20150528final_order_no_33306.pdf

Office of the Secretary
Service Date
May 28,2015
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF IDAHO POWER )
COMPANY’S APPLICATION FOR )CASE NO.IPC-E-15-14
AUTHORITY TO IMPLEMENT POWER )
COST ADJUSTMENT (PCA)RATES FOR )
ELECTRIC SERVICE FROM JUNE 1,2015 )ORDER NO.33306
THROUGH MAY 31,2016 )
On April 15,2015,Idaho Power Company applied for its annual Power Cost
Adjustment (PCA).Since 1993,the PCA has allowed the Company to increase or decrease its
rates to offset the Company’s annual “power supply costs.”Because about half of the
Company’s generation is from hydropower facilities,the Company’s actual cost to supply
electricity to customers varies each year depending on changes in Snake River stream flows,the
amount of purchased power,fuel costs,the market price of power,and other factors.1
This year,the Company reports that its power supply costs are less than the power
supply costs that the Company currently recovers through PCA rates.The Company has thus
applied to adjust its PCA rates,and claims its Application,if approved,will decrease its
customers’bills overall by about $10.1 million (or 0.91%)in the upcoming year,with a typical
residential customer’s bill decreasing by about 47ç per month.The Company’s proposed PCA
rates are reflected in an updated Schedule 55,which the Company has attached to the
Application.The Company requests that the new PCA rates take effect on June 1,2015.
On April 22,2015,the Commission issued a Notice of Application and Notice of
Modified Procedure setting a May 15,2015 comment deadline and a May 20,2015 reply
deadline.The Industrial Customers of Idaho Power intervened as a party in the case,but filed no
comments.Commission Staff submitted the only comments in the case,and supports the
Company’s Application with some modification to capture the benefits of the Settlement
Agreement that Staff and the Company asked the Commission to approve in Case No.IPC-E-15-
15 (requesting that the Commission approve a Settlement Stipulation in which the parties
propose that the Company change how it calculates its power costs when determining the PCA’s
true-up component).The Company filed a reply that concurs with Staff’s comments.
For example,the revenue from the sale of sulfur dioxide (SO2)allowances.
ORDER NO.33306 1
Having reviewed the record,including the Application,comments,and reply,we
enter this Order approving the Company’s Application,as modified to reflect the Settlement
Agreement approved in IPC-E-15-15,with the new PCA rates to take effect June 1,2015.Our
decision is explained below.
THE PCA MECHANISM
The Company’s annual PCA combines three traditional components and two
additional components to generate a new PCA rate for the upcoming year.Sections A and B,
below,discuss the traditional and additional PCA components.
A.Traditional PCA Components
The PCA’s traditional components include:(1)a firecast of upcoming power supply
expenses;(2)the true-up of the prior year’s forecasted power supply costs in light of the
Company’s actual power supply costs for that year;and (3)a reconciliation that tracks the
Company’s recovery of the prior year’s true-up.These traditional components are explained
below.
1.Forecast.The Company uses its most recent Operating Plan to Jàrecast its
expected power supply costs for the upcoming PCA year (the 12-month period from April
through March).See Order No.30715.Expected power supply costs include:fuel costs;
transmission costs for purchased power;Public Utility Regulatory Policies Act of 1978
(“PURPA”)contract expenses;surplus sales revenues;and revenues from the sale of renewable
energy credits and sulfur dioxide allowances.The Company may recover 95%of the difference
between the non-PURPA projected power supply costs and the power supply costs already
embedded in rates,100%of the costs of its PURPA power supply costs,and 100%of its
demand-side management (“DSM”)incentive and conservation costs.See Order No.30715,
Order No.32426 at 3.The Company converts the power supply cost difference to a cents-per-
kilowatt-hour (/kWh)rate by dividing the power supply cost difference by the amount of energy
it expects to sell in the upcoming year.
