HomeMy WebLinkAbout20130910Stipulation.pdfYHFfrII*HI,IOUNTAIN
September 9,2013
VIA ELECTRONIC FILING
AND OVERNIGHT DELIVERY
Jean D. Jewell
Commission Secretary
Idaho Public Utilities Commission
472W. Washington
Boise,ID 83702-5983
Re:CASE NO. PAC.E.13.O2
IN THE MATTER OF THE APPLICATION OF ROCKY MOUNTHN POWER
FOR AN ORDER AUTHORIZING A CHANGE IN DEPRXCIATION RATES
Dear Ms. Jewell:
Please find enclosed for filing an original and seven (7) copies of Rocky Mountain Power's
Stipulation in the above referenced case.
All formal correspondence regarding this Application should be addressed to:
Data Request Response Center
PacifiCorp
825 NE Multnomah, Suite 2000
Portland, OR97232
Email : datarequest@nacifi corp.com
Informal inquiries may be directed to Ted Weston, Idaho Regulatory Affairs Manager, at (801)
220-2963.
:ilir; SI? I il 201 South Main, Suite 2300
Salt Lake City, Utah 841l1
Daniel E. Solander
Rocky Mountain Power
201 South Main Street, Suite 2300
Salt Lake City, Utah 841I I
Telephone: (801) 220-4014
Fax: (801) 220-3299
Email : daniel. solander@pacifi corp. com
Sincerely,
Q-lful^^
Daniel E. Solander
Senior Counsel
Enclosures
Service List
CERTIFICATE OF SERVICE
I hereby certify that on this 9ff of Septemb er,20l3,I caused to be served, via e-mail, a
true and correct copy of the foregoing Stipulation on Depreciation Rate Changes in Case
No. PAC-E-13-02 to the following:
James R. Smith Monsanto Company
P.O. Box 816
Soda Springs, Idaho 83276
E-Mail : j im.r. smith@monsanto.com
Brubaker & Associates
16690 Swingley Ridge Rd., #140
Chesterfield, MO 63017
E-Mail : bcollins@consultbai.com
Ronald L. Williams
Williams Bradbury, P.C.
l0l5 W. Hays Street
Boise, ID 83702
E-mail : ron@williamsbradbury.com
Tim Buller
PacifiCorp Idaho Industrial Customers
Agrium Us Inc.A.,lu-West Industries
E-mail : tbul ler@aerium.com
Randall C. Budge
Racine, Olson, Nye, Budge & Bailey,
Chartered
201E. Center
P.O. Box 1391
Pocatello, lD 83204-1391
E-Mail: rcb@racinelaw.net
Neil Price
Attomey
Idaho Public Utilities Commission
PO Box 83720
Boise, ID 83720-0074
E-mail : nprice@puc. state. id.us
Don Schoenbeck
RCS,Inc.
900 Washington Street, Suite 780
Vancouver, WA 98660
E-mail: dws@r-c-s-inc.com
Carrie Meyer
Supervisor, Regulatory
Mark C. Moench (8946)
Daniel E. Solander (8932)
201 South Main Street, Suite 2300
Salt Lake City, Utah 84111
Telephone No. (801) 220-4014
Facsimile No. (801) 220-3299
mark.moench@pacifi corp. com
daniel. solander@pacifi corp. com
Attorneysfor RoclE Mountain Power
IN THE MATTER OF THE
APPLICATION OF ROCKY
MOUNTAIN POWER FOR AN ORDER
AUTHORIZING A CHANGE IN
DEPRECIATION RATES
BEF'ORE THE IDAHO PUBLIC UTILITIES COMMISSION
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Case No. PAC-E-I3-02
STIPULATION
STIPULATION
This Stipulation ("Stipulation") is entered into by and among Rocky Mountain
Power, a division of PacifiCorp ("Rocky Mountain Power" or the 'oCompany"),
Monsanto Company ("Monsanto"), PacifiCorp Idaho Industrial Customers ("PIIC") and
Staff for the Idaho Public Utilities Commission ("Staff'), together the "Stipulating
Parties." The Stipulating Parties submit this Stipulation on Depreciation Rate Changes
("Stipulation") in resolution of all issues in this Case and request that the Commission
approve new depreciation rates for Rocky Mountain Power as stipulated herein to
become effective on January t,2014.
