7
15.3
4.9
6.4
12.9
12.3
HCC Total
ROR Total
Total
s61.6
196.6
758.2
669.7
244.4
9'14.1
589.6
211.4
801.0
725.O
248.2
973.2
874.7
324.3
1,199.0
599.8
330.5
930.3
534.4
282.7
817.1
363.4
211.6
575.0
395.8
22',t.2
617.0
4/.2.5
196.7
639.2
347.0
173.3
520.3
458.7
183.1
641.8
546.9
235.3
782.2
'HCC=Hells Canyon Complex, -ROR= Run of River
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource
Bownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 'l&2
Upper Salmon 3&4
6.9
10.7
7.0
8.4
8.4
o. /
14.4
7.2
13.5
12.8
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2024
247.4
105.2
208.4
oz
36.1
46.7
1.4
1.9
11.3
22.3
3.2
11.7
15.3
6.5
13.4
12.7
212024
295 8
125.4
247.8
10.8
A2
38.9
50.8
1.4
1.9
11.4
25.0
12.5
12.0
16.4
16.4
6.6
15.7
14.6
3t2024
250.5
111.3
227.1
13.6
6.1
36.1
47.2
1.3
1.8
12.2
21.9
3.2
11.2
15.6
7.0
13.4
126
4t2024
317.4
134.6
272.6
38.6
6.1
37.1
51.0
1.2
1.8
12.3
22.8
5.0
12.0
16.9
8.6
7.2
14.1
13.3
5t2024
387.7
160.9
326.6
74.3
6.1
42.4
50.7
2.1
1.8
13.4
28.7
15.4
12.0
16.9
18.2
7.5
17.7
17.2
612024
262.4
1 '10.3
226.0
91.5
5.9
38.8
44.8
7.1
1.7
12.0
26.8
15.4
12.0
15.2
18.9
7.0
17.0
15.8
7t2024
236.2
1 00.1
197.3
87.3
59
34.9
35.5
7.4
1.7
12.1
22.4
6.4
12.0
12.6
10.7
6.9
13.6
12.8
8t2024
153.9
70.3
138.3
oJ. /
o.,
27.6
30.5
12.0
1.8
12.4
15.4
9t2024
165.7
76.5
'150.0
36.1
o.z
36.1
42.7
7.3
1.8
13.0
22.5
10t2024
191 .1
84.8
167.1
10.3
o.J
37.0
46.5
1.5
'1.9
13.0
23.4
o.c
'15.4
7.0
14.1
13.3
11t2024
147.9
oo.z
131 .9
6.2
34.5
44.3
1.3
1.9
11.5
21.4
5.4
15.2
6.4
I t.o
12.0
12t2024
202.1
85.2
1 69.1
6.2
34.7
45.1
1.4
1.9
11.4
21.6
8.7
15.3
4.9
6.4
12.9
12.2
aMW
238.2
102 6
205.2
35.5
6.1
JO.Z
44.7
3.8
1.8
12.2
22.9
5.1
9.7
15.0
6.9
13.9
13.1
HCC Total
ROR Total
Total
561.0
196.3
757.3
669.0
240.7
909.7
s88.9
210.6
799.5
724.G
248.0
972.6
875.2
324.3
t,199.5
598.7
330.0
928.7
533.6
282.1
815.7
362.5
210.8
573.3
392.2
220.3
612.5
443.0
t95.9
638.9
346.0
172.8
s't8.8
456.4
182.7
639.1
545.9
234.5
780.5
'HCC=Hells Canyon Complex, -ROR= Run of River
2017 lntegrated Resource Plan-Appendix C Page 131
Existing Resource Data ldaho Power Company
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, Toih Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
BIiSS
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
Type
HCC-
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2025
247.1
1 05.1
208.1
6.2
36.0
466
1.4
1.9
11.3
22.2
3.2
11.7
15.3
7.7
6.5
13.3
12.6
2t202s
295.6
125.3
247.6
10.5
6.3
38.2
50.4
1.4
1.9
11.4
24.8
12.3
12.0
16.2
16.1
6.6
15.5
14.5
3t202s
249.8
111.0
226.5
13.5
6.1
36.0
47.1
1.3
1.8
12.2
21.9
3.1
11.2
15.6
7.3
13.4
12.6
4t2025
317.4
134.6
272.6
387
6.1
37.1
50.9
1.2
1.8
12.3
22.8
4.9
12.0
16.9
8.4
7.2
14.1
iJ.J
5t2025
387.8
160.9
326.6
74.3
6.1
42.4
50.6
2.1
1.8
13.4
28.7
15.4
12.0
16.9
18.2
7.5
17.7
17.2
6t2025
261.9
1 'r 0.1
225.6
91.5
5.9
38.8
44.6
7.1
12.0
26.7
15.4
12.0
15.2
'18.9
7.0
16.9
4E a
7t2025
235.8
99.9
197.0
87.3
5.9
34.8
35.3
7.4
12.1
22.3
6.4
12.0
12.6
10.7
6.9
13.5
12.8
8t2025
153.5
70.1
137.9
63.6
6.1
27.4
30.4
12.0
1.8
12.4
15.3
6.9
10.6
9t2025
164.1
75.6
148.4
36.1
oz
36.0
42.5
7.3
1.8
13.0
22.3
10t202s
191.2
84.7
166.9
10.3
6.3
36.9
46.3
1.5
1.9
13.0
23.3
6.3
15.4
11t202s
148.2
66.3
132.0
6.2
34.3
44.2
1.3
'1.9
11.5
21.3
12t2025
200.7
84.6
167.9
o.z
34.6
45.1
1.4
1.9
11 .4
21.6
aMW
237.8
102.3
204.8
35.5
6.1
36.0
44.5
3.8
1.8
12.2
22.8
51
9.7
15.0
7.7
6.9
13.8
13.1
7.0
8.3
8.3
8.7
15.3
4.9
6.4
12.8
12.1
6.7
14.3
5.4
1 5.1
7.2
13.4
12.7
7.0
14.0
13.2
6.4
12.5
'l 1.9
HCC Total
ROR Total
Total
560.3
19s.8
756.1
668.5
238.1
906.6
587.3
210.2
797.5
724.6
247.7
972.3
875.3
324.2
1,199.4
597.6
329.5
927.1
532.7
281.6
814.3
361.5
210.O
571.5
388.0
219.5
607.5
M2.8
195.3
638.1
346.5
172.1
518.6
453.2
182.4
635.6
544.9
233.9
778.7
*HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
HCC'
HCC
HCC
ROR
ROR'"
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2026
246.6
104.9
207.7
2t2026
294.0
124.7
246.3
1 0.1
6.3
37.2
50.0
1.4
1.9
11.4
24.5
12.1
12.0
15.9
15.5
6.6
15.3
14.3
3t2026
249.8
111.0
226.4
13.4
6.1
35.9
46.9
1.3
1.8
12.2
21.8
2.6
11.2
15.6
t.5
7.0
13.3
12.6
4t2026
316.6
134.2
271.9
38.8
6.1
36.9
50.8
1.2
1.8
12.3
22.8
4.7
12.0
16.9
8.3
7.2
14.1
13.3
5t2026
388.2
161 .1
327.0
74.3
6.1
42.5
50.6
2.1
1.8
13.4
28.8
15.4
12.0
16.9
18.2
7.5
17.7
17.2
6t2026
261.3
109.9
225.1
91.5
5.9
387
44.5
7.1
1.7
12.0
26.6
15.4
12.0
1 5.1
18.9
7.0
16.8
15.6
7t2026
235.4
99.7
196.6
87.3
5.9
34.7
35.2
7.4
1.7
12.1
22.2
6.4
12.0
12.5
10.7
6.9
13.5
12.7
8t2026
1 53.1
69.9
137.5
63.5
6.1
30.2
12.0
1.8
12.4
15.2
6.9
10.6
7.0
8.2
8.3
9t2026
162.4
74.7
146.7
36.0
o.z
35.8
42.2
7.3
1.8
13.0
22.1
67
14.3
7.2
13.3
12.6
10t2026
191.2
84.6
166.7
10.2
6.3
36.8
46.1
1.5
1.9
13.0
23.1
6.3
15.3
7.0
13.9
13.1
11t2026
148.3
bo.5
132.1
12t2026
198.8
83.8
166.3
aMW
237.1
102.1
204.2
35.4
6.1
35.9
44.3
3.8
1.8
12.2
22.7
9.7
14.9
7.6
6.9
13.7
13.0
oz
50.u
46.5
1.4
1.9
11.3
22.1
3.2
11.7
15.3
7.7
6.5
13.3
12.6
6.2
34.2
43.9
1.3
1.9
1 1.5
21.1
5.4
15.0
6.4
12.4
11.8
6.2
34.5
45.0
1.4
1.9
11.4
21.5
8.7
15.2
4.8
6.4
12.7
12.1
HCC Total
ROR Total
Total
559.2
195.6
754.8
665.0
234.5
899.5
587.2
209.1
796.3
722.7
247.2
969.9
876.3
324.4
1,200.6
596.3
328.9
92s.2
531.7
281.1
812.8
360.5
209.4
569.9
383.7
218.5
602.2
442.5
194.4
636.9
346.7
171.2
517.9
448.9
181.8
630.7
543.4
233.0
776.4
"HCC=Hells Canyon Complex, *ROR= Run of River
Page 132 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Hydro Modeling Results (PDR580) (continued)
Average Megawaft (aMW) 7orh Percentile Water, 70th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
BIiSS
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2027
246.2
104.7
207.4
o_z
35.9
46.4
1.4
1.9
11.3
22.1
JJ
11.7
15.2
7.7
6.5
13.2
12.5
2t2027
289.9
123.O
243.0
9.5
6.3
36.7
49.5
1.4
1.9
11 .4
23.6
11.3
12.0
15.8
14.6
6.6
14.6
13.7
3t2027
249.5
1 10.8
226.1
13.2
6.1
35.5
46.5
1.3
1.8
12.2
21.7
2.5
11.2
15.4
7.2
7.0
13.2
12.5
4t2027
316.2
134.0
271.4
38.7
6.1
36.8
50.7
1.2
1.8
12.3
22.8
4.5
12.0
16.8
8.2
7.2
14.1
tJ.c
st2027
387.5
160.8
326.4
74.2
6.1
42.5
51.0
2.1
1.8
13.4
28.8
15.4
12.O
17.0
18.2
7.5
17.7
17.2
6t2027
260.4
109.5
224.4
91.3
5.9
38.6
44.3
7.1
1.7
12.0
26.5
15.4
12.0
1 5.1
18.9
7.0
16.7
15.5
7t2027
234.9
99.5
196.2
87.3
5.9
34.5
35.1
7.4
1.7
12.1
22.1
6.4
12.0
12.5
10.7
6.9
13.4
12.6
8t2027
152.6
69.7
137.1
63.5
6.1
27.2
30.1
12.0
1.8
12.4
15.1
6.9
10.5
7.O
8.2
8.2
9t2027
160.6
73.8
144.9
35.9
o.z
35.6
42.0
7.3
1.8
13.0
22.0
6.7
14.2
7.2
13.2
12.5
10t2027
191 .8
84.8
167.1
10.3
6.3
36.6
45.9
1.5
1.9
13.0
23.O
6.3
15.3
7.0
13.8
13.0
11t2027
148.2
66.3
131 .9
6.2
34.1
43.7
'1.3
1.9
1 1.5
21.0
5.4
14.9
6.4
12.3
11.7
12t2027
196.3
82.7
164.2
6.2
34.4
44.9
1.4
1.9
11 .4
21.4
8.6
15.2
4.8
6.4
12.7
12.0
aMW
236.2
101 .6
203.3
35.3
6.1
35.7
44.2
3.8
1.8
12.2
22.5
4.9
9.7
14.8
7.5
6.9
13.6
12.9
HCC Total
ROR Total
Total
558.3
195.2
753.5
655.9
228.9
884.8
586.4
207.4
793.8
721.6
246.5
968.1
874.6
324.8
1,199.4
594.3
328.1
922.4
530.6
280.s
811.1
359.4
208.9
568.3
379.3
217.6
s96.9
4/,3.7
193.8
637.5
346.4
170.5
516.9
4/,3.2
181.3
624.5
54'.1.1
232.0
773.1
*HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 70rh Percentile Water, 70th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
'1,000 Springs
BIiSS
C.J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2028
245.0
104 2
206.4
6.2
35.8
46.3
1.4
1.9
11.3
220
3.3
11.7
15.4
6.5
13.2
12.5
2t2028
285.9
121.3
239.7
8.1
b_5
36.5
49.1
1.4
1.9
11 .4
22.9
6.8
12.0
15.7
10.0
6.6
14.1
13.2
3t2028
249.0
1 10.5
225.6
12.9
6.1
35.2
46.1
1.3
1.8
12.2
21.3
2.2
10.0
15.3
o.J
7.0
12.9
12.2
4t2028
315.9
133.8
271.1
386
6.1
Jb_ /
50.6
1.2
'1.8
.t2.3
22.8
4.4
12.0
16.8
8.1
7.2
14.1
13.3
st2028
387 5
160.7
326.4
74.2
6.1
42.5
50.9
2.1
1.8
13.4
28.8
't5.4
12.0
17.0
18.2
7.5
17.7
17.2
6t2028
259 9
109.2
223.9
91.0
5.9
38.5
44.1
7.1
1.7
12.0
26.4
15.4
12.0
15.0
18.8
7.0
16_6
15.4
7t2028
234.5
99.3
195.8
87.3
5.9
34.5
35.0
7.4
1.7
12.1
22.0
6.4
12.O
12.4
10.7
6.9
13.3
12.6
8t2028
152.1
695
136.7
63.2
6.1
27.0
29.9
12.0
1.8
12.4
15.0
9t2028
159.4
73.2
143.7
35.9
6.2
35.4
41.7
7.3
1.8
13.0
21.8
10t2028
191.7
84.6
166.8
10.3
OJ
36.5
45.7
1.5
1.9
13.0
22.8
11t2028
148.3
bbJ
132.0
ot
33.9
43.5
1.3
1.9
11.5
20.9
12t2028
195.6
82.4
163.6
6.2
34.3
44.7
1.4
1.9
11 .4
21.3
aMW
235.4
101.2
202.6
35.1
6.1
35.6
44.0
3.8
1.8
12.2
22.3
4.5
9.6
14.8
6.9
13.5
12.8
69
10.5
7.0
81
8.1
67
14.2
7.2
13.0
12.4
63
15.4
7.0
13.7
12.9
5.4
14.9
64
12.2
11.6
8.6
1 5.1
4.8
6.4
12.6
12.0
HCC Total
ROR Total
Total
555.6
195.1
750.7
646.9
2r6.0
862.9
585.1
202.9
788.0
720.8
246.0
966.8
874.7
324.7
1,199.3
593.0
327.O
920.0
s29.6
280.1
809.7
3s8.3
207.9
s66.2
376.3
216.6
s92.9
u3.1
193.2
636.3
3.f6.6
169.8
516.4
441.6
180.7
622.3
s39.3
230.0
769.3
'HCC=Hells Canyon Complex, *ROR= Run of River
2017 lntegrated Resource Plan-Appendix C Page 133
Modeling Results (PDR580) (continued)
Existing Resource Data ldaho Power Company
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource
Brownlee
O16ow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2029
244.0
103.8
205.5
6.2
35.7
46.1
1.4
1.9
1 1.3
21.9
3.3
11.7
15.4
7.7
6.5
13.1
12.4
2t2029
281.7
1 19.5
236.2
5.9
o.J
36.4
48.5
1.4
'1.9
11 .4
22.9
5.7
12.0
15.7
10.0
b.6
14.0
13.2
3t2029
248.6
1 10.3
225.2
12.8
6.1
34.9
45.9
1.3
1.8
12.2
21.2
2.0
9.8
15.2
6.0
7.0
12.8
12.2
4t2029
315.2
133.5
270.5
38.4
6_1
36.5
50.5
1.2
'1.8
12.3
22.8
4.0
11 .8
16.8
78
7.2
14.1
13.2
5t2029
387.6
160.7
326.4
74.1
6.1
42.5
50.5
2.1
1.8
13.4
28.7
15.4
12.0
16.8
18.2
1E
17.7
17.2
6t2029
259.2
109.0
223.4
90.9
5.9
38.3
43.9
7.1
1.7
12.0
26.3
15.4
12.0
14.9
18.8
7.0
16.5
15.4
7t2029
234.0
99.1
195.5
87.3
5.9
34.3
34.9
7.4
1.7
12.1
21.9
6.4
120
12.4
10.7
6.9
13.2
12.5
8t2029
151 .6
69.2
136.3
63.1
6.1
26.9
29.7
12.0
1.8
12.4
14.9
9t2029
1 58.1
72.5
142.5
35.8
6.2
35.2
41.5
7.3
1.8
13.0
21.6
10t2029
191 .5
84.5
166.5
10.2
6.3