2.True-Up.The Company’s power supply cost forecast is not 100%accurate,which
means that PCA rates based on that forecast allow the Company to recover more or less than the
power supply costs that the Company actually incurred during the year.To account for this
difference,the Company trues tip its forecasted power supply costs from the prior year to match
its actual power supply costs from that year.The true-up amount is the difference between:(1)
ORDER NO.33306
forecasted power supply costs and base power supply costs (i.e.,normalized power supply costs
that the Company is already authorized to recover through base rates),and (2)revenues from the
forecast rate that accrued during the prior year.The Company converts the true-up amount into a
0/kWh rate by dividing the true-up amount by the amount of energy it expects to sell in the
upcoming year.
3.Reconciliation.The Company reconciles the true-up by using the new PCA rate to
credit or charge customers for any over-recovered or under-recovered balance from the prior
year’s true-up.Reconciliation ensures that the Company only recovers its actual power supply
costs,and that the Company’s native load customers only pay for the power that the Company
actually sold to them.See Order No.29334 at 42 Customers receive a rate credit when the
Company’s power supply costs are low,but are assessed additional charges when power supply
costs are high.
B.Additional PCA Components
Besides the PCA’s traditional components,this year’s PCA includes:(1)a DSM
Rider credit;and (2)revenue sharing.These additional PCA components are discussed below.
1.DSM Rider Credit.The Company continues to apply a DSM Rider credit to the
PCA.This credit,which is about $4 million,ensures the change to base level Net Power Supply
Expenses (“NPSE”)that the Commission approved in March 2014 remains revenue neutral.See
Order No.33000.The DSM Rider credit is uniformly applied to each customer class and will
continue to be included in annual PCAs until NPSE included in base rates is re-established as
part of a general rate case.
2.Revenue Sharing.In 2010,Commission Order No.30978 established a revenue-
sharing mechanism that can be used to reduce PCA rates.The Commission subsequently
modified the revenue-sharing mechanism in Order No.32424 and extended it through 2014.The
revenue-sharing mechanism currently requires that:(1)customers and the Company equally
share in actual year-end earnings of 10%through 10.5%ROE in any year from 2012 through
2014,with the customer portion used to reduce rates when the PCA takes effect;and (2)
customers receive 75%,and the Company receive 25%,of actual year-end earnings above
2 This reconciliation component has been referred to as the “true-up of the true-up.”
ORDER NO.33306 3
10.5%,with the customer portion to reduce amounts in the Company’s Pension Balancing
Account that the Company otherwise would collect from customers through rates.3
THE APPLICATION
With this Application,the Company asks the Commission to approve a $63.1 million
PCA amount for 2015-2016.This amount includes an $8.0 million revenue sharing rate credit
and a $4.0 million DSM Rider credit,and would decrease the Company’s total annual billed
revenue from customers by about $10.1 million (or 0.91%).If the Application is approved as
filed,the Company’s major customer classes would be impacted as follows:
Proposed 2015 Revenue Impact by Class:
Percentage_Decrease_from_Current_Billed_Rates
Small Large
General General Large Overall
Residential Service Service Power Irrigation Change
(0.45%)(0.07%)(1.15%)(1.83%)(0.91%)(0.91%)
Source:Application Attach.2,Revenue Impact Summary;See a/so,News Release
filed with Application.
The Company’s billed revenue from its three special contract customers would decrease as
follows:Micron—(2.22%);Simplot—(2.45%);DOE (INL)—(2.31%).
To recover the new PCA amount,the Company combines the three traditional PCA
components (i.e.,forecasted power supply costs,true-up,and reconciliation)to propose a
2015/2016 PCA rate surcharge of 0.5405/kWh (0.28 15/kWh +0.24830/kWh +0.01070/kWh).
The Company expects this rate will allow it to recover traditional PCA costs in one year.The
proposed rate is 0.190/kWh less than current PCA rates.
The Company continues to apply the $4 million DSM Rider credit to the PCA.The
DSM Rider credit yields a uniform rate credit for all customer classes of(0.0286)/kWh.
