Application

APPLICATION OF ROCKY MOUNTAIN POWER
Joe Dallas (ISB# 10330)
825 NE Multnomah Street, Suite 2000
Portland, OR 97232
Telephone: [phone]
Email: [e-mail]

Attorney for Rocky Mountain Power

BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION

IN THE MATTER OF THE APPLICATION
OF ROCKY MOUNTAIN POWER TO
UPDATE LOAD AND GAS FORECASTS
USED IN THE INTEGRATED RESOURCE
PLAN AVOIDED COST MODEL

) CASE NO. PAC-E-26-14
)
) APPLICATION OF
) ROCKY MOUNTAIN POWER
)

Rocky Mountain Power, a division of PacifiCorp, (“Company”), hereby respectfully
submits this Application to the Idaho Public Utilities Commission, ("Commission"), in compliance
with Order Nos. 32697 and 32802 to update the load forecast, natural gas forecast, and long-term
contract components of the Integrated Resource Plan ("IRP") avoided cost model. In support of
this Application, Rocky Mountain Power states as follows:
1. Rocky Mountain Power provides electric service to retail customers in the states of
Idaho, Utah, and Wyoming. Rocky Mountain Power is a public utility in the state of Idaho and is
subject to the Commission's jurisdiction with respect to its prices and terms of electric service to
retail customers pursuant to Idaho Code 61-129. Rocky Mountain Power provides retail electric
service to approximately 91,000 customers in the state of Idaho.
I. BACKGROUND
2. Order No. 32697 specified that the inputs to the IRP methodology calculation,
utilized to determine the avoided cost for all new Public Utility Regulatory Policies Act of 1978
(“PURPA ”) qualifying facility ("QF") projects that exceed the published rate eligibility cap, will
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APPLICATION OF ROCKY MOUNTAIN POWER
be updated every two years upon acknowledgement of the utility's IRP filing with the exception
of the load and the natural gas forecasts which are to be updated annually by June 1st of each year.
The Commission ruled:
“We find that, in order to maintain the most accurate and up to date reflection of a
utility's true avoided cost, utilities must update fuel price forecasts and load
forecasts annually between IRP filings. For the sake of consistency, these annual
updates should occur simultaneously with SAR updates - on June 1 of each year. In
addition, it is appropriate to consider long-term contract commitments because of
the potential effect that such commitments have on a utility's load and resource
balance. We find it reasonable to include long-term contract considerations in an
IRP Methodology calculation at such time as the QF and utility have entered into
a signed contract for the sale and purchase of QF power. We further find it
appropriate to consider PURPA contracts that have terminated or expired in each
utility's load and resource balance. We find it reasonable that all other variables
and assumptions utilized within the IRP Methodology remain fixed between IRP
filings (every two years).”1

3. Order No. 32802 changed the due date of the annual update from June 1st to October
15th of each year. If approved, the load forecast, natural gas forecast, and contract information
presented below will be incorporated into Rocky Mountain Power's IRP avoided cost model.
Consistent with the Commission's prior orders, this methodology will be utilized by the Company
as the starting point for negotiation of contractual avoided cost rates as of January 1, 2027.
II. LOAD FORECAST
4. The Company's May 2026 load forecast and the load forecast used in Case No.
PAC -E-25-19 are summarized in Table 1. The May 2026 load forecast reflects assumptions used
to develop the 2025 IRP Update preferred portfolio as well as the energy efficiency selections as
reported in PacifiCorp’s March 31, 2026 IRP Update filing, and remains the most recent forecast
that is consistent with the load assumptions and resource selections in the 2025 IRP Update. The

1 In the matter of the Commission’s review of PURPA QF contract provisions including the Surrogate Avoided
Resources (SAR) and Integrated Resource Planning (IRP) methodologies for calculating avoided cost rates. Case
No. GNR-E-11-03, Order No. 32697, p. 22.
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APPLICATION OF ROCKY MOUNTAIN POWER
May 2026 load forecast shows an increase in load compared to the December 2024 load forecast
provided in Case No. PAC -E-25-19, which was subsequently approved by Commission Order No.
36890. The change in the forecast is primarily due to load growth in Utah, including the inclusion
of Kennecott retail load starting January 1, 2026 following the approval of a load service contract
for Kennecott by the Utah Public Service Commission and growth of other existing customer load
over time. Forecasted load in Idaho is slightly higher than the prior forecast, but annual volumes
remain relatively stable over time. Consistent with the prior filing, no large new loads are included
in the forecast, and resources procured to serve large new loads have been excluded from the list
of executed contracts.
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APPLICATION OF ROCKY MOUNTAIN POWER
Table 1

