20220519Reply Comments.pdf

\ rr _ Irr' "a r L - l,i'r L v i..STHH.
;,i? Hl,',i l! Ps 3: 52
. .1...1 i-i-:, :li -1Y-r'^iie1gru
Lisa D. Nordstrom
AnnAoOnPOolIE ny
P.O.8ox 70 (83707)
lzlt W. ldrho 5t.
Boisc. lD 8i1702
LISA D. NORDSTROM
Lead Counse!
I nordstrom@ida hoporrer.com
May 1 9,2022
Jan Noriyuki, Secretary
ldaho Public Utilities Commission
11331 W. Chinden Boulevard
Building 8, Suite 201-A
Boise, ldaho 83714
Re: Case No. IPC-E-22-11
Application of Idaho Power Company for Authority to lmplement Power Cost
Adjustment ("PCA) Rates for Electric Service from June 1 ,z0z2,through May
31,2023
Dear Ms. Noriyuki:
Attached for electronic filing is ldaho Power Company's Reply Comments in the
above-entitled matter.
lf you have any questions about the attached documents, please do not hesitate to
contact me.
Very truly yours,
X*!.7("*t..*,
LDN:sg
Enclosures
LISA D. NORDSTROM (lSB No. 5733)
ldaho Power Company
1221 West ldaho Street (83702)
P.O. Box 70
Boise, ldaho 83707
Telephone: [phone]
Facsimile: [phone]
lnordstrom@ida hooower.com
Attorney for ldaho Power Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPANY FOR
AUTHORITY TO IMPLEMENT POWER
cosT ADJUSTMENT (PCA',) RATES
FOR ELECTRIC SERVICE FROM JUNE
1,2022, THROUGH MAY 31 ,2023,
CASE NO. IPC-E-22-11
IDAHO POWER COMPANY'S
REPLY COMMENTS
)
)
)
)
)
)
)
)
)
COMES NOW, ldaho Power Company ("ldaho Powe/' or.Company"), hereby
respectfully submits the following Reply Comments in response to Comments filed by
Staff ("Staff') of the ldaho Public Utilities Commission ("Commission") and the !ndustrial
Customers of ldaho Power ("lClP') in the matter of the Company's application for
authority to implement Power Cost Adjustment ('PCA') rates for electric service from June
1,2022, through May 31 ,2023.
IDAHO POWER COMPANY'S REPLY COMMENTS - 1
I. BACKGROUND
On April 15,2022, ldaho Power applied to the Commission for an order approving
an update to Schedule 55 based on the quantification of the 2022-2023 PCA to become
effective June 1 ,2022, for the period June 1 ,2022, through May 31 ,2023. As filed, the
2022-2023 PCA would result in an overall revenue increase of approximately $103.4
million, or an 8.27 percent increase over the current billed revenue. Since the original
filing, in response to a production request from Staff, the Company calculated an updated
2022-2023 PCA forecast based on updated modeling assumptions for the Company's
Jim Bridger Power Plant ("Bridgef). With the updated forecast, the revised 2022-2023
PCA would result in a $94.9 million increase in PCA revenue relative to current rates, an
$8.5 million decrease from the originalfiling.
On May 13,2022, Staff and lClP filed comments in this case. Staffs comments
recommended approval of the Bridger-adjusted PCA amount of $94.9 million, based on
its review of the Application and an extensive audit of the Company's filing. Staff also
recommended that the Company keep the Commission and Staff apprised of water and
weather conditions that may warrant an out-of-cycle PCA adjustment, and recommended
additional analysis surrounding an outage at Unit 3 of the Company's Hells Canyon Power
Plant. lClP's comments largely centered around rate mitigation, proposing to spread the
requested PCA increase over a two-year period.
IDAHO POWER COMPANY'S REPLY COMMENTS - 2
II. REPLY COMMENTS
ldaho Power appreciates and acknowledges Staffs extensive review of the
Company's filing, and agrees with Staffs conclusion that the filed PCA components
appropriately calculate the 2022-2023 PCA rates under the currently approved
methodology. ldaho Power supports Staffs recommendation to file an updated Schedule
55 reflecting an $8.5 million decrease in PCA revenue collection from the originalfiling as
a result of updated Bridger assumptions. Additionally, ldaho Power is largely supportive
of Staffs recommendations related to the Hells Canyon Unit 3 outage and continued
communication regarding evolving hydro conditions. Lastly, while ldaho Power is not
necessarily opposed to rate mitigation measures as discussed in its initialApplication, the
Company remains concerned with the risk of future compounding effects that may result
from the lClP's proposal to spread the PCA rate increase over a two-year period. Each
of these issues is discussed in more detail below.