INTRODUCTION
l. The terms and conditions of this Stipulation are set forth herein. The
Parties agree that this Stipulation represents afur,just and reasonable compromise of the
issues raised in this proceeding and that this Stipulation is in the public interest. The
Parties recommend that the Idaho Public Utilities Commission ("Commission") approve
the Stipulation and all of its terms and conditions. See IDAPA 31.01.01 .271,272, and
274.
PROCEDURAL BACKGROTIND
2. On January 22,2013, Rocky Mountain Power filed its Application for an
order authorizing the Company to change depreciation rates effective January 1,2014,
together with the direct testimony of Henry E.Lay, John J. Spanos, and K. Ian Andrews.
A depreciation study, recommending depreciation rates for all depreciable plant accounts,
was an exhibit to the testimony of Mr. Spanos. Based on historical December 31, 2011,
plant balances, which were then used to develop projected plant balances and rates as of
December 31, 2013, depreciable plant balances and relative allocation factors, Rocky
Mountain Power's proposed depreciation rates resulted in an increase in depreciation
expense of $4.5 million in Idaho ($8.9 million including the early retirement of the
Carbon planD.
3. Monsanto and PIIC were granted intervenor status by the Commission on
March 28,2013, and May 8,2013, respectively.
4. On March 22,2013, Staff filed a Decision Memo with the Commission
stating that Staff had conducted an initial review of the Application and had been in
communication with the Company regarding a collaborative process to include all
interested stakeholders potentially affected by the Application. Staff recommended that
the Commission issue a Notice of Application and Intervention Deadline , after which the
Staff would issue aNotice of Public Workshop to include all interested parties.
5. The Commission issued its Notice of Application on March 28,2013. The
Commission issued a press release on May 3,2013, informing the public that Staff would
conduct a public workshop on Thursday, May 9, 2013, regarding Rocky Mountain
Power's Application.
6. Based upon the discussions at the public workshop, and the settlement
discussions between the Stipulating Parties, as a compromise of the positions in this
proceeding, and for other consideration as set forth below, the Stipulating Parties agree as
follows, subject to the approval by the Commission of the terms and conditions of this
Stipulation as described below.
TERMS AND CONDITIONS
Substantive Terms of the Stipulation
7. The Stipulating Parties, as well as parties from Utah and Wyoming due to
the system wide impacts of depreciation, have jointly engaged in good faith, arms-length
negotiations in an effort to resolve this matter. The negotiations have resulted in the
agreement of the Stipulating Parties on the terms and conditions as set forth herein.
8. The Stipulating Parties agree that the proposed depreciation rates set forth
in Attachment 1- Stipulated Rates attached hereto and incorporated herein, represent just
and reasonable depreciation rates for Rocky Mountain Power in Idaho commencing
January 1,2014.
9. The depreciation rates, originally proposed by the Company in its January
22, 2013, filing, result in an estimated increase in annual depreciation expense across
PacifiCorp's six jurisdictions of approximately $160.8 million ($83.9 million excluding
the early retirement of the Carbon Plant), based on estimated plant balances as of
December 31,2013, before the additional Oregon depreciation expense for shorter coal
plant lives. Table I shows the estimated impact of the agreed-upon changes to the
depreciation rates on the Company's filed depreciation study.
In Attachment 2 - Jurisdictional Allocation, detailed jurisdictional allocations are
provided by category. As a result of the settlement discussions, the Stipulating Parties
have agreed to the following adjustments to the Company's filed depreciation study and
proposed rates, as described in Paragraphs 9-29. These adjustments are sunmarized in
Table 2 below and indicate the estimated impact on depreciation expense.