Rocky Mountain Power
Load Forecast Update
Annual GWh
Load Forecast May 2026
Year California Idaho Oregon Utah Washington Wyoming FERC Total
2026 827 3,959 15,740 28,737 4,503 9,548 299 63,613
2027 822 3,957 15,710 29,483 4,643 9,410 142 64,167
2028 817 3,957 15,703 30,203 4,788 9,395 - 64,863
2029 808 3,943 15,611 30,680 4,756 9,305 - 65,103
2030 801 3,932 15,563 31,162 4,741 9,284 - 65,483
2031 795 3,921 15,520 31,702 4,724 9,244 - 65,906
2032 790 3,914 15,555 32,112 4,700 9,204 - 66,275
2033 782 3,901 15,510 32,432 4,652 9,123 - 66,399
2034 774 3,893 15,545 32,857 4,621 9,058 - 66,747
2035 767 3,890 15,652 33,490 4,601 9,003 - 67,401
2036 764 3,898 15,849 34,224 4,606 9,002 - 68,344
2037 762 3,900 15,987 35,131 4,602 8,965 - 69,348
2038 760 3,910 16,159 35,750 4,607 8,935 - 70,120
2039 759 3,924 16,357 36,408 4,624 8,909 - 70,980
2040 760 3,950 16,623 37,237 4,663 8,910 - 72,142
2041 757 3,966 16,850 38,048 4,678 8,867 - 73,165
2042 758 3,990 17,144 39,430 4,741 8,890 - 74,953
2043 758 4,015 17,393 40,270 4,773 8,877 - 76,086
2044 760 4,051 17,727 41,260 4,827 8,895 - 77,520
2045 759 4,082 18,046 42,118 4,861 8,874 - 78,740
Load Forecast - Dec 2024
Year California Idaho Oregon Utah Washington Wyoming FERC Total
2026 836 3,814 15,853 27,778 4,453 9,516 287 62,538
2027 832 3,813 15,832 28,405 4,605 9,481 138 63,106
2028 829 3,815 15,827 28,898 4,756 9,432 - 63,557
2029 822 3,801 15,767 29,169 4,724 9,374 - 63,655
2030 817 3,791 15,755 29,553 4,705 9,312 - 63,933
2031 812 3,780 15,746 30,094 4,689 9,280 - 64,401
2032 809 3,773 15,771 30,376 4,669 9,217 - 64,616
2033 802 3,755 15,770 30,532 4,625 9,139 - 64,623
2034 797 3,746 15,840 30,792 4,597 9,056 - 64,827
2035 793 3,740 15,977 31,196 4,578 8,999 - 65,283
2036 793 3,747 16,204 31,758 4,582 8,996 - 66,079
2037 790 3,743 16,379 32,418 4,577 8,958 - 66,865
2038 789 3,752 16,594 32,863 4,587 8,929 - 67,513
2039 789 3,765 16,844 33,342 4,608 8,905 - 68,254
2040 792 3,790 17,147 33,958 4,651 8,909 - 69,246
2041 790 3,803 17,415 34,523 4,669 8,867 - 70,069
2042 792 3,826 17,746 35,633 4,730 8,893 - 71,620
2043 793 3,850 18,009 36,228 4,761 8,887 - 72,528
2044 797 3,883 18,355 36,911 4,814 8,907 - 73,668
2045 797 3,910 18,626 37,471 4,846 8,892 - 74,540
Loads are net of Demand Side Management
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APPLICATION OF ROCKY MOUNTAIN POWER
III. NATURAL GAS PRICE FORECAST
5. The Company’s most recent Official Forward Price Curve (“OFPC”) was
prepared on September 30, 2026 (“2609 OFPC”). The price forecast used in Case No. PAC-E-
25-19 was prepared on September 30, 2025 (“2509 OFPC”). Table 2 provides the 2609 OFPC
natural gas prices summarized annually by market hub. The 2509 OFPC is also provided for
reference only. In the near term, from 2027 to 2030, the forecasted natural gas prices in all hubs
are predominantly lower in the 2609 OFPC forecast compared to the prior-year forecast. For
2031 and beyond, the gas price forecast is slightly higher for the Opal Gas hub, which is the
primary index for the Company’s natural gas fired resources in Utah and Wyoming, while prices
at other gas hubs have fallen somewhat.
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APPLICATION OF ROCKY MOUNTAIN POWER
Table 2