A. Chanqe to Forecast NPSE due to Updated Bidoer Assumotions
As discussed on page 10, Iines 1 through 11, of the Direct Testimony of Jessica
G. Brady, ldaho Power's filed PCA in this case reflected Bridger Unit 1 availability for
dispatch at the revised state implementation plan (SlP) levels, and Bridger Unit 2
availability at a 25 percent level from June through October 2022 in consideration of
ongoing uncertainty retated to U.S. Environmental Protection Agency negotiations. Since
the filing of the PCA, confidential settlement discussions have progressed to a point
where ldaho Power feels more confident in its ability to operate the Bridger plant at levels
higher than those included in the initial filing.
As a result, ldaho Power calculated an estimated change in net power supply
IDAHO POWER COMPANY'S REPLY COMMENTS.3
expenses ("NPSE') if Bridger is fully available for the summer of 2022. By taking the
difference between Bridger dispatch costs and known gas and power purchase prices
from Energy Risk Management firm orders and multiplying that by the megawatt-hours
for June through September 2022, the Company calculated a total estimated decrease of
$9.34 million in system forecast NPSE from the original filing. This equates to an
estimated $8.5 million decrease in total ldaho jurisdictional PCA collection. Table 1
presents an updated separation of the proposed $94.9 million increase into each
component included in the Company's proposed rates.
Table 1 Updated Revenue lmpac by C.omponent
Une No. Rate CrmDonent 202L-2022PCA 2022-2023PCA Difference
1
2
3
4
5
PCA Forecast
PCA Balancing Adjustment
PCA Total
Revenue Sharing
s
s
131,825,053
(18,320,281)
s !70,324,638
s 38,664,487
s
S
38,499,575
56,984,768
s
s
113,504,783 s 208,989,125
S (s68,771)
s
s
95,484,:143
(568,77LI
Total Revenue lmpact $ u3,504,783 s 208,420,355 5 9q,9t5,572
ldaho Power concurs with Staff that it is appropriate to update the PCA forecast in
this case to reflect a reasonable adjustment to expected operating conditions. To
incorporate the change in Bridger assumptions, ldaho Power has calculated an updated
PCA forecast rate. Table 2 presents the system-level differences between currently
approved base level NPSE and the updated forecast NPSE for the 2022-2023 PCA Year
by FERC account.
IDAHO POWER COMPANY'S REPLY COMMENTS -4
Table 2 Uodated 2022-2023 PCA FORECAST flotalSvstem)
Line
No.FERC Account Base NPSE Forccast Dlfference
1
2
3
4
5
6
95% Sharino Accounts
Account501, Coal
Account 536, Water for Power
Account 547, Other Fuel
Account 555, Purchased
Power Non-PURPA
Account 565, 3rd Party
Transmission
Account 447. Sumlus Sales
$
$
$
$
$
$
108,503,180
2,380,597
33,367,563
$ 151,179,160
$0
$ 79,067,982
$
$
$
$
$
$
42,675,980
(2,380,597)
45,700,4'.19
62,606,593 $ 98,482,808 35,876,215
5,455,955
(s1.735.153)
$ 5,149,239
s 65.085.848)
(306,716)
(13.350.695)
7
I
$ 160,578,735 $ 268,793,342 $ 108,214,607
100% Sharino Accounts
Account 555, PURPA
Account 555, Demand
Response lncentives
$
$
133,853,869
't1.252.265
$ 212,586,058
$ 8,115,900
$
$
78,732,189
(3,136,365)
I Total s 305.684.869 S 489.495.300 $ 183.810.431
The updated forecast for non-PURPA expenses is $268,793,U2, resulting in a
difference of $108,214,607 from base NPSE. As a result, the updated rate for non-
PURPA expenses is 0.6552 cents per kilowatt-hour ('kwh'), which is calculated by
multiplying $108,214,607 from Table 2 by 95 percent and then dividing it by the System-
level Sales Forecast of 15,690,546 MWh (($108,214,607 * 0.95) / 15,690,546) = $6.552
/M\ /h = 0.6552 cents/kwh). The rates for PURPA expenses and demand response
incentives have not changed from the origanal filing (0.5018 cents per k\ Jh and negative
0.0209 cents per kwh respectively). The updated forecast portion of the PCA rate is
1.3606 cents per kwh, which is calculated by adding the non-PURPA expense of 0.6552
cents per kwh to the PURPA expense of 0.5018 cents per kwh to the demand response
incentive payment of negative 0.0209 cents per kwh (0.6552 + 0.5018 + -0.0209 = 1 .1361
cents/kwh). When combined with the Balancing Account rate (which has not changed
IDAHO POWER COMPANY'S REPLY COMMENTS - 5
from the original filing) of 0.2579 cents per kWh, the updated uniform PCA rate is 1.3940
cents per k\M. This is reflected in the updated Schedule 55 in Aftachment 'l to these
comments. The updated percentage rate change by class is detailed in Attachment 2.