(remainder of page intentionally left blank)
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Table I
lncrease in Annual Depreciation Expense
Based on Estimated Plant Balances as of December 3'1, 2013
$8.9 $4.5
($+.21 ($2.21
$4.6 $1.8
$160.8 $83.9
($72.6) ($45.3)
$88.3 $38.6
Table 2
Estimated Imoacts of Depreciation Rate Chanses
Adjustment Total Company Wvomins Utah Idaho
RMP Original Filing $r 60,8 r3,194 927,269,244 $70,463,058 $8,851,849
A Extend Life on Gadsby to 2032 (379, r 98)(60,244)(159,273')(21,405)
B Correct James River life to 2015 and
eliminate negative removal cost 626.168 99,481 263,008 35,346
C
Reduce net removal cost for CCCT gas
production units from $20lkW to
$15/kW and change interim retirement
curve for Account 343
(2,576,862)(409,382)(1,084,204)(145,878)
D Lower Wind Production net removal
cost from $9/kW to $7 /kw (32,122)(5,103)(13,492)(1,8 l3)
E Reduce Carbon net removal cost from
S330/kW to $l l7lkW (27,277,3s8)(4,333,625)(1r,457,239\(1,539,774)
F
Change Production interim retirement
curves: Account 3l I to 120-Rl 5;
Account 3 l2 to 68-5o; Account 3 I 4 to
57-S"
(6,393,360)( l,015,730)(2,685,386)(360,8e8)
G
Change Transmission interim
retirement curyes: Account 353 to 58-
Ss; Account 356 to 60-Rr and merge
Account 353.7 with Account 353
(2,546,s05)(404,570)(1,069,602)(143,747)
H
Distribution changes including merging
Distribution Account 362.7 with
Account 362 in Utah, Idaho and
Wvomins
(345,207)(8,654)(102,669)(4,621)
I Change net salvage percentages on
Minins Accounts 399.41 and399.43 (128,830)(22,821)(54,203)(8,083)
J
Expedite Amortization Period for
Production Excess Reserves to offset
Carbon Shortened Life
(s,790,21s)(9r9,906)(2,432,049)(326,851)
K Expedite Amortization Period for
Additional Production Excess Reserves (r,86r,s22)(295,745\(78 r,891)(105,081)
L Expedite Amortization Period for
Distribution Excess Reserve ( I 9,599,599)(887,03 l )(17,564,617)(1,147,951)
M
Calculate depreciation rates and
remaining lives using June 30, 2013
actual plant and reserve balances for all
plant without a designated terminal life
(1,906,995)(575,740)(955,628)(n6,192)
N Change General Plant lives for
Accounts 390,392.09 and 396.03 (2,121,718)(30e,162)(r,246,291)(224,779)
o Extend Klamath life to 2022 for
Wvomins & Idaho'(2,217,094\(3s2,23s)(r2s,152)
SETTLEMENT $88,262,777 $17,768,777 $31,r19,522 $4,614,970
31,2022.
I Utah already treats the Klamath-Associated assets as having a depreciable end life of December
10. The Stipulating Parties have agreed to extend the terminal life estimate for
the Gadsby Plant from December 31, 2022, to December 31, 2032. This adjustment
results in new lower depreciation rates, including the impact of adding estimated interim
retirements for the extended period. The stipulated depreciation rates also include
recognition of the excess reserve adjustment in the calculation. The stipulated
depreciation rates have been computed using an estimated terminal removal rate of
$40lkw. (Adjustment A)
I 1. The Stipulating Parties have agreed to shorten the terminal life on the
James River Plant from December 31,2016, to December 31, 2015, to correct an error in
the original Application, and to reduce net salvage estimated in the calculation from -l%o
to zero. These changes result in higher depreciation rates. (Adjustment B)
12. The Stipulating Parties agree that, for the Chehalis Plant, Currant Creek
Plant, Lake Side Plant, Hermiston Plant and Gadsby Peaker Plant (Units 4-6), the interim
retirement curve for Account 343 Prime Movers is changed from a 40-Rr to a 45-Rz.s.