Rocky Mountain Power
Natural Gas Price Update
$/MMBtu
Official Forward Price Curve (2609) - 09/30/2026
Year Opal Gas Index Sumas Index Stanfield Index San Juan Index
Henry Hub
Index AECO Index
SOCALBOR
Index
2026(a) $3.41 $3.55 $2.59 $2.92 $3.20 $1.56 $4.04
2027 $3.11 $3.04 $2.43 $2.71 $3.21 $1.61 $3.83
2028 $3.75 $3.91 $2.95 $3.32 $3.73 $1.90 $4.56
2029 $3.87 $4.09 $3.20 $3.48 $3.89 $2.21 $4.64
2030 $4.75 $4.78 $4.40 $4.39 $4.99 $3.57 $5.47
2031 $5.51 $5.42 $5.39 $5.16 $5.92 $4.69 $6.17
2032 $5.31 $5.14 $5.14 $4.96 $5.72 $4.36 $5.97
2033 $5.23 $5.02 $5.02 $4.87 $5.57 $4.19 $5.89
2034 $5.36 $5.10 $5.11 $4.98 $5.70 $4.23 $6.03
2035 $5.54 $5.20 $5.23 $5.14 $5.84 $4.24 $6.22
2036 $5.80 $5.38 $5.43 $5.39 $6.07 $4.42 $6.49
2037 $5.94 $5.47 $5.55 $5.51 $6.19 $4.47 $6.65
2038 $6.03 $5.40 $5.53 $5.59 $6.25 $4.35 $6.75
2039 $6.28 $5.57 $5.72 $5.82 $6.48 $4.51 $7.02
2040 $6.53 $5.73 $5.92 $6.06 $6.71 $4.68 $7.29
2041 $6.84 $5.92 $6.13 $6.35 $6.99 $4.82 $7.61
2042 $7.08 $6.02 $6.26 $6.58 $7.21 $4.91 $7.86
2043 $7.50 $6.31 $6.59 $6.99 $7.64 $5.21 $8.30
2044 $7.90 $6.58 $6.89 $7.39 $8.05 $5.48 $8.73
2045 $8.16 $6.72 $7.06 $7.64 $8.30 $5.61 $9.01
(a) 2026 Forecast gas prices are for November and December only
Offical Forward Price Curve (2509) - 09/30/2025
Year Opal Gas Index Sumas Index Stanfield Index San Juan Index
Henry Hub
Index AECO Index
SOCALBOR
Index
2026(a) $4.79 $5.83 $3.87 $4.41 $4.33 $2.66 $5.04
2027 $3.89 $4.26 $3.26 $3.70 $3.95 $2.38 $4.18
2028 $3.80 $4.35 $3.34 $3.68 $3.94 $2.52 $4.15
2029 $4.30 $4.69 $4.47 $4.39 $4.75 $3.57 $4.89
2030 $4.83 $5.16 $5.52 $5.10 $5.52 $4.49 $5.63
2031 $5.04 $5.37 $5.79 $5.38 $5.85 $4.64 $5.91
2032 $5.11 $5.43 $5.90 $5.48 $5.92 $4.68 $6.02
2033 $5.18 $5.44 $6.00 $5.57 $6.00 $4.73 $6.13
2034 $5.31 $5.58 $6.18 $5.73 $6.14 $4.82 $6.31
2035 $5.46 $5.70 $6.35 $5.89 $6.26 $4.96 $6.48
2036 $5.58 $5.84 $6.54 $6.06 $6.39 $5.03 $6.67
2037 $5.74 $5.99 $6.72 $6.22 $6.49 $5.17 $6.86
2038 $5.92 $6.17 $6.95 $6.44 $6.66 $5.30 $7.10
2039 $6.13 $6.38 $7.21 $6.67 $6.81 $5.48 $7.36
2040 $6.37 $6.63 $7.52 $6.97 $7.07 $5.67 $7.68
2041 $6.58 $6.85 $7.78 $7.22 $7.29 $5.84 $7.94
2042 $6.93 $7.19 $8.19 $7.61 $7.69 $6.15 $8.36
2043 $7.26 $7.51 $8.58 $7.99 $8.08 $6.43 $8.75
2044 $7.58 $7.82 $8.97 $8.38 $8.50 $6.70 $9.15
2045 $7.90 $8.14 $9.37 $8.75 $8.85 $6.96 $9.56
(a) 2026 Forecast gas prices are for November and December only
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APPLICATION OF ROCKY MOUNTAIN POWER
IV. CONTRACT TERMINATIONS, EXPIRATIONS, AND ADDITIONS
6. Since filing Case No. PAC -E-25-19, the Company has signed fifteen long-term
contracts, including ten long-term contracts with qualifying facilities, for a total nameplate
capacity of approximately 447 megawatts. Four long-term contracts have terminated or expired
for a total nameplate capacity of approximately 19 megawatts. Table 3 provides a list of signed
and expired or terminated contracts since October 1, 2025.
7. Rocky Mountain Power currently has 42 non-PURPA, long-term power purchase
agreements with a nameplate capacity of 5,370 megawatts, and 170 PURPA QF contracts with a
nameplate capacity of 2,208 megawatts. New, terminated, and expired contracts are reflected in
the IRP model on a continuous basis.
Table 3