B. Hells Canvon Unit 3 Outaoe
Pages 8 and 9 of Staffs Comments discuss their analysis of an outage at Hells
Canyon Unit 3 during the historical PCA period. Based on concerns regarding certain
unknowns and extenuating circumstances at the time their Comments were filed, Staff
recommends that the Company work with Staff to 'gather additional information, perform
analysis, and determine a fair and reasonable outcome for customers." \Mile ldaho
Power believes its actions were prudent with regard to both planned and unplanned
maintenance at Hells Canyon Unit 3 during the historical PCA period, the Company is
supportive of Staffs recommendation to continue dialogue surrounding this issue.
C. Water and Weather Condition Updates
On page 6 of its Comments, Staff notes that additiona! snowfall has occurred since
the Company's filing in this case. While Staff does not believe this warrants an adjustment
to the PCA at this time, they recommend the Company keep both Staff and the
Commission apprised of changing conditions during the PCA year to determine if an off-
cycle update to reduce the PCA is appropriate. The Company is not opposed to continuing
communications with Staff and the Commission regarding evolving hydro conditions, and
supports Staffs recommendation in this matter.
D. Rate Mitiqation
The lClP's Comments proposed to spread the requested PCA rate increase over a
two-year time period for rate classes receiving a greater than ten percent increase, which
IDAHO POWER COMPANY'S REPLY COMMENTS -6
would include Schedules 19,42, and Special Contracts. While ldaho Power is amenable
to rate mitigation if the Commission deems some form of measure to be prudent, after
reviewing lClP's proposa!, the Company's concerns with rate pancaking remain.
lClP's recommendation reflects the application of rate mitigation only to certain
classes, which would create additionaladministrative burden to implement different rates
and PCA calculations for both the forecast and the balancing account components of the
PCA. Additionally, on page 3 of their comments, lClP states that classes experiencing
double-digit rate increases should be allowed to "opt" to spread this year's increase over
a two-year period. While the Company is not entirely clear what is meant by use of the
word "opt," if it is lClP's contention that each individual customer would be required to
select a mitigated vs. unmitigated option, the Company would not be supportive of this
proposal, as it would unduly complicate customer rates, customer communication, and
the underlying accounting supporting the PCA.
It should also be noted that, if approved in accordance with Staffs and ldaho Power's
recommendation, the PCA forecast will be reduced by $A.S million to reflect updated
assumptions associated with Bridger. Additionally, on May 18,2022,1daho Power filed
comments in Case No. IPC-21-17 related to the accelerated depreciation of coal-related
investments at Bridger, in which the Company included a proposal to implement the
requested balancing account mechanism in a manner that would result in no immediate
change to customer rates. lf the Company's proposal is approved in that case, it would
result in the remova! of upward pressure on rates effective June 1 , 2022 relative to
investments at the Bridger plant. Based on these changes since the Company's initial
filing, and after reviewing the lClP's rate mitigation proposal, the Company believes the
IDAHO POWER COMPANY'S REPLY COMMENTS - 7
Commission should approve the filed PCA amount adjusted for the updated Bridger
assumptions and collect the entirety of that amount over the 2022-2023 PCA Year.