36.3
45.5
1.5
'1.9
13.0
22.7
11t2029
148.2
66.2
131 .9
6.2
33.7
43.3
1.3
1.9
11.5
20.7
12t2029
195.4
82.3
163 4
6.2
34.2
44.4
14
1.9
11.4
21.1
aMW
234.6
't00.9
201.9
34.9
6.1
35.4
43.7
3.8
't.8
12.2
22.2
4.4
9.5
14.8
7.0
6.9
13.4
127
6.9
10.4
6.7
14.1
6.3
15.4
5.4
14.8
7.9
1 5.1
4.3
6.4
12.4
11.8
7.0
8.0
8.0
6.4
12.1
11.5
7.2
12.9
12.2
7.0
I J.O
12.8
HCC Total
ROR Total
Total
553.3
194.5
747.8
637.4
211.9
849.3
584.1
201.3
785.4
7',tg.2
244.5
963.7
874.7
323.9
1,198.6
591.6
326.2
9't7.8
528.6
279.5
808.1
357.1
207.1
564.2
373.1
215.5
588.6
442.5
192.4
634.9
346.3
168.9
515.2
M1.1
178.5
619.6
537.4
228.7
766.1
'HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 70th Percentile Water, 70rh Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
6.2
35.3
46.0
1.4
1.9
1 1.3
21.8
2.5
11.7
15.3
7.7
6.5
13.0
12.3
6.3
36.3
47.8
1.4
1.9
11.4
22.8
5.6
12.0
15.6
9.9
6.6
14.0
13.2
Type
HCCr
HCC
HCC
ROR
ROR-'
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1/2030
242.8
103.2
204.5
2t2030
278.3
1 18.1
233.5
3/2030
248.3
'I 10.1
224.4
11.2
6.1
33.9
45.5
1.3
1.8
12.2
20.8
9.4
15.4
5.7
7.O
12.5
1 1.9
4t2030
31 5.1
133.4
270.3
37.2
6.1
36.4
50.3
1.2
1.8
12.3
22.8
3.8
11.6
16.7
7.6
7.2
14.1
13.2
5/2030
387.1
160.6
326.1
74.1
6.1
42.5
50.5
2.1
1.8
13.4
28.6
1 5.1
12.0
16.8
17.9
7.5
17.7
17.1
6/2030
258.6
108.7
222.9
90.9
qo
38.2
43.7
7.1
1.7
12.0
26.1
15.4
12.0
14.9
18.7
7.0
16.4
15.3
7t2030
233.5
98.9
1 95.1
87.3
AO
J4.Z
34.7
7.4
1.7
12.1
21.8
6.4
12.0
12.3
10.7
6.9
13.1
12.4
8/2030
151.1
69.0
135.8
63.0
6.1
26.7
29.5
12.0
1.8
12.4
14.7
6.9
10.4
7.0
7.9
8.0
9/2030
156.7
71.8
141.1
35.8
62
35.0
41.3
1.8
13.0
21.5
6.7
14.'.|
7.2
12.8
12.1
10/2030
191.7
84.5
166.6
10.2
6.3
36.1
45.2
1.5
1.9
13.0
22.5
6.3
15.3
11t2030
148.6
66.4
132.2
o.z
33.6
43.1
1.3
1.9
11.5
20.6
5.4
14.7
6.4
12.0
11.4
12t2030
194.9
82.1
'163.0
6.2
34.1
44.2
1.4
1.9
11 .4
21.0
7.9
15.0
4.3
6.4
12.4
I 1.8
aMW
233.9
100.6
201.3
34.1
6.1
35.2
43.5
3.8
1.8
12.2
22.1
4.1
9.5
14.7
6.9
6.9
13.3
12.6
7.0
13.4
12.7
HCC Total
ROR Total
Total
550.5
192.8
743.3
629.9
204.8
834.7
583.2
't94.8
778.O
718.8
242.3
961.1
873.8
323.1
1,'t 96.9
590.2
325.4
915.6
527.5
278.8
806.3
355.9
206.3
562.2
369.5
214.8
584.3
4/,2.8
191.3
634.'r
347.2
168.2
515.4
44]0.o
178.0
618.0
535.8
226.7
762.5
.HCC=Hells Canyon Complex, -ROR= Run of River
Page 134 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource
Brownlee
Oxbor
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
6.9
10.3
7.0
7.8
7.9
6.3
15.2
7.0
13.3
12.6
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2031
243.1
103.4
204.8
6.2
35.1
46.0
1.4
1.9
1 1.3
22.1
4.0
12.0
15.3
8.9
6.5
13.3
12.6
2t2031
277.7
117.8
232.9
3t2031
247.8
109.9
224.4
1 1.0
6.1
33.8
45.2
1.3
1.8
12.2
20.7
1.6
10.0
15.3
6.2
12.4
11.8
4t2031
314.5
133.2
269.8
36.8
6.1
36.3
50.2
1.2
1.8
12.3
22.8
3.6
11.4
16.5
7.4
7.2
14.1
13.2
5t2031
386.4
160.3
325.5
74.1
6.1
42.5
49.9
2.1
1.8
13.4
26.o
14.6
12.0
16.8
17.7
7.5
17 .7
17.1
6/2031
257.5
108.2
222.0
90.8
5.9
38.0
43.5
7.1
1.7
12.0
26.0
14.6
12.0
14.8
18.2
7.0
16.3
15.2
7t2031
233.1
98.7
194.7
87.3
5.9
34.1
34.6
7.4
1.7
12.1
21.7
6.4
12.0
12.3
10.7
6.9
13.0
12.4
8/2031
150.7
68.8
135.4
62.9
6.1
26.6
29.3
12.0
1.8
12.4
14.6
9/2031
154.9
70.8
139.3
35.8
6.2
34.8
41.0
7.3
1.8
13.0
21.3
6.7
14.1
7.2
12.6
12.O
10t2031
191.9
84.5
166.6
10.2
o_J
35.9
45.0
1.5
1.9
13.0
22.4
11t2031
148.8
66.4
132.3
12t2031
194.2
81.8
162.5
aMW
233.4
100.3
200.8
34.1
6.1
35.1
43.3
3.8
1.8
12.2
22.0
4.4
9.6
14.7
7.0
6.9
13.2
12.6
6.3
36.2
47.4
1.4
1.9
11 .4
22.8
7.5
12.0
15.5
10.2
b_o
13.9
'I 3.1
6.2
34.0
44.1
1.4
1.9
11 .4
21.0
8.6
15.0
4.8
6.4
12.3
11.8
6.2
JJ.3
43.3
1.3
1.9
1 1.5
20.5
5.4
14.7
6.4
1 1.9
11.4
HCG Total
ROR Total
Total
55'1.3
196.s
747.8
628.4
206.2
834.6
s82.1
196.s
778.6
717.5
240.9
958.4
872.2
321.8
't,194.0
587.7
323.2
910.9
526.5
278.4
804.9
3il.9
205.5
560.4
364.9
213.8
578.7
443.0
190.5
633.5
347.5
158.1
515.6
438.5
178.9
6',t7.4
534.5
226.7
761.2
'HCC=Hells Canyon Complex. -ROR= Run of River
Average Megawatt (aMl,V) 70ih Percentile Water, 70th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
6.2
35.0
45.8
1.4
1.9
1 1.3
22.0
4.0
12.0
15.2
8.9
6.5
13.2
12.5
6.3
35.4
47.0
1.4
1.9
11.4
22.4
5.3
12.0
15.4
9.8
6.6
13.6
124
Type
HCC'
HCC
HCC
ROR
ROR--
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2032
242.7
103.2
204.5
2t2032
268.8
117 .5
234.1
3t2032
247.1
109.6
223.7
9.6
6.1
44.9
1.3
1.8
12.2
20.1
8.8
15.2
5.2
7.0
1 1.9
11.4
4t2032
313.8
132.9
269.2
36.6
6.1
36.2
50.0
1.2
1.8
12.3
22.0
3.1
10.7
16.4
6.8
7.2
13.5
12.7
5t2032
385.3
159.8
324.7
74.1
6.1
42.5
50.0
2.1
1.8
13.4
28.6
14.3
12.0
16.8
17.5
7.5
17.7
17 .1
612032
256.'1
107.7
220.9
90.8
5.9
37.9
43.3
7.1
1.7
12.0
25.9
14.3
12.0
14.7
18.2
7.0
16.2
15. 1
7t2032
232.6
98.5
194.3
87.2
5.9
34.0
34.4
7.4
1.7
12.1
21.6
6.4
12.0
12.2
10.7
6.9
13.0
'12.3
8t2032
1 50.1
68.5
134.9
62.5
6.1
26.4
29.1
12.0
1.8
12.4
14.5
6.9
10.2
7.0
7.7
7.8
9t2032
153.4
70.0
137.8
35.7
6.2
34.6
40.8
7.3
1.8
13.0
21.1
6.7
14.0
7.2
12.5
1 1.9
10t2032
191 .8
84.4
166.3
10.2
o_J
358
44.8
1.5
1.9
13.0
22.2
6.3
15.1
11t2032
148.5
66.3
132.0
6.2
33.2
43.1
1.3
1.9
11.5
20.3
5_4
14.7
6.4
1 1.8
1 1.3
12t2032
194.2
81.8
162.4
6.2
33.9
43.9
1.4
1.9
11.4
20.8
8.6
14.9
4.8
6.4
12.2
11.6
aMW
232.0
100.0
200.4
33.9
6.1
34.9
43.1
3.8
1.8
12.2
21.8
4.0
9.5
14.6
6.8
6.9
13.0
12.4
7.0
13.2
12.5
HCC Total
ROR Total
Total
550.4
195.8
746.2
620.4
201.3
821.7
580.4
t88.9
769.3
715.9
236.6
952.5
869.9
321.4
1,19't.3
584.7
322.2
906.9
525.4
277.7
803.1
353.5
204.3
557.8
361.2
2't2.8
573.9
442.5
189.7
632.2
346.8
167.2
5't4.0
438.4
178.0
616.4
532.5
224.7
757.1
'HCC=H€lls Canyon Complex, *ROR= Run of River
2017 lntegrated Resource Plan-Appendix C Page 135
Existing Resource Data ldaho Power Company
Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 70th Percentile Water, 70th Percentile Load
Resource
Brcwnlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
6.2
34.8
45.2
1.4
1.9
11.3
21.8
J.J
12.0
1 5.1
8.5
6.5
1 3.1
12.4
o.J
35.2
46.9
1.4
1.9
11.4
21.9
5.1
12.0
15.3
9.4
b.o
13.3
12.5
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
112033
242.2
103.0
204.1
2t2033
267.9
117.1
233.3
3/2033
246.8
'109.4
223.4
9.4
6.1
33.1
44.5
1.3
1.8
122
19.9
4t2033
313.3
132.6
268.6
36.4
6.1
36.'t
49.8
1.2
1.8
12.3
21.1
2.3
10.4
16.2
6.6
7.2
12.8
12.1
5/2033
385.6
159 9
324.8
74.1
6.1
42.4
49.9
2.1
1.8
13.4
28.7
14.3
12.0
16.8
17.5
7.5
17 .7
17.2
6/2033
255.1
107.3
220.1
90.9
5.9
37.6
43.1
7.1
1.7
12.0
25.8
14.3
12.0
14.6
18.2
7.0
16.2
15.0
7t2033
232.0
98.3
193.9
87.2
5.9
33.8
34.2
7.4
1.7
12.1
21.5
6.4
12.0
12.2
10.7
6.9
12.9
12.2
8/2033
149.6
68.3
134.4
62.5
6.1
26.3
28.9
12.0
1.8
12.4
14.3
9/2033
151.5
69.1
136.0
35.7
6.2
34.4
40.5
7.3
1.8
13.0
20.9
r0/2033
192.1
84.4
166.4
10.2
6.3
35.6
44.7
'1.5
1.9
13.0
22.1
11t2033
148.7
66.3
132.0
6.2
33.1
43.1
1.3
1.9
1 1.5
20.2
12t2033
193.7
81.6
162.0
6.2
33.8
43.5
1.4
1.9
11.4
20.7
aMW
231.5
99.8
199.9
33.9
6.1
34.7
42.9
3.8
1.8
12.2
21.6
3.8
9.4
14.5
6.7
6.9
12.9
12.3
8.6
15.1
4.8
7.0
1 1.8
1 1.3
8.6
14.9
4.8
6.4
12.1
11.6
6.9
10.2
b./
13.9
6.3
1 5.1
5.4
14.6
7.0
7.6
7.7
7.2
12.4
1 1.8
7.0
13.1
12.4
6.4
11.6
11.2
HCC Total
ROR Total
Total
#9.3
193.4
742.7
618.3
199.2
817.5
579.6
187.0
766.6
714.5
232.4
946.9
870.3
321.4
1,191.7
582.5
321.s
904.0
524.2
277.0
801.2
352.3
203.6
555.9
356.5
211.8
568.3
u2.9
189.1
632.0
347.O
166.6
5r3.6
437.3
177.3
614.6
531.2
223.4
754.6
*HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 70ih Percentile Water, 70th Percentile Load
Resource
Brcurnlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
8.3
15.0
4.6
7.0
11.7
11.2
16.0
3.8
7.2
12.6
120
Type
HCC'
HCC
HCC
ROR
ROR-'
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2034
241.8
102.9
203.8
6.2
34.7
45.1
1.4
1.9
11.3
21.7
J.5
12.0
15.1
8.5
6.5
13.0
12.3
2t2034
tbb_v
1 16.6
232.4
6.3
35.2
46.7
1.4
1.9
11.4
21.8
5.1
12.0
15.2
8.8
6.6
1 3.1
12.4
3t2034
246.7
109.3
223.3
9.2
6.1
32.9
44.3
1.3
1.8
12.2
'19.8
4t2034
312.2
132.1
267.8
35.6
ot
35.7
48.6
1.2
1.8
12.3
20.9
512034
384 9
159.6
324.2
74.1
6.1
42.5
49.9
2.1
'1.8
13.4
28.5
14.3
12.0
16.8
17.3
7.5
17.7
17.1
6t2034
254.4
107.0
219.5
90.8
5.9
37.4
42.9
7.1
1.7
12.O
25.3
14.2
12.0
14.6
18.2
7.0
15.8
14.7
7t2034
231.6
98.1
193.5
87.2
5.9
33.7
34.0
7.4
1.7
12.1
21.4
6.4
12.0
12.1
10.7
6.9
12.8
12.1
8t2034
149.1
68.0
134.0
62.4
6.1
26.1
28.7
12.0
1.8
12.4
14.2
6.9
1 0.1
9t2034
1 50.1
683
134.5
35.6
6.2
34.2
40.2
7.3
1.8
'13.0
20.8
6.7
13.8
10t2034
'191 .9
84.3
1 66.1
10.2
6.3
35.4
44.5
1.5
1.9
13.0
21.9
6.3
151
11t2034
148.8
66.4
132.1
12t2034
193.2
81.4
161.6
aMW
231.O
ooq
199.4
JJ.6
6.1
34.5
42.6
3.8
1.8
12.2
21.4
J_b
9.1
14.4
6.4
6.9
12.7
12.2
7.0
7.5
7.6
7.0
13.0
12.3
6.4
1 1.5
11.1
7.2
't2.2
11.7
6.2
33.0
43.0
1.3
1.9
11.5
20.0
5.4
14.6
oz
33.7
43.5
1.4
1.9
11 .4
20.6
8.6
14.8
4.8
6.4
12.0
'l 1.5
HCC Total
ROR Total
Total
548.5
{92.9
741.4
615.9
197.9
813.8
579.3
185.5
764.8
712.1
221.1
933.2
868.6
321.O
1,189.7
s80.9
319.7
900.6
523.2
276.3
799.5
351.1
202.7
553.8
352.8
210.7
563.5
4d,2.3
't88.3
630.6
347.3
166.0
513.3
436.2
176.8
613.0
529.9
221.6
751.4
'HCC=Hells Canyon Complex, *ROR= Run of River
Page 136 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Modeling Results (PDR580) (continued)
Average Megawatt (aiiw) 70s Percentile Water, 70th Percentile Load
Resource
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2035
241.4
102.7
203.4
6.2
34.6
44.9
1.4
1.9
11.3
21.2
3.3
12.0
15.1
8.0
6.5
12.6
12.0
2t20x5
26s.2
1 15.8
230.8
6.3
34.9
46.6
1.4
1.9
11.4
21.7
5.1
12.0
't5.2
8.8
6.6
13.1
12.4
3/2035
246.5
1 09.1
222.8
9.,|
6.1
32.8
44.0
1.3
1.8
12.2
19.7
4t2035
312.2
132.O
267.5
35.5
6.'l
35.5
47.6
1.2
1.8
12.3
20.8
6.6
15.9
7.2
12.5
11.9
5/2035
384.1
159.3
323.6
73.9
6.1
42.4
49.9
2.1
'1.8
13.4
28.4
'14.3
12.0
16.8
17.3
7.5
17.7
17.0
612035
253.8
106.7
219.0
90.7
5.9
37.2
42.7
7.1
1.7
12.0
25.1
14.2