There is no change in the proposed terminal removal dates for each of these plants from
those presented in the study. The Stipulating Parties agree to lower the terminal removal
cost for the CCCT gas units from the Company's proposed level of $20lkW to $15/kW.
(Adjustment C)
13. The Stipulating Parties agree that wind generation units will use a 30-year
terminal life. The terminal removal cost has been lowered from the Company's proposed
level of $9&W to $7/kW. (Adjustment D)
14. The Stipulating Parties agree that the Carbon Plant terminal net salvage
estimate is reduced from the proposed $330/kW to $117lkw and the stipulated
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depreciation rates are calculated based on the April 2015 retirement date. This terminal
net salvage estimate of $117lkW is used for calculating rates in this Stipulation and will
not be relied on in developing future removal cost estimates for other generation
facilities. Until actual results are available, updated current estimates will be provided as
needed in future filings, and to the extent the updated estimates differ from the $l l7lkw,
this issue can be reexamined in those filings. The amount ultimately deferred for the
Carbon Plant will be trued up to actual prudently incurred removal costs in accordance
with the procedures set forth in the stipulation in Case No. PAC-E-13-04 (the "GRC
Stipulation"). The remaining plant balances for Carbon Plant will be recovered through
2020 consistent with the GRC Stipulation. (Adjustrnent E)
15. The Stipulating Parties accept the Company's proposed method in the
study to use Iowa Curves to determine interim retirements for production facilities with
terminal lives. The proposed depreciation rates reflect adjustments to the retirement
curves on coal generation facilities in Account 3l I Structures and Improvements from
90-Rz to 120-Rr.s, Account 312 Boiler Plant Equipment from 60-Lr to 68-5o and Account
314 Turbogenerator Units from 55-Lr to 57-So. Reliance on the Company's Iowa Curve
method for settlement purposes shall not prevent parties from taking a different position
on this issue in future depreciation cases. (Adjustment F)
16. The Stipulating Parties agree to extend lives on transmission assets by: (1)
extending the curve for Account 353 Station Equipment from the proposed 57-So to a
58-56, (2) extending the curve for Account 356 Overhead Conductors and Devices from
60-R: to 63-R.:; and (3) merging Account 353.7 Supervisory Equipment with Account
353 Station Equipment resulting in a change to the life-curve combination and related net
salvage for those assets from the proposed 20-Rz with zero net salvage to 58-So with -5%
net salvage. All other lives and retirement curves are accepted as proposed by the
Company. Any transmission excess reserve balance will be amortized over the
remaining life of the assets rather than on an expedited basis. As part of calculating the
stipulated depreciation rates, the depreciation reserve has been redistributed within the
transmission function resulting in reduced rates on all accounts within the transmission
function and an overall reduction in the composite depreciation rates on those facilities.