E. Bridoer Rate Reouest Clarification
On page 6 of their Comments, lClP incorrectly characterizes the Company's
Application in this case as requesting approval of the Bridger-related increase in Case
No. IPC-E-21-17. To clariff, the Company included the proposed Bridger rate increase
for demonstrative purposes only, to inform the Commission of the cumulative impact of
allfilings effective June 1 ,2022. The Company's inclusion of these cumulative rate impact
tables in the Company's initialfiling should not be interpreted as a request for Commission
approval of the Bridger-related increase in the PCA case.
ilr. coNcLUstoN
ldaho Power appreciates the thorough audit performed by Staff, and the comments
filed by both Staff and !ClP. The Company respectfully requests that the Commission
approve its filing to implement PCA rates effective June 1,2022, adjusted forthe updated
Bridger generation assumptions as detailed in these comments. ldaho Power also
supports Staffs recommendations to continue communications regarding the Hells
Canyon Unit 3 outage and evolving hydro conditions.
DATED at Boise, ldaho, this 19th day of May 2022.
,(* !.7("1-t "-*,,
LISA D. NORDSTROM
Attorney for ldaho Power Company
IDAHO POWER COMPANY'S REPLY COMMENTS - 8
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that on the 19th day of May 2022,1 served a true and correct
copy of ldaho Power Company's Reply Comments upon the following named parties by
the method indicated below, and addressed to the following:
)Lecrtr &r"t.
Stacy Gust, Regulatory Administrative
Assistant
Commission Staff
Dayn Hardie
Deputy Aftorney General
ldaho Public Utilities Commission
11331 W. Chinden Blvd., Bldg No.8,
Suite 201-A (83714)
PO Box 83720
Boise, lD 83720-0074
_Hand Delivered
-U.S.
Mai!
Overnight Mail
-FAX
FTP SiteX Email:[e-mail]
lndustrial Customers of ldaho Power
Peter J, Richardson
515 N.27th Street
Boise, ldaho 83702
_Hand Delivered
_U.S. Mail
Overnight Mail
_FAX
FTP SiteX Emai!: [e-mail]
Dr. Don Reading
6070 Hill Road
Boise, ldaho 83703
Hand Delivered
_U.S. Mail
_Overnight Mail
_FAX
FTP SiteX Email:[e-mail]
IDAHO POWER COMPANY'S REPLY COMMENTS - 9
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
cAsE NO. IPC-E-22-11
IDAHO POWER GOMPANY
ATTACHMENT NO. 1
SGHEDULE 55
(GIean and Legislative)
ldaho Power Company Seventeenth Revised Sheet No. 55-1
Cancels
|.P.U.C. No. 29. Tariff No. 101 Sixteenth Revised Sheet No. 55-1
SCHEDULE 55
POWER COST ADJUSTMENT
APPLICABILITY
This schedule is applicable to the electric energy delivered to all ldaho retai! Customers served
under the Company's schedules and Special Contracts. These loads are referred to as "firm" load for
purposes of this schedule.
BASE POWER COST AND PROJECTED POWER COST
The Base Power Cost of the Company's rates, expressed in cents per k\Mr, is computed by
dividing the sum of the Company's power cost components by firm k\//tt sales. The power cost
components are segmented into three categories as described in the table below:
The Projected Power Cost is the Company estimate, expressed in cents per k\Mr, of the power
cost components for the forecasted time period beginning April 1 each year and ending the following
March 31.
BALANCING ADJUSTMENT
The Balancing Adjustment is based upon the differences between previous Projected Power Cost
and the power costs actually incurred. The Balancing Adjustment is 0.2579 cents per k\Mt.
EARNINGS SHARING
Order Nos. 30978, 32424,33149, and 34071 directed the Company to share a portion of its
earnings above a certain threshold with customers through the annual Power Cost Adjustment. The
Company's 2021 earnings were above the prescribed threshold resulting in a credit of 0.0038 cents per
k\ Jh.
IDAHO
lssued per Order No.