The Company also applies the revenue sharing component to the PCA.The
Company’s 2014 year-end ROE for Idaho was 11.19%;thus,the revenue sharing component
yields a total customer benefit of $24,692,279,which consists of:(1)a $7,999,145 revenue
sharing credit;and (2)a $16,693,134 offset to the Company’s pension balancing account.The
revenue sharing credit reduces the 2015-2016 PCA calculation by about $7.6 million.The
Company proposes to uniformly spread the revenue sharing credit among its rate schedules,and
In Case No.IPC-E-14-14,the Commission modified the revenue sharing mechanism from Order No.32424 and
extended that mechanism beyond 2014.The modified revenue sharing mechanism will apply in calendar year 2015
and be reflected in the next PCA.See Order No.33149.
ORDER NO.33306 4
to assign the credit to energy rates in each schedule.This class-specific energy credit yields a
different combined PCA/DSM Rider/revenue sharing energy rate for each rate schedule.
THE COMMENTS
Staff filed comments in this case that support the Company’s Application,with an
adjustment that decreases the PCA’s true-up deferral balance by $l.47l million.The Company
filed reply comments that concur with Staff’s recommendations.The comments are summarized
below.
A.Staff (ominents
In summary,Staff states that it analyzed the traditional PCA components (forecast,
true-up,and reconciliation)and additional components (revenue sharing and DSM Rider credit),
verified the Company’s calculations,and agrees with all of the Company’s proposed PCA
components except the true-up.Staff’s comments on the true-up appear below,followed by
Staff’s overall recommendation in this case.
1.True-Up.The Company proposes a $34.5 million true-up deferral balance,and a
0.2483/kWh true-up rate.Staff explains that the Company’s proposed true-up deferral balance
consists of the following items:
True-Up Deferral
Description Deferral
Amount
Load Change Adjustment $1 1,817,280
Water Leases (770,091)
Fuel Expense -Coal 23,337,488
Fuel Expense -Gas 1,968,648
Surplus Sales 2,115,917
Non-Firm Purchases 21,106,744
Third Party Transmission Expense 234,406
Hoku First Block Revenue 3,216,534
Subtotal 63,026,925
Emission Allowance Sales Credits (16,250)
Renewable Energy Credit (REC)Sales (2,400,487)
Subtotal 60,610,189
Amount After Jurisdictional Allocation and Sharing 54,700,695
ORDER NO.33306 5
Qualifying Facilities -After Jurisdictional Allocation 22,154,787
Demand Response Incentive Payments (3,261,639)
Total Expense Items 73,593,843
Revenue from PCA Forecast 39,275,784
Deferral Balance 34,318,059
Interest on the Deferral Balance 197,922
Total Deferral 534,515.981
Staff agrees that the Company’s true-up calculations are correct.But Staff
recommended the Commission reduce the true-up deferral balance by SI .471 million to reflect
the Staff and Company’s Settlement Agreement in Case No.IPC-E-15-15.
In Case No.IPC-E-15-15,the Company asked the Commission to modify the PCA
true-up calculation.Staff and the Company,which are the only parties in that case,ultimately
entered a Settlement Agreement in which they agree that the Commission should replace the
true-up’s load change adjustment rate (LCAR)methodology (which tracks the difference
between base system load at generation and actual system load at sales)with a sales-based load
adjustment methodology (that tracks the difference between Idaho actual sales at meter and
Idaho base sales at meter).This solution addresses a “line loss”inaccuracy that Staff identified
in last year’s PCA.
The Settlement Agreement in IPC-E-15-15 specifies that the new true-up
methodology should apply as of January 1,2015,and be incorporated into the PCA rates
established in this case.Staff notes that applying the agreed upon true-up adjustment here would
reduce the true-up deferral balance that customers would otherwise pay by $1 .471 million.Staff
represents that the Company accepts Staff’s proposed 51.471 million true-up adjustment in this
case.Staff notes that this adjustment results in a new true-up rate of 0.2376/kWh.