12.0
14.5
18.2
7.0
15.7
14.6
7t2035
231.1
97.9
1 93.1
87.2
5.9
33.6
33.9
7.4
1.7
't2.1
21.3
6.4
12.0
12.1
10.7
6.9
't2.7
12.1
8r2035
148.6
67.8
133.6
62.4
6.1
26.0
28.6
12.0
1.8
't2.4
't4.1
6.9
10.0
7.0
7.4
7.5
9/2035
148.2
67.3
132.7
35.6
6.2
34.0
40.0
7.3
1.8
1s.0
20.6
6.7
13.8
7.2
12.1
1 1.6
l0/2035
192.2
84.3
166.1
10.3
6.3
35.3
44.2
1.5
1.9
13.0
21.8
6.3
15.0
7.0
12.8
12.2
11t2035
148.9
66.4
132.2
6.2
32.8
42.8
1.3
1.9
1't.5
19.9
5.4
14.5
6.4
11.4
11.0
12t203s
192.7
81.2
161.2
6.2
33.6
43.5
1.4
1.9
11.4
20.5
8.6
14.8
4.8
6.4
1 1.9
11.4
aMW
230.4
99.2
198.8
33.7
6.1
u.4
42.4
3.8
't.8
12.2
21.3
3.6
9.'l
14.4
6.0
6.9
12.6
12.1
8.3
14.9
4.6
7.0
1 1.6
11.1
HCC Total
ROR Total
Total
547.5
190.9
738.4
6{ 1.8
157.4
809.2
578.4
184.6
763.0
711.7
214.9
926.6
867.0
320.5
1,187.5
579.5
318.7
89E.2
522.1
275.9
798.0
350.0
202.1
552.1
348.1
209.9
558.0
4d,2.6
187.5
630.1
347.5
165.2
512.7
/$5.1
178.4
611.5
528.4
220.3
74,.8
'HCC=Hells Ganyon Complex, *ROR= Run of River
Average Megawaft (ailW) 70th Percentile Water, 70th Percentile Load
Resource
American Falls
1,000 Springs
Bliss
C.J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
UpperSalmon 1&2
Upper Salmon 3&4
Type
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
112036
240.8
102.4
2029_
6.2
34.4
44.2
1.4
1.9
1 1.3
20.7
2.5
10.7
15.0
6.8
6.5
12.2
11.6
2t2036
264.2
1 15.3
229.9
6.3
34.8
46.4
1.4
1.9
't't.4
2',1.6
5.1
12.0
15.1
8.8
6.6
13.1
12.4
3/2036
245.9
108.8
222.2
8.9
6.1
32.7
43.7
1.3
1.8
12.2
19.6
4t2036
311 .6
131 .6
266.8
35.5
6.1
35.4
47.5
1.2
1.8
12.3
20.7
5/2036
384.5
159.5
323.8
73.9
6.1
42.3
49.9
2.1
1.8
13.4
28.4
14.3
12.0
16.8
17.2
7.5
17.7
17.0
6/2036
253.1
106.4
218.4
90.7
5.9
37.1
42.6
7.1
1.7
12.0
25.0
14.2
't2.0
14.4
18.2
7.0
15.5
14.5
7t2036
230.6
97.6
192.6
87.2
5.9
33.4
33.7
7.4
1.7
12.1
21.2
6.4
12.0
12.0
10.7
6.9
12.6
12.0
8/2036
148.1
67.6
1 33.1
62.2
6.1
25.8
28.4
12.0
1.8
't2.4
14.0
9/2036
146.3
66.3
130.9
35.6
6.2
33.8
39.7
7.3
1.8
13.0
20.4
10/2036
192.4
84.3
166.1
10.3
6.3
35.1
44.O
1.5
1.9
13.0
21.6
11t2036
148.8
66.3
132.0
6.2
32.7
42.7
1.3
1.9
11.5
19.8
12t2036
192.6
81.1
161.1
aMw
229.9
98.9
't98.3
33.7
6.1
34.3
42.2
3.8
1.8
12.2
21.1
3.5
9.0
14.3
5.9
6.9
12.5
12.0
6.2
33.5
43.4
1.4
1.9
11.4
20.4
8.3
14.8
4.6
7.0
1 1.5
11.1
6.6
15.8
7.2
12.5
1 1.9
6.9
10.0
7.0
7.3
7.5
6.7
13.7
7.2
12.O
11.4
6.3
14.9
7.O
12.7
12.1
5.4
14.5
6_4
'fi.3
10.9
8.6
14.7
4.8
6.4
1 1.9
11.4
HCC Total
ROR Total
Total
546.1
{85.3
731.4
609.4
196.9
806.3
576.9
183.7
760.6
710.0
214.5
924.5
867.8
320.3
1,188.1
577.9
3r8.0
895.9
520.8
275.1
795.9
348.8
201.3
550.{
343.4
208.8
552.2
4{.2.8
186.6
629.4
317.1
164.7
511.8
434.8
r76.0
6r0.8
527.1
2{9.3
746.4
'HCC=Hells Canyon Complex, *ROR= Run of River
2017 lnlegrated Resource Plan-Appendix C Page 137
Existing Resource Data ldaho Power Company
Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, Torh Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
BIiSS
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
HCC.
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2017
221.6
93.5
184.6
0.0
6.2
33.4
42.0
1.4
1.9
1 1.3
21.0
1.9
9.9
14.4
6.1
6.5
12.4
11.8
2t2017
195.7
83.9
1 66.8
0.0
6.3
33.6
41.9
1.4
1.9
11 .4
21.3
3.1
10.9
14.3
7.0
6.6
12.8
12.2
3t2017
231.8
99.8
202 2
0.0
6.1
32.0
41.0
1.3
1.8
12.2
19.5
0.0
48
14.1
0.0
7.0
1 1.5
1 1.0
412017
225.4
96.2
196.0
29.7
6.1
32.4
40.9
1.3
'1.8
12.3
20.0
0.0
4.0
14.1
0.0
7.2
11 .9
11.4
st2017
272.1
1 15.0
235.9
69.4
6.1
37.4
43.1
1.5
1.8
13.4
24.9
8.3
12.0
14.7
11.1
7.5
15.7
14.6
6t2017
167.1
72.2
146.6
86.9
(o
35.7
39.0
4.2
1.7
12.0
24.0
8.2
12.0
13.4
12.0
7.0
14.8
13.8
712017
222.0
93.7
184.1
87.0
(o
33.9
32.4
7.0
1.7
12.1
22.0
6.4
12.0
11.7
10.3
6.9
13.3
12.5
8t2017
141.5
64.4
126.6
56.5
6.1
26.7
29.5
10.3
1.8
12.4
15.1
0.0
6.5
'10.4
0.0
7.0
8.1
8.2
9t2017
131.6
59.0
116.2
27.3
o.z
35.4
39.1
6.3
1.8
13.0
22.1
0.0
6.5
13.9
0.0
7.2
13.3
12.6
10t2017
192.4
83.4
164.2
8.1
6.3
36.1
43.1
1.3
1.9
13.0
23.0
0.0
6.2
14.8
0.0
70
13.8
13.0
11t2017
148.2
65.7
130.4
0.0
6.2
33.9
42.7
1.3
1.9
11.5
21.4
0.0
7.3
14.6
3.7
6.4
I Z.O
1 1.9
12t2017
178.7
78.0
153.9
0.0
6.2
33.8
41.7
1.3
1.9
11.4
21.3
0.0
9.7
14.4
5.9
6.4
12.6
12.O
aMW
194.0
83.7
167.3
30.4
6.1
33.7
39.7
3.2
1.8
12.2
21.3
2.3
8.5
13.7
4.7
6.9
12.7
12.1
HCC Total
ROR Total
Total
499.7
180.1
679.8
446.4
184.7
631.1
533.8
162.4
696.2
5't 7.6
193.1
710.7
623.0
281.4
904.4
385.9
290.7
576.6
499.8
275.0
774.8
332.5
198.5
531.0
306.8
204.6
511.4
4/,o.0
187.5
627.5
344.3
175.5
5't9.8
410.6
178.6
589.2
4/,5.0
209.3
654.4
'HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 90th Percentile Water, 7Oh Percentile Load
Resource
Brcwnlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2018
212.0
89.8
177.5
0.0
6.2
33.3
42.2
1.4
1.9
1 1.3
21.1
0.0
9.2
14.4
5.6
6.5
12.5
1 1.9
2t2018
197 8
84.8
168.5
0.0
o.J
33.5
42.1
1.4
1.9
11 .4
21.3
3.1
'10.8
14.4
6.9
6.6
12.8
12.1
3t2018
232.9
100.3
203.1
0.0
6.1
32.0
41.4
1.3
1.8
12.2
19.4
0.0
4.2
14.2
0.0
7.0
11.4
11.0
4t2018
226.0
96.5
196.5
29.6
6.1
32.5
41.1
1.3
1.8
12.3
20.1
0.0
4.0
14.2
0.0
7.2
12.0
11.5
5/2018
273.6
115.7
237.1
70.0
6.1
38.1
43.4
1.5
1.8
13.4
25.6
9.7
12.0
14.8
12.4
7.5
16.2
15.1
6t2018
'168.1
72.7
147.5
87.7
RO
36.3
39.6
4.2
1.7
12.0
24.4
9.6
12.0
13.6
12.6
7.0
15.1
14.1
7t2018
222.3
93.8
184.3
87.1
5.9
34.0
32.0
7.0
1.7
12.1
22.0
6.4
12.0
11.7
10.3
6.9
13.3
12.6
8t2018
141.5
64.4
126.7
56.5
6.1
26.9
29.5
10.3
1.8
12.4
15.1
0.0
6.5
10.4
0.0
8.1
8.2
9t2018
131 .5
59.0
116.2
28.5
6.2
35.4
39.1
6.3
1.8
13.0
22.1
0.0
6.5
13.9
0.0
7.2
13.3
12.6
10t2018
192.2
83.4
164.1
8.7
6.3
36.2
43.1
1.3
1.9
13.0
23.0
0.0
6.2
14.9
0.0
7.0
13.8
13.0
11t2018
148.6
65.8
130.7
0.0
6.2
33.7
42.5
t.J
1.9
11.5
21.2
0.0
6.6
14.6
0.0
6.4
12.4
1 1.8
12t2018
178.8
78.0
153.9
0.0
6.2
JJ. /
41.8
1.3
'1.9
11 .4
21.2
0.0
9.1
14.3
5.5
6.4
12.5
1 1.9
aMW
193.8
83.7
167.2
30.7
ol
33.8
39.8
3.2
1.8
12.2
21.4
2.4
8.3
13.8
4.4
6.9
12.8
12.2
HCC Total
ROR Total
Total
479.3
177.4
656.7
451.1
184.6
535.7
536.3
162.',|
698.4
519.0
193.7
712.7
626.4
287.5
913.9
388.3
295.9
684.2
500.4
274.9
775.3
332.6
't98.7
531.3
306.6
205.9
512.4
439.7
188.3
628.0
345.1
170.2
515.3
410.7
177.2
587.9
444.6
209.7
654.3
'HCC=Hells Canyon Complex, -ROR= Run of River
Page 138 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 70rh Percentile Load
Resource
Bmwnlee
Otbov,
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Mllner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
HCC'
HCC
HCC
ROR
ROR"
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2019
209.6
88.8
175.5
0.0
6.2
32.9
41.4
1.4
1.9
1 1.3
20.6
0.0
7.1
14.2
J.t
6.5
12.1
1 1.5
a2u9
202.3
86.7
172.3
0.0
6.3
33.3
41.5
1.4
1.9
11.4
20.9
0.0
8.7
14.3
5.1
6.6
12.4
1 1.8
3t2019
231.5
99.7
201.9
0.0
6.1
32.0
41.5
1.3
1.8
12.2
19.4
0.0
4.2
14.2
0.0
7.0
11.4
11.0
4t2019
226.6
96.7
197.0
29.4
6.1
32.5
41.4
1.3
1.8
12.3
20.2
0.0
4.3
14.2
0.0
7.2
12.1
11.6
sr20t9
274.5
116.1
237.9
70.0
6.1
38.3
43.8
1.5
'1.8
13.4
26.1
10.3
12.0
14.9
13.0
7.5
16.6
15.4
6/2019
168.3
72.7
147.6
87.7
5.9
36.7
40.6
4.2
1.7
12.0
24.5
10.2
12.0
13.9
1 3.1
7.0
15.2
14.2
7t2019
222.5
93.9
184.5
87.1
59
34.1
32.1
7.0
1.7
12.1
22.1
6.4
12.0
11.7
10.3
6.9
13.3
12.6
8t2019
141.6
64.5
126.8
56.2
6.1
27.0
29.6
10.3
1.8
12.4
15.1
0.0
6.5
10.4
0.0
7.0
82
82
9/2019
129.8
58.1
114.6
28.7
6.2
35.3
39.0
6.3
1.8
13.0
22.1
0.0
6.5
13.9
0.0
7.2
13.3
12.6
10/20r9
192.6
83.4
164.1
8.8
6.3
36.2
43.1
1.3
'1.9
13.0
23.0
0.0
6.2
14.8
0.0
7.0
'13,8
13.0
11t2019
149.3
66.1
131.2
0.0
6.2
33.5
42.0
1.3
1.9
1 1.5
20.8
0.0
5.4
14.4
0.0
6.4
12.1
1 1.6
12t2019
178.1
77.7
153.3
0.0
6.2
41.3
1.3
1.9
11 .4
20.7
0.0
7.0
14.2
0.0
6.4
12.2
1 1.6
aMW
193.9
83.7
167.2
30.7
61
33.8
39.8
3.2
1.8
12.2
21.3
2.2
7.7
13.8
3.8
6.9
12.7
12.1
HCC Total
ROR Total
Total
473.9
170.7
64/,.6
461.3
175.6
536.9
533.1
162.2
695.3
520.3
194.4
714.7
628.5
290.6
919.1
388.5
299.0
687.6
500.9
275.2
776.1
332.9
198.7
531.6
302.5
205.9
508.3
4/,0.1
188.3
628.4
346.6
167.2
5't3.8
409.1
167.4
576.5
444.8
207.9
652.7
'HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW 90th Percentile Water, 70rh Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2020
209.7
88.8
175.6
0.0
6.2
32.9
41.4
1.4
1.9
11.3
20.6
0.0
7.2
14.2
3.7
6.5
12.1
1 1.6
2t2020
196.6
84.3
167.4
0.0
b.5
32.1
40.1
1.4
1.9
11 .4
20.1
0.0
8.4
13.8
4.9
6.6
12.0
11.4
3t2020
231.5
99.7
201.9
0.0
6.1
32.0
41.5
1.3
1.8
12.2
19.4
0.0
4.2
14.2
0.0
7.0
11.4
1 1.0
4t2020
226.7
96.8
197.1
29.3
6.1
32.5
41.7
1.3
1.8
I Z.J
20.2
0.0
4.3
14.3
0.0
7.2
12.1
11.6
st2020
274.9
116.2
238.2
70.0
6.1
38.2
44.0
1.5
1.8
13.4
25.9
10.0
12.O
15.0
12.6
7.5
16.5
15.3
6t2020
168.1
72.7
147.5
87.7
5,9
36.2
40.3
4.2
1.7
12.0
24.5
9.9
12.0
13.8
13.0
7.0
1 5.1
14.2
7t2020
222.4
93.9
184.4
87.1
5.9
34.0
32.1
7.0
1.7
12.1
22.0
6.4
12.0
11.7
10.3
6.9
13.3
12.6
8t2020
141.5
64.4
126.6
56.7
6.1
26.9
29.5
10.3
1.8
12.4
15.1
0.0
6.5
10.4
0.0
7.0
8.1
8.2
9t2020
129.4
58.0
114.3
28.8
6.2
35.2
38.9
6.3
1.8
13.0
22.0
0.0
6.5
13.9
0.0
7.2
13.2
12.5
10t2020
192.5
83.3
164.0
8.8
6.3
36.1
43.1
1.3
1.9
13.0
23.0
0.0
6.2
14.8
0.0
7.0
13.8
13.0
11t2020
149.2
66.0
131.1
0.0
6.2
33.4
41.9
1.3
1.9
1't.5
20.7
0.0
5.4
14.4
0.0
6.4
12.1
1 1.5
12t2020
178.0
77.6
153.2
0.0
6.2
33.3
41 .6
1.3
1.9
11 .4
20.7
0.0
7.0
14.2
0.0
6.4
12.2
11.6
aMW
193.4
83.5
166.8
30.7
6.1
33.6
39.7
3.2
1.8
12.2
21.2
2.2
7.6
13.7
3.7
6.9
12.7
12.0
HCC Total
ROR Total
Total
474.1
170.9
645.0
/148.3
170.3
618.6
533.1
162.2
695.3
520.6
194.7
715.3
629.3
289.7
919.0
388.3
297.6
68s.9
500.7
275.0
775.7
332.s
198.9
531.4
30't.7
205.5
507.1
439.8
188.2
628.0
346.3
't66.8
513.'l
408.8
167.8
576.6
443.5
207.3
650.9
'HCC=Hells Canyon Complex, '*ROR= Run of River
2017 lntegrated Resource Plan-Appendix C Page 139
Existing Resource Data ldaho Power Company
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, Torh Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
Type
HCC.