Effective - June 1,2022
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company Twelfth Revised Sheet No. 55-2
Cancels
I.P.U.C. No. 29. Tariff No. 101 Eleventh Revised Sheet No. 55-2
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
POWER COST ADJUSTMENT
The Power Cost Adjustment (PCA) is the sum of: 1) 95 percent of the difference between the
Projected Power Costs in Category 1 and the Base Power Costs in Category 1;2) 100 percent of the
difference between the Projected Power Costs in Category 2 and the Base Power Costs in Category 2;
3) 100 percent of the difference between the Projected Power Costs in Category 3 and the Base Power
Costs in Category 3; 4) the Balancing Adjustment; and 5) Earnings Sharing. The following table calculates
the rates for Categories 1, 2 and 3.
The following table shows the determination of PCA rates for Categories 1,2, and 3:
Category Description
Base Power
Cost
Projected
Power Cost Difference Sharing
o/o Rate
(d per k\M)
1
The sum of fuel
expense and
purchased
power expense
(excluding
purchases from
cogeneration
and small power
producers), less
the sum of off-
system surplus
sales revenue
and revenue
from market-
based special
contract oricino.
1.0234 1 7 I 31 0.6897 95o/o 0.6552
2
Purchased
power expense
from
cogeneration
and small power
producers.
0.8531 1.3549 0.50'18 lOOo/o 0.50'18
3
Demand
response
incentive
oavments.
0.0751 0.0541 -0.0209 lOOo/o -0.0209
Total 1.9516 3.1221 1.1705 1.13606
IDAHO
lssued per Order No.
Effective - June 1,2022
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company Eleventh Revised Sheet No. 55-3
Cancels
|.P.U.C. No. 29. Tariff No. 101 Tenth Revised Sheet No. 55-3
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
The monthly Power Cost Adjustment rates applied to the Energy rate of all metered schedules and
Special Contracts are shown below. The monthly Power Cost Adjustment applied to the per unit charges
of the nonmetered schedules is the monthly estimated usage times the cents per k\Mt rates shown below.
Schedule Cateqorv
Balancino
Adiustment
Earninos
Sharino
Total PCA
I 2 3
1 0.6552 0.5018 (0.0209)0.2579 (0.0047)1.3893
3 0.6552 0.5018 (0.0209)0.2579 (0.0045)1.3895
5 0.6552 0.5018 (0.0209)o.2579 (0.0045)1.3895
6 0.6552 0.5018 (0.0209)0.2579 (0.0047)1.3893
7 0.6552 0.5018 (0.0209)0.2579 (0.0059)1.3881
I 0.6552 0.5018 (0.0209)0.2579 (0.0059)1.3881
9S 0.6552 0.s018 (0.0209)o.2579 (0.0035)1.3905
9P 0.6552 0.5018 (0.0209)0.2579 (0.0031)1.3909
9T 0.6552 0.5018 (0.0209)0.2579 (0.0035)1.3905
15 0.6552 0.5018 (0.0209)0.2579 rc.0122)1.3818
19S 0.6552 0.5018 (0.0209)0.2579 (0.0035)1.3905
19P 0.6552 0.5018 (0.0209)0.2579 (0.0027)1.3913
197 0.6552 0.5018 (0.0209)o.2579 (0.0025)1.3915
24 0.6552 0.5018 (0.0209)0.2579 (0.0038)1.3902
40 0.6552 0.5018 (0.0209)0.2579 (0.0042)1.3898
41 0.6552 0.5018 (0.0209)0.2579 (0.0074)1.3866
42 0.6552 0.5018 (0.0209)0.2579 (0.0030)1.3910
26 0.6552 0.5018 (0.0209)o.2579 *1.3940
29 0.6552 0.5018 (0.0209)0.2579 *1.3940
30 0.6552 0.5018 (0.0209)0.2579 *1.3940
* Earnings Sharing Credits are applied as monthly amounts per the table below
Schedule SpecialContract Monthlv Credit
26 Micron ($1.307.24)
29 Simolot ($328.56)
30 DOE $432.24\
EXPIRAT!ON
The Power Cost Adjustment included on this schedule will expire May 31 ,2023.
IDAHO
lssued per Order No.
Effective - June 1,2022
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
LEGISLATIVE
ldaho Power Company@Revised Sheet No. 55-1
Cancels
!.P.U.C. No. 29, Tariff No. 101 FifteenthSixteenth Revised Sheet No. 55-1
SCHEDULE 55
POWER COSTADJUSTMENT
APPLICABILITY
This schedule is applicable to the electric energy delivered to all ldaho retail Customers served
under the Company's schedules and Special Contracts. These loads are referred to as "firm" load for
purposes of this schedule.