2.Overall Recommendation.Based on its analysis,Staff recommended the
Commission approve the Company’s proposed PCA rates as modified to include the sales-based
adjustment rate true-up adjustment discussed above.Staff recommended a uniform 0.5287/kW
PCA rate surcharge to collect an NPSE amount of $73.67 million.This PCA surcharge rate
includes the true-up adjustment proposed in Case No.IPC-E-15-15,and is significantly less than
the current rate of 0.73040/kWh.Staff further recommended the Commission approve the
Company’s proposed revenue sharing amounts;specifically,PCA revenue sharing of $7,999,145
and a pension balancing account contribution of $16,693,134.Staff also recommended that the
ORDER NO.33306 6
$4 million in DSM Rider funds be credited to customers as a reduction in the 2015-2016 PCA.
Staff recommended the Commission approve the Schedule 55 rates reflected in Attachment C to
Staffs comments,a copy of which is also attached to this Order as Attachment 1.Staff
recommended the new base rates and updated Schedule 55 rates be effective June 1,2015.Staff
notes that its recommendations,if approved,will decrease customers’bills overall by about
$11.6 million (or 1.05%).instead of by $10.1 million (or 0.91%)as originally proposed in the
Application.
B.Company Reply Comments
In reply to Staffs comments,the Company acknowledges Staffs review and
confirmation of the Company’s PCA calculations.The Company also supports Staffs
recommendation to further decrease the filed PCA deferral balance by another $1.47 1 million to
reflect the parties’Settlement Agreement in Case No.IPC-E-15-15.The Company affirms that
this adjustment accurately quantifies the January 1,2015,implementation of the PCA deferral
modifications detailed in the Settlement Agreement.The Company believes that Staff
appropriately incorporated the Settlement Agreement’s terms into the Company’s filed 2015-
2016 PCA rates,and requests that the Commission approve those rates as specified in
Attachment C to Staff’s comments,which also is attached to this Order as Attachment 1.
FINDINGS AND DISCUSSION
We have reviewed the record,including the Company’s Application and the
comments filed in this case.We note that there is no disagreement between the parties in this
matter,or any opposition to the PCA rates they have ultimately proposed.Based on our review
of the record,we find it fair,just,and reasonable to approve the Company’s proposed PCA rates,
as modified to include the true-up adjustment discussed above.The resulting uniform PCA
surcharge rate of 0.5287Ø/kW is much less than the current rate of 0.73040/kWh and will enable
the Company to collect an NPSE amount of $73.67 million.We find that the Company’s
proposed PCA revenue sharing of $7,999,145,pension balancing account contribution of
$16,693,134,and $4 million DSM Rider credit,are accurately calculated and will further reduce
the 2015-2016 PCA.We find it is fair,just,and reasonable to approve Schedule 55 rates as
reflected in Attachment 1 to this Order,with the new rates to take effect June 1,2015.
ORDER NO.33306 7
ORDER
IT IS HEREBY ORDERED that Idaho Power’s proposed PCA rates,as modified to
include the sales-based adjustment to the true-up,as approved in Case No.IPC-E-15-15,are
approved effective June 1,2015 through May 31,2016.
IT IS FURTHER ORDERED that the Company’s proposed PCA revenue sharing
credit of $7,999,145.pension balancing account contribution of $16,693,134.and $4 million
DSM Rider credit are approved.
IT IS FURTHER ORDERED that the PCA revenue decrease shall be combined and
offset with the revenue sharing credit and DSM Rider credit to produce new Schedule 55 rates,
as shown in Attachment 1 to this Order,with the new rates to be effective June 1,2015.The
Company shall promptly file conforming tariffs.
THIS IS A FINAL ORDER.Any person interested in this Order may petition for
reconsideration within twenty-one (21)days of the service date of this Order.Within seven (7)
days after any person has petitioned for reconsideration,any other person may cross-petition for
reconsideration.See Idaho Code §6 1-626.
ORDERNO.33306 8
DONE by Order of the Idaho Public Utilities Commission at Boise,Idaho this
day of May 2015.
PAtKJELL NDER,ESIDENT
MACK A.REDFORD,COMMISSIONER
KR TINE RAPER,C MMISSIONER
ATTEST:
/1LAJ.i1L
Jn D.Jewe1J
mmission Secretary
():IPC-E-l 5-14kk2
ORDER NO.33306 9
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