Long Term Contracts signed since the October 2025 Filing
No. Contract Type
Nameplate
(MW) Start Date End Date
1 Central Oregon Irrigation District (COID) Siphon OR Standard QF PPA 6.00 1/1/2026 12/31/2026
2 Exxon Mobil Corporation WY QF PPA 107.40 1/1/2026 12/31/2026
3 Eagle Point Irrigation District OR Standard QF PPA 0.94 2/13/2026 2/12/2027
4 Wolverine Creek Energy LLC Non-QF PPA 64.25 2/20/2026 12/31/2026
5 Kelly Creek Solar, LLC OR Community Solar QF PPA 2.25 4/8/2026 4/7/2046
6 J Bar 9, LLC WY QF PPA 0.10 5/1/2026 10/16/2026
7 Douglas County Forest Products OR Standard QF PPA 6.25 6/1/2026 5/31/2031
8 Medford Irrigation District OR Community Solar QF PPA 0.80 10/31/2026 9/29/2046
9 Lomaside Solar, LLC OR Community Solar QF PPA 1.10 12/9/2026 12/30/2043
10 Cowlitz Meaningful Priority Share of Grant PUD Priest Rapids Non-QF PPA 22.30 1/1/2027 12/31/2027
11 EWEB Priority Share of Grant PUD Priest Rapids Project Non-QF PPA 19.11 1/1/2027 12/31/2027
12 PacifiCorp's Share of Grant PUD Meaningful Priority Slice Non-QF PPA 150.00 1/1/2027 12/31/2027
13 Tacoma Power Meaningful Priority Share of Grant PUD Priest Rapids Non-QF PPA 38.70 1/1/2027 12/31/2027
14 Tesoro Refining & Marketing Co UT QF PPA 25.00 1/1/2027 12/31/2027
15 Shoshone Irrigation District LLC WY QF PPA 2.90 1/1/2027 12/31/2046
Total Signed MW 447.1
Long Term Contracts Expired or Terminated since the October 2025 Filing
No. Contract Type
Nameplate
(MW) Date
1 Roseburg Forest Products - Weed (RFPC Weed PPA QF)CA QF PPA 10.0 3/4/2026
2 TMF Biofuels OR Standard QF PPA 4.8 4/30/2026
3 Oregon Environmental Industries OR Standard QF PPA 2.9 7/31/2026
4 Kettle Butte Digester LLC ID QF PPA 1.7 8/30/2026
Total Expired or Terminated MW 19.4
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APPLICATION OF ROCKY MOUNTAIN POWER
V. COMMUNICATIONS
8. Communications regarding this filing should be addressed to:
Anna DeMers
Idaho Regulatory Affairs Manager
Rocky Mountain Power
315 W. 27th Street
Cheyenne, WY 82001
Telephone: [phone]
Email: [e-mail]
Joe Dallas (ISB# 10330)
825 NE Multnomah Street, Suite 2000
Portland, OR 97232
Telephone: [phone]
Email: [e-mail]
In addition, Rocky Mountain Power requests that all data requests regarding this Application be
sent in Microsoft Word to the following:
By email (preferred): [e-mail]
By regular mail: Data Request Response Center
PacifiCorp
825 Multnomah, Suite 2000
Portland, Oregon 97232
Informal questions may be directed to Anna DeMers, Idaho Regulatory Affairs Manager at (801)
534-5019.
VI.MODIFIED PROCEDURE
9.The Company believes that a hearing is not necessary to consider the issues
presented herein and respectfully requests that this Application be processed under Modified
Procedure; i.e., by written submissions rather than by hearing. RP 201 et seq.
8
APPLICATION OF ROCKY MOUNTAIN POWER
VII.REQUEST FOR RELIEF
WHEREFORE, Rocky Mountain Power hereby respectfully submits its updated load
forecast, natural gas forecast, and QF contract information in compliance with the Commission's
directives in Order Nos. 32697 and 32802 and requests that the Commission issue an order
approving this updated information for inclusion in the Company’s IRP avoided cost calculations
effective January 1, 2027.
DATED this 15th day of October 2026.
Respectfully submitted,
ROCKY MOUNTAIN POWER
______________________________
Joe Dallas (ISB# 10330)
825 NE Multnomah Street, Suite 2000
Portland, OR 97232
Telephone: [phone]
Email: [e-mail]
Attorney for Rocky Mountain Power
9