The Base Power Cost of the Company's rates, expressed in cents per k\M, is computed by
dividing the sum of the Company's power cost components by firm kWh sales. The power cost
components are segmented into three categories as described in the table below:
The Projected Power Cost is the Company estimate, expressed in cents per kWh, of the power
cost components for the forecasted time period beginning April 1 each year and ending the following
March 31.
BALANCING ADJUSTMENT
The Balancing Adjustment is based upon the differences between previous Projected Power Cost
and the power costs actually incurred. The Balancing Adjustment is (0.2{423@ cents per kWh.
EARNINGS SHARING
Order Nos. 30978, 32424, 33149, and 34071 directed the Company to share a portion of its
earnings above a certain threshold with customers through the annual Power Cost Adjustment. The
Company's 2O2A! earnings were bde*Sbgthe prescribed threshold resulting in a credit of 0.0e00
0038 cents per k\flh.
IDAHO
lssued per Order No.€5290
Effective --
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company envent+nryemn Revised Sheet No. 55-2
Cancels
|.P.U.C. No. 29. Tariff No. lOlTenthEleventh Revised Sheet No. 55-2
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
POWER COST ADJUSTMENT
The Power Cost Adjustment (PCA) is the sum of: 1) 95 percent of the difference between the
Projected Power Costs in Category 1 and the Base Power Costs in Category 1; 2) 100 percent of the
difference between the Projected Power Costs in Category 2 and the Base Power Costs in Category 2;
3) 100 percent of the difference between the Projected Power Costs in Category 3 and the Base Power
Costs in Category 3; 4) the Balancing Adjustment; and 5) Earnings Sharing. The following table calculates
the rates for Categories 1, 2 and 3.
The following table shows the determination of PCA rates for Categories 1, 2, and 3
Category Description
Base Power
Cost
Projected
Power Cost Difference Sharing
o/o Rate
(6 per kWtr)
1
The sum offuel
expense and
purchased
power expense
(excluding
purchases from
cogeneration
and small power
producers), less
the sum of off-
system surplus
sales revenue
and revenue
from market-
based special
contract pricinq.
1.WzW 1.51747137 0.45626897 95%0.43345552
2
Purchased
power expense
from
cogeneration
and smallpower
producers.
0.88468531 1.355449 0.471 15018 lOOo/o 0.47115018
3
Demand
response
incentive
payments
0.077s51 0.052741 -0.025209 1O0o/o -0.02520209
Total 2J2371.9516 2Jf,€€,3.1221 0s0241.1705 o3;I931.13606
IDAHO
lssued per Order No.€5299
Effective -_
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company +enthEleventh Revised Sheet No. 55-3
Cancels
l.P.U.C. No. 29. Tariff No. 101 AlinthTenth Revised Sheet No. 55-3
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
The monthly Power Cost Adjustment rates applied to the Energy rate of all metered schedules and
Special Contracts are shown below. The monthly Power Cost Adjustment applied to the per unit charges
of the nonmetered schedules is the monthly estimated usage times the cents per kWh rates shown below.