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
'U202'.\
210.0
88.9
175.8
0.0
6.2
32.8
41 .1
1.4
1.9
1 1.3
20.4
0.0
6.0
14.1
0.0
6.5
12.0
11 .4
212021
202.6
86.8
172.6
0.0
6.3
33.0
41 5
1.4
1.9
11 .4
20.6
0.0
7.6
14.3
4.0
6.6
12.3
11.7
3t2021
231.5
99.7
202.0
0.0
6.1
32.2
41.7
1.3
1.8
12.2
19.5
0.0
4.2
14.3
0.0
7.0
1 1.5
110
4t2021
227.1
96.9
197.4
29.4
6.1
32.6
41.8
IJ
1.8
12.3
20.3
00
4.3
14.3
0.0
7.2
12.2
11.6
5t2021
275.5
116.5
238.7
69.9
6.1
38.2
44.0
1.5
1.8
13.4
25.9
9.7
12.O
15.0
12.4
7.5
16.5
15.3
6t2021
1 68.1
72.7
147.5
87.7
5.9
36.2
40.1
4.2
1.7
12.0
24.4
9.6
12.0
13.7
12.8
7.0
15.1
14.1
712021
222.4
93.9
184.4
87.1
5.9
34.0
32.1
7.0
1.7
12.1
22.0
6.4
12.0
11.7
10.3
6.9
13.3
12.6
8t2021
141.4
64.3
126.6
56.6
6.1
26.9
29.5
10.3
1.8
12.4
15.0
0.0
6.5
10.4
0.0
7.0
8.1
8.1
9t2021
128.7
57.7
113.7
28.7
6.2
35.1
38.9
b.J
1.8
13.0
21.9
0.0
6.5
'13.8
0.0
7.2
13.1
12.4
10t202,1
192.7
83.4
164.1
8.8
6.3
36.1
43.0
1.3
1.9
13.0
22.9
0.0
6.2
14.8
0.0
7.0
13.7
12.9
1'U202'l
149.4
66.2
131 .3
0.0
6.2
33.4
41.9
1.3
1.9
1 't.5
20.7
0.0
5.4
14.4
0.0
6.4
12.0
11.5
12t2021
177.0
77.2
152.4
0.0
6.2
33.0
41.3
1.3
1.9
11 .4
20.5
0.0
5.9
14.2
0.0
6.4
1 1.9
11.4
aMW
193.9
83.7
167.2
30.7
6.1
33.6
39.7
3.2
1.8
12.2
21.2
2.1
7.4
13.8
J,C
6.9
12.6
12.0
HCC Total
ROR Total
Total
474.7
't65.0
639.7
462.0
172.6
634.6
s33.2
162.9
696.r
s21.4
195.2
716.5
630.7
289.1
919.8
388.3
296.6
684.9
500.7
275.0
775.7
332.3
198.6
s30.9
300.1
204.9
504.9
4/]0.2
'187.8
628.0
346.9
166.7
s13.6
406.6
165.4
572.O
444.8
206.6
6s't.4
'HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 90th Percentile Water, 7orh Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
HCC-
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2022
210.4
89.1
176.1
0.0
6.2
33.0
41.7
1.4
1.9
1 1.3
20.8
0.0
7.6
14.3
4.0
6.5
12.2
11 .7
2t2022
202.9
86.9
172.8
0.0
6.3
33.2
41.7
1.4
1.9
11 .4
21.0
0.0
9.1
14.3
5.5
6.6
12.5
11.9
3t2022
231 8
99.8
202.2
0.0
6.1
32.1
41.6
1.3
1.8
12.2
19.4
0.0
4.2
14.2
0.0
7.0
11 .4
11.0
4t2022
224.7
95.9
195.5
30.5
6.1
32.6
41.2
1.3
1.8
12.3
20.3
0.0
4.0
14.1
0.0
7.2
12.2
11.6
5t2022
275.9
116.7
239.0
70.1
6.1
38.4
43.9
1.5
1.8
13.4
26.0
9.6
12.0
15.0
12.3
7.5
16.6
15.4
6t2022
167.9
72.6
147.3
87.4
5.9
36.2
39.1
4.2
1.7
12.0
9.5
12.0
13.4
12.6
7.0
14.9
14.0
712022
222.1
93.8
184.2
86.7
5.9
34.0
32.0
7.0
1.7
12.1
21.9
6.4
12.0
1 1.6
10.3
6.9
13.2
12.5
8t2022
141 .1
64.2
126.3
56.0
6.1
26.8
29.4
10.3
1.8
12.4
14.9
0.0
6.5
10.3
0.0
7.0
8.0
8.1
9t2022
128.2
57.4
113.2
28.6
6.2
35.0
38.8
6.3
1.8
13.0
21.8
0.0
6.5
13.8
0.0
7.2
13.0
12.3
10t2022
192.5
83.3
164.0
8.6
6.3
36.0
43.0
1.3
1.9
13.0
22.8
0.0
6.2
14.8
0.0
7.0
13.6
12.9
11t2022
149.3
66.1
131 2
0.0
6.2
33.4
41.8
1.3
1.9
11.5
20.7
0.0
5.4
14.4
0.0
6.4
12.0
11.5
12t2022
178.0
77.7
153.3
0.0
6.2
33.4
41.8
1.3
1.9
11.4
20.9
0.0
7.5
14.2
3.9
6.4
12.3
't1.7
aMW
193.7
83.6
167.1
30.7
6.1
33.7
39.7
3.2
1.8
12.2
21.2
2.1
7.8
13.7
4.1
6.9
12.7
12.1
HCC Total
ROR Total
Total
475.6
172.5
648.1
462.6
176.8
639.4
533.8
162.4
696.2
5't6.1
195.2
7',t1.3
63r.6
289.5
921.1
387.8
294.2
682.0
500.1
274.1
774.2
331.6
197.5
529.1
298.8
204.2
503.0
439.8
187.3
G27.1
346.6
166.6
s13.2
409.0
172.9
s81.9
444.4
207.8
652.2
'HCC=Hells Canyon Complex, *ROR= Run of River
Page 140 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) goth Percentile Water, 70th Percentile Load
Resource
American Falls
1,000 Springs
Bliss
C.J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type 1t2023
210.1
89.0
't 75.9
0.0
6.2
33.0
41.6
1.4
1.9
't 1.3
20.7
0.0
7.6
14.2
4.0
6.5
12.2
1'1.6
2t2023
203.2
87.1
173.0
o.o
6.3
33.2
41.6
1.4
1.9
11.4
20.9
0.0
9.1
14.3
5.5
6.6
12.5
1 1.9
3t2023
231.5
99.7
202.O
0.0
6.1
32.0
41.5
1.3
1.8
12.2
19.3
0.0
4.2
14.2
0.0
7.0
11.4
10.9
4t2023
224.6
95.9
195.3
30.5
6.1
32.6
41.2
1.3
1.8
12.3
20.3
0.0
4.0
't4.1
0.0
7.2
12.1
11.6
5t2023
276.1
116.7
239.2
70.1
6.1
38.4
43.9
1.5
1.8
13.4
26.0
9.5
12.0
15.0
12.2
7.5
16.5
15.4
6t2023
167.6
72.5
147.1
87.4
5.9
36.1
38.9
4.2
1.7
12.O
24.0
9.4
12.0
13.4
12.4
7.0
14.8
'13.8
7t2023
221.8
93.6
183.9
86.7
5.9
33.9
3'1.9
7.0
't.7
12.1
21.9
6.4
12.0
'I 1.6
10.3
6.9
13.2
12.5
8t2023
't40.7
64.0
126.0
56.0
6.1
26.7
29.2
'10.3
1.8
12.4
14.8
0.0
6.5
'10.3
0.0
7.0
8.0
8.0
9t2023
126.9
56.8
112.1
28.6
6.2
34.9
38.8
6.3
1.8
13.0
21.6
0.0
6.5
13.8
0.0
7.2
12.9
12.2
10t2023
192.6
83.3
1112023
148.8
65.9
33.2
41.7
1.3
1.9
1 1.5
20.6
0.0
5.4
14.3
0.0
6.4
11.9
11 .4
12t2023
178.1
77.7
153.4
0.0
6.2
33.4
41.7
1.3
1.9
11.4
20.8
0.0
7.5
14.2
3.9
6.4
12.2
11.7
aMW
193.5
83.5
166.9
30.6
6.1
33.6
39.6
3.2
1.8
12.2
21.1
2.1
7.8
13.7
4.0
6.9
12.6
12.0
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
35.9
43.0
1.3
1.9
13.0
22.7
0.0
6.2
14.7
0.0
7.0
13.6
12.8
'164.0 130.8
8.5 0.0
6.3 6.2
HCC Total
ROR Total
Total
475.O
172.1
647.1
463.3
176.6
639.9
533.2
t62.0
695.2
515.8
195.1
7't0.9
632.0
289.2
921.2
387.2
293.1
680.3
499.3
273.9
773.2
330.7
197.0
527.7
295.8
203.7
499.5
439.9
t86.8
626.7
345.5
165.9
511.4
4iJ9.2
172.6
581.8
443.9
207.3
6st.2
'HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW 90th Percentile Water, 7Oh Percentile Load
Resource
American Falls
1,000 Springs
Bliss
C.J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 'l&2
Upper Salmon 3&4
Type
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
112024
209.8
88.9
175.7
0.0
6.2
32.9
41.5
1.4
1.9
1 1.3
20.7
0.0
7.6
14.2
4.0
6.5
12.1
11.6
2t2024
193.2
82.8
164.6
0.0
o.J
32.0
40.2
1.4
'1.9
11.4
20.1
0.0
8.8
13.8
5.3
o_o
't2.0
11.4
3t20u
231.2
99.6
201.7
0.0
6.1
31.9
41.4
1.3
1.8
12.2
19.3
0.0
4.2
14.2
0.0
7.0
11.3
10.9
4t2024
224.4
95.8
195.2
30.4
6.1
32.6
41.2
1.3
1.8
12.3
20.2
0.0
4.0
14.1
0.0
7.2
12.1
11.6
5t2024
276.3
115.8
239.3
70.1
6.1
38.5
43.9
1.5
1.8
13.4
26.0
9.3
12.O
15.0
12.O
7.5
16.5
15.4
6t2024
167.3
72.3
146.8
87.4
5.9
36.1
38.8
4.2
1.7
12.0
23.8
9.2
12.0
13.3
12.3
7.0
14.6
13.7
7t2024
221.5
93.5
183.6
86.7
5.9
33.8
31.8
7.0
1.7
12.1
21.8
6.4
12.O
11.6
10.3
6.9
13.1
12.4
8t2024
140.3
63.9
125.6
56.0
6.1
26.6
29.1
10.3
1.8
12.4
14.7
0.0
6.5
10.2
0.0
7.0
7.9
8.0
9t2024
125.5
56.2
1 10.9
28.5
6.2
34.7
38.7
6.3
1.8
'13.0
21.5
0.0
6.5
13.8
0.0
7.2
12.8
12.1
10t2024
192.3
83.1
163.6
8.5
6.3
35.7
42.9
1.3
1.9
13.0
22.6
0.0
6.2
14.7
0.0
7.0
13.5
12.7
11t2024
't49.2
66.0
131.0
0.0
6.2
33.1
41.6
1.3
1.9
1 1.5
20.5
0.0
5.4
14.3
0.0
6.4
11.9
1't.3
12t2024
177.9
77.6
1 53.1
0.0
6.2
33.3
41.4
1.3
1.9
11.4
20.7
0.0
7.5
14.2
3.9
6.4
12.2
1 1.6
aMW
192.4
83.0
165.9
30.6
6.1
33.4
39.4
3.2
'1.8
12.2
21.0
2.1
't 3.6
4.0
6.9
12.5
1 1.9
HCC Total
ROR Total
Total
474.4
171.8
646.2
&o.7
171.0
611.7
532.5
16r.7
694.2
5r5.4
{94.9
710.3
632.4
288.9
92{.3
386.4
292.1
678.5
498.6
273.4
772.0
329.8
t96.5
526.3
292.5
203.{
495.6
,$9.0
186.2
625-2
3&.2
r65.5
511.7
/O8.6
172.O
580.6
441.4
206.4
647.8
'HCC=Hells Canyon Complex, *ROR= Run of River
2017 lntegrated Resource Plan-Appendix C Page 141
Existing Resource Data ldaho Power Company
Hydro Modeling Results (PDR580) (continued)
Average ilegawatt (aMW) 90h Percentile Water, 70th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
HCC.