(Adjustment G)
17. The Stipulating Parties agree to extend lives on distribution assets by
merging Account 362.7 Supervisory Equipment with Account 362 Substation Equipment,
and using the appropriate state-specific lives for Account 362 in Utah, Idaho and
Wyoming. (Adjustment H)
18. The Stipulating Parties agree to amortize net salvage on specific mining
accounts as follows: (1) stipulated depreciation rates for Utah mining assets have been
established using a terminal life as established in the filed study; (2) net salvage
percentages have been adjusted for Account 399.41 Surface Processing Equipment -
Preparation Plant from -7%o to -6%o and for Account 399.46 Longwall Equipment from
5%o to 7Yo; and (3) depreciation reserves have been reallocated within the mining
accounts. As a result, the stipulated depreciation rates are lower than the Company's
proposed rates on most of the mining accounts. (Adjustment I)
19. In order to offset the depreciation expense impacts of the shortened
remaining life at the Carbon Plant, which is calculated to be $34.7 million, the Stipulating
Parties agree to expedite the amortization of the excess depreciation reserve at the
Gadsby Plant and the Hunter Plant. The Stipulating Parties agree that the excess reserve
atthe Gadsby Plant and the Hunter Plant, calculated as of December 31, 2011, will be
returned on a straight line basis. The excess reserve of $21,073,503 associated with the
Gadsby Plant will be amortized based on 9 years and the excess reserve of $29,635,920
associated with the Hunter Plant will be amortized based on 5 years, resulting in an
annual amortization of $8.2 million. These amounts will be recorded as a separate item
by crediting depreciation expense and debiting the depreciation reserve. The new
depreciation rates for the Hunter Plant and Gadsby Plant have been recomputed
excluding the above identified amoturts of excess reserye. This recalculation of rates
produced an estimated increase in depreciation expense of $2.4 million. Coupled with
the $8.2 million excess reserve amount, this results in a net annual decrease in
depreciation expense of $5.8 million. The Stipulating Parties agree the excess reserve
amortization will occur annually starting January 1,2014, and will continue until the full
$34.7 million is returned or ending with the implementation of new rates resulting when
new rates from the next depreciation study are implemented. During the next
depreciation case, an assessment will be made as to the final disposition of any remaining
amount of the $34.7 million which has not been returned at that time. (Adjustment J)
20. The Stipulating Parties agree to amortize depreciation excess reserve for
two other steam generationplants with an excess reserve as of December 31,2011, the
Blundell Plant with an excess reserve of $7,852,016 and the Colstrip Plant with an excess
reserve of $22,930,383, as follows: (l) the annual amount is determined for each plant
with any excess reserve by dividing the excess reserve by l0; (2) the annual amortization
will occur beginning January 1,2014, until new depreciation rates resulting from the next
depreciation study are implemented; and (3) the stipulated depreciation rates are
determined by excluding the identified excess reserve in the calculation. This adjustment
is intended to offset the large steam plant increase in this Stipulation and does not set
precedent for any future depreciation study. (Adjustment K)
21. The Stipulating Parties agree to amortize depreciation excess reserve on
distribution plant for Utah, Idaho and Wyoming as follows: the annual amortization has
been determined for each state by identifying the excess reserve for each state
individually in the Company's filed study as of December 31, 2011, and then dividing the
excess reserve for Utah by 6.5 years, the excess reserve for Idaho by 13 years, and the
excess reserve for Wyoming by 15 years. The stipulated depreciation rates have been
determined by excluding the identified excess reserve amounts from the calculation. The
annual amortization will occur beginning January 1,2014, until new depreciation rates
from the next depreciation study are implemented. This adjustment is intended to offset
the large steam plant increase in this Stipulation and does not set precedent for any future
depreciation study. (Adjustment L)
22. The Stipulating Parties agree to stipulated depreciation rates calculated
using June 30, 2013, actual account balances within specific functions without terminal
lives, including transmission, Utah, Idaho and Wyoming distribution and Utah, Idaho and
Wyoming general plant. (Adjustment M)
23. The Stipulating Parties agree to adjust general plant lives to be consistent
with the Oregon Settlement. Utah, Idaho and Wyoming depreciation rates have been
adjusted using the life-curve combinations agreed to in Oregon. For Idaho, Account 390
Structures and Improvements, the life has been changed from 55& to 58-Rr, Account
10
392.09 Transportation Equipment-Trailers from 33-Lzto 34-Lz and Account 396.03 Light
Power Operated Equipment from 8-Rz to 9-Lg. Each state's estimated salvage remains as
provided in the Company's originally filed depreciation study. (Adjustment N)
24. For the depreciation rates for Wyoming and ldaho, the Stipulating Parties
agree to adjust Klamath-Accelerated depreciation to an end date of December 31, 2022,
consistent with the approved life in Utah. The life may be reassessed in the next
depreciation cases in Wyoming and ldaho. If Klamath-Accelerated facilities are retired
prior to December 31,2022, return of and on any remaining balance will continue after
retirement of the facilities as though it remained in service through December 31,2022,
and the Stipulating Parties agree not to challenge this recovery based on "used and
useful" arguments. (Adjustment O)
25. The Stipulating Parties agree to the Company's proposal to move the
balance of communication equipment to mass asset accounting with a consistent 24-year
life and a depreciation rate of 4.3%. The depreciation reserves will continue to be
maintained on a state basis which ensures no inadvertent jurisdictional transfer of
depreciation reserve benefits created from different depreciation rates historically being
used by each state.