Schedule Cateoorv
Balancino
Adiustment
Earninos
Sharino
Total PCA
1 2 3
1
0.43346552 0.47115018 (0.0252209)(o.tzuM)(0.004n-
e,76711.3893
3
oA3€l,-.0.47115018 (0.0452289)(0.1w28e)(0.0045L
0,75711.3895
5
o.43€./,-.0.47115018 (0.035220e)(o.+wzgzg (0.0045F
01.75713895
6
0.43340552 0.471150't8 (0.02e20e)(0.4wru (0.004n-
01.75713893
7
o.M@ 0.47115018 (0.0252289 (0.1242579)(0.0059F
o1.75713881
I 0.M552 0.47115018 (0.035220e)@Amn (0.0059)-
o1.75713881
9S
0.43346552 0.47115018 (0.0252209)(0.+?,2?t/vd-(0.0035)-
e1.75713905
9P
0l€€/6552 0.47115018 (0.0352209)(0.1,P925791 (0.0031)-
e1.75713909
9T
0.4€€/6552 0.47115018 (0.025220e)(0.199925791 (0.0035)-
01.75713905
15
0.M552 0.471 15018 (0.025220e)(0.w2@ rc.0122Y
01.75713818
19S
o.43345552 0.47115018 (0.0252209 (0.1,92257!4 (0.0035)-
01.75713905
19P
0.43346552 0.47115018 (0.0252209)(0.1,gg257e1 (0.002n-
01.75713913
197 0.43346552 0.47115018 (0.03e209)@.1,9925791 (0.0025F 01.75713915
24 0./€€4,6552 0.47115018 (0.0252209)$.1422579)(0.0038)-91.75713902
40 0.&6552 0.47115018 (0.0252209)$.1,992579A (0.0042)-10.75713898
41 0.43A46552 0.47115018 (0.0253209)$.w2579)(0.0074)-01.75713866
42 0.M552 0.47115018 (0.0252209)$.199e2579).(0.0030)-e1.75713910
26 0A€€/6552 0.47115018 (0.02*209)$.w2579)*e1.75713940
29 0.4334$552 0.47115018 (0.0252209)$.1*22579)*01.75713940
30 0.4p€/6552 0.47115018 (0.02*209)$.1,9925791 *91.75713940
* Earnings Sharing Credits are applied as monthly amounts oer the table below.ranCse+urrently
$gSg+erment*
Schedule Soecial Contract Monthlv Credit
26 Micron ($1,307.24)
IDAHO
lssued per Order No.3529e
Effective -_
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
122'1 West ldaho Street, Boise, ldaho
ldaho Power Company +enthEleventh Revised Sheet No. 55-3
Cancels
EXPIRATION
The Power Cost Adjustment included on this schedule will expire May 31 ,2024.
29 Simolot ($328.56)
30 DOE $432.241
IDAHO
lssued per Order No.€5299
Effective --
lssued by IDAHO PO\ /ER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
l.hho PoFr Company
C.lcuhtff ot tu[nm lJrfrcl mn-m6
Strb ol ld.hoPffi Cat Adl6tnnt t R.ru 8h.dng
FlLd Afrll 15,2022
Summry ot Rr[n[ lnpact
Cmnt Blll.d R.vana b PDpo-d Bllhd R.6nlx
NorEliz.dR.t!
Sch.
!e.
AEngp
Nur$ar otCurlmo)
Cumt
BillGd
Eivsur
Milg
Pcr kvlh
TotlI
Aqurnncnb
b Er.d
RME
PDpo$d
Toirl BlLd
RMnua
M[3
P.r kwr
Paml
Ci.n0.
BilLdto Bilbde)
BMI1
EncrW
ft\i/hl (r)Lim
No I-.rfllrrddhD
Unifbm T.rilf Raler:
I
2
3
a
5
6
7
8I
t0
11
12
13
11
t5
16
17
R.tkLntd Swi6
R.d&f, lid Srryio Tinl}ol.Dry
Raaldcntd ScM6 Onsilr Glnrntion
Smll Gcncnl Srrvio
Smll G.nml S.de Oh9it GrmEfm
Lrrlo GcmnlScwio
Durkb D.m Ugftthe
LlI!.PffiScMe
UnmtrEd Gon.nl S.Mm
I
3
1
5
6
7
8
I
t5
t0
21
40
41
12
/t90,293
21
0
968
12,024
30,348
80
37,91S
0
116
19,'t20
't,863
2,080
786
5,458,972,07t