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2025
209.6
88.8
175.4
0.0
6.2
32.8
41.4
1.4
1.9
1 1.3
20.5
0.0
7.6
14.2
4.0
6.5
12.0
1 1.5
u202s
195.7
83.9
166.8
0.0
6.3
33.0
41.5
1.4
1.9
11 .4
20.7
0.0
9.1
14.2
5.5
b.b
12.4
11.8
3t2025
230.9
99.4
201.4
0.0
6.1
31.8
41.2
1.3
1.8
12.2
19.2
0.0
4.2
14.2
0.0
7.0
1'1.3
10.8
4t2025
224.2
95.7
195.0
303
o. I
32.5
41 .1
1.3
1.8
12.3
20.2
0.0
4.0
14.1
0.0
7.2
12.1
11 .5
5t2025
276.4
1 16.9
239.4
69.8
6.1
38.5
44.O
1.5
1.8
13.4
25.9
9.2
12.0
15.0
'1 1.9
7.5
16.5
15.3
6t2025
167.0
72.2
146.5
87.3
59
36.0
38.6
4.2
1.7
12.0
23.6
9.1
12.0
13.3
12.3
7.0
14.4
13.6
7t2025
221.0
93.3
183.3
86.7
5.9
33.7
31.6
7.0
1.7
12.1
21.7
6.4
12.0
1 1.5
10.3
6.9
13.0
12.3
8t202s
139.9
63.7
125.3
56.0
6.1
26.5
28.9
10.3
1.8
12.4
14.6
0.0
6.5
10.2
0.0
7.0
7.8
70
9t202s
124.1
55.5
109.6
28.4
6.2
34.5
38.6
6.3
1.8
13.0
21.3
0.0
6.5
13.8
0.0
7.2
12.7
120
10t202s
192.2
83.0
163.4
8.4
6.3
35.6
42.8
1.3
'1.9
13.0
22.4
0.0
6.2
14.6
0.0
7.0
13.4
12.6
11t2025
149.1
65.9
130.9
0.0
6.2
33.0
41.5
1.3
1.9
11 .5
20.3
0.0
5.4
14.2
0.0
6.4
1 1.8
'1 1.3
12t2025
177.5
77.4
152.9
0.0
o.z
33.2
41.3
1.3
1.9
11.4
20.6
0.0
7.5
14.1
4.0
6.4
12.1
1 1.5
aMw
192.3
83.0
165.8
30.6
6.1
33.4
39.4
3.2
1.8
12.2
20.9
2.1
7.8
13.6
4.0
6.9
12.5
11.8
HCC Total
ROR Total
Total
473.8
17'1.2
645.0
446.4
175.8
622.2
531.7
,t61.2
692.9
514.9
194.5
709.4
632.7
288.3
921.0
385.7
291.1
576.8
497.6
272.7
770.3
328.9
195.9
524.8
289.2
202.2
491.4
438.6
185.4
624.0
345.9
't 64.9
510.8
407.8
171.5
s79.3
441.1
206.2
647.3
*HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 90th Percentile Water, Toth Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2026
209.2
88.6
175.1
00
6.2
32.7
41.'l
1.4
1.9
1 1.3
20.4
0.0
7.6
14.1
4.0
6.5
12.0
'11.4
2t2026
192.4
82.4
164.0
0.0
6.3
32.9
41.5
1.4
10
11 .4
20.6
0.0
9.2
14.1
5.5
6.6
12.3
11.7
3t2026
230.5
99.2
201.1
0.0
6.1
31.7
41.1
'1.3
1.8
12.2
1 9.1
0.0
4.2
14.2
0.0
7.0
11.2
10.8
4t2026
223.9
95.5
194.7
30.3
ol
32.5
41.0
1.3
1.8
12.3
20.1
0.0
4.0
14.1
0.0
7.2
12.0
11.5
st2026
276.5
1 16.9
239.5
69.5
6.1
38.3
44.0
1.5
1.8
13.4
25.9
9.2
12.0
15.0
I 1.9
75
16.5
15.3
6t2026
166.8
72.1
146.4
87.0
(o
35.7
38.4
4.2
1.7
12.0
23.4
9_1
12.0
13.2
12.3
7.0
14.4
13.5
7t2026
220.7
93.2
183.0
86.7
50
33.6
31.5
7.O
1.7
12.1
21.6
6.4
12.0
'I 1.5
'10.3
6.9
13.0
12.3
8t2026
139.5
63.4
124.9
56.0
6.1
26.3
28.8
10.3
1.8
12.4
14.5
0.0
6.5
10.1
0.0
7.0
7.7
7.8
9t2026
121.6
54.4
107.4
28.1
6.2
34.3
38.6
6.3
1.8
13.0
21.1
0.0
6.5
13.7
0.0
7.2
12.5
1 1.9
10t2026
192.7
83.1
163.5
8.3
o.J
35.4
42.7
1.3
1.9
13.0
22.3
0.0
6.2
14.6
0.0
7.0
13.3
12.5
't1t2026
149.5
66.1
131.2
0.0
oz
32.9
41.5
'1.3
1.9
11.5
20.2
0.0
5.4
14.2
0.0
6.4
11.7
11.2
12t2026
177 .1
77.3
152.5
0.0
6.2
JJ. I
41.2
1.3
't.9
11 .4
20.6
0.0
7.5
14.1
4.0
6.4
12.0
11.5
aMW
191.7
82.7
165.3
30.5
6.1
33.3
39.3
3.2
1.8
12.2
20.8
2.1
7.8
13.6
4.0
6.9
12.4
1 1.8
HCC Total
ROR Total
Total
472.9
170.5
6€.4
438.8
175.4
614.2
530.8
160.8
691.6
514.1
194.2
708.3
632.9
287.8
920.7
385.3
289.9
675.2
496.9
272.4
769.3
327.8
195.2
523.0
283.3
201.2
484.5
439.3
184.7
624.O
346.8
164.5
511.3
406.9
171.2
578.1
439.7
205.6
645.3
'HCC=Hells Canyon Complex, *ROR= Run of River
Page 142 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Hydro Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon '1&2
Upper Salmon 3&4
Type
HCC-
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2027
208.8
88.5
174.8
0.0
6.2
32.6
41.0
1.4
'1.9
1 1.3
20.2
0.0
7.7
14.1
4.1
5.5
11.8
11.3
2t2027
192.0
82.3
163.7
0.0
6.3
Jt. I
41.5
1.4
1.9
11 .4
20.5
0.0
9.2
14.1
5.5
6.6
12.2
11.6
3t2027
230.1
99.1
200.7
nn
6.'l
31.7
41.0
1.3
1.8
12.2
19.0
0.0
4.2
14.1
11 .1
10.7
4t2027
223.6
95.4
194.5
30.3
6.1
32.5
40.9
1.3
1.8
12.3
20.1
0.0
4.0
14.1
0.0
12.0
1 1.5
5t2027
276.5
1 '16.9
239.5
69.5
6.1
38.2
44.O
1.5
1.8
13.4
25.8
8.6
12.0
15.0
11 .4
7.5
16.4
15.2
6t2027
166.7
72.0
1 46.3
86.9
5.9
35.3
38.1
4.2
1.7
12.0
23.3
86
12.0
13.1
tl J
7.0
14.3
13.4
7t2027
220 2
93.0
182.6
86.7
5.9
33.4
31.3
7.0
1.7
12.1
21.5
64
12.0
11.4
10.3
6.9
12.9
12.2
8t2027
139.0
63.2
124.5
56.0
6.1
26.2
286
10.3
1.8
12.4
14.4
0.0
6.5
10.1
0.0
7.0
t.o
7.7
9t2027
120.2
53.7
106.2
27.8
6.2
34.1
38.4
6.3
1.8
13.0
21.0
0.0
6.5
13.6
0.0
7.2
12.4
'1 1.8
10t2027
192.6
83.0
163.4
8.2
6.3
35.3
42.5
1.3
1.9
13.0
22.2
00
6.2
14.5
0.0
7.0
1 3.1
12.4
11t2027
149.4
66.0
131 .1
0.0
6.2
32.7
41.4
1.3
1.9
'I 1.5
20.1
0.0
5.4
't4.1
0.0
6.4
1 1.6
11.1
12t2027
176.8
77.1
152.2
0.0
6.2
33.0
41.2
1.3
1.9
11.4
20.5
0.0
7.6
14.1
4.0
6.4
12.0
11 .4
aMW
101 ?
82.5
165.0
30.4
6.1
33.1
39.2
3.2
1.8
12.2
20.7
2.0
7.8
13.5
4.0
6.9
12.3
11 .7
HCC Total
ROR Total
Total
472.1
170.0
642.1
438.0
174.9
6't 2.9
529.9
160.3
690.2
513.5
194.1
707.6
632.9
286.3
919.2
385.0
288.2
673.2
495.8
271.6
767.4
326.7
194.6
521.3
280.0
200.1
480.1
439.0
't83.8
622.8
346.5
163.8
510.3
406..t
171.0
577.1
438.8
204.9
643.7
'HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
BIiSS
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
UpperSalmon 1&2
Upper Salmon 3&4
Type
HCC-
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2028
208 4
88.3
17 4.5
00
6.2
32.5
40.9
1.4
1.9
1 1.3
20.1
0.0
7.7
14.1
4.1
6.5
11.7
11 .2
2t2028
185 0
79.3
157.8
0.0
o.c
31.5
40.0
1.4
1.9
11.4
19.7
0.0
8.9
13.7
5.3
6.6
11.7
11 .1
3t2028
228.1
98.2
199.1
00
61
31.6
40.9
1.3
1.8
12.2
18.9
0.0
4.2
14.1
0.0
7.0
11.0
10.6
412028
223.2
95.3
194.2
30.3
6.1
325
40.8
1.3
1.8
12.3
200
0.0
4.0
14.0
0.0
72
11.9
11 .4
5t2028
276.6
117.0
239.6
69.3
6.1
37.8
44.0
1.5
1.8
13.4
25.6
8.3
12.0
15.0
11.1
7.5
16.2
1 5.1
6t2028
166.4
71.9
146.1
86.8
5.9
34.9
37.9
4.2
12.0
23.2
8.2
12.0
13.0
1 1.9
7.0
14.2
13.3
7t2028
219.7
92.8
182.2
86.7
50
33.3
31.2
7.0
1.7
12.1
21.4
6.4
12.0
11.4
10.3
6.9
12.8
12.2
8t2028
138.6
63.0
124.1
56.0
6.1
26.1
28.4
10.3
1.8
12.4
14.3
0.0
6.5
10.0
0.0
70
7.5
7.7
9t2028
118.1
^)7
104.3
27.7
6.2
33.9
38.2
6.3
1.8
13.0
20.8
0.0
6.5
13.5
0.0
7.2
12.3
11.7
10t2028
193.0
83.1
163.5
8.2
OJ
35.1
42.4
1.3
'1.9
13.0
22.0
0.0
6.2
14.4
0.0
7.0
13.0
12.3
11t2028
149.6
66.1
131.2
0.0
6.2
32.6
41.3
1.3
1.9
11.5
19.9
0.0
5.4
14.1
0.0
6.4
1 1.5
11.0
12t2028
176.4
76.9
151.9
00
o.z
32.9
41.1
1.3
1.9
11.4
20.4
0.0
7.6
14.1
4.0
6.4
11.9
11 .4
aMW
190.3
82.0
164.0
30.4
6.1
32.9
38.9
3.2
1.8
12.2
20.5
1.9
7.7
13.5
3.9
6.9
12.1
1 1.6
HCC Total
ROR Total
Total
471.2
169.5
640.7
422.O
't69.4
591.4
525.4
159.8
685.2
512.7
193.6
706.3
633.2
284.6
917.8
384.4
286.3
670.7
494.7
271.2
765.9
325.7
194.0
519.7
275.0
199.0
474.0
439.6
{83.0
622.6
346.9
163.2
510.1
405.2
170.6
575.8
436.3
203.7
640.0
'HCC=Hells Canyon Complex, *ROR= Run of River
2017 lntegrated Resource Plan-Appendix C Page 143
Existing Resource Data ldaho Power Company
Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 7orh Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
HCC-
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2029
208.0
88.1
174.2
0.0
6.2
32.4
40.8
1.4
1.9
1 1.3
20.0
0.0
7.7
14.1
4.1
6.5
11.6
11.1
2t2029
191 .3
81.9
1 63.1
0.0
6.3
32.5
41.3
1.4
1.9
11 .4
20.2
0.0
9.1
14.1
5.4
b_b
12.O
11 .4
3t2029
227.6
98.0
198.7
0.0
6.1
31.5
40.4
1.3
1.8
12.2
18.8
0.0
4.2
14.1
0.0
7.0
11.0
'10.6
4t2029
222.8
95.'t
193.9
30.3
6.1
32.4
40.5
1.3
1.8
12.3
19.9
0.0
3.9
14.0
0.0
7.2
11.9
11 .4
5t2029
276.7
117 .0
239.6
69.0
6.1
37.7
43.9
1.5
1.8
13.4
25.3
8.3
12.0
15.0
11.1
7.5
16.1
14.9
6t2029
165.6
71.6
145.4
86.8
5.9
34.6
37.7
4.2
1.7
12.0
23.0
8.2
12.0
13.0
11.8
7.0
14.0
13.2
7t2029
219.2
92.6
181 .8
86.7
5.9
55.2
31.0
7.0
1.7
12.1
21.3
6.4
12.0
11.3
10.3
6.9
12.7
12.1
8t2029
1 38.1
62.8
123.6
56.0
6.1
25.9
28.2
10.3
1.8
12.4
14.2
0.0
6.5
9.9
0.0
7.0
7.4
7.6
9t2029
116.2
51.9
102.7
27.5
o.z
33.7
37.9
6.3
1.8
13.0
20.6
0.0
6.5
'13.4
0.0
7.2
12.1
1 1.6
10t2029
192.9
83.0
163.3
8.4
6.3
34.9
42.2
1.3
1.9
''t3.0
21.9
0.0
o.t
14.4
0.0
7.0
'12.9
12.2
11t2029
149.7
66.1
131.3
0.0
6.2
32.4
41.1
1.3
1.9
11.5
19.8
0.0
5.4
14.1
0.0
6.4
11 .4
10.9
12t2029
175.9
76.7
151.5
0.0
6.2
32.8
40.9
1.3
1.9
11.4
20.3
0.0
7.6
14.1
4.0
6.4
I 1.8
1 1.3
aMW
190.3
82.1
164.1
30.4
6.1
32.8
38.8
3.2
1.8
12.2
20.4
1.9
7.8
13.5
3.9
6.9
12.1
11 .5
HCC Total
ROR Total
Total
470.3
r69.0
639.3
436.3
173.6
609.9
524.3
1 59.1
683.4
5'l 1.8
r93.0
704.8
633.3
283.5
9't6.8
382.5
28s.2
667.8
493.5
270.5
764.1
324.5
193.2
517.7
270.7
197.8
468.5
439.2
182.5
621.7
347.1
162.5
509.6
404.1
170.0
574.1
436.5
203.3
639.8
'HCC=Hells Canyon Complex, *ROR= Run of Rrver
Average Megawatt (aMW) 90th Percentile Water, Toth Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
BIiSS
C J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
Type
HCC.