26. The Stipulating Parties agree that the Company will provide a section in
the next depreciation study, for informational purposes only, listing the specific mining
assets, reserve balances, and respective lives owned by its Wyoming mining subsidiary.
27. A new depreciation study will be filed with the Idaho Public Utilities
Commission no later than five years from the date of the written order resolving the
issues in this Docket, or as otherwise ordered by the Commission. The Stipulating Parties
1l
agree the Company will maintain the right to file a new depreciation study sooner than
five years.
28. The Stipulating Parties agree the Company will implement a reporting
system to keep the Stipulating Parties and the Utah, Idaho and Wyoming Commissions
informed regarding any matters likely to have implications regarding potential stranded
costs of generating assets. The Company will propose a reporting method by no later than
December 31,2013.
29. The Stipulating Parties agree the Company will provide updated cost
estimates regarding Carbon Plant's terminal net salvage, including any new third-party
studies as part of the Company's next general rate cases in Idaho, Utah and Wyoming.
30. The Stipulating Parties agree to adhere to the depreciation study treatment
established according to paragraphs 10-14 of the Stipulation in Case PAC-E-13-04 (the
"GRC Stipulation") if approved by the Idaho Public Utilities Commission. The parties
are requesting that the stipulated depreciation rates from this study be effective on
January l, 2014 for purposes of financial reporting. Per the GRC Stipulation, the
Company will establish a regulatory asset that will track for further recovery or refund,
the aggregate net difference between the depreciation expense that would have been
booked beginning in2014 under the depreciation rates in effect as of the date of the GRC
Stipulation and the depreciation expense actually booked beginning in 2014 under the
depreciation rates approved by the Commission in this Case until the new depreciation
rates are reflected in customer rates. Recovery of the deferral shall be allocated to
customers on a proportionate basis, based on the cost of service relationships established
t2
in the next Idaho general rate case with rates proposed to be effective on or after January
1,2016, as modified by future cost of service studies in future rate cases.
31.
General Terms and Conditions
To the extent this Stipulation calls out specific rates, or includes any
discussion of rates for states other than Idaho, those discussions are for illustrative
purposes only, and the Stipulating Parties do not intend to bind other state commissions
or create precedent in other states.
32. The Parties agree that this Stipulation represents a compromise of the
positions of the Parties on all issues in this proceeding. Other than the above referenced
positions and any testimony or comments filed in support of the approval of this
Stipulation, ffid except to the extent necessary for a Party to explain before the
Commission its own statements and positions with respect to the Stipulation, all
negotiations relating to this Stipulation shall not be admissible as evidence in this or any
other proceeding regarding this subject matter.
33. The Parties submit this Stipulation to the Commission and recommend
approval in its entirety pursuant to IDAPA 31.01.01.274. The Parties request that the
Commission notice the filing of the Stipulation and establish a procedural schedule,
including public and technical hearings as necessary, for the review and consideration of
the Stipulation by the Commission. The Parties shall support this Stipulation before the
Commission, and no Party shall appeal any portion of this Stipulation or Order approving
the same. If this Stipulation is challenged by any person not a party to the Stipulation,
the Parties to this Stipulation reserve the right to cross-examine witnesses and put on such
case as they deem appropriate to respond fully to the issues presented, including the right
to raise issues that are incorporated in the settlement embodied in this Stipulation.