,r,52'1,055
0
17,662,3:il
65,895,684
137,395,735
100,/t25
3,900,728,49r
5,247i23
2,391,392,176
1,897,512,119
13,925,30'l
23,760,014
2,U7,*1
t573,825,900
!r5{,030
t0
1r,788,31!7
t7,342,186
t18,011,/65
,272E5
t290,'1,18,886
$178,806
t14r,897,963
l'15,1,75,t,865
$1,229,632
t3,589,588
$re{,266
105.12
I 00-,al
0.00
101.25
111.12
r3't.09
1a3.29
71.9
2a2.74
59-25
8't.56
E6.30
151.08
6a_70
t3,t,51 1,658
s28,5S0
30
$r1,697
1,r16,593
t866,902
$1201
t24,708,579
132,96
315,r66S79
E12,012,{46
088,107
t149,559
118,054
t608,337,558
',a2.,a29t0
$1,900,034
s7,758,7,9
118,676,367
828,487
1314,657,4,r5
tl,311,7t2
t158,86,1,342
s't60,767,311
11,317,739
t3.739,t47
t,'O2,3N
6.01%
6.30%
N/A
6.25%
5.67%
a.61*
r1.40%
6.5216
2.57%
10.70%
7.78%
7.17%
1.17%
9.80q6
111.11
106.73
0.00
't07.58
117.71
137.40
r49.59
u.72
219.02
85.60
87.E0
0a,63
157.37
71.U
Sfrct tightng
Tilfic Contd Uohlim
Tolrl Unibm T.dlb
Tot l Sp.cial Confrolr
596,318 13,920,07't,060 11,194,3r13.t00 85.A' t88,r12,982 11,282,1!6.,172
3 1,071,974,663 t55,966,760 52.21 t8,802,590 t62,769,35{r
594,321 t+092,O18,$12 11,250,290,940 t!.40 114,31!,!72 ll,!'15,21t,522
92.13
5E.55
19.73
7.38%
12.15%
7.59%
(1)Jun.01,2022 - uay31,2023 FomsbdT.nYor(SEine 2022 Fomll)
(2) Pamnlrgc irTsai dod not indudc otrpomrlt Ilridr aE .pplcd rs parn[rgpr, RidB rnd F6!rdti$ Fos.
ldrho Pmr ConprnyCdcLts ot R.m[ lm0.ct 2022{O2t
8i.b o, ld.hoPffi Coet AdlBtnil A R.[m Ehrtnf
FlLd Apdl it,2022
Sumry olR.Em nD.st- Rrb3 C,le, rnd 24 Obtlhdo L.vd D.tllCmilAlbdh[m bPtDp6.d BllLd bmm
Llm
!a
AEEec
Nurr$ar ot
Curblim(t)
Nomllz.d
En rly
Gvlft) 0)
3,304,176.8,10
502,904,508
3,557,1,(l
Cufrlnl
Blllcd
RaEM Prr kl il
Adlutmcnts
io tlillGd
Rmu
Prcposd
Totrl BILd
Rmm
t270,972,W
3t3,505,100
1280,8811
P*kvtir
P.mt
ch.nlr
f,irbdro Brbd (2)
Ramu
MilltMtb
Trrif Daloirtha
t nlbm Txi[ R.i!r:
I L.r!6 Gcnml SaqE.ry2 LeEcG.nad Primry3 Lnlcc.mlTnffiisim4 Totdsdrdibe
37,635
200
,t
t250,04t,9E7
t39,&16,7a9
1267,'l3t
75.66
07.18
75.'10
$20,927,508
t3,758,/t50
t22,531
82.01
73.52
81./t3
8.37%
9.,t3%
8.4396
R.t!
Sdr.
No.
ss
OP
ST
19S
10P
t9T
2,tS
217
37,9'19 3,90,728,491 t200,t'8,868 74.38
'it1,708,579
131a,857,'lt5 9.7i2 8.5296
I Lrr!!PMrs.ffid.,y7 Ll'lePmrPtimry8 l.lllc PmrTnntnilsbn0 TotrlSchcafi19
0
111
2
0
2,358,406,546
3'1,880,&30
$0
$139,847,.t26
fi,8t 0,537
s0
$14,958,010
32$,860
t0
115it,E05,436
t2,Gio2o6
0.00
59.30
5826
0.00
65.et
62.60
0.00%
10.7096
11.2&
'll lrieEtbn Sccoid.ryt2 lfiigltion Tnn${3aim
13 TotrlSch.dul.2it
t't6 2,391,392,176
19,120
0
I,897,512, t r9
0
115,166,670 1156,864,642
,12,012,4A fi66,767,311
t0 t0
tl4t,c07,963
tl54,754,665
t0
59.25
81.56
0.00
65.m
87.80
0.00
10.79*
7.76%
0.fiM'19,120 1,897,512,119 115,t,754,665 81.56 ,12,012,* 1160,767,3t1 87.89 7.76%
(l)Jum 0l, m22- M.y3l,2023 FrclbdTc{Y.s(Sprim 2@2 Folud)