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2030
207.6
87.9
173.8
0.0
6.2
32.3
40.8
14
1.9
1 1.3
to o
0.0
7.7
't4.1
4.1
6.5
1 .1.6
11.1
2t2030
190.8
81.8
162.7
0.0
6.3
32.4
41.1
1.4
1.9
11.4
20.2
0.0
9.1
14_1
5.4
6.6
11.9
11.4
3/2030
227.2
97.8
198.3
0.0
6.1
31.4
40.3
1.3
1.8
12.2
18.7
0.0
4.2
14.1
0.0
7.0
10.9
10.5
4t2030
222.2
94.8
193.4
30.9
o_t
32.3
40.3
1.8
12.3
19.9
0.0
eo
13.9
0.0
7.2
11.8
11.3
5/2030
276.7
117.O
239.7
69.0
6.'l
37.7
43.9
1.5
1.8
13.4
25.3
8.2
12.0
15.0
1 1.0
7.5
16.0
14.9
6/2030
164.9
71.2
144.8
86.4
5.9
34.4
37.5
4.2
1.7
12.0
22.8
8.1
12.0
12.9
1 1.6
7.0
13.9
1 3.1
7t2030
218.8
92.4
181.4
86.7
5.9
33.1
30.8
7.0
1.7
12.1
21.2
6.4
12.0
11.2
10.3
6.9
12.7
12.0
8/2030
137.6
62.5
123.2
56.1
6.1
258
28.0
10.3
t.o
12.4
14.0
0.0
6.5
oo
0.0
7.0
7.3
7.5
9/2030
114.5
51 .1
10'1 .1
27.4
6.2
33.6
37.7
6.3
1.8
13.0
20.5
0.0
6.5
13.4
0.0
7.2
12.0
10/2030
192.9
82.9
1 63.1
8.3
6.3
34.8
42.1
1.3
1.9
13.0
21.7
0.0
6.2
14.3
0.0
7.0
12.8
12.1
1'U2030
149.9
66.2
131 .4
0.0
6.2
32.3
40.9
1.3
1.9
I 1.5
19.7
0.0
5.4
14.1
0.0
6.4
1 1.3
10.8
'12t2030
175.5
76.5
151.2
0.0
6.2
32.7
40.8
1.3
1.9
11.4
20.2
0.0
7.6
14.0
4.0
6.4
11.7
11.2
aMW
189.9
81.8
163.7
30.4
6.1
32.7
38.7
3.2
1.8
12.2
20.3
1.9
7.8
13.4
3.9
6.9
12.0
1 1.5
HCC Total
ROR Total
Total
469.3
168.8
638.1
435.3
173.2
608.5
523.3
158.6
681.9
510.4
193.0
703.4
633.4
283.2
916.6
380.9
283.6
564.5
492.6
269.9
762.5
323.3
192.6
515.9
266.6
197.1
463.7
€8.9
181.7
620.6
347.5
161.9
509.4
403.2
,r69.4
572.6
435.4
202.7
638.1
'HCC=Hells Canyon Complex, *ROR= Run of River
Page 144 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
BIiSS
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1 &2
Upper Salmon 3&4
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2031
207.2
87.7
173.5
0.0
6.2
32.3
41.O
1.4
1.9
11.3
19.9
0.0
7.7
14.1
4.1
6.5
1 1.6
11.1
2t2031
190.4
81 .6
162.4
0.0
b_J
32.4
41.0
1.4
1.9
11.4
20.1
9.2
14.1
(R
6.6
11.9
1 l.3
3t203',1
226.7
97.6
197.9
0.0
6.1
31.6
40.6
'1.3
1.8
12.2
18.7
0.0
4.2
14.1
0.0
7.0
10.8
10.5
4t2031
221.8
94.7
193.0
31 .1
6.1
32.2
40.1
1.3
1.8
12.3
19.8
0.0
3.9
13.9
0.0
7.2
11.8
11.3
5t2031
276.7
117.0
239.7
68.8
6.1
37.7
43.8
1.5
1.8
13.4
25.2
8.1
12.0
15.0
10.8
7.5
15.9
14.8
6t2031
164.4
71.0
144.4
86.6
(o
34.2
37.3
4.2
1.7
12.0
22.6
8.0
12.0
12.9
1'1.3
7.0
13.7
12.9
7t2031
218 3
92.2
181.0
86.5
5.9
33.0
30.7
7.0
1.7
12.1
21.1
6.4
12.0
11.2
10.3
6.9
12.6
12.O
8t2031
137.1
62.3
122.7
56.0
6.1
25.6
27.9
10.3
1.8
12.4
13.9
0.0
6.5
9.8
0.0
7.0
7.2
7.4
9t2031
1 13.9
50.8
100.6
27.4
6.2
33.4
37.4
6.3
1.8
13.0
20.3
0.0
6.5
13.3
0.0
7.2
1 1.9
11.4
10t2031
192.3
82.6
162.7
8.3
6.3
34.6
42.0
1.3
1.9
13.0
21.6
0.0
6.2
14.2
00
70
12.7
12.0
11t2031
149 6
66.0
131 .1
0.0
6.2
32.1
40.8
1.3
1.9
11.5
19.5
0.0
5.4
14.1
0.0
6.4
11.2
10.7
12t2031
177.7
77.5
153.0
0.0
6.2
32.7
40.6
1.3
1.9
11.4
20.1
0.0
7.6
14.0
4.0
6.4
11.7
11.2
aMw
189.7
81.8
163.5
30.4
6.1
32.7
38.6
3.2
1.8
12.2
20.2
1.9
7.8
13.4
3.8
6.9
1 1.9
11.4
HCC Total
ROR Total
Total
468.4
169.0
637.4
434.4
173.1
607.5
522.2
159.0
681.2
509.5
192.8
702.3
633.4
282.3
915.7
379.8
282.4
G62.2
491.5
269.3
760.8
322.1
191.8
513.9
265.3
,t96.0
461.3
437.6
181.0
6't8.6
346.7
't61.2
507.9
408.2
169.1
577.3
434.9
202.2
637.2
*HCC=Hells Canyon Complex, *ROR= Run of River
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource
Brownlee
OSow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
UpperSalmon'l&2
Upper Salmon 3&4
Type
HCC.
HCC
HCC
ROR
ROR'-
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2032
206.6
87.5
173.0
00
6.2
32.2
40.9
1.4
1.9
11.3
19.8
0.0
7.7
14.1
4.1
6.5
1 1.5
11.1
2t2032
183.4
78.6
'156,4
0.0
bJ
31.2
39.4
1.4
1.9
11 .4
19.3
0.0
8.9
13.5
5.3
6.6
11.4
10.9
3t2032
226 3
97.4
197.6
0.0
6.1
31.6
40.5
1.3
1.8
12.2
18.6
0.0
4.2
14.0
0.0
7.0
10.8
10.4
4t2032
221.4
94.5
't92.7
31 .1
6.1
32.1
39.8
1.3
'1.8
12.3
19.7
0.0
3.9
13.8
0.0
7.2
11.7
11.2
512032
276.8
117.0
239.7
68.4
6.1
37.6
43.8
'1.5
1.8
13.4
24.9
7.8
12.O
14.9
10.5
7.5
15.7
14.7
6t2032
163.8
70.8
143.8
86.4
5.9
33.9
37.1
4.2
1.7
12.0
22.2
7.7
12.0
12.8
1 1.0
7.0
13.4
12.7
7t2032
217.8
91.9
180.6
86.5
5.9
328
306
7.0
1.7
12.1
21.0
6.4
12.0
11.1
10.3
6.9
12.5
1'1.9
8t2032
136.5
62.1
122 2
56.0
6.'l
25.5
27.7
10.3
't.8
12.4
13.8
0.0
6.5
9.8
0.0
7.0
7.1
7.3
9t2032
1 13.8
508
100.6
27.2
6.2
33.2
37 1
6.3
1.8
13.0
20.1
0.0
6.5
13.2
0.0
7.2
11.7
11.2
10t2032
190.2
81.7
160.9
8.3
6.3
34.4
41.8
1.3
1.9
13.0
2',t.4
0.0
6.2
14.2
0.0
7.0
12.6
11.9
1',U2032
149.7
66.1
131.2
0.0
6.2
32.0
40.5
1.3
1.9
1 1.5
19.4
0.0
5.4
14.0
0.0
6.4
11.0
10.6
12t2032
176.5
77.0
152 0
0.0
6.2
32.6
40.5
1.3
'1.9
11.4
20.0
0.0
7.6
14.0
4.0
6.4
116
11 .1
aMW
188.6
81.3
162.6
30.3
61
32.4
38.3
3.2
1.8
12.2
20.0
1.8
7.7
13.3
3.8
6.9
11.7
1'1.3
HCC Total
ROR Total
Total
467.1
168.5
635.7
418.5
167.5
s85.9
521.3
158.6
679.9
508.6
192.0
700.5
633.s
280.5
914.0
378.4
280.',|
658.5
490.3
268.6
758.9
320.8
191.2
512.0
26s.2
194.7
459.9
432.8
180.2
613.0
347.0
160.3
507.3
405.5
168.6
574.1
432.4
200.9
633.3
'HCC=Hells Canyon Complex, *ROR= Run of River
2017 lntegrated Resource Plan-Appendix C Page 145
Existing Resource Data ldaho Power Company
Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, 7oth Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
HCC.
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
112033
206.4
87.4
172.8
0.0
6.2
32.0
40.8
1.4
1.9
1 1.3
197
0.0
7.7
14.0
4.1
6.5
11.4
10.9
212033
189.5
81.2
161.7
0.0
6.3
32.2
40.7
1.4
1.9
11.4
19.9
0.0
9.2
14.0
5.5
b.b
11.7
11.2
3/2033
225.8
97.2
197.2
0.0
6.1
31.5
40.4
1.3
1.8
12.2
18.5
0.0
4.2
14.0
0.0
7.0
10.7
10.3
4t2033
221.1
94.4
192.5
30.1
6.1
32.1
39.3
1.3
1.8
12.3
19.7
0.0
39
13.6
0.0
7.2
11 .7
11.2
5/2033
276.4
1 16.9
239.4
68.4
6.1
J/.O
43.8
1.5
1.8
13.4
24.9
7.7
12.0
14.9
10.5
7.5
15.7
14.6
6/2033
163.2
70.5
143.4
85.9
5.9
33.8
36.9
4.2
1.7
12.0
22.1
7.6
12.0
12.8
10.9
7.0
13.3
12.6
7t2033
217.3
91.7
180.2
86.6
5.9
32.7
30.4
7.0
1.7
'12.1
20.9
6.4
12.0
11.1
10.3
6.9
12.4
1 1.8
8/2033
136.0
61.8
121.8
56.0
6.1
25.3
27.5
10.3
1.8
12.4
13.6
0.0
6.5
9.7
0.0
7.0
7.0
7.3
9/2033
1 13.8
50.8
100.6
27.1
6.2
33.0
36.9
6.3
1.8
13.0
19.9
0.0
6.5
13. 1
0.0
7.2
11.6
11.1
10t2033
188.0
80.8
1 59.1
8.2
6.3
34.3
41.6
1.3
1.9
13.0
21.3
0.0
6.2
14.1
0.0
7.0
12.4
11.8
11t2033
149.9
66.1
131 .3
0.0
6.2
31.8
40.3
1.3
1.9
1 1.5
19.3
0.0
5.4
13.9
0.0
6.4
10.9
10.6
12t2033
175.9
76.7
151 .5
0.0
6.2
32.4
40.3
1.3
1.9
't1.4
19.9
0.0
7.6
'13.9
4.0
6.4
11.5
1 1.0
aMW
188.6
81.3
162.6
30.2
6.1
32.4
38.2
3.2
1.8
12.2
20.0
1.8
7.8
13.3
3.8
6.9
11.7
11.2
HCC Total
ROR Total
Total
466.6
167.8
634.4
432.4
172.0
604.4
s20.2
158.1
678.3
508.0
190.3
698.3
632.7
280.3
913.0
377.1
278.8
655.9
489.2
268.1
757.3
319.6
190.4
s't0.0
265.2
193.5
458.8
427.9
179.3
607.2
347.3
159.6
506.9
404.1
167.8
571.9
432.5
200.5
633.0
'HCC=Hells Canyon Complex, -ROR= Run of River
Average Megawatt (aMW) 90th Percentile Water, 70th Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
HCCr
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2034
206.3
87.4
172.7
0.0
6.2
31.8
40.4
1.4
1.9
11.3
19.5
0.0
7.7
13.9
4.1
6.5
11.2
10.8
212034
189.1
81.0
161.3
0.0
6.3
32.0
40.5
1.4
1.9
1',1.4
19.8
0.0
9.2
13.9
5.5
6.6
1 1.6
11.1
3t2034
225.4
97.0
196.8
0.0
6.1
31.4
40.3
1.3
1.8
12.2
18.3
0.0
4.2
'13.9
0.0
7.0
10.6
10.3
4t2034
220.8
94.3
192.2
30.9
6.1
31.8
39.2
1.3
1.8
12.3
19.6
0.0
3.9
13.6
0.0
7.2
I 1.6
1't.1
5t2034
275.9
116.7
239.0
68.4
6.1
37.6
43.5
1.5
t.o
13.4
24.7
7.5
12.0
14.8
10.2
7.5
15 6
14.5
6t2034
162.6
70.3
142.9
85.1
5.9
33.6
36.4
4.2
1.7
12.0
21.9
7.4
12.0
12.6
10.7
7.0
1 3.1
12.4
7t2034
216.8
91.5
179.8
86.6
(o
32.6
30.4
7.0
1.7
12.1
20.8
6.4
12.0
11.0
10.3
6.9
12.3
11.7
8t2034
135.5
61.6
121.3
56.0
6.1
25.2
27.3
10.3
1.8
12.4
13.5
0.0
6.5
9.7
0.0
7.0
6.9
7.2
9/2034
113.7
50.8
100.6
26.6
6.2
32.8
36.6
b.J
1.8
13.0
19.7
0.0
6.5
13.0
0.0
7.2
1 1.5
11.0
10t2034
186.2
80.0
157.6
8.1
6.3
34.1
41.4
1.3
1.9
13.0
21.1
0.0
6.2
14.2
0.0
7.0
12.3
11.7
11t2034
149.7
66.0
131 .1
0.0
6.2
31.6
40.1
1.3
1.9
'1 1.5
19.1
0.0
5.4
13.9
0.0
6.4
10.8
10.5
12t2034
175.4
76.5
151 .1
0.0
6.2
32.3
40.2
1.3
1.9
11.4
19.8
0.0
7.6
13.9
4.0
6.4
11.4
1 1,0
aMW
1 88.1
81.1
162.2
30.1
6.1
32.2
38.0
3.2
1.8
12.2
19.8
1.8
7.8
13.2
3.7
6.9
1 1.6
11 .1
HCC Total
ROR Total
Total
466.4
166.6
633.0
431.4
171.2
602.6
519.2
157.5
676.7
507.3
190.4
697.7
631.6
279.0
910.6
375.8
276.1
651.9
488.1
267.6
755.7
318.4
't89.8
508.2
265.1
192.1
457.2
423.8
178.5
602.3
345.8
158.8
505.6
403.0
167.4
570.4
431.4
199.6
631.0
'HCC=Hells Canyon Complex, *ROR= Run of River
Page 146 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Existing Resource Data
Modeling Results (PDR580) (continued)
Average Megawatt (aMW) 90th Percentile Water, Toth Percentile Load
Resource
Brownlee
OSo,,
Hells Canyon
American Falls
1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon 1&2
Upper Salmon 3&4
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
112035
206.2
87.3
172.6
0.0
6.2
31.7
40.3
1.4
1.9
1 1.3
19.4
0.0
13.9
4.1
AE
11.2
10.8
2t203s
188.6
80.8
160.9
0.0
6.3
31 9
40.4
1.4
1.9
11 .4
19.7
0.0
9.2
13.9
EE
6.6
11 .5
11.1
3/2035
224.8
96.8
196.4
0.0
6.1
31.3
40.1
1.3
1.8
12.2
18.2
0.0
4.2
13.9
nn
7.0
10.5
10.2
4t2035
220.5
94.1
192.0
30.9
6.1
31.7
39.1
1.3
1.8
12.3
19.5
0.0
3.9
13.6
0.0
7.2
11.5
11 .1
5/2035
275.6
1 16.5
238.7
68.4
6.1
37.4
43.0
1.5
1.8
13.4
24.5
12.0
14.7
10.1
7.5
15.4
14.4
6/2035
162.1
70.0
142.4
84.9
5.9
33.4
35.7
4.2
1.7
12.0
21.7
7.1
12.0
12.5
10.6
7.0
13.0
I Z.C
7t2035
216.3
91.3
179.4
86.6
50
32.4
30.3
7.0
1.7
12.1
20.7
6.4
12.0
11.0
10.3
6.9
12.2
11 .7
8/2035
135.0
61.4
120.9
56.0
6.1
25.0
27.1
10.3
1.8
12.4
13.4
0.0
6.5
9.6
0.0
7.0
6.8
7.1
9/2035
113.7
50.8
100.6
26.4
6.2
32.5
36.3
6.3
1.8
13.0
19.5
0.0
6.5
13.0
0.0
7.2
11.3
10.9
10t2035
183.7
78.9
155.4
8.1
6.3
33.9
41.2
1.9
13.0
20.9
0.0
6.2
14.1
0.0
7.0
12.2
1 1.6
11t2035
150.2
oo.z
131.4
0.0
6.2
31.4
39.9
1.3
1.9
11.5
19.0
0.0
5.4
13.8
0.0
6.4
10.7
10.4
12t2035
175.0
/b_J
150.7
0.0
6.2
32.1
40.0
1.3
1.9
11.4
19.7
0.0
7.6
13.8
4.0
6.4
11.3
'10.9
aMw
187.6
80.9
161 .8
30.1
6.1
32.1
37.8
3.2
1.8
12.2
19.7
1.7
7.8
13.2
3.7
6.9
11.5
11.0
HCC Total
ROR Total
Total
466.1
t66.3
632.4
430.3
r70.8
601.1
518.0
156.9
674.9
s06.6
190.0
696.6
630.8
277.3
908.1
374.5
274.1
6la.6
487.0
267.1
754.1
317.3
189.0
506.3
265.1
t90.8
455.9
418.0
'177.6
595.5
347.8
158.0
505.8
402.0
166.6
568.6
430.3
198.7
629.0
'HCC=Hells Canyon Complex, "ROR= Run of River
Average Megawatt (aMW) 90th Percentile Water, 70ih Percentile Load
Resource
Brownlee
Oxbow
Hells Canyon
American Falls
'1,000 Springs
Bliss
C .J. Strike
Cascade
Clear Lake
Lower Malad
Lower Salmon
Milner
Shoshone Falls
Swan Falls
Twin Falls
Upper Malad
Upper Salmon l&2
Upper Salmon 3&4
Type
HCC'
HCC
HCC
ROR
ROR*
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
ROR
1t2036
205.4
87.0
172.0
0.0
6.2
31.6
39.9
1.4
1.9
1 1.3
19.3
0.0
7.7
13.8
4.1
65
11.1
10.7
212036
181.7
77.8
155.0
0.0
6.3
30.7
38.8
1.4
1.9
11.4
19.0
0.0
8.9
't3.3
5.3
6.6
1'1.1
10.7
3/2036
224.5
96.6
196.1
0.0
6'r
31.2
40.0
1.3
1.8
12.2
1 8.1
0.0
4.2
'13.9
0.0
70
10.4
1 0.1
4t2036
220.2
94.0
191 .7
31.2
6.1
31.6
39.0
1.3
1.8
12.3
19.4
0.0
3.9
13.5
0.0
7.2
'l 1.5
1 1.0
5/2036
275.6
116.5
238 7
68.4
6.1
42.7
1.5
1.8
13.4
24.4
o_t
12.0
14.6
9.8
75
15.4
14.3
6/2036
161.5
69.8
141 .9
84.8
59
35.0
4.2
1.7
12.0
21.6
6.6
12.0
12.3
10.5
7.0
12.9
12.2
7t2036
215.8
91.1
179.0
86.4
5.9
32.3
30.3
7.0
1.7
12.1
20.5
6.4
12.0
10.9
10.3
69
12.1
1 1.6
8/2036
134.5
61 .1
120.4
55.6
o. I
24.9
26.9
10.3
1.8
12.4
13.2
0.0
6.5
9.5
0.0
7.0
6.7
7.0
9/2036
I IJ.O
508
100.6
26.3
o.z
32.3
36.'l
6.3
1.8
13.0
'19.3
0.0
6.5
12.9
0.0
7.2
11.1
10.7
1 0/2036
17 4.7
78.1
153.5
8.1
63
33.7
40.9
1.3
1.9
13.0
20.8
0.0
6.2
14.0
0.0
7.O
12.1
1 1.5
1,1t2036
149.7
66.0
'131 .0
U.U
OZ
31.3
39.7
1.3
1.9
1 1.5
18.8
0.0
5.4
13.7
0.0
6.4
't0.6
10.3
12t2036
174.9
/o.J
150.6
0.0
6.2
32.0
39.8
1.3
1.9
11 .4
'19.6
0.0
7.6
13.8
4.0
6.4
11.2
10.8
aMW
186.0
80.4
160.9
30.1
6.1
31.8
37.4
3.2
1.8
12.2
19.5
1.6
7.7
13.0
J_t
6.9
11.4
10.9
HCC Total
ROR Total
Total
464.4
165.4
629.8
414.5
165.4
579.9
517.2
156.4
673.6
505.9
189.8
695.7
630.8
275.7
906.5
373.2
272.1
645.3
r185.9
266.3
752.2
316.0
187.8
503.8
265.0
189.6
454.6
406.3
't76.7
583.0
346.7
157.2
503.9
401.8
156.0
567.8
427.3
197.4
624.7
'HCC=Hells Canyon Complex, *ROR= Run of River
2017 lntegrated Resource Plan-Appendix C Page 147
Portfolio Analysis, Results, and Supporting Documentation ldaho Power Company
PonrroLro ANALYSTS, Resurrs,
AND SUPPORTING DOCUTUIENTATION
Portfolio Emissions
IPC Emissfons
COz Emission
(o
(f)oq
F-FoN
Noo
oc
P
6oF
100,000,000
98,000,000
96,000,000
94,000,000
92,000,000
90,000,000
88,000,000
86,000,000
84,000,000
82,000,000
80,000,000
NOx Emission
10,m0
70,000
60,000
50,000
40,m0
30,m0
(o(r)oN
NoN
xoz
al,EoF
E
P
m020,
il
P_1 P 2 P_3 P_4 P_5 P_6 P_7 P_8 P_9 P_1 0 P_11 P_12
P_7 P_8 P_9 P_10 P_11 P 12
Page 148
0 P_1 P_2 P_3 P_4 P_5 P_6
2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Portfolio Analysis, Results, and Supporting Documentation
HG Emission
1.2
1.0
o.2
0.0
SOz Emission
50,m0
45,m0
40,000
.8
.6
.4
0
0
0
@(f)oNIt-oN
(,
I
a
L
P
EoF
P_1 P_2 P_3 P_4 P_5 P_6 P_7 P_8 P_9 P_10 P_11 P_12
@(f)
R 35,m0
t-5 so.moAI
I ru,*oa
E 20,000oFa 15,000
oF 10,m0
5,0m
0 p_1 P_2 P_3 P_4 P_5 P_6 P_7 P_8 P_9 P_10 P_11 P_12
2017 lntegrated Resource Plan-Appendix C Page 149
Compliance with State of Oregon IRP Guidelines ldaho Power Company
GOUPIIANCE WITH Srere oF OREGoN IRP GuIoeUINES
Guideline 1 : Substantive Requirements
a. All resources must be evaluation on a consistent and comparable basis.