13
Notwithstanding this reservation of rights, the Parties to this Stipulation agree that they
will continue to support the Commission's adoption of the terms of this Stipulation.
34. In the event the Commission rejects or modifies any part or all of this
Stipulation, or imposes any additional material conditions on approval of this Stipulation,
each Party reserves the right, upon written notice to the Commission and the other Parties
to this proceeding, within 15 days of the date of such action by the Commission, to
withdraw from this Stipulation. In such case, no Party shall be bound or prejudiced by
the terms of this Stipulation, and each Party shall be entitled to seek reconsideration of
the Commission's order, file testimony as it chooses, cross-examine witnesses, and do all
other things necessary to put on such case as it deems appropriate.
35. The Parties agree that this Stipulation is in the public interest and that all
of its terms and conditions are fair, just and reasonable.
36. No Party shall be bound, benefited or prejudiced by any position asserted
in the negotiation of this Stipulation, except to the extent expressly stated herein, nor
shall this Stipulation be construed as a waiver of the rights of any Party unless such rights
are expressly waived herein. Execution of this Stipulation shall not be deemed to
constitute an acknowledgment by any Party of the validity or invalidity of any particular
method, theory or principle of regulation or cost recovery. No Party shall be deemed to
have agreed that any method, theory or principle of regulation or cost recovery employed
in arriving at this Stipulation is appropriate for resolving any issues in any other
proceeding in the future. No findings of fact or conclusions of law other than those stated
herein shall be deemed to be implicit in this Stipulation.
t4
37. The obligations of the Parties under this Stipulation are subject to the
Commission's approval of this Stipulation in accordance with its terms and conditions
and, ifjudicial review is sought, upon such approval being upheld on appeal by a court of
competent j urisdiction.
BASED ON THE FOREGOING, the Stipulating Parties request that the
Commission issue an Order approving this Stipulation and adopting the terms and
conditions of this Stipulation.
RESPECTFULLY SUBMITTED: August _,2013.
Mark C. Moench
Daniel E. Solander
Attorneys for Roclcy Mountain Power
Randall C. Budge
Attorneyfor Monsanto
ra tJ/(',,t/ t U --
ffi
Attorney for P aciJiCorp ldaho Industrial
Customers
Attorney for ldaho Publ ic Utilities
Conunission Staff
D. Neil Ptice
l5
37. The obligations of the Parties undsr this Stipulation are subjeot to the
Commission's apprroval of this Stipnluion in accordance with its tcrms and conditions
ard, ifjudicial revie$, is soWnq upon such approval bciug upheld on appeal by a court of
competeirt j urisdiction
BASED ON THE FORECTOING, the Stipulating Parties request that the
Commission issrre an Odor this Stipuldion and adopdng the tms aod
conditions of this Stipulation
RESPECTIII.TLLY SUBMTTED: Angrrst 12013.
Daniel E. Solmdcr
Attornqs for Rocky Motptah Pover
Randall C. Budge
Anorncyfor l,{onsanto
Ronald Williams
Attomey for PrcifiCorp ldalo It dusffial
Castonurs
D. Nail Price
Attorney for ldalo Public Utilities
Coruntsston &0ff
l5
37. The obligations of the Parties under this Stipulation ane subject to the
Cornmission's approval of this Stipulation in accordance with its tenns and conditions
an4 ifjudicial review is sougfut, upon such approval being upheld on appeal by a corut of
competent juridiction.
BASED ON TIIE FOREGOING, the Stipulating Parties r€quest that the
Cmunission issue an Ordcr approving this Stipulation and adopting the terrns and
conditions of this Stiplatioa.
RESPECTFTTLLY SUBMITTED: August _,2013.
Mark C, Moe,nch
Daniel E. Solander
Attorneysfor Ro&y Mwntain Power
Ronald lfr/illiams
Ataruey for P acitiC orp ldaho Infits trial
Customers
D. Neil Price
Attorney for ldaho Public Utilities
Commission Snf
Attorneyfor Monsanto
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