o All known resources for meeting the utility's load should be considered, including supply-
side options which focus on the generation, purchase and transmission of power - or gas
purchases, transportation, and storage - and demand side options which focus on
conservation and demand response.
. Utilities should compare different resource fuel types, technologies, lead times, in-service
dates, durations and locations in portfolio risk modeling.
o Consistent assumptions and methods should be used for evaluation of all resources.
o The after-tax marginal weighted-average cost of capital (WACC) should be used to discount
all future resource costs.
ldaho Power response:
Supply-side and purchased resources for meeting the utility's load are discussed in Chapter 3. ldaho Power Today-
Existing Supply-side Resources; demand-side options for are discussed in Chapter 5. Demand-Side Resources; and
transmission resources are discussed in Chapter 6. Iriansmission Planning-Existing Transmisslon Sysfem.
New resource options including fuel types, technologies, lead times, in-service dates, durations and locations are described
in Chapter 4. Future Supply-side Generation and Storage Resources, Chapter 5. Demand-Side resources, Chapter 6.
Transmission Planning, and ChapterT. Planning Peiod Forecasfs.
The consistent modeling method for evaluating new resource options is described in Chapter 7. Planning Peiod
Forecasfs-Resource Cost Analysis and Chapter 9. Modeling Analysis and Result-Planning Case Portfolio Analysis.
The WACC rate used to discount all future resource costs is stated in Chapter 9. Modeling Analysis and Resu/fs Table 9.1
Financial Assumptions.
b. Risk and uncertainty must be considered.
o At a minimum, utilities should address the following sources of risk and uncertainty:
l. Electric utilities: load requirements, hydroelectric generation, plant forced outages, fuel
prices, electricity prices, and costs to comply with any regulation of greenhouse gas
emissions.
2. Natural gas utilities: demand (peak, swing and baseload), commodity supply and price,
transportation availability and price, and costs to comply with any regulation of
greenhouse gas emissions.
o Utilities should identifr in their plans any additional sources of risk and uncertainty.
ldaho Power response:
Electric utility risk and uncertainty factors (load, NG and water conditions) for resource portfolios are considered in Chapter
9b Modeling Analysis and Resu/fs-Sfochastic Risk Analysis. Plant forced outages are modeled in Aurora on a unit basis
and is shown in the Technical Appendix, Existing Resource Dat*Hydroelectic and Thermal Plant Data.
Additional sourc€s of risk and uncertainty are discussed in Chapter 9. Modeling Analysis and Resu/fs.
c. The primary goal must be the selection of a portfolio of resources with the best combination of
expected costs and associated risks and uncertainties for the utility and its customers.
r The planning horizon for analyzing resource choices should be at least 20 years and account
for end effects. Utilities should consider all costs with a reasonable likelihood of being
Page 150 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Compliance with State of Oregon IRP Guidelines
a
o
a
included in rates over the long term, which extends beyond the planning horizon and the life
ofthe resource.
Utilities should use present value of revenue requirement (PVRR) as the key cost metric. The
plan should include analysis of current and estimated future costs for all longJived resources
such as power plants, gas storage facilities, and pipelines, as well as all short-lived resources
such as gas supply and short-term power purchases.
To address risk, the plan should include, at a minimum:
a. Two measures of PVRR risk: one that measures the variability of costs and one that
measures the severity of bad outcomes.
b. Discussion of the proposed use and impact on costs and risks of physical and financial
hedging.
The utility should explain in its plan how its resource choices appropriately balance cost
and risk.
ldaho Power response:
The IRP methodology and the planning horizon of 20 years are discussed in Chapter 1. Summary-lntroduction.
Modeling analysis of current and estimated future costs for all long-lived resources such as power plants, gas storage
facilities, and pipelines, as well as all short-lived resources such as gas supply and short-term power purchases is
discussed in Chapter 9. Modeling Analysis and Resu/fs.
The discussion of cost variability and extreme outcomes, including bad outcomes is discussed in Chapter 9. Modeling
Analysis and Risk.ldaho Powe/s Risk Management Policy regarding physical and financial hedging is discussed in
Chapter 1 a. Summary-lntroduction.
ldaho Power's plan is presented in Chapter 19. Summary-Action Plan and in more detail in Chapter 10. Prcfened Portfolio
and Action Plan.
d. The plan must be consistent with the long-run public interest as expressed in Oregon and federal
energy policies.
ldaho Power response:
Long-run public interest issues are discussed in Chapter 2. Political, Regulatory, and Operational /ssues
Guideli ne 2: Procedural Requirements
a. The public, which includes other utilities, should be allowed significant involvement in the
preparation of the IRP. Involvement includes opportunities to contribute information and ideas,
as well as to receive information. Parties must have an opportunity to make relevant inquiries of
the utility formulating the plan. Disputes about whether information requests are relevant or
unreasonably burdensome, or whether a utility is being properly responsive, D&y be submitted to
the Commission for resolution.
ldaho Power response:
The IRP Advisory Council meetings are open to the public. A roster of the IRP Advisory Council members along with
meeting schedules and agendas is provided in the Technical Appendix, IRP Advisory Council.
2017 lnlegrated Resource Plan-Appendix C Page 151
Compliance with State of Oregon IRP Guidelines ldaho Power Company
b. While confidential information must be protected, the utility should make public, in its plan, any
non-confidential information that is relevant to its resource evaluation and action plan.
Confidential information may be protected through use of a protective order, through
aggregation or shielding of data, or through any other mechanism approved by the Commission.
ldaho Power response:
ldaho Power makes public extensive information relevant to its resource evaluation and action plan in its plan. This
information is discussed in IRP Advisory Council meetings and found throughout the 2017 lRP, the 2017 Load and Sales
Forecast and in the 2017 Technical Appendix.
c. The utility must provide a draft IRP for public review and comment prior to filing a final plan
with the Commission.
ldaho Power response:
ldaho Power provided copies to members of the IRPAC on Thursday, May 11, 2017.The company requested for comments
to be provided no later than Friday, June 12,2017.
Guideline 3: Plan Filing, Review, and Updates
a. A utility must file an IRP within two years of its previous IRP acknowledgment order. If the
utility does not intend to take any significant resource action for at least two years after its next
IRP is due, the utility may request an extension of its filing date from the Commission.
ldaho Power response:
The OPUC acknowledged ldaho Power's 2015 IRP on April 28,2016 in Order 16-160. The ldaho Power 2017 IRP will be
filed by June 30, 2017.
b. The utility must present the results of its filed plan to the Commission at a public meeting prior
to the deadline for written public comment.
ldaho Power response:
ldaho Power will schedule a public meeting at the OPUC following the June 30,2017 filing of the 2017 IRP
c. Commission staff and parties should complete their comments and recommendations within six
months of IRP filing.
ldaho Power response:
No response needed.
d. The Commission will consider comments and recommendations on a utility's plan at a public
meeting before issuing an order on acknowledgment. The Commission may provide the utility an
opportunity to revise the plan before issuing an acknowledgment order.
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ldaho Power Company Compliance with State of Oregon IRP Guidelines
ldaho Power response:
No response needed.
e. The Commission may provide direction to a utility regarding any additional analyses or actions
that the utility should undertake in its next IRP.
ldaho Power response:
No response needed.
f. Each utility must submit an annual update on its most recently acknowledged plan. The update is
due on or before the acknowledgment order anniversary date. Once a utility anticipates a
significant deviation from its acknowledged IRP, it must file an update with the Commission,
unless the utility is within six months of filing its next IRP. The utility must summarize the
update at a Commission public meeting. The utility may request acknowledgment of changes in
proposed actions identified in an update.
ldaho Power response:
ln Order No. 16-160, the OPUC waived for ldaho Power the requirement to file an annual update to the 2015 IRP
g. Unless the utility requests acknowledgement of changes in proposed actions, the annual update is
an informational filing that:
o Describes what actions the utility has taken to implement the plan;
. Provides an assessment of what has changed since the acknowledgment order that affects the
action plan, including changes in such factors as load, expiration of resource contracts,
supply-side and demand-side resource acquisitions, resource costs, and transmission
availability; and
o Justifies any deviations from the acknowledged action plan.
ldaho Power response:
No response needed.
Guideline 4: Plan Components
At a minimum, the plan must include the following elements:
a. An explanation of how the utility met each of the substantive and procedural requirements;
ldaho Power response:
ldaho Power provides information on how the company met each requirement in a table is presented in the Technical
Appendix and will be provided to the OPUC staff in an informal letter.
b. Analysis of high and low load growth scenarios in addition to stochastic load risk analysis with
an explanation of major assumptions;
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Compliance with State of Oregon IRP Guidelines ldaho Power Company
ldaho Power response:
High-groMh scenarios at the 90th and 95th percentile levels for peak hour, and at the 70th and 90th percentile levels for
energy are provided in ChapterT. Planning Peiod Forecasfs. Stochastic load risk analysis is discussed in Chapter9.
Modeling Analysis and Resu/fs-Sfochastic Risk Analysis. Major assumptions are discussed in Chapter 7. Planning Peiod
Forecasfs and Chapter 9a. Modeling Analysis and Results-Planning Case Portfolio Analysis.
c. For electric utilities, a determination of the levels of peaking capacity and energy capability
expected for each year of the plan, given existing resources; identification of capacity and energy
needed to bridge the gap between expected loads and resources; modeling of all existing
transmission rights, as well as future transmission additions associated with the resource
portfolios tested;
ldaho Power response:
Peaking capacity and energy capability for each year of the plan for existing resources is discussed in Chapter 7. Planning
Peiod Forecasfs. Detailed forecasts are provided in the Technical Appendix, Sa/es and Load Forccast Data and Chapter
10. Existing Resource Data, and Chapter 5. Load and Resource Balance Dafa. ldentification of capacity and energy needed
to bridge the gap between expected loads and resources is discussed in Chapter 8. Portfolios.
d. For natural gas utilities, a determination of the peaking, swing and base-load gas supply and
associated transportation and storage expected for each year ofthe plan, given existing resources;
and identification of gas supplies (peak, swing and base-load), transportation and storage needed
to bridge the gap between expected loads and resources;
ldaho Power response:
Not applicable.
Identification and estimated costs of all supply-side and demand-side resource options, taking
into account anticipated advances in technology;
ldaho Power response:
Supply-side resources are discussed in Chapter 4. Future Supply-Side Generation and Storage Resources. Demand-side
resources are discussed in Chapter S-Demand-Side Resources. Resource costs are discussed in ChapterT. Planning
Peiod Forecasfs - Resource Cosfs and presented in the Technical Appendix, Supply-Side Resource Data Levelized Cosf
of Energy. Demand-side resources and their levelized costs and technologies are covered in Chapter 5. Demand-Side
Resources and in the Technical Appendix, Demand-Side Resource Data.
f. Analysis of measures the utility intends to take to provide reliable service, including
cost-risk tradeoffs;
ldaho Power response:
Resource reliability is covered in Chapter 9. Modeling Analysis and Resu/fs
g. Identification of key assumptions about the future (e.g., fuel prices and environmental
compliance costs) and alternative scenarios considered;
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ldaho Power Company Compliance with State of Oregon IRP Guidelines
ldaho Power response:
Key Assumptions including the natural gas price forecast are discussed in ChapterT. Planning Peiod Forecasfs and in the
Technical Appendix, Key Financial and Forccast Assumptions. Environmental compliance costs are addressed in the
Technical Appendix, Portfolio Analysri Resulfs and supporting Documentatior>Portfolio Emissrbns. Compliance
alternatives to SCR installation at Jim Bridger Units 'l and 2 are considered using portfolios with varying retirement dates of
Jim Bridger Units 1 and 2 and are discussed in Chapter I Portfolios.
h. Construction of a representative set of resource portfolios to test various operating
characteristics, resource types, fuels and sources, technologies, lead times, in-service dates,
durations and general locations - system-wide or delivered to a specific portion of the system;
ldaho Power response:
Resource portfolios considered for the 2017 IRP are described in Chapter 8. Portfolios. Resource portfolios were developed
using resources from the resource stack provided in Chapter 7. Planning Peiod Forecasfs-Resource Cost Analysis and
with guidance from the IRP Advisory Council and public participants.
i. Evaluation of the performance of the candidate portfolios over the range of identified risks and
uncertainties;
ldaho Power response:
Evaluation of the portfolios over a range of risks and uncertainties is discussed in Chapfer 9. Modeling Analysis
and Resu/fs.
j. Results of testing and rank ordering of the portfolios by cost and risk metric, and interpretation
of those results;
ldaho Power response:
Portfolio cost, risk results, interpretations and the selection of the preferred portfolio are provided in Chapter 9. Modeling
Analysis and Resu/fs.
k. Analysis of the uncertainties associated with each portfolio evaluated;
ldaho Power response:
The quantitative and qualitative uncertainties associated with each portfolio are evaluated in Chapter 9. Modeling Analysis
and Resu/fs.
l. Selection of a portfolio that represents the best combination of cost and risk for the utility and
its customers
ldaho Power response:
The preferred resource portfolio is identified in Chapter 10. Prcfened Portfolio and Action Plan.
m. Identification and explanation of any inconsistencies of the selected portfolio with any state and
federal energy policies that may affect a utility's plan and any barriers to implementation; and
2017 lntegrated Resource Plan-Appendix C Page 155
Compliance with State of Oregon IRP Guidelines ldaho Power Company
ldaho Power response:
Portfolio risk associated with the successful permitting to operate Jim Bridger Units 1 and 2 beyond their regional haze
compf iance dates without installation of SCR retrofits is discussed in Chapter 9 Modeling Analysis and Resu/fs.
n. An action plan with resource activities the utility intends to undertake over the next two to four
years to acquire the identified resources, regardless of whether the activity was acknowledged in
a previous IRP, with the key attributes of each resource specified as in portfolio testing.
ldaho Power response:
An action plan is provided in Chapter 1. Summary-Action Plan and in Chapter 10 Prefened Portfolio and Action Plan.
Guideline 5: Transmission
Portfolio analysis should include costs to the utility for the fuel transportation and electric
transmission required for each resource being considered. In addition, utilities should consider fuel
transportation and electric transmission facilities as resource options, taking into account their value
for making additional purchases and sales, accessing less costly resources in remote locations,
acquiring alternative fuel supplies, and improving reliability.
ldaho Power response:
The fuel transportation and electric transmission required for each resource being considered is presented in the Technical
Appendix, Cost lnputs and Operating Assumpfircns. Transmission assumptions for supply-side resources considered are
included in Chapter 6. Transmission Planning-Tnnsmission assumpflons in IRP portfolios. Transportation for natural gas
is discussed in ChapterT. Planning Peiod Forecasfs-Natural Gas Pice Forecast.
Guideline 6: Conservation
a. Each utility should ensure that a conservation potential study is conducted periodically for its
entire service territory.
Idaho Power response:
Applied Energy Group (AEG) conducted a study for the 2017 IRP and is described in Chapter 5 Demand-Side Resources.
b. To the extent that a utility controls the level of funding for conservation programs in its service
territory, the utility should include in its action plan all best cost/risk portfolio conservation
resources for meeting projected resource needs, speciffing annual savings targets.
ldaho Power response:
A forecast for energy efficiency effects in five-year blocks is provided in Chapfer5. Demand-Side Resources-Committed
EE forccast. Detailed monthly forecast values are a line item in the Technical Appendix, Load and Resource Balance Data.
Page 156 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company Compliance with State of Oregon IRP Guidelines
c. To the extent that an outside party administers conservation programs in a utility's service
territory at a level of funding that is beyond the utility's control, the utility should:
o Determine the amount of conservation resources in the best cost/risk portfolio without
regard to any limits on funding of conservation programs; and
o Identiff the preferred portfolio and action plan consistent with the outside party's
proj ection of conservation acquisition.
ldaho Power response:
Treatment of third party market transformation savings was provided by the Northwest Energy Efficiency Alliance (NEEA)
and is discussed in Chapfer 5. Demand-Srde Resources. NEEA savings are included as savings to meet targets because of
the overlap of NEEA initiatives and IPC's most recent potential study.
Guideline 7: Demand Response
Plans should evaluate demand response resources, including voluntary rate programs, on par with
other options for meeting energy, capacity, and transmission needs (for electric utilities) or gas
supply and transportation needs (for natural gas utilities).
ldaho Power response:
Demand response resources are evaluated in Chapter 5. Demand-Side Resources. Additional demand response above
baseline levels is considered in select portfolios and discussed in Chapter 5. Demand-Side Resources-Additional DR.
Guideline 8: Environmental Costs
Utilities should include, in their base-case analyses, the regulatory compliance costs they expect for
carbon dioxide (CO2), nitrogen oxides, sulfur oxides, and mercury emissions. Utilities should
analyze the range of potentialCO2 regulatory costs in OrderNo. 93-695, from zero to $40 (1990$).
In addition, utilities should perform sensitivity analysis on a range of reasonably possible cost adders
for nitrogen oxides, sulfur oxides, and mercury, if applicable.
Idaho Power response:
Compliance with existing environmental regulation is discussed in Chapter g. Modeling Analysis and Resu/fs-Qualitative
Risk Analysis. Emissions for each portfolio is shown in the Technical Appendix, Portfolio Analysr.s, Resu/fg and Suppofting
Documentation.
Guideline 9: Direct Access Loads
An electric utility's load-resource balance should exclude customer loads that are effectively
committed to service by an alternative electricity supplier.
ldaho Power response:
ldaho Power does not have any customers served by alternative electricity suppliers and ldaho Power has no direct
access loads.
20'17 lntegrated Resource Plan-Appendix C Page 157
Guideline 10: Multi-state Utilities
Multi-state utilities should plan their generation and transmission systems, or gas supply and
delivery, on an integrated-system basis that achieves a best cost/risk portfolio for all their
retail customers.
ldaho Power response:
ldaho Power's analysis was performed on an integrated-system basis discussed in Chapter 9. Modeling Analysis and
Resu/fs. ldaho Power will file the 2017 IRP in both the ldaho and Oregon jurisdictions.
Guideline 11 : Reliability
Electric utilities should analyze reliability within the risk modeling of the actual portfolios being
considered. Loss of load probability, expected planning reserve margin, and expected and worst-case
unserved energy should be determined by year for top-performing portfolios. Natural gas utilities
should analyze, on an integrated basis, gas supply, transportation, and storage, along with
demand-side resources, to reliably meet peak, swing, and base-load system requirements.
Electric and natural gas utility plans should demonstrate that the utility's chosen portfolio achieves
its stated reliability, cost and risk objectives.
ldaho Power response:
The capacity planning margin is discussed in Chapter 9. Modeling Analysis and Resu/fs-Capacity Planning Maryin
followed by the discussion of flexible resource needs assessment at Chapter 99. Modeling Analysis and Results-Flexible
Resource Needs Assessrnenf and the loss of load probabilities al Chapter th. Modeling Analysis and Resu/fs-LOLE.
Guideline 1 2: Distributed Generation
Electric utilities should evaluate distributed generation technologies on par with other supply-side
resources and should consider, and quantiff where possible, the additional benefits of distributed
generation.
ldaho Power response:
ldaho Power evaluated utility scale solar PV combined with reciprocating engines as resource options in four portfolios.
ln four other portfolios, reciprocating engines were paired with CCCT gas turbines. These portfolios are discussed in
Chapter 8. Portfolios.
Other distributed generation technologies were evaluated in ChapterT. Planning Peiod Forecasfs-Resource Cost
Analysis. Utility-scale solar and reciprocating engines were selected for further portfolio analysis based on their low-cost,
scalability, and efficiency. As shown in our load and resource balance, resource need is beyond the immediate action plan.
While utility scale solar and reciprocating engines are currently the low-cost choices, these future energy needs will
continually be reevaluated.
Guideline 13: Resource Acquisition
a. An electric utility should, in its IRP:
o Identify its proposed acquisition strategy for each resource in its action plan.
Compliance with State of Oregon IRP Guidelines ldaho Power Company
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ldaho Power Company Compliance with State of Oregon IRP Guidelines
Assess the advantages and disadvantages of owning a resource instead of purchasing power
from anotherparty.
Identifr any Benchmark Resources it plans to consider in competitive bidding.
ldaho Power response:
ldaho Power continues to evaluate resource ownership along with other supply options. ldaho Power conducts its resource
acquisition and competitive bidding processes consistent with the guidelines established by Oregon in Order No. 14-149
issued on April 30, 2014.
ldaho Power discusses asset ownership in Chapfer 10b. Prefened Portfolio and Action Plar+Action Plan (2017-2020).
ldaho Power's action plan includes ongoing permitting, planning studies, and regulatory filings associated with the
Boardman to Hemingway transmission line.
b. Natural gas utilities should either describe in the IRP their bidding practices for gas supply and
transportation, or provide a description of those practices following IRP acknowledgment.
ldaho Power response:
Not applicable.
a
2017 lntegrated Resource Plan-Appendix C Page 159
Gorurpr-rANcE wrrH EV GUTDELTNES
Guideline 1: Forecast the Demand for Flexible Capacity
Forecast the Demand for Flexible Capacity: The electric utilities shall forecast the balancing reserves
needed at different time intervals (e.g. ramping needed within 5 minutes) to respond to variation in
load and intermiffent renewable generation over the 2D-year planning period;
ldaho Power response:
A discussion of the 2017 IRP's analysis for the flexibility guideline is provided in Chapter 9. Modeling Analysis and
Resu lts-Flexi ble Resou rce Needs Assessrnenf .
Compliance with EV Guidelines ldaho Power Company
Guideline 2: Forecast the Supply for Flexible Capacity
Forecast the Supply of Flexible Capacity: The electric utilities shall forecast the balancing reserves
available at different time intervals (e.g. ramping available within 5 minutes) from existing
generating resources over the 2D-year planning period;
ldaho Power response:
A discussion of lhe 2017 IRP's analysis for the flexibility guideline is provided in Chapter 9. Modeling Analysis and
Re sults-Flexi ble Re sou rce Needs Assessment,
Guideline 3: Evaluate Flexible Resources on a Gonsistent and
Comparable Basis
In planning to fiIlany gap between the demand and supply of flexible capacity, the electric utilities
shall evaluate all resource options, including the use of EVs, on a consistent and comparable basis.
ldaho Power response:
The adoption rate of EVs is discussed in Appendix A Sales and Load Forecast, Company Sysfem LoafElectic Vehicles
Page'160 2017 lntegrated Resource Plan-Appendix C
ldaho Power Company State of Oregon Action ltems Regarding ldaho Power's 2015 IRP
Srere Or OnEGoN Acnoru lrems ReonnDrNG loeno Powen's
2015 lnp
Action ltem 1: BZH Transmission Line
Idaho Power will continue the ongoing permitting, planning studies and regulatory filings.
ldaho Power response:
Discussion specific to B2H is found in Chapter 6. Iriansmissrbn Planning-Boardman to Hemingway. Portfolio design for
lhe 2017 IRP provides a comparison of portfolios having B2H as a resource to portfolios not having B2H. A tabulation of
resource portfolios with respect to B2H inclusion is provided in Chapter 8. Portfolios.
Action ltem 2: Gateway West Transmission Line
Idaho Power will continue the ongoing permitting, planning studies and regulatory filings
ldaho Power response:
Discussion specific to Gateway West is found in Chapter 6e. Transmission Planning-Gateway West.
Action ltem 3: Energy Efficiency
Idaho Power will continue the pursuit of cost-effective energy efficiency-the forecast reduction for
the2015-2019 programs is 84 average megawatts (MW) for energy demand and 126 MW for
peak demand.
ldaho Power response:
Discussion specific to energy efficiency is found in Chapter 5. Demand-Side Resources. All portfolios contain achievable
energy efficiency. The monthly forecast is provided in the Technical Appendix, Load and Resource Balance Data.
Action Item 4: Section 111(d)
Idaho Power will coordinate with government agencies on implementation planning for Section
u l (d).
ldaho Power response:
All portfolios meet current regulatory requirements. Portfolio Emissions are shown in the Technical Appendix, Portfolio
EmLssrbns Graphs.
Action ltem 5: Shoshone Falls License Amendment
Idaho Power will file to amend the FERC license regarding the 50-MW expansion.
2017 lntegrated Resource Plan-Appendix C Page 161
State of Oregon Action ltems Regarding ldaho Power's 20'15 IRP ldaho Power Company
ldaho Power response:
ln April 2017 , ldaho Power filed with FERC to amend the FERC's July 2010 License Order which authorized ldaho Power to
upgrade the Shoshone Falls hydroelectric project changing the approved installed capacity from 50MW to 3.2MW.
Action ltem 6: Jim Bridger Unit 3
Idaho Power will complete the installation of selective catalytic reduction (SCR)
emission-control technology.
ldaho Power response:
lnstallation of selective catalytic reduction emission-control technology was completed on Jim Bridger Unit 3 in
November 2015.
Action ltem 7: Shoshone Falls Upgrades Study
Idaho Power will study options for smaller upgrades ranging in size up to approximately 4MW
ldaho Power response:
ln early 2016, ldaho Power explored a variety of smaller upgrade options. The most cost effective option was to replace
units 1 and 2 with a single 3.2 MW unit.
Action ltem 8: Jim Bridger Unit 4
Idaho Power will complete installation of SCR emission-control technology.
ldaho Power response:
lnstallation of selective catalytic reduction emission-control technology was completed on Jim Bridger Unit 3 in
November 2016.
Action ltem 9: North Valmy Units 1 and 2
Idaho Power will continue to work with NV Energy to synchronize depreciation dates and determine
if a date can be established to cease coal-fired operations.
ldaho Power response:
ln October and November 2016, ldaho Power filed applications with the IPUC an OPUC, respectively, requesting
authorization to accelerate depreciation for the North Valmy coal-fired power plant. The approved settlement stipulations in
both ldaho and Oregon agreed to an early shutdown of year-end 2019 for Unit 1 and year-end 2025 for Unil2.
Action ltem 10: Shoshone Falls 2017 Upgrade
Idaho Power will commence construction of a smaller upgrade.
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ldaho Power Company State of Oregon Action ltems Regarding ldaho Power's 2015 IRP
ldaho Power response:
The upgrade of Shoshone Falls is currently scheduled from May 20'1 8 through June 2019
Action ltem 11: Jim Bridger Units 1 and 2
Idaho Power will evaluate the installation of SCR technology for units I and2 at Jim Bridger in the
2017 rRP.
ldaho Power response:
The 2017 IRP focuses on evaluating the installation of SCR technology for units 1 and 2 at Jim Bridger. The discussion of
portfolios is in Chapter 8 Portfolios and the results are in Chapter 9. Modeling Analysis and Resu/fs. The preferred portfolio
and action plan, discussed in Chapter 10 does not include the installation of SCR equipment; rather it contemplates early
shut down for the units in lieu of installing the SCRs.
Action ltem 12: Shoshone Falls 2019 On-Line Date
Idaho Power will place the smaller upgrade on-line.
ldaho Power response:
The upgrade of Shoshone Falls is currently scheduled from May 2018 through June 2019
Other lssues
Selection of Preferred Portfolio-Staffagrees with Idaho Power's position that the Commission
should acknowledge Idaho Power's 2015 IRP Action Plan.
ldaho Power response:
No action needed.
Qualitative Risk Analysis: Staffrecommends Idaho Power include a more systematic evaluation of
the qualitative benefits of the resource portfolios in the 2017 IRP.
Idaho Power response:
Qualitative Risk Analysis is evaluated in Chapter 10d. Modeling Analysis and Resu/fs-Qualitative Risk Analysis
2015 IRP Update Waiver: Staff agrees and recommends the Commission waive Idaho Power's
obligation to file a20l5IRP Update.
ldaho Power response:
No action needed.
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State of Oregon Action ltems Regarding ldaho Power's 2015 IRP ldaho Power Company
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